APPENDICES, VOLUME 1 OF 3 Environmental Impact Assessment West African Gas Pipeline 1-A 1-B 2A-1 2A-2 2-B 2-C 2-D 5-C 5-D 6-A 6-B 6-C 7-A 7-B June 2004 APPENDICES, VOLUME 1 OF 3 Environmental Impact Assessment West African Gas Pipeline 1-A 1-B 2A-1 2A-2 2-B 2-C 2-D 5-C 5-D 6-A 6-B 6-C 7-A 7-B Prepared for West African Pipeline Company June 2004 Disclosure Locations Venues at which the Environmental Impact Assessments, Appendices, and Resettlement Action Plans ­ and Other Documents Supporting the West African Gas Pipeline Project ­ have been Disclosed to the Public are as Follows: Country Venue Location UNITED STATES World Bank Offices Washington, DC MIGA Washington, DC NIGERIA WAGP EA Rep Office Lagos Lagos State Ministry of Environment Lagos Ogun State Ministry of Environment Abeokuta Liaison Office Federal Ministry of Environment Lagos Liaison Office Federal Ministry of Environment Abeokuta Badagry Local Government Office Badagry Ado Odo Ota Local Government Office Ado Odo Ota Ifo Local Government Office Ifo Ogun State Ministry of Lands and Housing Abeokuta Lagos State Lands Bureau Lagos Federal Ministry of Environment Abuja TOGO WAGP EA Rep Office Lomé Ministère de l´Environnement et des Ressources Forestières Lomé Gbetsogbe Palace Gbetsogbe Domocile du chef traditionnel Gbetsogbe Baguida Baguida Ministère de l'Énergie et des Ressources Hydrauliques Lomé Ministry of Land Affairs Lomé BENIN WAGP EA Rep Office Cotonou Documentation Center of the Ministry of Environment, of Cotonou Habitat and Urbanism (MEHU) Beninese Agency for Environment (ABE) Cotonou Documentation Center of Ministry of Mines, Energy and Cotonou Hydraulic (MMEH) Mayoralty of Abomey-Calavi Abomey-Calavi Mayoralty of Ouidah Ouidah Institute of Endogenous Development and Exchanges (IDEE) Ouidah Documentation Center of the University of Abomey-Calavi Abomey-Calavi GHANA WAGP EA Rep Office Tema EPA Library Accra Greater Accra Regional Coordinating Council Accra EPA Greater Accra Regional Office Amasaman Accra Metropolitan Assembly Accra Shama Ahanta East Metropolitan Assembly Sekondi EPA Central Regional Office Cape-Coast Central Regional Coordinating Council Cape-Coast Western Regional Coordinating Council Sekondi EPA Zonal Office Tema Tema Municipal Assembly Tema EPA Western Regional Office Sekondi Volta Regional Coordinating Council Ho EPA Volta Regional Office Ho Ghana EPA Accra Table of Contents Acronyms and Abbreviations Authors and Contributions Acknowledgements Executive Summary........................................................................................................-ES-1 Project Benefits...................................................................................................... ES-1 Project Description................................................................................................. ES-3 Pipeline and Facilities................................................................................ ES-3 Construction............................................................................................... ES-5 Alternatives............................................................................................................ ES-6 Baseline Information.............................................................................................. ES-7 Natural Environment.................................................................................. ES-7 Human Environment.................................................................................. ES-8 Impacts and Mitigation .......................................................................................... ES-9 Secondary and Cumulative Impacts......................................................... ES-12 Results...................................................................................................... ES-12 Management and Monitoring Plan....................................................................... ES-17 Summary and Conclusion.................................................................................... ES-17 Chapter 1 Introduction.......................................................................................................1-1 1.1 Project Overview ..........................................................................................1-1 1.2 Project Justification.......................................................................................1-4 1.2.1 Global Perspective ............................................................................1-6 1.2.2 Regional Perspective.........................................................................1-8 1.2.3 National and Local Perspective ......................................................1-12 1.2.4 Project Implementation...................................................................1-17 1.3 Legal and Policy Framework......................................................................1-18 1.3.1 Introduction.....................................................................................1-18 1.3.2 International Legislation.................................................................1-21 1.3.3 Relationship of Project to World Bank Safeguard Policies and OPIC Prohibitions....................................................................1-21 Chapter 2 Project Description...........................................................................................2-1 2.1 General Layout and Physical Description.....................................................2-1 2.2 Natural Gas Sources ("Upstream of WAGP")............................................2-10 2.3 Natural Gas Consumption ("Downstream of WAGP")..............................2-11 2.4 Design and Other Pre-construction Activities ............................................2-13 2.5 Facility Descriptions...................................................................................2-13 2.5.1 Alagbado "Tee" ..............................................................................2-13 2.5.2 Onshore Pipeline in Nigeria............................................................2-20 2.5.3 Lagos Beach Compressor Station...................................................2-34 2.5.4 Offshore Pipeline and Shore Crossings ..........................................2-46 2.5.5 R&M Stations and Onshore Pipeline Laterals................................2-56 2.5.6 Ancillary Works (Concrete Weight-Coating Plant)........................2-74 2.6 Waste from Operations ...............................................................................2-79 Table of Contents 2.7 Operational Control and Safety Systems....................................................2-80 2.8 Remaining Uncertainties.............................................................................2-80 Chapter 3 Project Alternatives..........................................................................................3-1 3.1 Introduction...................................................................................................3-1 3.2 Project Alternatives.......................................................................................3-2 3.2.1 World Bank Regional Energy Sector Project Alternatives...............3-2 3.2.2 EIA Project-Level Alternatives.........................................................3-3 3.3 World Bank Regional Energy Sector Alternatives Analysis........................3-4 3.4 EIA Project-Level Alternatives Analysis......................................................3-6 3.4.1 No-Project Alternative......................................................................3-9 3.4.2 The Proposed Project Alternative: Developing a Gas Pipeline and Piping Gas from Nigeria to Benin, Togo, and Ghana................3-9 3.4.3 Power Generation and Delivery Alternative: Developing Gas- Powered Electricity Generating Stations in Nigeria, and Transmitting the Electrical Power to Benin, Ghana, and Togo......3-10 3.4.4 Natural Gas Fuel Export Alternative: Converting the Gas to LNG or CNG and Exporting via Tanker or Road from Nigeria to Benin, Togo, and Ghana .................................................................3-11 3.4.5 Renewable Fuels Alternative: Meeting Electricity Generating Demands in Benin, Ghana, and Togo with Renewable Resources (Hydropower, Solar, Wind, Agrofuels) ..........................................3-12 3.4.6 Project-Level Alternatives Rankings..............................................3-13 3.5 Overall Pipeline Routing Options...............................................................3-18 3.5.1 Onshore Option...............................................................................3-20 3.5.2 Offshore Option ..............................................................................3-21 3.5.3 Onshore/Offshore Option ­ Selected Overall Routing Option.......3-21 3.5.4 Comparison and Selection of Proposed Option..............................3-22 3.6 Conclusion ..................................................................................................3-23 Chapter 4 Project Design Alternatives .............................................................................4-1 4.1 Introduction...................................................................................................4-1 4.2 Evaluation Criteria for Alternatives..............................................................4-1 4.3 Routing Options from Existing Gas Transmission Network to Coastal Compressor Station...................................................................................................4-8 4.3.1 Selection Criteria for Onshore Route from Alagbado "Tee" to Compressor Station Site................................................................................4-8 4.3.2 Onshore Routing Options within Nigeria .........................................4-8 4.3.3 Extending Pipeline Onshore for Gas Delivery to Benin.................4-12 4.4 Onshore Lateral and R&M Station Alternatives.........................................4-15 4.4.1 Onshore Lateral and R&M Station Alternatives in Benin..............4-15 4.4.2 Onshore Lateral Alternatives in Togo.............................................4-23 4.5 Design Considerations ................................................................................4-23 4.5.1 Sizing of Offshore Pipeline and Midline Compression Facilities ..4-23 4.5.2 Future Compression Facilities at Takoradi.....................................4-27 4.6 Construction................................................................................................4-27 4.6.1 Pipeline Construction Methods.......................................................4-27 June 2004 Regional Final Draft EIA Rev 1 ii Table of Contents 4.6.2 Equipment Transport to Compressor Station..................................4-29 4.6.3 Ancillary Facility Construction.......................................................4-30 4.7 Commissioning and Start-up.......................................................................4-32 4.7.1 Treatment of Hydrotest Water prior to Discharge..........................4-32 4.7.2 Discharge of Hydrotest Water ........................................................4-32 4.8 Project Operations.......................................................................................4-32 4.8.1 Liquid Storage Tanks......................................................................4-32 4.8.2 Waste Management.........................................................................4-32 4.8.3 Sanitary Waste Water Disposal ......................................................4-33 4.8.4 Stormwater Management................................................................4-33 4.8.5 Utilities............................................................................................4-33 Chapter 5 Existing Situation..............................................................................................5-1 5.1 Existing Environment and Resources...........................................................5-1 5.1.1 Onshore Environment.......................................................................5-5 5.1.2 Offshore Environment ....................................................................5-45 5.1.3 Ecologically Sensitive Areas ..........................................................5-66 5.2 Existing Socioeconomic Aspects................................................................5-66 5.2.1 Introduction on Data Sources and SIA Methodology.....................5-66 5.2.2 Background and Geographic Detail................................................5-68 5.2.3 Macroeconomic Overview..............................................................5-70 5.2.4 Population and Demographics........................................................5-71 5.2.5 Ethnic and Cultural Background.....................................................5-72 5.2.6 Historical and Cultural Resources ..................................................5-74 5.2.7 Infrastructure and Quality of Life...................................................5-75 5.2.8 Education ........................................................................................5-77 5.2.9 Land Tenure and Residential Ownership........................................5-78 5.2.10 Land and Water Use........................................................................5-79 5.2.11 Energy Consumption ......................................................................5-79 5.2.12 Microeconomic Situation................................................................5-80 5.3 Existing Public Health Situation.................................................................5-86 5.3.2 Health Indicators.............................................................................5-89 5.3.3 Food and Nutrition..........................................................................5-90 5.4 Existing Safety Situation.............................................................................5-90 5.4.1 Overview.........................................................................................5-90 5.4.2 Institutions Responsible for Health Care Delivery.........................5-91 5.4.3 Institutions Responsible for Fire Fighting ......................................5-92 5.4.4 Institutions Responsible for Disaster Management ........................5-94 5.5 Stakeholder Consultations ..........................................................................5-95 5.6 Regulatory Oversight..................................................................................5-96 Chapter 6 Impact Assessment............................................................................................6-1 6.1 Introduction...................................................................................................6-1 6.2 Project Activities and Affected Media..........................................................6-2 6.2.1 Project Activities...............................................................................6-2 6.2.2 Affected Media .................................................................................6-3 6.3 Comprehensive Impacts Identification/Screening........................................6-4 June 2004 Regional Final Draft EIA Rev 1 iii Table of Contents 6.4 Impact Severity Assessment Methodology...................................................6-4 6.4.1 Significance Criteria .........................................................................6-4 6.4.2 Likelihood Criteria............................................................................6-7 6.4.3 Severity Matrix and Conclusions......................................................6-8 6.4.4 Uncertainties .....................................................................................6-9 6.5 Beneficial Impacts ......................................................................................6-13 6.5.1 Beneficial Environmental Impacts..................................................6-14 6.5.2 Beneficial Socioeconomic Impacts.................................................6-15 6.5.3 Community Development / Health and Safety Benefits.................6-23 6.6 Potential Onshore Impacts..........................................................................6-26 6.6.1 Site Preparation and Construction ..................................................6-26 6.6.2 Commissioning and Start-up...........................................................6-56 6.6.3 Operations and Maintenance...........................................................6-57 6.6.4 Decommissioning and Abandonment.............................................6-59 6.7 Potential Offshore Impacts .........................................................................6-60 6.7.1 Site Preparation and Construction ..................................................6-60 6.7.2 Commissioning and Start-up...........................................................6-67 6.7.3 Operations and Maintenance...........................................................6-68 6.7.4 Decommissioning ...........................................................................6-69 6.8 Emergency and Upset Conditions...............................................................6-69 6.8.1 Controlled Gas Release...................................................................6-69 6.8.2 Uncontrolled Gas Release...............................................................6-70 6.8.3 Fire..................................................................................................6-74 6.8.4 Explosion ........................................................................................6-75 6.8.5 Offshore Fuel Spills........................................................................6-77 6.9 Secondary and Cumulative Impacts............................................................6-78 6.9.1 Environmental Secondary Impacts .................................................6-78 6.9.2 Socioeconomic Secondary Impacts ................................................6-81 6.9.3 Upstream and Downstream Development Impacts.........................6-81 6.9.4 Health and Safety Secondary Impacts ............................................6-93 6.9.5 Cumulative Impacts ........................................................................6-94 Chapter 7 Mitigation and Amelioration Measures..........................................................7-1 7.1 Introduction...................................................................................................7-1 7.2 Required General Mitigation Measures........................................................7-3 7.3 Required Specific Mitigation Measures........................................................7-3 7.4 Potential Mitigation Measures....................................................................7-24 7.4.1 Utilize Horizontal Directional Drilling for Wetland Crossings in Benin and Nigeria.......................................................................7-25 7.4.2 Utilize Horizontal Directional Drilling for Lagoon Crossing in Benin...........................................................................................7-27 7.4.3 Perform the Shore Crossing from the North Side of the Lagos Lagoon Thus Avoiding the Barrier Island ......................................7-28 7.4.4 Replacement of Topsoil at R&M Station Site after Decommissioning ...........................................................................7-29 7.4.5 Residual High Impacts from Onshore Construction in Nigeria......7-29 June 2004 Regional Final Draft EIA Rev 1 iv Table of Contents Chapter 8 Health, Safety, and Environmental Management Plan.................................8-1 8.1 Health, Safety, and Environmental Management System ............................8-3 8.1.1 Operational Controls.........................................................................8-5 8.1.2 Change Management ......................................................................8-11 8.1.3 Biological and Cultural Resource Chance Finds ............................8-13 8.2 Monitoring ..................................................................................................8-13 8.2.1 Performance/Implementation Monitoring ......................................8-13 8.2.2 Empirical Monitoring......................................................................8-14 8.2.3 Monitoring Oversight Responsibilities...........................................8-14 8.3 WAPCo Human Resources, Roles, Responsibilities, and Authority..........8-20 8.4 EPC Contractors..........................................................................................8-25 8.5 Government Regulatory Agencies..............................................................8-27 8.6 Financial Resources ....................................................................................8-28 8.7 Institutional Strengthening and Capacity Building.....................................8-29 8.8 Reporting.....................................................................................................8-30 8.9 Health, Safety, and Environment Management Plan Sections ...................8-31 8.9.1 Land Use.........................................................................................8-32 8.9.2 Topography, Geology, and Soils ....................................................8-36 8.9.3 Habitats, Biological Resources, Water Resources, and Hydrology 8-41 8.9.4 Air Quality ......................................................................................8-49 8.9.5 Solid, Liquid, and Hazardous Waste...............................................8-54 8.9.6 Cultural Conditions.........................................................................8-58 8.9.7 Socioeconomic Conditions .............................................................8-62 8.9.8 Public and Worker Health and Safety.............................................8-67 8.9.9 Emergency Preparedness and Response.........................................8-71 Chapter 9 Regional Conclusion.........................................................................................9-1 References Appendices Appendix 1-A: EIA Terms of Reference Appendix 1-B: Nigeria Applicable Local and International Regulations Appendix 2A-1: Air Pollution and Greenhouse Gas Emissions Analyses Appendix 2A-2: Natural Gas Sources and Transmission Infrastructure ("Upstream of WAGP") Appendix 2-B: WAGP Waste Estimates Appendix 2-C: Onshore-Offshore Commissioning Procedures and Specifications List Appendix 2-D: Potential Hazardous Materials Appendix 5-A: First Season EBS Appendix 5-B: Second Season EBS Appendix 5-C: SPI Study Report June 2004 Regional Final Draft EIA Rev 1 v Table of Contents Appendix 5-D: Stakeholder Consultations Appendix 6-A: Anchor Handling Appendix 6-B: Air Quality Impact Assessment Appendix 6-C: Qualitative Risk Assessments Appendix 7-A: Mitigation Measures for Baobab Tree in Tema Appendix 7-B: HIV/AIDS Policy Appendix 8-A: Project Execution Plan Chapter 15: HSE Plan Appendix 8-B: Operational Controls 8B1.0 Tier 1: WAGP HSE Policy Statement 8B2.0 Tier 2: WAGP HSE Management System Procedures 8B2.1 WAGP External Communications Procedures (To Be Developed) 8B2.2 HES Training 8B2.3 HES Audit Protocol 8B2.4 WAGP Management of Change 8B2.5 WAGP Compliance and Permitting Plan 8B2.5.1 WAGP Project Authorizations 8B2.5.2 WAGP Pipelines Hydrotesting Discharge Ecotoxicity Testing Plan (Rev A) 8B2.5.3 WAGP Waste Water Discharge Controls (To Be Developed) 8B2.5.4 WAGP Stormwater Management Plan 8B2.5.5 WAGP Air Emissions Management Procedure 8B2.5.6 WAGP Project Execution Plan Chapter 21: Operations Plan 8B2.6 WAGP Waste Management Plan 8B2.7 Emergency Response 8B2.7.1 WAGP Spill Prevention and Control Procedure 8B2.8 WAGP Habitat, Biological, Cultural Resource Management Procedures 8B 2.8.1 ROW Reinstatement Criteria 8B 2.8.2 Proposed Wetland PL Construction Methods Study 8B 2.8.3 WAGP Sea Turtle Nesting Protection Procedure 8B 2.8.4 WAGP Chance Finds and Archeological Salvage Procedure 8B 2.8.5 WAGP Anchor Handling 8B 2.8.6 WAGP Procedure for Preventing Salt Water Intrusion into Fresh Water Lagoons and Creeks 8B2.9 Incident Investigation Procedure 8B3.0 WAGP Land Acquisition and Right of Way (ROW) Management Procedure 8B3.1 WAGP Resettlement Action Plan 8B3.2 WAGP ROW Access Policy 8B4.0 Risk Management 8B4.1 Onshore Pipeline and Facilities Design Basis 8B4.2 WAGP Environmental Design Basis 8B4.3 WAGP Loss Prevention Design Basis 8B4.4 Onshore-Offshore Technical Specifications List 8B5.0 WAGP Contractor Management Procedures June 2004 Regional Final Draft EIA Rev 1 vi Table of Contents 8B5.1 Exhibit F: HSE Standards 8B5.2 Exhibit N: WAGP Security Plan 8B5.3 Exhibit K: Drugs Standard-IFT Appendix 8-C: Environmental and Social Advisory Panel Terms of Reference June 2004 Regional Final Draft EIA Rev 1 vii Appendix 1-A Preliminary Terms of Reference and Scoping Reports West African Gas Pipeline Preliminary Terms of Reference Regional, Benin, and Togo WEST AFRICAN GAS PIPELINE PRELIMINARY TERMS OF REFERENCE August, 2002 Table of Contents OBJECTIVES ..........................................................................................................................3 1.0 PROJECT SUMMARY....................................................................................................4 1.1 Project Proposal ................................................................................................................. 4 1.2 Project Background............................................................................................................ 4 1.3 Project Purpose & Need..................................................................................................... 5 1.4 EIA Legal Framework ....................................................................................................... 6 1.5 Agency Support and Harmonization.................................................................................. 8 2.0 PROJECT DESCRIPTION.............................................................................................8 2.1 Scope of EIA...................................................................................................................... 9 2.2 Natural Gas Sources ("Upstream" of WAGP)................................................................... 9 2.3 Natural Gas Consumption ("downstream" of WAGP)...................................................... 9 2.4 General Layout & Physical Description .......................................................................... 10 2.5 Permanent Ancillary Systems & Facilities ...................................................................... 11 2.6 Operational Control and Safety Systems......................................................................... 13 2.7 Project Implementation Description ................................................................................ 14 3.0 PROJECT ALTERNATIVES SUMMARY.................................................................19 4.0 STAKEHOLDER CONSULTATIONS........................................................................20 5.0 EXISTING SITUATION ...............................................................................................22 5.1 Existing Health Situation................................................................................................. 22 5.2 Existing Safety Situation.................................................................................................. 22 5.3 Description of the Environmental Status (Existing Environment and Resources).......... 23 5.4 Existing Socio-Economic Aspects................................................................................... 24 6.0 IMPACT ASSESSMENT...............................................................................................26 7.0 MITIGATING AND AMELIORATING MEASURES ..............................................27 8.0 DETAILED ALTERNATIVES ANALYSIS................................................................29 9.0 ENVIRONMENTAL MANAGEMENT PLAN CONSIDERATIONS......................30 9.1 Waste Management.......................................................................................................... 31 9.2 Air Emissions................................................................................................................... 31 9.3 Emergency Preparedness and Response.......................................................................... 31 9.4 HSE Management Systems.............................................................................................. 32 10.0 PROPOSED TERMS OF REFERENCE ...................................................................33 10.1 Project Submission......................................................................................................... 33 10.2 EIA Implementation and Document Preparation........................................................... 35 10.3 EIA Document Submissions and Agency Review........................................................ 36 10.4 Post EIA Approval......................................................................................................... 38 West African Preliminary Terms of Reference Gas Pipeline APPENDIX 1 AGREED DESIGN STANDARDS APPENDIX 2 FOCUS AREAS FOR ENVIRONMENTAL BASELINE ASSESSMENT APPENDIX 3 CURRENT EIA REFERENCE MATERIALS APPENDIX 4 PRELIMINARY IMPACT SUMMARIES APPENDIX 5 DETAILED LIST-POTENTIAL MITIGATION MEASURES ATTACHMENT 1 Regional Map-West African Gas Pipeline ATTACHMENT 2 Nigeria Onshore Pipeline Route Map-West African Gas Pipeline ATTACHMENT 3 Compression Facility Layout Drawing-West African Gas Pipeline ATTACHMENT 4 Regulating & Metering Station Layout Drawing-West African Gas Pipeline ATTACHMENT 5 Benin Onshore Delivery Site Map-West African Gas Pipeline ATTACHMENT 6 Togo Onshore Delivery Site Map-West African Gas Pipeline ATTACHMENT 7 Tema (Ghana) Onshore Delivery Site Map-West African Gas Pipeline ATTACHMENT 8 Takoradi (Ghana) Onshore Delivery Site Map-West African Gas Pipeline August, 2002 Page 2 West African Preliminary Terms of Reference Gas Pipeline OBJECTIVES The overall objectives of this proposed EIA Terms of Reference document include the following: · Provide a framework leading to an appropriate regional harmonization of EIA expectations, review and timely approval of the submitted EIA documents for Benin, Ghana, Nigeria and Togo. · Satisfy Initial Project Proposal requirements for the 4 countries prior to formal application or registration of the project. · Satisfy Preliminary Impact Assessment requirements for the 4 countries. · Assist the 4 countries in Project Screening deliberations, following formal EIA application or registration. · Assist the 4 countries in EIA Scoping deliberations, following formal EIA application or registration., focusing the EIA on significant potential impacts associated with pipeline construction and operation. · Provide a framework such that the WAGP Joint Venture (Commercial Group) and the 4 countries can consistently inform and educate stakeholders, understand stakeholder concerns and solicit input from relevant interest groups and those who may be directly impacted by the Project. · Assist the Commercial Group with project planning, design and decision making. More specifically, the objective of this EIA Scoping/Terms of Reference document is to establish a comprehensive EIA approach leading to the following documents contained in the final EIA Report: · Project background, purpose & need · Detailed project descriptions, including general layout & physical descriptions, ancillary systems & facilities, operational control systems, and project implementation descriptions · Detailed descriptions of the existing environmental and socio-economic situation that incorporates stakeholder consultations, literature reviews and field studies. · Health & safety, environmental and socio-economic impact assessments that include qualitative and quantitative risk assessments among other tools and techniques. · Proposed mitigating and ameliorating measures as applied to pipeline routing, design, construction and operations impacts. · Alternatives Analysis, including the No-Project Alternative · Environmental Management Plans that appropriately incorporate monitoring, mitigation and management systems that are consistent with identified impacts and that provide a contingency for unforeseen impacts August, 2002 Page 3 West African Preliminary Terms of Reference Gas Pipeline In preparing the final EIA reports and documents, the Commercial Group intends to use all of the deliverables described above to continuously modify and improve construction and operational plans to: · enhance the benefits of the project · reduce the potential for, or consequences of, negative impacts · satisfy the cost and schedule expectations of the 4 countries and project investors 1.0 PROJECT SUMMARY 1.1 Project Proposal Chevron West African Gas, Ltd. on behalf of the West African Gas Pipeline (WAGP) Joint Venture intends to construct a 12-30 inch (30.5-76.2 cm), 617 km (383 mile), onshore and offshore gas pipeline from Nigeria to Ghana. The WAGP consortium is a joint venture partnership between Chevron Nigeria Limited (CNL), Nigerian National Petroleum Corporation (NNPC), The Shell Petroleum Development Company (SPDC) of Nigeria Limited, Societe Beninoise de Gaz S.A. (SOBEGAZ), Societe Togolaise de Gaz S.A (SOTOGAZ) and the Volta River Authority (VRA). Members of the Commercial Group intend to form a project company to be known as WAPCo for constructing, maintaining and operating the pipeline. The Commercial Group is considering a proposed pipeline route that extends from a proposed connection to the existing Escravos-Lagos Pipeline (ELP) at the Alagbado "Tee" near Itoki, Nigeria. The ELP is owned by Nigerian National Petroleum Corporation (NNPC) and operated by the Nigerian Gas Company (NGC), a subsidiary of NNPC. From the ELP connection, the pipeline route would proceed to a Nigerian beach location on land and continue offshore from the Nigerian beach location across the territorial waters of Nigeria, Benin, Togo and Ghana, terminating at Takoradi, Ghana. Gas delivery laterals from the main pipeline route will extend into Cotonou (Benin), Lome (Togo) and other gas delivery target locations in Ghana (Tema and Takoradi). With regard to the delivery points, these locations should achieve an equilibrium between the concerns of their acceptance by coastal communities, safety and environmental vulnerability. Offshore pipeline installation is anticipated to be in 30-100 m (100-300 feet) water depths at an approximate distance of 15 km (9 miles) from shore. Targeted gas delivery points at Cotonou, Lome, Tema, and Takoradi are anticipated to extend onshore only to the degree necessary to install Regulating and Metering Stations (1-2 km (0.6-1.2 miles) onshore), although in the case of Benin, gas delivery points could extend 5-9 km (3.1- 5.6 miles) inland. 1.2 Project Background On 5th September, 1995 a Heads of Agreement (HOA) was signed by the Governments of The Republic of Benin, The Republic of Ghana, The Federal Republic of Nigeria, and The Republic August, 2002 Page 4 West African Preliminary Terms of Reference Gas Pipeline of Togo to construct a pipeline to transport natural gas from Nigeria to Ghana through Benin and Togo. The HOA also required that an independent feasibility study be conducted to determine the viability of the pipeline. The Engineering Feasibility Study was carried out by Pipeline Engineering GmbH, PLE, of Germany and documented in a report issued in March 1999. This study determined that a West African Gas Pipeline (WAGP) was technically and commercially feasible, pending additional evaluation. In May 1999, the Governments of the Republic of Benin, the Republic of Ghana, the Federal Republic of Nigeria, and the Republic of Togo (collectively referred to as "the Countries"), appointed Chevron Nigeria Limited, Ghana National Petroleum Corporation, Nigerian National Petroleum Corporation, The Shell Petroleum Development Company of Nigeria Limited, Société Béninoise de Gaz S.A., and Société Togolaise de Gaz S.A., (collectively referred to as the "Commercial Group") Project Developer for the WAGP. In May 2001, the Ghana National Petroleum Corporation advised the Commercial Group of a proposal to assign their interest in the WAGP to the Volta River Authority. This assignment is completed.. On 11th August 1999, the Countries further entered into a Definitional Phase Memorandum of Understanding ("MOU") with the Commercial Group on the development of the WAGP. In the MOU, the Countries confirmed the designation of the Commercial Group as the Project Developer and granted the Commercial Group an exclusive right to establish the West African Gas Pipeline Company ("WAPCo") which would enter into a Concession Agreement with the Countries, granting to WAPCo an exclusive franchise to build, own and operate the WAGP. Further to the MOU, the project has now moved into a Definitional Phase. This phase is intended to fully establish the commercial viability of the Pipeline and execute certain technical studies, including a detailed Environmental Impact Assessment. In Abuja, Nigeria, on 4th February, 2000, the Countries signed the Inter-Governmental Agreement ("IGA") with the intention of maintaining a uniformity of approach (or "harmonization") to give effect to the undertakings they intend to make to WAPCo through the Concession Agreement. The Countries and the Commercial Group are currently engaged in negotiating the Concession Agreement for the Pipeline. 1.3 Project Purpose & Need The 1995 HOA recognized that "there exists ample resources of natural gas in Nigeria to satisfy the energy requirements of West Africa (and the Countries of West Africa have stated their strong interest to use natural gas resources of Nigeria to satisfy their energy needs.)" The purpose of the West African Gas Pipeline, therefore, is to transport natural gas from Nigeria to consumers in the countries of Benin, Togo, and Ghana. August, 2002 Page 5 West African Preliminary Terms of Reference Gas Pipeline The benefits to all WAGP stakeholders include the following: 1.3.1 Environment · Reduce Flaring, resulting in lower green house gas emissions · Displacing certain liquid fuels with natural gas, also reducing green house gas emissions. Electrical power producers and industries with the capability to use natural gas are the primary consumers that could immediately benefit from the construction of the pipeline. Other public and private sectors could also use the natural gas provided by WAGP, but this scenario would require separate development of infrastructure, energy policies, etc. 1.3.2 Socio-Economic · More secure energy supply via power generation or direct gas use by industries and others · Enables sustainable development and regional integration · Local and regional technology growth/transfer In compliance with the legislative and regulatory provisions of the affected countries, the project will be subject to an environmental impact assessment. The WAGP EIA will further quantify the benefits described above and will identify additional benefits as appropriate. 1.4 EIA Legal Framework Note to Countries ­ for EIA Application/Registration, only the appropriate country will be referenced in terms of compliance with laws, regulations, etc. The Commercial Group proposes to carry out the Environmental Impact Assessment of the pipeline project consistent with the following: · Compliance with the laws, regulations, and guidelines of the Republic of Benin, the Republic of Ghana, the Federal Republic of Nigeria, and the Republic of Togo, particularly: Benin - Loi-Cadre Sur L'Environment en Republique du Benin (Loi no 98-030 du 12 fevrier 1999) - Petroleum Law Ghana - Environmental Protection Agency Act, 1994 (Act 490) (Ghana) - Environmental Assessment Regulations ­ L.I. 1652 (Ghana) - National and other relevant applicable international laws - Lands Commission - Water Resources Commission - Local Govt. Act - Factories & Shops Act August, 2002 Page 6 West African Preliminary Terms of Reference Gas Pipeline - Beaches Ordinance Nigeria - Environmental Impact Assessment Decree No.86 of 1992, (Nigeria) - Federal Environmental Protection Agency (now Federal Ministry of Environment) Act, Cap. 131, Laws of the Federal Republic of Nigeria, 1990 as amended. - The Nigeria Department of Petroleum Resources (DPR) Environmental Guidelines & Standards for the Petroleum Industry on Environmental Impact Assessment for Oil and Gas Production Facilities (onshore & offshore); - Oil Pipelines Act, Cap. 338, Laws of the Federal Republic of Nigeria, 1990 - Oil and Gas Pipelines Regulations, 1995 (Nigeria) - Appropriate State regulations (Lagos State EPA, Ogun State) - The international agreements and conventions to which the Federal Republic of Nigeria is a Party Togo - Code de L'Environment (Loi no 88-14 du 3 novembre 1988) en Republique du Togo and the texts for it's implementation - The Mining Code - The international agreements and conventions to which the Republic of Togo is a Party - International Environmental Impact Assessment standards and guidelines including, at a minimum, appropriate World Bank standards and prudent operator standards established by onshore and offshore industry organizations (U.S. API, EU OGP, etc.) - Petroleum Code · Commercial Group corporate policies regarding responsible social and ethical behavior, incorporation of safety, health and environmental protection measures and responsiveness to community issues and concerns. · International investment criteria, particularly in terms of socio-economic assessments, transparent and effective stakeholder engagement, appropriately designed environmental management and social reinvestment, and technology transfer/capacity building opportunities. · As appropriate, environmental and socio-economic guidelines, standards, conventions and treaties, established at the local, national and international levels including: - The Nigeria Department of Petroleum Resources (DPR) Environmental Guidelines & Standards for the Petroleum Industry on Environmental Impact Assessment for Oil and Gas Production Facilities (onshore & offshore); - Oil Pipelines Act, Cap. 338, Laws of the Federal Republic of Nigeria, 1990 - Oil and Gas Pipelines Regulations, 1995 (Nigeria) August, 2002 Page 7 West African Preliminary Terms of Reference Gas Pipeline Following this framework and incorporating the best practices and lessons learned from other pipeline projects enhances stakeholder perceptions of the Countries and Commercial Group and reduces the potential for delays due to investor, NGO or community concerns. 1.5 Agency Support and Harmonization As described above, one of the intents of this document is to provide a framework leading to an appropriate regional "harmonization" of EIA expectations, review and timely approval of EIA reports for Benin, Ghana, Nigeria and Togo. The Commercial Group has identified the following "harmonization" opportunities and hopes to work with the Countries on these opportunities following review of this Proposed Terms of Reference/Scoping document. · Collaboration with Environmental and other agencies regarding EIA implementation. See Section 10 below for preliminary proposals for collaboration. · Methodologies of Study and Assessment · Report(s) Format - Dual Language Translation - Balance of Local, Regional and International contexts · Environmental Management Plans - Impact Avoidance and/or Mitigation - Monitoring - HSE Management Systems · Common Trans-Boundary Issues (i.e. the Gulf of Guinea Marine Environment) · Agency Review 2.0 PROJECT DESCRIPTION The WAGP Commercial Group will supplement the Project Description provided below to include a complete description of the Proposed Alternative, including details regarding siting of facilities, pipeline routing, and the project schedule. The EIA will also document significant project information for construction and pipeline operations including, but not limited to the following: · Raw Material Inputs/Product Output · Storage and emission inventories · Traffic generation · Effluents & Discharges · Noise · Air Emissions and energy use from · Aesthetics construction and operations · Night time operations · Storage/disposal of hazardous goods · Dedicated land use associated with long · Waste and /or byproducts generated term facilities · Spoil materials from dredging August, 2002 Page 8 West African Preliminary Terms of Reference Gas Pipeline 2.1 Scope of EIA The WAGP EIA will focus on the project description and related impacts associated with building the pipeline and operations associated with the transportation of natural gas. Sources of transported natural gas ("Upstream" of WAGP) and end uses of natural gas ("Downstream" of WAGP) will also be described to provide a proper regional context to the WAGP EIA and as an input to an appropriate level of assessment beyond the immediate or isolated impacts of the WAGP project. As discussed in the Impacts Section below, however, since these secondary impacts are outside the immediate scope of the WAGP project, the EIA for the pipeline will only outline these ancillary impacts and provide a framework for future consideration. It is expected that in accordance with the applicable laws in each of the countries those projects will undergo or have already undergone separate detailed impact assessments. The Commercial Group intends to demonstrate by means of the EIA that variations in the volume of transported gas, up to the design capacity of 400 million standard cubic feet per day (MMSCFD- 11.3 million cubic meters per day-MMm3D), will not significantly change the identified impacts associated with the gas pipeline. 2.2 Natural Gas Sources ("Upstream" of WAGP) The "base case" Project Description for WAGP will detail the facilities and activities associated with a pipeline system designed to transport and deliver up to 400 MMSCFD (11.3 MMm3D) of natural gas. To date the commercial group has identified 250 MMSCFD (7.1 MMm3D) in gas volume available for transport from oil and gas operations in Nigeria. Most of this available natural gas will be "associated gas", i.e. produced with oil from the same source. As associated gas reserves are depleted the delivery requirements will be supplemented with "non-associated" gas. Oil and gas facilities associated with the 150 MMSCFD (7.1 MMm3D) described above are already in place or are anticipated to be installed before the end of WAGP construction. The sources for gas volumes above 150 MMSCFD (4.2 MMm3D) are not specifically known at this time and could involve existing or new oil and gas facilities. 2.3 Natural Gas Consumption ("downstream" of WAGP) As stated above in the Project Summary, electrical power producers and industries with the capability to use natural gas are the primary consumers that could immediately benefit from the construction of the pipeline. Negotiations have started with potential gas transportation customers, and to date the Takoradi Thermal Power Station has signed a letter of intent NGas to purchase natural gas. Additional gas transportation opportunities will be pursued until the gas supply is exhausted "upstream" of the pipeline or when the 400 MMSCFD (11.3 MMm3D) design capacity is reached. August, 2002 Page 9 West African Preliminary Terms of Reference Gas Pipeline When gas demand reaches the 400 MMSCFD (11.3 MMm3D) design capacity, gas delivery volumes are anticipated as follows, based on current market analyses: Outlet Anticipated Delivery Cotonou, Benin 10 MMSCF/d 0.3 MMm3D Lomé, Togo 80 MMSCF/d 2.3 MMm3D Tema, Ghana 230 MMSCF/d 5.3 MMm3D Takoradi, Ghana 120 MMSCF/d 3.4 MMm3D The scope of the WAGP EIA includes gas transportation of up to 400 MMSFD (11.3 MMm3D). Beyond a qualitative, cumulative impact assessment in this EIA, the Commercial Group intends to address any project expansion over 400 MMSFD (11.3 MMm3D) via a supplementary EIA or equivalent mechanism. 2.4 General Layout & Physical Description The WAGP Commercial Group intends to construct a 12-30 inch (30.5-76.2 cm), 617 km (383 mile), onshore and offshore gas pipeline from Nigeria to Ghana. From the Alagbado "Tee" near Itoki, Nigeria, estimated segment lengths of the proposed pipeline are as follows: Alagbado "T" to Lagos Beach 57 Km 35 mile 30 in (76 cm) pipeline Lagos Beach to Benin Border 50 Km 31 mile 16-22 in (40-56 cm) pipeline Benin Border to Cotonou 44 Km 27 mile " " " " Cotonou to Lome 98 Km 61 mile " " " " Lome to Tema 160 Km 99 mile " " " " Tema to Takoradi 208 Km 129 mile " " " " Total 617Km 383 mile Other tie in points to the ELP system and different Nigeria land routing scenarios are currently under consideration - See Maps ­ Attachments 1 (regional) and 2 (onshore Nigeria). NOTE: The Environmental Impact Assessment will only focus on new construction associated with the West African Gas Pipeline. The existing ELP in Nigeria, "upstream" of WAGP and gas delivery systems "downstream" of WAGP will only be described and referenced in terms of secondary, indirect or cumulative impacts. A gas transmission "compression facility" is anticipated at a to-be-proposed Nigeria beach location with an estimated 140 m by 185 m (460 ft. by 607 ft.) footprint - see Attachment 3. Primary and Back-up Control Centers will also be constructed with similar footprints with final locations to be determined. August, 2002 Page 10 West African Preliminary Terms of Reference Gas Pipeline Offshore Pipeline installation is anticipated to be in 30-100 m (98-328 feet) water depths at an approximate distance of 15 km (9 miles) from shore. Gas delivery points at Cotonou, Lome, Tema, and Takoradi will extend onshore via 12"-20" (30-50 cm) laterals only to the degree necessary to install Regulating and Metering Stations (1-2 km (0.6-1.2 miles) onshore). Estimated footprint for the Regulating and Metering Stations is 68m by 68 m (223 x 223 ft.), although larger 30-100 m (98-328 feet) may be pursued to accommodate future mid-line compression to ensure delivery of the 400 MMSCFD (11.3 MMm3D).­ see Attachment 4. When commercial conditions demand the installation of mid-line compression, more than likely in Lome, a parallel 12"-20" (30-50 cm) lateral pipeline would be installed from the mid-line compressor station. Siting alternatives for gas delivery points are currently being considered. Proposed locations will reflect a balance of community acceptance, safety, environmental sensitivity, access, cost, operational considerations and other issues. Maps and drawings showing site locations currently under review include the following: Cotonou, Benin Attachment 5 Lomé, Togo Attachment 6 Tema, Ghana Attachment 7 Takoradi, Ghana Attachment 8 Some of these drawings show additional potential infrastructure development in terms of gas distribution system routing. As discussed below under impact analysis, this infrastructure development is considered an indirect impact of WAGP that ultimately will be addressed by project proponents other than the Commercial Group as defined above. If gas demand exceeds the 400 MMSCFD (11.3 MMm3D) "base case design capacity", one or two gas delivery locations may be considered for additional mid-line compression facilities with footprints similar to the Nigeria beach compression facility described above. Specific locations for additional mid-line compression will be examined during Front End Engineering and Design (FEED). Pipeline "looping" where additional parallel pipelines are installed offshore may also be considered for gas demand greater than 400 MMSCFD (11.3 MMm3D). 2.5 Permanent Ancillary Systems & Facilities Gas specifications will be established for delivery of "dry gas" from ELP to WAGP such that liquid hydrocarbon, water, and impurities are minimized during WAGP gas transportation operations. A minimum heating value of the gas will also be included in the gas specification. Gas transported in the ELP itself may have varying characteristics regarding liquid hydrocarbon content, water percentage, etc, depending on who supplies gas to the ELP and the negotiated gas delivery specifications between NGC, WAGP and non-WAGP gas sellers, transporters or buyers. August, 2002 Page 11 West African Preliminary Terms of Reference Gas Pipeline An export terminal, proposed for installation at the ELP connection point is required for custody transfer purposes and to ensure conformance with the WAGP "dry gas" specification. Potential components of the export terminal include: · Gas cleaning/ scrubbing facilities as may be determined during detailed design · Equipment for metering of the gas flow through the station for accounting purposes or custody transfer · Equipment for gas quality measurement to ensure conformance with the "dry gas" specification · Safety and shut down equipment Responsibilities for the export terminal will be established between WAPCo and NNPC/NGC by means of an interconnection agreement, which is currently being negotiated between the parties. Liquid handling and management facilities will also be installed at the Nigeria Beach "compression facility" and gas delivery R&M stations as a contingency for gas production upsets from gas suppliers to WAGP. Other ancillary systems associated with the Pipeline include: X-likely to be installed, subject to additional design and analysis Ancillary System Nigeria Beach Delivery Point R&M Stations "Compression facility" Control Room/Facilities, X X including SCADA and MAIN FACILITY SCADA BACK UP FACILITY Communications Centre LOCATION TO BE DETERMINED Workshop, Offices, X Sanitary Facilities Gas Filtration, Cleaning, X X Scrubbing Equipment Compressor(s) X Mid Line Compressors Possible Subject to Gas Demand Fuel Gas Supply System X X (for compressors, gas IF GENERATOR IS heaters, Generators, and INSTALLED instrumentation, etc.) Air Compression X X for Instrumentation IF GAS IS NOT USED Gas Coolers X IF MID-LINE COMPRESSORS ARE INSTALLED Gas Heaters X Electrical Systems X X August, 2002 Page 12 West African Preliminary Terms of Reference Gas Pipeline Ancillary System Nigeria Beach Delivery Point R&M Stations "Compression facility" Emergency Shutdown, X X Flare/Vent, Fire & gas detection systems Gas Metering Run X(COULD BE REQUIRED X FOR CONTROL PURPOSES) Gas Quality Measurement X X (as required by trans. agreements) Pressure Regulating Run X X Odorization Optional Laboratory Facilities TO BE DETERMINED TO BE DETERMINED (if appropriate) No effluent discharge systems are anticipated for long term pipeline operations, other than possibly sanitary waste discharge from the Nigeria Beach "compression facility" and possibly metering stations if toilets are provided for personnel. Effluent discharge may occur during pipeline hydro-testing following construction. The principal components of the R&M station will be installed in two parallel equipment runs to provide 100% operational back-up. These components are described as follows: · Filters to separate coarse particles and condensate droplets. The filter elements are periodically replaced or may be washable. At set liquid levels in the filter vessel, volumes of liquid or condensate are automatically removed to a liquid collection facility. · Line-heaters to compensate for temperature drop caused by the pressure reduction of the gas (Joule Thompson Effect). · Regulating runs to reduce the high gas pressure of the upstream pipeline system to the lower pressure of the distribution line. · Meter runs to measure natural gas volume flow at the R & M station. The meter modules can be orifice, turbine, vortex, ultrasonic or other types. The meter shall be equipped with flow computers and must be approved or certified for custody transfer. · Safety and shutdown protective devices with appropriate backup 2.6 Operational Control and Safety Systems The control system will consist of three tiers: · Primary and backup Supervisory Control and Data Acquisition (SCADA) computers located in the central Dispatch Centre, most likely to be located at the Lagos Beach compressor station. The main function of the SCADA system will be operational interface to support operation of the complete pipeline network. The SCADA system will report pipeline system status to the central Dispatch and Backup Dispatch Centres, showing normal, abnormal or alarm conditions, so operators can monitor and take action August, 2002 Page 13 West African Preliminary Terms of Reference Gas Pipeline if needed. Remote terminal units (RTU) at each field compressor, metering or pigging station to receive and execute commands from the Dispatch and Backup Dispatch Centres. · Communications/control computers also located in the Dispatching and Backup Dispatching Centres for the purpose of communications and issuing control commands and initiating corrective actions. Operators will be able to view the entire system and ensure that the demand for product flow is met and that pipeline operating conditions are safe and optimised. Corrective actions can be initiated, either automatically or with operator over-ride, if necessary. The Backup Dispatch Centre will likely be located at Tema, although final decisions have not been made. · The remote stations will have a degree of local automation and control which will ensure safe and continuous operation of the station independent of whether the operator is present on site and whether he will take the required corrective action. Similarly, the individual stations will be able to operate safely with or without communications from the central Dispatch or Backup Dispatch Centres. · Local control of the facilities from the plant for at least maintenance purposes The SCADA system will utilise VSAT telecommunications technology for data transmission and voice communications as it provides the lowest total cost of ownership. The system will be designed to serve only the pipeline's telecommunications needs. VSAT facilities will be located at each pressure reduction, metering, and compressor station. Local and international communications system where available will also be utilized as a back up in minimum. 2.7 Project Implementation Description 2.7.1 Engineering The basic physical components of the pipeline include the following: · Steel pipeline materials Fabrication details to be determined during engineering & design. · A thin external coating layer of corrosion resistant material (example ­ fusion bond epoxy) Material application to the pipeline segments is anticipated to occur during fabrication, with details determined during engineering and design. · Application of weight coating to the pipeline (typically concrete based material) The purpose of weight coating is to reduce buoyancy impacts of an offshore pipeline or river/lagoon crossings. Options for weight coating operations will be assessed during engineering and design, including the possibility of local operations during construction. · Compressor stations with Compressors, generators and other equipment August, 2002 Page 14 West African Preliminary Terms of Reference Gas Pipeline · Metering system and stations The technical standards for the engineering, design and construction of the WAGP system are proposed to be based on the ANSI, ASME and API systems. The primary design code of reference will be the ANSI/ ASME B31.8 "Gas Transmission and Distribution Piping Systems" design code. The ANSI/ ASME B31.8 design code is the only general pipeline code that covers both onshore and offshore gas pipeline systems as well as metering and compressor stations. The B31.8 code is a well-established design code and is the predominant code of reference for WAGP installations. The components of the pipeline system will be designed and installed using API, ASME or ANSI design codes that are specific for the component. The major design codes are listed in Appendix 1. Front End Engineering Design (FEED) is scheduled to start following a Preliminary Commercial Evaluation, with a duration of approximately 9-12 months. This design work will be done in a to-be-determined location under the direction of Commercial Group personnel knowledgeable in project execution and gas pipeline technology. In this phase of the engineering, the design will be progressed through the development of · Process designs · Piping and Instrumentation Diagrams (P& ID's) · System safety systems designs · Project equipment specifications as described above · Preliminary Drawings · Design Reports · Other key Project documentation It is during this phase that the Commercial Group will proactively solicit stakeholder input and evaluate Best Available Technology (BAT) for incorporation into the designs, to ensure that the project minimizes health, safety and environmental (HSE) impacts. Several detailed reviews will commence during the engineering phase including: Conceptual & Early FEED Stage Late FEED and Detailed Design Stage · Concept Safety Evaluation Studies · PFD, P&ID, SAFE Chart Reviews · Qualitative Risk Assessment Review · Detailed HAZOPS, SAFOPS, IPF · Process Flow Diagram (PFD) Reviews Classification and/or HAZAN Reviews · Piping & Instrumentation Diagram (P&ID) · Quantitative Risk Assessment Reviews Review/Study · High Level HAZOP Review · Equipment Layout · High Level HAZID Review · Hazardous Area Classification · Project Specifications Review · Fire/Explosion Study August, 2002 Page 15 West African Preliminary Terms of Reference Gas Pipeline Conceptual & Early FEED Stage Late FEED and Detailed Design Stage · Project Safety Case/HSE Review · Fire Protection Analysis · Escape/Evacuation/Rescue Studies · Safety Review/Criticality Ranking of Major Equipment · Project Specification and Material Selection Review · Fabrication inspection at an offsite location During these and other reviews, it is anticipated that representatives from EIA and Permit/License Approval agencies in each of the countries will participate to provide relevant input and guidance on regulatory compliance issues and prudent protective measures. Development of the detailed information to support the EIA process will be a critical engineering and FEED activity to ensure timely EIA approval before the start of construction. An iterative process of stakeholder input, design adjustment, impact analysis and follow-up stakeholder consultations will be used to develop a detailed HSE plan during engineering and FEED and ultimately incorporated into the EIA Environmental Management Plan. A smooth transition will be made from FEED into detailed engineering while ensuring continuity is maintained. Detailed drawings, construction specifications, and the bulk of the procurement will be completed. Certain reviews (such as HAZOPS), which commenced during the preliminary and front end engineering phases, will be completed during this phase as the vendor engineering information is received at the project's office. 2.7.2 Other Pre Construction Activities In addition to design activities, the WAGP Commercial Group will conduct the following activities, integrated with the Environmental Impact Assessment processes and deliverables: · Routing and Siting Surveys Onshore surveys will be conducted to determine ELP tie-in, pipeline routing, Nigeria Beach "Compression facility" and R&M location options in Benin, Togo and Ghana. Offshore surveys will also be conducted to determine appropriate marine routing of the pipeline. Relatively non-invasive survey techniques will be utilized, although soil and seabed coring operations are anticipated for geo-technical evaluation in both the onshore and offshore environments. Limited vegetative clearing may also be required in conjunction w/ onshore surveying operations. The commercial group intends to coordinate External Affairs, Engineering and EIA consulting resources in implementing the surveys, to ensure that all issues and impacts associated with routing and siting are comprehensively and consistently identified. An August, 2002 Page 16 West African Preliminary Terms of Reference Gas Pipeline appropriately scoped HSE Management plan will be prepared prior to routing and survey work to minimize the impacts of these activities. · Estate Surveying and identification of real estate titles This activity will determine land tenure aspects of the project for the Nigerian onshore portion of the project and gas delivery points in Benin, Togo and Ghana. This determination will include assessments of land ownership and other existing rights associated with potential routing or siting options for the pipeline and facilities. · Land and Right of Way Acquisition Based on the estate surveying work, the Commercial Group will negotiate the acquisition of permanent land rights (for facilities such as the compressor and R & M stations) and rights of way (for the length of pipeline itself). Other temporary and permanent estate acquisitions (camps, staging areas, roads, etc.) will also be pursued either directly by the Commercial Group or through contractors or other 3rd parties, with appropriate compensation guidelines established. The Commercial Group has been advised that legal ownership and control of the offshore area which the pipeline will traverse is vested in each of the countries on the national government. Accordingly the Commercial Group expects that negotiations for rights of way over these offshore areas will be held with the governments concerned. Compensation for acquisition of permanent land rights and rights of way will be fair and in accordance with local and international best practice and the Commercial group will liaise closely with appropriate government, community and traditional leaders during negotiations to acquire land or rights of way. The Commercial Group does not anticipate significant, if any resettlement, associated with the construction of the pipeline. Resettlement plans will be developed, however, if necessary and included in the EIA submittal. The Commercial Group also recognizes that initial land and right of way target areas may not be suitable at the time of construction and that alternative routes should be considered as a contingency. Proposed and alternative sites and routes will be pursued in a manner consistent with the description above and all agreements will include terms and conditions such as "...acquisition contingent on EIA approval, Permit issuance,..." etc. · Material Procurement, Staging and Transportation The pipeline itself, along with compressors, vessels, meter runs and pressure regulating equipment will be fabricated at an offsite fabrication yard. The locations of the fabrication yard(s) and staging areas have not been determined at this time. · Additional safety and operational reviews with EIA and Permitting agencies including August, 2002 Page 17 West African Preliminary Terms of Reference Gas Pipeline - Critical Safety Equipment & Quality Assurance Inspection and Testing - Functional Testing of Corrosion & Fire Protection Equipment · Other activities like logistical planning, contracting for construction, cost minimization Studies and other EIA support activities. 2.7.3 Construction The project description for the WAGP EIA will focus on the following construction activities and tasks, projected to occur over a 2-year period, associated with civil, mechanical and electrical engineering implementation. · Onshore site clearance and preparation, including construction camps, access roads, river/lagoon crossings, the pipeline right-of-way, and ancillary facility sites (Nigeria Beach "Compression facility", R&M Stations in Benin, Togo and Ghana) · Temporary construction support operations including local camps for onshore construction personnel, staging areas for both onshore and offshore operations, transportation, and possibly weight coating operations · Pipeline trenching, particularly onshore and for near shore gas delivery laterals. Offshore trenching or directional drilling requirements, if any, to be determined during engineering and design. · Pipeline placement/stringing, cleaning and welding · Pipeline inspection and testing · Pipeline burial particularly onshore and for near shore gas delivery laterals. · Ancillary facility and equipment installation (R&M Stations and the Nigeria Beach "Compression facility") · Onshore soil management and right-of-way reinstatement All construction activities will be executed in accordance with a project specific HSE plan that will attempt to reduce impacts to the local community and environment. The details of this plan will be developed during FEED and continuously updated based on consultations with non- government stakeholders, EIA approval agencies, pipeline permitting/licensing agencies and local governments/communities. 2.7.4 Training, Commissioning, and Start-up Hiring of commissioning/start-up contractors and pipeline operations personnel will commence during the latter stages of construction. An extensive training program will be conducted following personnel hiring. All training will be completed in time to support the commissioning and start-up schedule. The extent of personnel and other needs for commissioning and start up will be determined during FEED. August, 2002 Page 18 West African Preliminary Terms of Reference Gas Pipeline EIA and Permitting Agency reviews and participation is expected to continue during this stage including: · Project Workshops · Training for Pre Commissioning and Commissioning · Joint Safety Inspections · Pre-Start Up Safety Audit · Review of specific operating permit requirements Commissioning will begin upon mechanical completion and `pre-commissioning' of the pipeline facilities. The pipeline will be cleaned, hydrotested, de-watered, dried through loading with air, inert gas or other non-flammable material. Compressors and other equipment will be lubricated, calibrated and tested as well as all control and telecommunications including the VSAT systems. Commissioning ends and start-up will begin when the pipeline is ready for introduction of hydrocarbons. 2.7.5 Pipeline Operations The pipeline operations component of the EIA Project Description will focus particularly on activities and facilities associated with health and safety of both the workers and nearby communities. Specific physical descriptions will include: · Ancillary Equipment, particularly monitoring and control systems. · Emergency shut down systems · Fire prevention, detection, and suppression · Corrosion control systems including cathodic protection and "pigging" operations · Support systems such as access roads, waste management (sanitary, non-hazardous and hazardous), and as appropriate, use of hazardous materials, including the nature, transportation, storage, intended use, treatment, and final disposition. 2.7.6 Decommissioning and Abandonment As described in the Concession Agreement, the Commercial Group intends to decommission and abandon the Pipeline consistent with prevailing accepted industry practices. Plans for facility decommissioning, abandonment and facility/ROW reinstatement will also be described in this section of the EIA. This section of the EIA will also address decommissioning of temporary construction facilities including staging, weight coating, camps. 3.0 PROJECT ALTERNATIVES SUMMARY August, 2002 Page 19 West African Preliminary Terms of Reference Gas Pipeline The WAGP EIA will contain two alternatives sections - an overall Project Alternatives Summary and a Detailed Alternatives Analysis (see below). In the Project Alternatives Summary, the No- Project Alternative will be explicitly assessed, drawing from the 1999 Feasibility Study and other sources. The Project Alternatives Summary will also address regional pipeline routing alternatives (example ­ all offshore, all onshore, etc.) and technological alternatives to a gas pipeline (example ­ gas to liquids technology, Compressed Natural gas (CNG) and Liquefied Natural Gas (LNG), etc.). The Project Alternatives Summary section will also review alternatives associated with significant impacts associated with the Proposed Alternative. In summarizing Project level alternatives, discussion will be focussed on the following: · Best Available/ Practicable Technologies · Feasibility · Regional health, safety, environmental and/or socio-economic benefits · Local and regional suitability, including stakeholder acceptance · Institutional requirements · Costs (capital and operating) Other more specific alternative scenarios will be provided in the Detailed Alternatives Analysis section as described below: 4.0 STAKEHOLDER CONSULTATIONS The legislative provisions of the various countries emphasize the participation of the parties having a stake in the environmental impact assessment. As described throughout this document, informal meetings, focus group discussions and public forums will be continuously utilized in the preparation of the EIA to: · Inform and educate stakeholders on all aspects of the project, including the Proposed Alternative and other alternatives considered · Gather relevant information and data · understand critical stakeholder issues and concerns · Make appropriate adjustments to design, construction, operational and environmental management plans · Communicate design, construction , operational and environmental management plan adjustments · elicit support for the project Geographic and social linking of issues will be part of the public involvement mechanisms that will allow WAPCo to concurrently manage project impacts locally and regionally across the four countries. These consultations shall include local and/or indigenous communities and businesses as well as regional, national and international non-governmental organizations and entities that may be significantly impacted by the construction or operation of the Pipeline. The Commercial August, 2002 Page 20 West African Preliminary Terms of Reference Gas Pipeline Group shall document the consultations and transmit a summary of these consultations as part of the EIA Report documentation. As a means to facilitate stakeholder consultations, a WAGP External Affairs Plan will identify and assist in managing community concerns and impacts associated with every aspect of the project. It seeks to respond to the organizational, economic, socio-cultural, technical, health, safety, environmental, political as well as international aspects of the project. This plan will be dynamic and will be localized for each of the four countries. It will also reflect the concerns and interests of the international community and will be regularly evaluated and amended to suit the dynamic nature of the project and its setting. Specific components of the External Affairs Plan as it relates to the EIA study include the following: · Workshop for Public Affairs Staff of Relevant Government and Regulatory bodies · Seminars for regulatory agencies, customs, immigration related government agencies to facilitate corridor surveys · Forums for traditional authorities and communities at large · Seminars for local authorities · Workshops for community education staffs · NGO's and Environmental journalist seminars · Seminars for registered fishing groups, companies, consultants, individuals and organizations involved in research in the fishing industry · Seminars for academia · Durbar for chief fishermen and the associated communities · Mass education in all fishing communities · Orientations for project contractors · Pipeline route tours Key issues that have already been identified and incorporated into the External Affairs Plan include: · Limited scientific and socio-economic baseline data on project communities · Community expectations · Peoples attitude towards, perception of, and knowledge about project · Socio-cultural intrusion in terms of physical contact with WAGP personnel, pressure to conform to different standards, and changes to cultural values · Cultural sensitivities · Environmental concerns Sensitive marine ecosystems Sensitive areas of bio-diversity · Health and Safety concerns for communities and workers · EIA requirements, timing and credibility August, 2002 Page 21 West African Preliminary Terms of Reference Gas Pipeline · Land tenure and appropriate compensation for project impacts · Consultation/capacity building · Historical performance and perceptions of the Commercial Group · Fishing concerns · Respect for traditional authorities · Interference with economic activity · Security and safety of navigation (accidents) · Impact of project personnel and/or contractors · The need for independent monitoring 5.0 EXISTING SITUATION 5.1 Existing Health Situation Studies to determine the existing health situation along the pipeline route will be conducted with particular emphasis on areas of poor health or sanitary conditions. Through our contracting processes and negotiations with contractors, the Commercial Group will also consider opportunities to establish health baselines and "fitness for duty" criteria for workers in the region. Studies will also focus on health services options in the region such that immediate care can be provided to those suffering health impacts from project activities. The Commercial Group recognizes that illness and disease could be an impact from project activities, particularly during construction. Baseline health considerations that are already under review include: · Illness and disease inherent to the region (example malaria) · Illness and disease associated with sanitary conditions (example dysentery) · Socially transmitted disease such as AIDS, venereal disease etc. due to the interactions of workers and the communities. 5.2 Existing Safety Situation The routing and siting survey work will provide baseline information in terms of geographic and site-specific safety issues. Project Security issues will also be identified in terms of the potential for community unrest, civil disobedience, theft, robbery, etc. Worker Safety issues will also be assessed and managed by the Commercial Group through the development of a specific Project Safety Management Plan (PSMP). The PSMP will be a stand alone plan developed under the umbrella of an HSE Management System. The specific PSMP will incorporate existing policies and procedures of the Commercial Group. Key elements of the PSMP will include: · Management Leadership & Commitment · HSE Objectives August, 2002 Page 22 West African Preliminary Terms of Reference Gas Pipeline · Safety Contracting Processes - Assessment of Contractor Safety Performance and Programs - Job Safety Analysis - Safety Orientation & Training - Integration of Contractors' Safety Management Plan into PSMP · HSE Roles and Responsibilities · Policy Development - Stop Work for Safety Policy - Alcohol & Substance Abuse Policies - Fitness for Duty Policies · Consistent Procedures & Practices - Emergency Response Plan - Community Awareness/Outreach Plan - Incident Investigation & Reporting - Field Safety Audits - Medical Treatment Procedures Existing community safety issues will also be assessed including knowledge of construction, natural gas and pipeline operations. The capability of the communities to manage safety related events effectively will also be reviewed. As discussed above, design standards and engineering best practices will be employed in the development of WAGP, and the Country's safety review and permitting processes will ensure that the communities are adequately protected. 5.3 Description of the Environmental Status (Existing Environment and Resources) The status of the environment and of its various components prior to the project will be set forth, where various sensitive points and constraints will identified and addressed. Appendix 2 provides a matrix of project locations and focus areas of the environmental baseline studies including: Biological Environment Physical Environment · Flora/Fauna · Land/Physical Characteristics · Areas of Ecological interest, including · Water Quality and surface water rare or endangered species, sensitive hydrology habitats · Air shed characteristics · commercially important species and · Land Capabilities and usage fishing zones · Potential Environmental Contaminants · Oceanographic Parameters · Rural & Regional Infrastructure along the pipeline route · Climatic and Weather Conditions August, 2002 Page 23 West African Preliminary Terms of Reference Gas Pipeline This matrix attempts to particularly identify areas of higher impact due to pipeline construction or operations. Environmental baseline studies will also identify, as much as possible, any existing environmental contamination. The Commercial Group intends to compile and analyze baseline data generally through literature review and empirical field analyses, using Geographic Information Systems (GIS) as a means to manage and communicate data. Appropriate literature research and field studies will be done for the Proposed Alternative and other scenarios, particularly in terms routing and siting of the pipeline and related facilities. The Commercial Group will rely on stakeholder consultations, academic efforts and public information (for example prior EIA efforts) in the literature review. Appendix 3 is a list of marine and near shore reference materials already collected for the WAGP EIA. Prior to field data collection, the Commercial Group will consult with the Ministries and Agencies of the four countries on the fundamental study approach including sampling/analysis methodologies, data quality expectations, etc. The Commercial Group recognizes that wet and dry season investigations are appropriate to establish environmental baseline conditions. The initial draft EIA documents will include baseline results from the initial season of investigation. Information from the second season of investigation will be included in a subsequent EIA submittal or as a monitoring component of an approved Environmental Management Plan, following input received from the Countries. The Commercial Group intends to use the information associated with the existing environmental situation in a number of ways including: · identifying potential areas of high impact due to pipeline construction or operations, as described above · as material for WAGP personnel training and for stakeholder education and reference during construction and operations · as inputs to qualitative and quantitative risk assessments (example air dispersion modeling, potential receptors from catastrophic gas releases or fire hazards, etc.) 5.4 Existing Socio-Economic Aspects The Commercial Group recognizes that socio-economic studies of existing conditions are critical to gaining public acceptance of the WAGP Project and minimizing project impacts and disruptions to communities and other stakeholders. Also, as described in the EIA Legal Framework section above, funding from international investors requires submission of socio- economic studies, appropriate compensation and mitigation plans and social reinvestment objectives in addition to environmental impact assessments. The Commercial Group intends to satisfy these requirements through the following efforts: August, 2002 Page 24 West African Preliminary Terms of Reference Gas Pipeline · Stakeholder Consultations as described above · Knowledge, Attitudes, Acceptance and Perception (KAAP) studies · Existing Socio-Economic Characteristics of the areas impacted by the project · The current Local, National and Regional Economic Situation as it relates to WAGP The KAAP study will be conducted in Ghana, Togo, Benin and Nigeria to help in the implementation of the Pipeline Project. Specifically, the study will ascertain how much people in the region know about the project, what it intends to do and its impact on human livelihood. Given the knowledge of the people about the uses of gas and how it will be transported and distributed in the Project, the study will determine the attitudes and perceptions of people towards the project. The study will involve focus group discussions of the population, and the administration of a questionnaire through an in depth interview of a sample of people. One common questionnaire and survey guidelines will be designed and used in all 4 countries. A sample of individuals will be identified in communities along the proposed gas pipeline and those outside the pipeline. The study will be conducted by knowledgeable resource persons based in each country. Other socio-economic studies will focus on population density, infrastructure and life pattern studies for the land components of the pipeline. This data will be compiled with existing and potential employment opportunities, permanent and temporary housing situations and the social interactions of impacted communities to understand how the project might impact local communities and stakeholders. Similar studies will be conducted for fishing communities along the offshore route and near the gas delivery points in Benin, Togo and Ghana. The existing cultural setting of project areas will be appropriately assessed in terms of architecture, cultural events, native/tribal lands, villages, schools, hospitals, homes for the aged, country parks, agricultural areas, fishing camps, hunting reserves, and areas of archaeological, paleological and religious significance. Another significant area of interest to indigenous people and communities will be any real or perceived impacts to water usage including domestic, industrial, recreational, transportation, agricultural, and fisheries. As stated above, one of the primary socio-economic benefits of WAGP is the facilitation of regional economic integration and growth through the delivery of a reliable, cost-competitive, and cleaner burning energy source. Baseline socio-economic assessments will be conducted to quantify this expected benefit, including: · Existing economic activities i.e. local industries, cottage industries, etc. · Local business that could provide services to the project · Potential industries that could be developed and the possible constraints in developing these industries · Potential employment opportunities to be generated by the project and the possible constraints in developing these opportunities? August, 2002 Page 25 West African Preliminary Terms of Reference Gas Pipeline · Public expectations in terms of technology transfer, capacity building or social reinvestment? · "Compensation" expectations of the communities · What types of mechanisms would the communities like to see in terms of direct benefit, compensation, etc. · Tax income to the states, direct and indirect · People's perceptions of energy pricing, infrastructure situation, etc. · People's perceptions of Government Energy Policies and Growth Policies · Current Fuel Usage · Perceptions of how reliable energy sources will impact growth, policies, etc. · Perceptions of changing from wood based fuels to electricity and/or natural gas? · Growth projections in terms of GDP and other indicators · Other possible multiplier effects of the project in terms of local and regional economic development and cumulative impacts including possible constraints 6.0 IMPACT ASSESSMENT Generally, the EIA will address impacts in a comprehensive manner, determining whether the impacts are considered: Positive/beneficial or Negative/adverse, Primary/direct or Secondary/indirect, Short Term or Long Term, Reversible or Irreversible. The impacts assessment will incorporate an appropriate level of assessment beyond the immediate or isolated impacts of the WAGP project to put the project in the context of regional development and regional impacts. These impacts will be combined with the project impacts above to determine the cumulative impacts related to the WAGP Project. As an example, natural gas production from Nigeria and gas consumption in Benin, Togo and Ghana are potential areas of assessment ancillary to the West African Gas Pipeline. However, since these impacts are outside the immediate scope of the WAGP project, the EIA for the pipeline will only outline these ancillary impacts. It is expected that in accordance with the applicable laws in each of the countries those projects will undergo or have already undergone separate detailed impact assessments. More specifically, and in the context of the existing health, safety and environmental and socio- economic aspects of the project, the impact assessment will identify significant impacts associated with: August, 2002 Page 26 West African Preliminary Terms of Reference Gas Pipeline · Future land usage; · Health and safety impacts to both local · Impacts to existing features; communities and WAGP personnel · Historic land use; · Conditions and processes in the natural · Ways of life; environment; · Energy supply/demand; · Significant air quality and standards · Local, National and Regional violations; Economic Benefit Assessments · Ground and surface water quality/ quantity · WAGP Social Reinvestment changes; opportunities as appropriate for · Water uses; community and regional impacts · Encroachment issues (wetlands, coastal · Significant noise zones, fish habitat, wildlife habitat, wild and · Populations scenic rivers, areas of biodiversity) · Changes associated with imported pests, disease vectors, fish migration routes, and fish nursery areas. Screening criteria, including probability, magnitude, prevalence, risks, importance, and effectiveness of mitigation measures, will be used to assess the significance of project impacts. This screening will cover all activity phases of the project including site investigation/ preparation, construction, construction support, transportation, raw materials supply, operations and maintenance, future and related activities, and ultimately decommissioning of the facility. Expected areas of impact include the physical, chemical, biological, aesthetic, and socio- economic aspects of WAGP in addition to understanding the relationships between activities and areas. Methodology and approach are critical to developing impact assessments that are comprehensive and credible to stakeholders. As discussed above, specific measurable indicators of impact probability, magnitude and significance will be developed. In developing these indicators, the project will provide stakeholders a context and framework that includes the extent and quality of available data and sources of information, along with the assumptions, uncertainties and degrees of confidence associated with both explicit and risk based assessments. Appendix 4A and 4B outline the potential positive and negative aspects of the West African Gas Pipeline project in terms of health, safety, environmental and socio-economic impacts. As described above, the Commercial Group intends to quantify the probability and severity of these and other identified impacts during the course of the EIA. 7.0 MITIGATING AND AMELIORATING MEASURES This section of the EIA will focus on enhancing the positive impacts of the project and avoiding, reducing or mitigating negative impacts of WAGP. Potential benefit enhancement opportunities include: August, 2002 Page 27 West African Preliminary Terms of Reference Gas Pipeline X-Potential Application to WAGP Mitigation Measure Pre- Construction Construction Operations Decommissioning Additional commercial commitments to transport natural gas, further X reducing green house gas emissions Technology transfer X X X and/or capacity building Social reinvestment X X X Potential avoidance or mitigation measures could include: X-Potential Application to WAGP Mitigation Measure Pre- Construction Construction Operations Decommissioning Project location/siting X X Design adjustments and/or X X new technology application Early warning and X X emergency shut down controls Construction adjustments X X Schedule adjustments X X Environmental and socio- X X X economic education and orientation Notices and/or barriers X X X placed at strategic locations along the onshore pipeline route warning the public Notifications to local and X international cartographic, survey and marine authorities to update and publish nautical charts and topographic maps. For residual or X X unavoidable impacts, August, 2002 Page 28 West African Preliminary Terms of Reference Gas Pipeline Mitigation Measure Pre- Construction Construction Operations Decommissioning rehabilitation of impaired features or some type of offsite compensation or enhancement of similar resources. Erosion and sediment X X X X control Vegetation control X X HSE Management X X X Systems including · Compliance Assurance · Safe Operations · Pollution Prevention · Emergency Preparedness and Response In developing mitigation measures and the subsequent Environmental Management Plan, the Commercial Group recognizes that certain adjustments to mitigation measures may be needed due to · changes from baseline assessments · new information · ineffectiveness of mitigation measures As appropriate, and in consultation with the Countries and other stakeholders, the Commercial Group will modify proposed mitigation measures and other elements of the Environmental Management Plan. Appendix 5 provides a more detailed list of mitigation measures that the Commercial Group will consider in conducting the EIA and in developing it's project execution plans. 8.0 DETAILED ALTERNATIVES ANALYSIS The Detailed Alternatives Analysis section of the EIA will provide a bridge between the project impacts and the proposed mitigation measures and ultimately the Environmental Management Plan. It will be more specific in nature including explicit and risk based assessments of: · Best Available/ Practicable Technologies · Feasibility · Associated health/safety, environmental and/or socio-economic benefits · Monitoring requirements · Local and regional suitability, including stakeholder acceptance · Institutional requirements August, 2002 Page 29 West African Preliminary Terms of Reference Gas Pipeline · Training requirements · Costs (capital and operating) Specific alternative scenarios will include: · Site Selection and Routing · Design Considerations · Raw material sources · Project Implementation including site preparation, construction, construction support, personnel and material requirements, and commissioning/start-up · Pipeline Operations · Mitigation measures to avoid project impacts and measures associated with residual or unavoidable impacts Continuous stakeholder consultations will provide a critical input to the alternatives analysis, in terms of idea/scenario generation and acceptance of the Proposed Alternative. 9.0 ENVIRONMENTAL MANAGEMENT PLAN CONSIDERATIONS Make this a bullet under Proposed Terms of Reference for Ghana The Environmental Management Plan (EMP) will be developed and used as a tool in the construction and operation of WAGP to minimize and mitigate significant negative impacts from the project. Components of the Environmental Management Plan include monitoring, documentation, evaluation, prediction, warning, prevention, control and reduction of impacts identified in the EIA. The Environmental Management Plan shall also include activities intended to enhance the positive environmental, safety and socio-economic aspects of the Pipeline. The Environmental Management Plan shall provide a means to ensure that legal air and water standards are complied with and that proper waste minimization and waste management processes are implemented. Ecological mitigation measures shall be included in the Environmental Management Plan addressing impacts to vegetation, wildlife, marine ecosystems and bio-diversity. The Environmental Management Plan will provide a means to assess the effectiveness of these mitigation measures. Socio-economic mitigation measures will be identified in the Environmental Management Plan to reduce negative impacts to communities and to enhance the positive benefits of the project to the communities, the States and the region. Particularly for surveillance and monitoring, specific measurement parameters will be recommended, including measurement methods, locations, frequency and action thresholds. Appropriate thresholds will include those that forewarn or immediately warn of unfavorable project impacts, but that also trigger project execution controls to eliminate or minimize the level of impact or that lead to governmental reporting/ enforcement. August, 2002 Page 30 West African Preliminary Terms of Reference Gas Pipeline The following specific components will be included in the EMP. · Evolution of the erosion phenomena and reestablishment of natural drainage before and after pipeline layout and burial · Restoration of vegetal cover and productivity of agricultural zones put back in exploitation after the work · Efficiency of actions taken to preserve sensitive areas · Follow-up of impact on marine biodiversity and fishing and maritime transportation activities · ROW Surveilance and other monitoring along the pipeline, particularly for any socio- economic encroachment · Notices at strategic locations along the pipeline (warnings, safety, etc.) · Other appropriate mitigation measures as identified in Section 7 and Appendix 5. 9.1 Waste Management The general waste management philosophy adopted by the project to handle wastes can be summarized as; · Utilize processes that inherently generate less waste streams · Modify process as required to minimize waste quantities generated from source · Maximize recycle or re-use of waste streams after appropriate treatment · Utilize safe storage and handling procedures for hazardous waste streams · Effective monitoring and control of disposal units, with early warning systems · Inventory control, audit and post project evaluation of regulatory trend to ensure continued compliance 9.2 Air Emissions During the front end engineering phase of the WAGP project, all air emissions, major & minor, resulting from continuous, intermittent or upset conditions of any of the pipeline equipment will be characterized. Each stream will be evaluated to ensure that there are no components which violate 'Air pollutant emission limits' standards. 9.3 Emergency Prevention, Preparedness and Response The Commercial Group intends to develop an Emergency Preparedness and Response Plan for inclusion in the WAGP EIA and in line with permit requirements for each of the countries. The following steps are anticipated in the development of this plan; · Assessment of hazards and risks of an unplanned incident to both the communities and WAGP personnel; · Plan Development for managing those hazards and risks; August, 2002 Page 31 West African Preliminary Terms of Reference Gas Pipeline · Communication of relevant information to employees, contractors, appropriate agencies and the public; · Barriers etc. to minimize exposure · Conducting emergency response exercises independently and in co-ordination with community support organisations; · Responding immediately and appropriately to incidents, providing the necessary financial, technical and personnel resources to effectively respond. 9.4 Energy and Resource Conservation The Commercial group will, to the extent possible, conserve and protect natural resources. As most of the negative impacts are likely to occur during construction, the Commercial Group will pay particular attention to ecological, water, and other natural resource issues during routing, siting and execution planning. Water resources are the most likely resource that could be affected during pipeline operations. This EIA and the development of a natural resources inventory will identify those natural resources most at risk. This EIA and subsequent monitoring and analyses during the construction and operational phase will be used to continuously identify potential pathways of exposure and potential or actual receptors affected by releases and emissions. Pathways may include air dispersion and contamination of surface water or groundwater. Receptors can be local communities and sensitive ecological habitats. The Commercial Group will also a natural resource damage assessment plan in the unlikely event of an unplanned, negative event, so that the response and post-incident mitigation is timely and effective. For unavoidable adverse impacts, the Commercial Group will develop and implement certain mitigation measures e.g., personnel training, activity scheduling, and reclamation. 9.5 HSE Management Systems As discussed above in Mitigation Measures, HSE Management Systems will be established for WAGP construction and operations, including, but not limited to the following aspects: · Compliance Assurance · Safe Operations · Pollution Prevention · Prevention of gas leaks and subsequent environmental impact · Emergency Preparedness/Response In support of these and other components, the Commercial Group will establish policies, objectives, procedures, monitoring/reporting processes and responsibilities, in addition to August, 2002 Page 32 West African Preliminary Terms of Reference Gas Pipeline providing the necessary resources (funding, people) for implementation. Additional details will be provided in the submitted EMP, including a schedule of implementation as the Project scope, associated impacts and proposed mitigation measure are better defined. 10.0 PROPOSED TERMS OF REFERENCE In accordance with the legal and technical directives of the Countries, the Commercial Group commits to the following regarding Environmental Impact Assessment requirements: 10.1 Project Submission 10.1.1 Project Registration/Application This document is included in the EIA registration/application as a means to describe the project for the purposes of agency screening and to: Indicate the preliminary environmental, health and safety impacts of the project; Indicate a clear commitment, to the extent possible, to avoid adverse environmental, health and safety impacts during implementation of the project; Indicate a clear commitment, to the extent possible, to address unavoidable environmental, health and safety impacts and steps where necessary for their reduction; and Provide a summary of alternatives that will be considered in the EIA Report or Impact Statement submittal. 10.1.2 Registration/Application Fees and EIA Agency Resource Requests Consistent with each country's EIA process, the Commercial Group, as part of the application process, includes the appropriate application fees in the registration documents. Within a reasonable time frame following EIA registration/application, the EIA Agencies will formally advise the Commercial Group of estimated fees and charges necessary for Agency oversight and review of WAGP EIA documents. The Commercial Group requests in this EIA application/registration that appropriate EIA agency resources be identified and dedicated to the Commercial Group to: Ensure compliance with each country's EIA requirements. Without sacrificing transparency or independence, ensure appropriate efficiency and comprehensiveness in the implementation of baseline studies, impact assessments, August, 2002 Page 33 West African Preliminary Terms of Reference Gas Pipeline stakeholder consultations, agency review and agency decisions regarding approval of EIA submittals. 10.1.3 EIA Report Focus Areas (draft terms of reference) In submitting the EIA application/registration documents, the Commercial Group commits that subsequent environmental impact assessments, statements or reports will appropriately address the following A description of the project An analysis of the need for the undertaking Alternatives to the project including the "no project" alternative Matters on site selection including rationales for the choice of the proposed site and alternative site considerations An identification of existing, relevant health, safety and environmental conditions including social, economic and other aspects of potential concerns Information on potential, positive and negative impacts of the project from the environmental, social, economic and cultural aspects in relation to the different phases of development of the project The potential impact on the health of project personnel and the surrounding communities Proposals to mitigate potential negative socio-economic, cultural and public health impacts of the project Proposals to be developed to monitor predictable environmental impact and proposed mitigation measures Contingency plans (existing or to be evolved) to address any unpredicted negative health, environmental or safety effect Consultation with members of the public likely to be affected by WAGP operations Maps, plans, tables graphs, diagrams and other illustrative material that will assist with comprehension of environmental impact assessment documents A provisional environmental management plan Appropriate details regarding the payment of compensation for possible damage to land or property arising from WAGP Indications of potential regional, national, or international impacts August, 2002 Page 34 West African Preliminary Terms of Reference Gas Pipeline It is intended that this proposed Terms of Reference/Scoping document provides the detail necessary to demonstrate the commitment of the Commercial Group to submit EIA documents containing the areas of emphasis listed above. 10.1.4 Project Presentations As needed following project registration/application, the Commercial Group will provide summary presentations to appropriate agencies and approval authorities in each country. These presentations will introduce the project, include a summary of this Terms of Reference/Scoping document, and provide information regarding Project personnel and consultant experience in natural gas, pipeline operations and EIA preparation. 10.2 EIA Implementation and Document Preparation 10.2.1 Stakeholder Consultations Immediately following EIA registration, the Commercial Group commits to a Stakeholder Consultation and Engagement process consistent with Section 4 of this document. 10.2.2 WAGP/Agency Interaction and Collaboration As appropriate, and without sacrificing the transparency or independence of the EIA agencies or EIA consultants, WAGP and it's EIA consultants will interface and collaborate with the government agencies having EIA approval authority and other appropriate agencies in each country. Some interface and collaboration is expected to occur at a regional level (i.e. involving all 4 countries) to ensure harmonization and consistency across the 4 countries associated with WAGP. At other times, it will be more appropriate to interface at a National, State or local level. Areas of interface identified to date include: Work Plans for Environmental and Socio-economic baseline surveys Adjustments and evolution of the Stakeholder Consultation Plan Stakeholder Consultation participation by the Commercial Group, the Countries or both Results of Stakeholder Consultations Progress reports on the preparation of EIA documents Preliminary discussion of mitigation measures and environmental management plans (particularly in terms of trans-boundary issues) Health and Safety Design reviews with other agencies and competent authorities, as outlined in Section 2.7.1 (Engineering Activities). August, 2002 Page 35 West African Preliminary Terms of Reference Gas Pipeline 10.2.3 Continuing EIA Support and Processing Fees Consistent with the legal requirements in each country, the to-be-developed Concession Agreement, and as identified following EIA registration/application, the Commercial Group commits to timely payment of appropriate EIA support and processing fees and other costs that could include one or more of the following: Skills Reinforcement Workshops, Capacity Building and/or Technology Transfer EIA Agency Monitoring And Assisting The Promoter In The Field "Public Information and Sensitization" (i.e. Stakeholder Consultations) Regional Environmental & Permitting Group Meetings Regional EIA Report Review Workshops 10.3 EIA Document Submissions and Agency Review 10.3.1 EIA Document Content and Structure Consistent with the legal requirements in each country, the Commercial Group commits to submittal of the following EIA documents and supporting information: Benin Environmental Evaluation Dossier (Environmental Impact Studies) Ghana Environmental Impact Statement for the purposes of receiving a Environmental Permit. Nigeria EIA Report leading to an Environmental Impact Statement and Certification (FMEnv) EIA Report (DPR) Togo Environmental Evaluation Dossier (Environmental Impact Studies) The Commercial Group intends for these EIA documents to be concise and be confined to the most important environmental problems. The main text will focus on results, conclusions and recommendations with the support of tables summarizing the collected data and of the appropriate references. Detailed and un-interpreted data will be presented in the appendices or in a separate volume. The reports will be written in French and English and will be structured/formatted as follows: Title Page including Project Title, Promoter's Name, Author(s) of study, Competent Authority for the project, Authority to which the study is addressed, and Date Summary Table of Contents List of Tables, Figures, and Attachments, including a Table of Acronyms and Abbreviations EIA Preparers Acknowledgements Executive Summary Introduction, including the Project Proposal and Project Justification August, 2002 Page 36 West African Preliminary Terms of Reference Gas Pipeline The Body of Report including 1. Project context and description 2. Description of receptor environments 3. Description and analysis of project alternatives 4. Impact analysis of selected alternative from all standpoints (environment, natural resources, social, economic, health, safety, etc.) Proposed Mitigation Measures Technological Risks & Contingency Plan Environmental Management Plan Conclusions Bibliography and other references Attachments and Appendices This Terms of Reference/Scoping Document provides additional details on the intended EIA report contents, following the structure/format above. All information the Commercial Group considers confidential shall be presented in a separate report. The requisite number of copies of the complete study, both in electronic format and hard copy, will be provided to each country. 10.3.2 Public Notification, Display, and Review Consistent with each country's laws and regulations, the Commercial Group will adhere to the public notice, display and review procedures with particular attention paid to: Appropriate and timely advertisements and notices to interested parties either directly or through appropriate media (newspaper, radio, town hall etc.). Provisions made for additional copies of the EIA documents The required durations of notices and display Commercial Group participation at public forums following notification and display periods. 10.3.3 Continuing EIA Support, Review Processing and Approval Fees Consistent with the legal requirements in each country, the to-be-developed Concession Agreement, and as identified following EIA registration/application, the Commercial Group commits to timely payment of appropriate EIA support and processing fees and other costs that could include one or more of the following: Continuing Skills Reinforcement Workshops, Capacity Building and/or Technology Transfer (particularly for Report Review Commissions, Panels, etc.) Administration Of Panel Review, Report Display, and Public Hearing Advertisement August, 2002 Page 37 West African Preliminary Terms of Reference Gas Pipeline "Commission Study Evaluation Workshop", "Public Hearing" or "Public Meeting" Expenses for the purposes of information or debate. Appropriate "Media Coverage: Radio, Press, and Television Logistics arrangements for certain (appropriate?) attendees at Public Hearing Appropriate expenses associated with review, report validation and decision making by "Public Hearing Commissions", In-house Agency personnel or equivalent bodies. Administrative Charges, Processing and Permit Fees (for Clearance/Approval) Environmental Certification Fees (in Ghana, see 10.4 below) Appropriate Environmental Management Plan Monitoring Expenses (see 10.4 below) 10.4 Post EIA Approval After the EIA is approved, and consistent with the legal requirements in each country, and/or as established through the to-be-developed WAGP Concession Agreement, the Commercial Group intends to pursue the following with the continued support and input from the Countries EIA agencies and other Country government representatives: Obtain other authorities, licenses or approvals to Construct and Operate WAGP Implement the Environmental Management Plan in terms of pre-construction resource commitments (personnel, HSE funding, etc.) Begin pre-construction and construction activities. Implement the Environmental Management Plan as approved by the Countries. As detailed in the approved Environmental Management Plan, monitor HSE and socio- economic impacts and adjust the Environmental Management Plan accordingly. In Ghana, obtain an Environmental Certificate following evidence of commencing operations (assumed to include construction) and conformance with the approved Environmental Management Plan. Submit an Annual Environmental Report as required per Ghanaian law. August, 2002 Page 38 West African Gas Pipeline EIA Preliminary Scoping Report Appendix 1 Agreed Design Standards OFFSHORE PIPELINE CODES AND SPECIFICATIONS Governing design code ANSI/ASME B31.8 ­ 2000 Edition (or latest) "Gas Transmission and Distribution Piping Systems". Supplemental recommended practices API RP 1111 ­ 1999 Edition (or latest) "Design, Construction, Operation, and Maintenance of Offshore Hydrocarbon Pipelines". API RP 14C ­ 6th edition (or latest) "Recommended Practice for Analysis, Design, Installation and Testing of Basic Surface Safety Systems for Offshore Production Platforms". DNV Offshore Standard OS-F101 "Submarine Pipeline Systems" January 2000 Edition (or latest). Major offshore pipeline component specifications as referenced in B31.8 Line Pipe Specification ­ API 5L ­ 42nd Edition (or latest) "Specification for Line Pipe". Welding Specification ­ API 1104 ­ 1999 Edition (or latest) "Standard for Welding Pipelines and Related Facilities". Corrosion Protection ­ NACE RP0675 (latest edition) "Control of External Corrosion on Offshore Steel Pipelines". Pipeline Valves ­ API 6D ­ 21st Edition (or latest) "Specification for Pipeline Valves". Pipeline Flanges ­ ASME B16.5 ­ 1996 Edition (or latest) "Pipe Flanges and Flanged Fittings NPS 1/2 Through NPS 24". Pipeline Fittings ­ ASME B16.9 ­ 2001 Edition (or latest) "Factory-Made Wrought Butt- welding Fittings". ONSHORE PIPELINE CODES AND SPECIFICATIONS Governing design code ANSI/ASME B31.8 ­ 2000 Edition (or latest) "Gas Transmission and Distribution Piping Systems". Major onshore pipeline component specifications as referenced in ANSI/ASME B31.8 Line Pipe Specification ­ API 5L ­ 42nd Edition (or latest) "Specification for Line Pipe". Welding Specification ­ API 1104 ­ 1999 Edition (or latest) "Standard for Welding Pipelines and Related Facilities". Corrosion Protection ­ NACE RP0169 (latest edition) "Control of External Corrosion on Underground or Submerged Steel Pipelines". West African Gas Pipeline Page 1- 1 August, 2002 West African Gas Pipeline EIA Preliminary Scoping Report Appendix 1 Agreed Design Standards Pipeline Valves ­ API 6D ­ 21st Edition (or latest) "Specification for Pipeline Valves". Pipeline Flanges ­ ASME B16.5 ­ 1996 Edition (or latest) "Pipe Flanges and Flanged Fittings NPS 1/2 Through NPS 24". Pipeline Fittings ­ ASME B16.9 ­ 2001 Edition (or latest) "Factory-Made Wrought Butt- welding Fittings". ONSHORE COMPRESSOR STATION CODES AND SPECIFICATIONS Governing design code ANSI/ASME B31.8 ­ 2000 Edition (or latest) "Gas Transmission and Distribution Piping Systems". Major compressor station component specifications as referenced in ANSI/ASME B31.8 Piping Materials -ASTM materials in accordance with B31.8. Welding Specification ­ In accordance with ASME Section IX requirements as provided in ANSI B 31.8. Pipeline Valves ­ API 6D ­ 21st Edition (or latest) "Specification for Pipeline Valves". Pipeline Flanges ­ ASME B16.5 ­ 1996 Edition (or latest) "Pipe Flanges and Flanged Fittings NPS 1/2 Through NPS 24". Pipeline Fittings ­ ASME B16.9 ­ 2001 Edition (or latest) "Factory-Made Wrought Butt- welding Fittings". Other component codes or specification for compressor station Electrical Code ­ British Standards, CENELEC, IEC, ISO, NEMA. Instrument Code ­ ISA, API RP 551, IEC, NEMA. Fire Protection Code ­ NFPA. Compressor Code ­ API Standard 617 ­ 1995 Edition (or latest) "Centrifugal Compressors for Petroleum, Chemical, and Gas Service Industries". Power turbines ­ API 616. Gas Measurement Code ­ API MPMS 14.3 - 1995 Edition (or latest) "Manual of Petroleum Measurement Standards Chapter 14 ­ latest edition "Natural Gas Fluids Measurement Section 3 - Concentric, Square-Edged Orifice Meters Part 1 - General Equations and Uncertainty Guidelines" or ISO 5167. Pressure Vessel Code ­ ASME Sec VIII D1 ­ 1998 Edition (or latest) "BPVC SECTION VIII Rules for Construction of Pressure Vessels DIVISION 1". West African Gas Pipeline Page 1- 2 August, 2002 West African Gas Pipeline EIA Preliminary Scoping Report Appendix 1 Agreed Design Standards ONSHORE REGULATION AND METERING STATIONS AND TERMINALS CODES AND SPECIFICATIONS Governing design code ANSI/ASME B31.8 ­ 2000 Edition (or latest) "Gas Transmission and Distribution Piping Systems". Major R&M station component specifications as referenced in ANSI/ASME B31.8 Materials : ASTM/API in line with the requirements of ANSI B31.8. Welding Specification ­ API 1104 ­ 1999 Edition (or latest) "Standard for Welding Pipelines and Related Facilities". Pipeline Valves ­ API 6D ­ 21st Edition (or latest) "Specification for Pipeline Valves". Pipeline Flanges ­ ASME B16.5 ­ 1996 Edition (or latest) "Pipe Flanges and Flanged Fittings NPS 1/2 Through NPS 24". Pipeline Fittings ­ ASME B16.9 ­ 2001 Edition (or latest) "Factory-Made Wrought Butt- welding Fittings". Other component codes or specification for R&M stations Electrical Code ­ British Standards (BS), CENELEC, IEC, ISO, NEMA. Instrument Code ­ ISA, API RP 551, IEC, NEMA. Fire Protection Code ­ NFPA. Gas Measurement Code ­ API MPMS 14.3 - 1995 Edition (or latest) "Manual of Petroleum Measurement Standards Chapter 14 ­ latest edition "Natural Gas Fluids Measurement Section 3 - Concentric, Square-Edged Orifice Meters Part 1 - General Equations and Uncertainty Guidelines" or ISO 5167. Pressure Vessel Code ­ ASME Sec VIII D1 ­ 1998 Edition (or latest) "BPVC SECTION VIII Rules for Construction of Pressure Vessels DIV1". OTHER MISCELLANEOUS FACILITIES Buildings Local Building codes in each country shall be applicable. Civil works British Standards, EN, ISO. OTHER DESIGN REQUIREMENTS DNV will be used as a supplement in areas of deficiency of ANSI B31.8 with emphasis on stability calculations and its verifications. West African Gas Pipeline Page 1- 3 August, 2002 West African Gas Pipeline EIA Preliminary Scoping Report Appendix 1 Agreed Design Standards Anodes shall be utilised to ensure maintenance design life for the offshore pipeline of between 40 and 50 years. Pig traps will be provided for internal intelligent pigging inspection, including on spur lines. The WAGP Regulations shall provide for the use of intelligent pigging and remotely operated vehicles for inspection, at periods to be agreed which shall not adversely affect Project economics. A maintenance philosophy and emergency management plan shall be established in accordance with this Agreement, covering maintenance and emergency response and repair procedures. The Company shall maintain stocks of spare parts and training of staff consistent with the agreed maintenance philosophy and plan. To the extent practicable and as agreed to between the Company and the WAGP Authority, maintenance standards as contained in the design standards above will be followed. West African Gas Pipeline Page 1- 4 August, 2002 APPENDIX 2 FOCUS AREAS FOR ENVIRONMENTAL BASELINE ASSESSMENT Nigeria Offshore Cotonou Lome Tema Takoradi Effasu Environmental Data Onshore Marine Environment Gas Delivery Point Gas Delivery Point Gas Delivery Point Gas Delivery Point Gas Delivery Point Land/Physical Characteristics. Climate/Meteorological Factors XX X X X X X X Terrain XXX XXX X X XX XX X Geo surface materials XX XX X X X X X Relief/topographic characteristics XXX XXX X X X X X Environmental Contaminants XX XX XX X X Land Capabilities Agriculture XXX X X X X Forestry XX X XX Wildlife XXX X XX XXX Fisheries XXX XXX XXX XXX XXX XXX Significant Geographic Areas. XX XX XX XX XX XX XX Environmental Field Data Airsheds XX X XX XX XX XX XX Overall Air Quality Assessments XX XX XX XX XX XX Noise Level Assessments XXX XX XX X X Water Quantity/Quality Assessments Hydrology XX XX XX XX XX XX Ground Water Studies XX Stream/Lagoon Characteristics XXX XX XX XX XX XX Watershed Characteristics XXX X X X X X Oceanographic Parameters XXX XX XX XX XX XX (Geomorphology, Waves & Currents) Flora/Fauna Types/distribution XXX XX Vegetative Cover Characteristics XXX XX X X XX XX XXX Soil Studies XX XXX XX XX XX XX XX Biological Descriptions via Maps Ecological Zones XX XX X X XX XXX XXX Sensitive Areas XX Unique Ecosystems XX XXX XX XX XXX Areas of ecological interest XX XXX XX XX XXX Areas of scientific interest XX XXX XX XX XXX Areas of High Economic Concern XX X XX XX XX XX X Aquatic Studies Hydrobiology X XXX XX XX XX XX XX (plankton, benthic fauna, etc.) Fisheries X XXX XXX XXX XXX XXX XXX Freshwater & Marine Wildlife X XXX XXX XXX XXX XXX XXX X-Limited description necessary XX- Routine description anticipated to appropriately describe the existing situation, including potential for secondary impacts XXX- Detailed description needed due to an anticipated higher level of impact WEST AFRICAN GAS PIPELINE Page 2-1 August, 2002 APPENDIX 3 CURRENT EIA REFERENCE MATERIALS 1. Perspectives in Integrated Coastal Areas Management in the Gulf of Guinea (UNIDO Large Marine Ecosystem Project for the Gulf of Guinea) 2. Nearshore Dynamics and Sedimentology of the Gulf of Guinea (UNIDO Large Marine Ecosystem Project for the Gulf of Guinea) 3. State of the Coastal and Marine Environment of the Gulf of Guinea (UNIDO Large Marine Ecosystem Project for the Gulf of Guinea) 4. Towards Integrated Coastal Zone Management in the Gulf of Guinea A Framework Document 5. Coastal Profile of Nigeria (UNIDO Large Marine Ecosystem Project for the Gulf of Guinea) 6. Profil de la zone cotiere du Benin (UNIDO Grand Ecosysteme Marin de Golfe de Guinee) 7. Cote D'Ivoire Profil environmental de la zone cotiere (UNIDO Grand Ecosysteme Marin de Golfe de Guinee) 8. Profil Environmental du Littoral du Togo (UNIDO Grand Ecosysteme Marin de Golfe de Guinee) 9. Zonation of Ghanaian Fishing Grounds 10. Coastal Zone Profile of Ghana 11. Towards an integrated Coastal Zone Management Strategy for Ghana (Ghana EPA and World Bank) 12. The Coastal Zone of West Africa: Problems and Management 13. African Perspectives on the Clean Development Mechanism 14. An Overview of the Environmental Impact of the Shrimp and Prawn Industry in Ghana 15. Draft Report of the Wetland Typology Working Group West African Gas Pipeline Page3-1 March, 2003 APPENDIX 4A PRELIMINARY IMPACT SUMMARY - POTENTIALLY POSITIVE IMPACTS X- probability and severity to be determined Environmental Impact Location Pre-Construction Construction* Operations Decommissioning Reduced greenhouse gas emissions from Nigerian Regional X oilfield flaring Reduced greenhouse gas emissions from the use of natural gas as an alternative energy source in Benin, Togo and Ghana Potential for reduced deforestation/desertification Socio-Economic Impacts National and Regional industrial or economic Regional X benefits facilitated by the delivery of reliable, competitively priced, cleaner burning fuel WAGP social reinvestment opportunities including Regional X X X technology transfer and capacity building Stakeholder reactions to perceptions and actual Regional X X X X performance of the Commercial Group Proposed compensation schemes Nigeria Onshore X X and Gas Delivery Points Temporary employment opportunities All X X *Pre-Construction and Construction Impacts includes support activities such as camps for onshore construction personnel, staging areas for both onshore and offshore operations, land and marine transportation, and possibly weight coating operations APPENDIX 4B PRELIMINARY IMPACT SUMMARY - POTENTIALLY NEGATIVE IMPACTS X- probability and severity to be determined Health and Safety Impacts Location Pre-Construction Construction* Operations Decommissioning Transfer of disease and illness due to Onshore Pipeline X X Limited X · initial health conditions of workers and local Route communities · interactions between project personnel and Nigeria Beach the communities Compression · sanitary conditions of work, housing and feeding locations Gas Delivery · R&M Locations Injuries due to construction equipment selection All above plus X X X and/or operation Marine Injuries or illness due to the use of hazardous All above plus X X X materials Marine Injuries or Illness due to improper waste management All above plus X X X (sanitary, non-hazardous or hazardous wastes) Marine Environmental Impacts Location Pre-Construction Construction* Operations Decommissioning Cumulative impacts to areas of ecological concern due Regional X to regional economic growth. Examples include the Gulf of Guinea Marine Ecosystem and areas of high biodiversity between Effasu and Takoradi. Changes to historical/traditional land usage Nigeria Onshore and X X X X Gas Delivery Points Vegetative clearing Nigeria Onshore and Camps X Gas Delivery Points Access roads Weight Coating Right of Way And Facility Site Preparation Loss of habitat and related impacts to flora and fauna Nigeria Onshore and X X X from vegetative clearing Gas Delivery Points *Pre-Construction and Construction Impacts includes support activities such as camps for onshore construction personnel, staging areas for both onshore and offshore operations, land and marine transportation, and possibly weight coating operations APPENDIX 4B PRELIMINARY IMPACT SUMMARY - POTENTIALLY NEGATIVE IMPACTS X- probability and severity to be determined Environmental Impacts Location Pre-Construction Construction* Operations Decommissioning Erosion associated with vegetative clearing, pipeline Nigeria Onshore and X X Limited Limited trenching/backfilling and right of way reinstatement Gas Delivery Points Material handling impacts from vegetative clearing Nigeria Onshore and X X and excess soil excavation Gas Delivery Points River, stream or lagoon crossings or dredge/fill Nigeria Onshore and X X activities possibly the Benin (erosion, water quality impacts in terms of pollution Gas Delivery Points and/or disruptions to water supply, etc.) Coastal and wetland ecological issues Nigeria Beach X X X "Compression facility" and R&M Stations Coastal stability issues Nigeria Beach X X "Compression facility" and R&M Stations Temporary (short duration) impacts from traffic, Nigeria Onshore X X X noise, and waste generation management and Gas Delivery Points Temporary air emissions from equipment and All X X activities including dust and other air pollutants such as SOX, NOX, and particulates Intermittent air pollutant emissions Nigeria Onshore X and Gas Delivery Points Fires Nigeria Onshore Limited Limited X Limited and Gas Delivery Points *Pre-Construction and Construction Impacts includes support activities such as camps for onshore construction personnel, staging areas for both onshore and offshore operations, land and marine transportation, and possibly weight coating operations APPENDIX 4B PRELIMINARY IMPACT SUMMARY - POTENTIALLY NEGATIVE IMPACTS X- probability and severity to be determined Environmental Impacts Location Pre-Construction Construction* Operations Decommissioning Commercial Group approach to existing land Nigeria Onshore X X contamination and Gas Delivery Points Temporary impacts to fisheries, aquatic Offshore Route ­ Limited X vegetation/wildlife and benthic fauna from survey and Main Pipeline and construction activities Laterals Temporary impacts from marine traffic, noise, and Offshore Route ­ Limited X waste generation management Main Pipeline and Laterals Pipeline stability impacts associated with Offshore Route ­ X X oceanographic parameters such as geomorphology, Main Pipeline and currents and waves. Laterals Water column impacts from pipeline disruptions and Offshore Route ­ X natural gas releases Main Pipeline and Laterals Effluent discharge from pipeline hydrotesting Offshore Route ­ X operations Main Pipeline and Laterals Socio-Economic Impacts Location Pre-Construction Construction* Operations Decommissioning Stakeholder reactions to perceptions and actual Regional X X X X performance of the Commercial Group Physical changes to communities along the Nigeria Onshore and X X X pipeline route, including aesthetics Gas Delivery Points Changes to historical/traditional land usage Proposed compensation schemes Nigeria Onshore and X X Gas Delivery Points *Pre-Construction and Construction Impacts includes support activities such as camps for onshore construction personnel, staging areas for both onshore and offshore operations, land and marine transportation, and possibly weight coating operations APPENDIX 4B PRELIMINARY IMPACT SUMMARY - POTENTIALLY NEGATIVE IMPACTS X- probability and severity to be determined Socio-Economic Impacts Location Pre-Construction Construction* Operations Decommissioning River, stream or lagoon crossings or Nigeria Onshore and X X dredge/fill activities possibly Benin gas (erosion, water quality impacts in terms of delivery point pollution and/or disruptions to water supply, etc.) Temporary (short duration) impacts from Nigeria Onshore and X X traffic, noise, and waste generation Gas Delivery Points management Physical/social interactions between WAGP All X X Limited personnel and local communities Community health and safety impacts due to Nigeria Onshore and X operational disruptions or natural gas releases Gas Delivery Points Fires resulting from disruptions to pipeline operations Nigeria Onshore and X or natural gas releases Gas Delivery Points Impacts to local and commercial fishing Offshore Route ­ X X Limited Main Pipeline and Laterals *Pre-Construction and Construction Impacts includes support activities such as camps for onshore construction personnel, staging areas for both onshore and offshore operations, land and marine transportation, and possibly weight coating operations APPENDIX 5 DETAILED LIST-POTENTIAL MITIGATION MEASURES · As agreed between the Countries and WAGP, observe protective perimeters around the following sensitive zones, and avoid and/or reinstate deforestation or the elimination of vegetation cover, including: - Shorelines, - Known wildlife habitats, - Water supply basins, - Steep and erosion-sensitive gradients, - Wet areas, · Conserve and reuse topsoil during the burial of the pipe, · Establish a work calendar in keeping with those periods of time that are sensitive to wildlife elements, · Plan to allow for considerable flexibility in the means of crossing sensitive habitats (e.g., waterways, wet areas) or protected habitats (e.g., the habitat of a rare plant species), · Reduce to a minimum the length of the work in sensitive areas, · Control access to work sites, · Use adequate road signs on the routes leading to the work sites, · Establish adequate personnel training procedures with regard to the protection of the environment, · Limit the expropriation of right-of-ways, fragmentation of properties, agricultural and forestry areas, · Coordinate the work with other land users, · Encourage the employment of the local workforce, · At the end of the work, clean and return the elements of the environment that were affected to their original condition. Use species indigenous and suitably adapted to the host environment, · Compensate for major residual impacts, · Formulate an emergency action plan in coordination with the interested authorities in the event of an accidental spill during the construction and operational phases. Specific Measures Protection of the quality of surface waters · Control traffic in order to avoid leaks and spills of hazardous materials (hydrocarbons, etc.), . Conserve vegetation near waterways and wet areas, · Measures to be taken in the event of the accidental contamination of the ground, air, and water, · Avoid moving machinery near potable water connections. A security perimeter should be established and identified on the sites by marking them or by closing them in by whatever means necessary, · When necessary to cross waterways: - Implement all necessary measures (wire fences, nets, protective paneling, etc.) to avoid having construction materials, wastes, or wood residues fall into waterways, - Place filtration berms and sediment barriers in the ditches that drain the work sites, . Cross perpendicularly where the embankments are stable and the waterways are narrow, . Use methods that minimize perturbations to aquatic environments and wet areas, . Show preference for existing structures or plan for the installation of culverts whose bearing capacity is sufficient for the machinery being used, · At the end of the work, remove all temporary installations used to cross waterways. Reestablish, if necessary, the normal flow of the waterways and restore the original bed and banks, · Take all necessary precautions during the refueling of transport vehicles and machinery at the work site to avoid accidental spills. Prohibit the refueling of machinery near waterways. Protection of the water table · Properly seal wells and bore holes prior to abandonment, · Use appropriate drilling practices. Modification of the flow of surface water · Schedule intervention periods in areas subject to flooding or in which there is the likelihood of heavy runoffs at times other than the high water season or heavy rains, · avoid blocking the drainage of surface water and provide for the means of restoration, · Restrict to a minimum vehicular traffic beyond the right of way in order to avoid the creation of ruts, and consequently, runoff, · Be mindful of surface drainage at all times. West African Gas Pipeline Page5-1 August, 2002 APPENDIX 5 DETAILED LIST-POTENTIAL MITIGATION MEASURES · Avoid blocking waterways, trenches, or any other channel. · Remove any debris that blocks the normal flow of surface water, · Provide accommodations for vehicular traffic anytime there is a risk of compaction or alteration of wet areas. Soil erosion and destabilization · Mechanically stabilize the soil in order to reduce the potential of erosion, · Avoid excavation and burial in steeply sloped ground and avoid creating grade breaks, · Provide for the placement of siltation ponds in areas subject to heavy erosion, · Obtain the necessary authorizations for work in wet areas, · Provide for the rehabilitation of the site after the work, · Limit activities in erodible soils. Select vehicles suited to the nature of the soil, · Avoid the creation of access ways along the axis of long, continuous descending grades in favor of a perpendicular or diagonal orientation, · At the completion of the work, level the disturbed soil and quickly undertake the sodding and planting of trees or brushes in order to control soil erosion. Modification of the soil characteristics · Scarify as needed damaged sites, regrade the sites, then replace the layer of topsoil that was previously put to the side during construction work, · Provide accommodations for vehicular traffic anytime there is a risk of compaction or alteration of the surface. · Restore the operational site by restoring the original profile of the topography and the soil, · Strictly regulate heavy machinery traffic. Restrict the number of traffic lanes and limit the movement of the machinery to the work sites and to marked access ways, · Maintain transportation vehicles and machinery in good working order so as to avoid oil and fuel leaks and all other pollutants. Changes to air quality and noise exposure · Near inhabited areas, avoid heavy truck traffic and carrying out loud work outside of normal working hours, · Maintain transportation vehicles and machinery in good working order in order to minimize gaseous emissions and noise, · Use dust-control liquids and dust-recovery machinery. Destruction or modification of the vegetation cover · Clearly define the cut zones in order to limit the deforestation thereto, · Protect trees from the machinery on the edge of the right-of-ways, · Restore the vegetation at end of the work, · Avoid the deforestation and the destruction of bordering vegetation, · During cutting operations, provide for wood stacking areas beyond wet areas, · Prohibit the digging of trenches within a meter of a tree. Destruction or modification of wildlife habitats · Obtain special authorization to perform work within wildlife or ecological preserves, · No work will be done in breeding grounds during breeding seasons. Schedule work and set the calendar of activities taking into account the use the wildlife makes of the land, · Protect known productive habitats, wet areas and spawning beds, · Avoid restricting the movement of fish by paying attention to the size of culverts, the speed of the flow of water, and the water level at the point of minimum flow. Perturbation to customs and traditions · Provide for a work schedule that will avoid disturbing the traditional life of communities, · Establish a communication program to inform communities of on-going work and establish appropriate measures to minimize the disturbance caused by the work. Population displacement · Reach an agreement with communities with regard to the ways and means of resettlement and respect those commitments, West African Gas Pipeline Page5-2 August, 2002 APPENDIX 5 DETAILED LIST-POTENTIAL MITIGATION MEASURES · Negotiate, if necessary, for the acquisition of land or the right of passage and provide for the adequate compensation, · Guarantee access to private property and the safety of residents and passersby during the course of the work by enacting the appropriate measures (fencing, guards, etc.). Service interruptions during the work · During service interruptions, notify the concerned jurisdictions and take the appropriate measures to keep interruptions to a minimum for the residents of the affected area. Disturbances caused by construction or maintenance work · Minimize the accumulation of waste produced by the use of construction materials, · Insure the appropriate management of chemical products used in the placement of pipe (handling, storage, installation, disposal, etc.), · Avoid the storage of machinery in areas other than those identified as essential to the work. Provide for a clear definition of the boundaries of said areas, · Avoid the accumulation of all types of wastes on and off the work site; remove the wastes to waste disposal sites provided for that purpose. Damages caused to roads, risks of accidents, and traffic caused in connection with construction work · Avoid blocking public access, · Use road signs to notify work in progress, · Comply with road bearing capacity and repair damage caused to roads at the end of the work, · Circumvent gathering places. Public safety and management of hazardous materials · Heighten the safety of workers and of the surrounding communities by establishing safety and emergency action plans, · Insure that all employees adhere to the safety program, · Provide for the establishment of emergency plans and action plans in the event of an accidental spill of contaminants or of a gas leak. Post in a location visible to the workers a poster showing the names and telephone numbers of the people in charge and describing the alert protocol, · Keep on hand a supply of absorbent materials as well as properly designated recipients designed to contain petroleum residue and wastes in the event of a spill, · Inform the drivers and operators of machines of the security standards to be followed at all times, · When action is necessary to remove or contain pollutants or contaminated substances, solid or liquid, the site selection and the disposal method must observe applicable standards, · Provide for storage areas for contaminated products and equip them with devices designed to protect against any accidental spills. Modification of a known historical site or building · Obtain the necessary authorizations prior to the execution of the work. Disruption of known or potential cultural or archeological sites · Prior to the commencement of the work, undertake archeological assessments in identified potential sites and encourage the appropriate analysis and reclamation of archeological artifacts, or avoid these sites altogether. · Complete the gathering of inventory data by means of mapping and photographic surveys, · During the work, scrutinize the work site for artifacts of archeological importance, and in the event of any discovery, suspend all activities and notify the competent authorities, · In order to prevent theft or vandalism, refrain from letting the general public know the exact location of archeological or exceptional sites, · Identify or protect culturally or religiously significant sites. Visual changes to known historical sites and monuments · Provide for facilities that are in harmony with the historical heritage, Optimize the placement and the architecture of facilities in such a way as to integrate them into the landscaping. West African Gas Pipeline Page5-3 August, 2002 APPENDIX 5 DETAILED LIST-POTENTIAL MITIGATION MEASURES Location of facilities · In urban area, seek out those sites that present characteristics that are compatible with the facilities to be built, · Set a premium on the use of small-footprint facilities to minimize the loss of space, · Demonstrate a preference for areas where the facilities will be less visible, · Select sites located near the edge of a property or at the far end of a street block, · Install as necessary noise barriers in order to lessen the acoustic impact. Impeding road traffic and community activities · Adjust work schedules so as not to disturb traffic. Establish an adequate system of road signs and detours. · Notify communities of pending work: scope, duration and location, · In urban areas, clean the streets used by trucks and machinery so as to keep them clean and clear. Disruption of farming activities · Prior to the start of work, check with farmers regarding the use that they intended for their land, · Perform the work in such a fashion as to harm as little as possible existing farming practices (duration, timing, magnitude), · Keep to a minimum areas in which farming will be impossible during and after the work and compensate for losses, · Maintain at all times access to isolated areas, · Enter the right of way by the use of existing routes or move about at the edge of cultivated land and coordinate the creation of access roads in cooperation with farmers, · Place the facilities, to whatever degree possible, at the edge of lots or cultivated land or distribute them in such a way as to occupy as little as possible cultivated land, · Loosen soil compacted by machinery and put disturbed production areas back into production. Disruption to forestry activities · Notify the owners of the occupied land of work duration, · Provide for coordination mechanisms with the competent authorities for the disposal of merchantable timber harvested from private lands or with private owners for the recovery of firewood. Disruption of tourist activities · Avoid encumbering tourist and recreation areas or take the necessary measures to insure access and safe use during and after the work, · Devise arrangements that insure compatibility between tourist and recreative activities and the operation of the gas pipeline. West African Gas Pipeline Page5-4 August, 2002 Preliminary Scoping Report Ghana WEST AFRICAN GAS PIPELINE FINAL ENVIRONMENTAL IMPACT ASSESSMENT SCOPING REPORT Prepared For: Ghana Ministry of Environment Science & Technology Ghana Environmental Protection Agency March, 2003 Table of Contents OBJECTIVES ..........................................................................................................................2 1.0 PROJECT SUMMARY....................................................................................................3 1.1 Project Proposal ............................................................................................................3 1.2 Project Background.......................................................................................................3 1.3 Project Purpose & Need................................................................................................4 1.4 EIA Legal Framework ..................................................................................................5 1.5 Agency Support and Harmonization.............................................................................6 2.0 PROJECT DESCRIPTION.............................................................................................6 2.1 Scope of EIA.................................................................................................................6 2.2 Natural Gas Sources ("Upstream" of WAGP)..............................................................7 2.3 Natural Gas Consumption ("downstream" of WAGP).................................................7 2.4 General Layout & Physical Description .......................................................................8 2.5 Permanent Ancillary Systems & Facilities ...................................................................9 2.6 Operational Control and Safety Systems....................................................................11 2.7 Project Implementation Description ...........................................................................12 3.0 PROJECT ALTERNATIVES SUMMARY.................................................................17 4.0 STAKEHOLDER CONSULTATIONS........................................................................17 4.1 Scoping Consultations .............................................................................................19 5.0 EXISTING SITUATION ...............................................................................................19 5.1 Existing Health Situation............................................................................................19 5.2 Existing Safety Situation.............................................................................................19 5.3 Existing Environment and Resources.........................................................................20 5.4 Existing Socio-Economic Aspects..............................................................................29 6.0 IMPACT ASSESSMENT...............................................................................................30 7.0 MITIGATING AND AMELIORATING MEASURES ..............................................31 8.0 DETAILED ALTERNATIVES ANALYSIS................................................................33 9.0 PROPOSED TERMS OF REFERENCE .....................................................................34 9.1 Project Submission......................................................................................................34 9.2 EIA Implementation and Document Preparation........................................................36 9.3 EIA Document Submissions and Agency Review......................................................37 Waste Management......................................................................................................39 Air Emissions...............................................................................................................39 Emergency Prevention, Preparedness and Response...................................................39 Energy and Resource Conservation.............................................................................40 HSE Management Systems..........................................................................................40 9.4 Post EIA Approval......................................................................................................41 West African Final Scoping Report Gas Pipeline APPENDIX 1 AGREED DESIGN STANDARDS APPENDIX 2 FOCUS AREAS FOR ENVIRONMENTAL BASELINE ASSESSMENT APPENDIX 3 CURRENT EIA REFERENCE MATERIALS APPENDIX 4 PRELIMINARY IMPACT SUMMARIES APPENDIX 5 DETAILED LIST-POTENTIAL MITIGATION MEASURES ATTACHMENT 1 Regional Map-West African Gas Pipeline ATTACHMENT 2 Nigeria Onshore Pipeline Route Map-West African Gas Pipeline ATTACHMENT 3 Compression Facility Layout Drawing-West African Gas Pipeline ATTACHMENT 4 Regulating & Metering Station Layout Drawing-West African Gas Pipeline ATTACHMENT 5 Benin Onshore Delivery Site Map-West African Gas Pipeline ATTACHMENT 6 Togo Onshore Delivery Site Map-West African Gas Pipeline ATTACHMENT 7 Tema (Ghana) Onshore Delivery Site Map-West African Gas Pipeline ATTACHMENT 8 Takoradi (Ghana) Onshore Delivery Site Map-West African Gas Pipeline March, 2003 Page 1 West African Final Scoping Report Gas Pipeline OBJECTIVES The overall objectives of this Final EIA Scoping document include the following: · Provide a framework leading to an appropriate regional harmonization of EIA expectations, review and timely approval of the submitted EIA documents for Benin, Ghana, Nigeria and Togo. · Satisfy Initial Project Proposal requirements for the 4 countries prior to formal application or registration of the project. · Satisfy Preliminary Impact Assessment requirements for the 4 countries. · Assist the 4 countries in Project Screening deliberations, following formal EIA application or registration. · Assist the 4 countries in EIA Scoping deliberations, following formal EIA application or registration., focusing the EIA on significant potential impacts associated with pipeline construction and operation. · Provide a framework such that the WAGP Joint Venture (Commercial Group) and the 4 countries can consistently inform and educate stakeholders, understand stakeholder concerns and solicit input from relevant interest groups and those who may be directly impacted by the Project. · Assist the Commercial Group with project planning, design and decision making. More specifically, the objective of this EIA Scoping/Terms of Reference document is to establish a comprehensive EIA approach leading to the following documents contained in the final EIA Report: · Project background, purpose & need · Detailed project descriptions, including general layout & physical descriptions, ancillary systems & facilities, operational control systems, and project implementation descriptions · Detailed descriptions of the existing environmental and socio-economic situation that incorporates stakeholder consultations, literature reviews and field studies. · Health & safety, environmental and socio-economic impact assessments that include qualitative and quantitative risk assessments among other tools and techniques. · Proposed mitigating and ameliorating measures as applied to pipeline routing, design, construction and operations impacts. · Alternatives Analysis, including the No-Project Alternative · Environmental Management Plans that appropriately incorporate monitoring, mitigation and management systems that are consistent with identified impacts and that provide a contingency for unforeseen impacts In preparing the final EIA reports and documents, the Commercial Group intends to use all of the deliverables described above to continuously modify and improve construction and operational plans to: · enhance the benefits of the project March, 2003 Page 2 West African Final Scoping Report Gas Pipeline · reduce the potential for, or consequences of, negative impacts · satisfy the cost and schedule expectations of the 4 countries and project investors 1.0 PROJECT SUMMARY 1.1 Project Proposal Chevron West African Gas, Ltd. on behalf of the West African Gas Pipeline (WAGP) Joint Venture intends to construct a 12-30 inch (30.5-76.2 cm), 617 km (383 mile), onshore and offshore gas pipeline from Nigeria to Ghana. The WAGP consortium is a joint venture partnership between Chevron Nigeria Limited (CNL), Nigerian National Petroleum Corporation (NNPC), The Shell Petroleum Development Company (SPDC) of Nigeria Limited, Societe Beninoise de Gaz S.A. (SOBEGAZ), Societe Togolaise de Gaz S.A (SOTOGAZ) and the Volta River Authority (VRA). Members of the Commercial Group intend to form a project company to be known as WAPCo for constructing, maintaining and operating the pipeline. The Commercial Group is considering a proposed pipeline route that extends from a proposed connection to the existing Escravos-Lagos Pipeline (ELP) at the Alagbado "Tee" near Itoki, Nigeria. The ELP is owned by Nigerian National Petroleum Corporation (NNPC) and operated by the Nigerian Gas Company (NGC), a subsidiary of NNPC. From the ELP connection, the pipeline route would proceed to a Nigerian beach location on land and continue offshore from the Nigerian beach location across the territorial waters of Nigeria, Benin, Togo and Ghana, terminating at Takoradi, Ghana. Gas delivery laterals from the main pipeline route will extend into Cotonou (Benin), Lome (Togo) and other gas delivery target locations in Ghana (Tema and Takoradi). With regard to the delivery points, these locations should achieve an equilibrium between the concerns of their acceptance by coastal communities, safety and environmental vulnerability. Offshore pipeline installation is anticipated to be in 30-100 m (100-300 feet) water depths at an approximate distance of 15 km (9 miles) from shore. Targeted gas delivery points at Cotonou, Lome, Tema, and Takoradi are anticipated to extend onshore only to the degree necessary to install Regulating and Metering Stations (1-2 km (0.6-1.2 miles) onshore), although in the case of Benin, gas delivery points could extend 5-9 km (3.1- 5.6 miles) inland. 1.2 Project Background On 5th September, 1995 a Heads of Agreement (HOA) was signed by the Governments of The Republic of Benin, The Republic of Ghana, The Federal Republic of Nigeria, and The Republic of Togo to construct a pipeline to transport natural gas from Nigeria to Ghana through Benin and Togo. The HOA also required that an independent feasibility study be conducted to determine the viability of the pipeline. The Engineering Feasibility Study was carried out by Pipeline March, 2003 Page 3 West African Final Scoping Report Gas Pipeline Engineering GmbH, PLE, of Germany and documented in a report issued in March 1999. This study determined that a West African Gas Pipeline (WAGP) was technically and commercially feasible, pending additional evaluation. In May 1999, the Governments of the Republic of Benin, the Republic of Ghana, the Federal Republic of Nigeria, and the Republic of Togo (collectively referred to as "the Countries"), appointed Chevron Nigeria Limited, Ghana National Petroleum Corporation, Nigerian National Petroleum Corporation, The Shell Petroleum Development Company of Nigeria Limited, Société Béninoise de Gaz S.A., and Société Togolaise de Gaz S.A., (collectively referred to as the "Commercial Group") Project Developer for the WAGP. In May 2001, the Ghana National Petroleum Corporation advised the Commercial Group of a proposal to assign their interest in the WAGP to the Volta River Authority. This assignment is completed.. On 11th August 1999, the Countries further entered into a Definitional Phase Memorandum of Understanding ("MOU") with the Commercial Group on the development of the WAGP. In the MOU, the Countries confirmed the designation of the Commercial Group as the Project Developer and granted the Commercial Group an exclusive right to establish the West African Gas Pipeline Company ("WAPCo") which would enter into a Concession Agreement with the Countries, granting to WAPCo an exclusive franchise to build, own and operate the WAGP. Further to the MOU, the project has now moved into a Definitional Phase. This phase is intended to fully establish the commercial viability of the Pipeline and execute certain technical studies, including a detailed Environmental Impact Assessment. In Abuja, Nigeria, on 4th February, 2000, the Countries signed the Inter-Governmental Agreement ("IGA") with the intention of maintaining a uniformity of approach (or "harmonization") to give effect to the undertakings they intend to make to WAPCo through the Concession Agreement. The Countries and the Commercial Group are currently engaged in negotiating the Concession Agreement for the Pipeline. 1.3 Project Purpose & Need The 1995 HOA recognized that "there exists ample resources of natural gas in Nigeria to satisfy the energy requirements of West Africa (and the Countries of West Africa have stated their strong interest to use natural gas resources of Nigeria to satisfy their energy needs.)" The purpose of the West African Gas Pipeline, therefore, is to transport natural gas from Nigeria to consumers in the countries of Benin, Togo, and Ghana. The benefits to all WAGP stakeholders include the following: 1.3.1 Environment · Reduce Flaring, resulting in lower green house gas emissions · Displacing certain liquid fuels with natural gas, also reducing green house gas emissions. Electrical power producers and industries with the capability to use natural gas are the primary consumers that could immediately benefit from the March, 2003 Page 4 West African Final Scoping Report Gas Pipeline construction of the pipeline. Other public and private sectors could also use the natural gas provided by WAGP, but this scenario would require separate development of infrastructure, energy policies, etc. 1.3.2 Socio-Economic · More secure energy supply via power generation or direct gas use by industries and others · Enables sustainable development and regional integration · Local and regional technology growth/transfer In compliance with the legislative and regulatory provisions of the affected countries, the project will be subject to an environmental impact assessment. The WAGP EIA will further quantify the benefits described above and will identify additional benefits as appropriate. 1.4 EIA Legal Framework The Commercial Group proposes to carry out the Environmental Impact Assessment of the pipeline project consistent with the following: · Compliance with the laws, regulations, and guidelines of the Republic of Benin, the Republic of Ghana, the Federal Republic of Nigeria, and the Republic of Togo. For Ghana this includes but is not limited to: - Environmental Protection Agency Act, 1994 (Act 490) (Ghana) - Environmental Assessment Regulations ­ L.I. 1652 (Ghana) - National and other relevant applicable international laws - Lands Commission - Water Resources Commission - Local Govt. Act - Factories & Shops Act - Beaches Ordinance · Commercial Group corporate policies regarding responsible social and ethical behavior, incorporation of safety, health and environmental protection measures and responsiveness to community issues and concerns. · International investment criteria, particularly in terms of socio-economic assessments, transparent and effective stakeholder engagement, appropriately designed environmental management and social reinvestment, and technology transfer/capacity building opportunities. · As appropriate, environmental and socio-economic guidelines, standards, conventions and treaties, established at the local, national and international levels including: Following this framework and incorporating the best practices and lessons learned from other pipeline projects enhances stakeholder perceptions of the Countries and Commercial Group and reduces the potential for delays due to investor, NGO or community concerns. March, 2003 Page 5 West African Final Scoping Report Gas Pipeline 1.5 Agency Support and Harmonization As described above, one of the intents of this document is to provide a framework leading to an appropriate regional "harmonization" of EIA expectations, review and timely approval of EIA reports for Benin, Ghana, Nigeria and Togo. The Commercial Group has identified the following "harmonization" opportunities and hopes to work with the Countries on these opportunities following review of this Proposed Terms of Reference/Scoping document. · Collaboration with Environmental and other agencies regarding EIA implementation. See Section 10 below for collaboration suggestions. · Methodologies of Study and Assessment · Report(s) Format - Dual Language Translation - Balance of Local, Regional and International contexts · Environmental Management Plans - Impact Avoidance and/or Mitigation - Monitoring - HSE Management Systems · Common Trans-Boundary Issues (i.e. the Gulf of Guinea Marine Environment) · Agency Review 2.0 PROJECT DESCRIPTION The WAGP Commercial Group will supplement the Project Description provided below to include a complete description of the Proposed Alternative, including details regarding siting of facilities, pipeline routing, and the project schedule. The EIA will also document significant project information for construction and pipeline operations including, but not limited to the following: · Raw Material Inputs/Product Output · Storage and emission inventories · Traffic generation · Effluents & Discharges · Noise · Air Emissions and energy use from · Aesthetics construction and operations · Night time operations · Storage/disposal of hazardous goods · Dedicated land use associated with long · Waste and /or byproducts generated term facilities · Spoil materials from dredging 2.1 Scope of EIA The WAGP EIA will focus on the project description and related impacts associated with building the pipeline and operations associated with the transportation of natural gas. Sources of transported natural gas ("Upstream" of WAGP) and end uses of natural gas ("Downstream" of WAGP) will also be described to provide a proper regional context to the March, 2003 Page 6 West African Final Scoping Report Gas Pipeline WAGP EIA and as an input to an appropriate level of assessment beyond the immediate or isolated impacts of the WAGP project. As discussed in the Impacts Section below, however, since these secondary impacts are outside the immediate scope of the WAGP project, the EIA for the pipeline will only outline these ancillary impacts and provide a framework for future consideration. It is expected that in accordance with the applicable laws in each of the countries those projects will undergo or have already undergone separate detailed impact assessments. The Commercial Group intends to demonstrate by means of the EIA that variations in the volume of transported gas, up to the design capacity of 400 million standard cubic feet per day (MMSCFD- 11.3 million cubic meters per day-MMm3D), will not significantly change the identified impacts associated with the gas pipeline. 2.2 Natural Gas Sources ("Upstream" of WAGP) The "base case" Project Description for WAGP will detail the facilities and activities associated with a pipeline system designed to transport and deliver up to 400 MMSCFD (11.3 MMm3D) of natural gas. To date the commercial group has identified 250 MMSCFD (7.1 MMm3D) in gas volume available for transport from oil and gas operations in Nigeria. Most of this available natural gas will be "associated gas", i.e. produced with oil from the same source. As associated gas reserves are depleted the delivery requirements will be supplemented with "non-associated" gas. Oil and gas facilities associated with the 150 MMSCFD (7.1 MMm3D) described above are already in place or are anticipated to be installed before the end of WAGP construction. The sources for gas volumes above 150 MMSCFD (4.2 MMm3D) are not specifically known at this time and could involve existing or new oil and gas facilities. 2.3 Natural Gas Consumption ("downstream" of WAGP) As stated above in the Project Summary, electrical power producers and industries with the capability to use natural gas are the primary consumers that could immediately benefit from the construction of the pipeline. Negotiations have started with potential gas transportation customers, and to date the Takoradi Thermal Power Station has signed a letter of intent NGas to purchase natural gas. Additional gas transportation opportunities will be pursued until the gas supply is exhausted "upstream" of the pipeline or when the 400 MMSCFD (11.3 MMm3D) design capacity is reached. When gas demand reaches the 400 MMSCFD (11.3 MMm3D) design capacity, gas delivery volumes are anticipated as follows, based on current market analyses: Outlet Anticipated Delivery Cotonou, Benin 10 MMSCF/d 0.3 MMm3D Lomé, Togo 80 MMSCF/d 2.3 MMm3D Tema, Ghana 230 MMSCF/d 5.3 MMm3D Takoradi, Ghana 120 MMSCF/d 3.4 MMm3D March, 2003 Page 7 West African Final Scoping Report Gas Pipeline The scope of the WAGP EIA includes gas transportation of up to 400 MMSFD (11.3 MMm3D). Beyond a qualitative, cumulative impact assessment in this EIA, the Commercial Group intends to address any project expansion over 400 MMSFD (11.3 MMm3D) via a supplementary EIA or equivalent mechanism. 2.4 General Layout & Physical Description The WAGP Commercial Group intends to construct a 12-30 inch (30.5-76.2 cm), 617 km (383 mile), onshore and offshore gas pipeline from Nigeria to Ghana. From the Alagbado "Tee" near Itoki, Nigeria, estimated segment lengths of the proposed pipeline are as follows: Alagbado "T" to Lagos Beach 57 Km 35 mile 30 in (76 cm) pipeline Lagos Beach to Benin Border 50 Km 31 mile 16-22 in (40-56 cm) pipeline Benin Border to Cotonou 44 Km 27 mile " " " " Cotonou to Lome 98 Km 61 mile " " " " Lome to Tema 160 Km 99 mile " " " " Tema to Takoradi 208 Km 129 mile " " " " Total 617Km 383 mile Other tie in points to the ELP system and different Nigeria land routing scenarios are currently under consideration - See Maps ­ Attachments 1 (regional) and 2 (onshore Nigeria). NOTE: The Environmental Impact Assessment will only focus on new construction associated with the West African Gas Pipeline. The existing ELP in Nigeria, "upstream" of WAGP and gas delivery systems "downstream" of WAGP will only be described and referenced in terms of secondary, indirect or cumulative impacts. A gas transmission "compression facility" is anticipated at a to-be-proposed Nigeria beach location with an estimated 140 m by 185 m (460 ft. by 607 ft.) footprint - see Attachment 3. Primary and Back-up Control Centers will also be constructed with similar footprints with final locations to be determined. Offshore Pipeline installation is anticipated to be in 30-100 m (98-328 feet) water depths at an approximate distance of 15 km (9 miles) from shore. Gas delivery points at Cotonou, Lome, Tema, and Takoradi will extend onshore via 12"-20" (30-50 cm) laterals only to the degree necessary to install Regulating and Metering Stations (1-2 km (0.6-1.2 miles) onshore). Estimated footprint for the Regulating and Metering Stations is 68m by 68 m (223 x 223 ft.), although larger 30-100 m (98-328 feet) may be pursued to accommodate future mid-line compression to ensure delivery of the 400 MMSCFD (11.3 MMm3D).­ see Attachment 4. When commercial conditions demand the installation of mid-line compression, more than likely in Lome, a parallel 12"-20" (30-50 cm) lateral pipeline would be installed from the mid-line compressor station. Siting alternatives for gas delivery points are currently being considered. Proposed locations will reflect a balance of community acceptance, safety, environmental sensitivity, access, March, 2003 Page 8 West African Final Scoping Report Gas Pipeline cost, operational considerations and other issues. Maps and drawings showing site locations currently under review include the following: Cotonou, Benin Attachment 5 Lomé, Togo Attachment 6 Tema, Ghana Attachment 7 Takoradi, Ghana Attachment 8 Some of these drawings show additional potential infrastructure development in terms of gas distribution system routing. As discussed below under impact analysis, this infrastructure development is considered an indirect impact of WAGP that ultimately will be addressed by project proponents other than the Commercial Group as defined above. If gas demand exceeds the 400 MMSCFD (11.3 MMm3D) "base case design capacity", one or two gas delivery locations may be considered for additional mid-line compression facilities with footprints similar to the Nigeria beach compression facility described above. Specific locations for additional mid-line compression will be examined during Front End Engineering and Design (FEED). Pipeline "looping" where additional parallel pipelines are installed offshore may also be considered for gas demand greater than 400 MMSCFD (11.3 MMm3D). 2.5 Permanent Ancillary Systems & Facilities Gas specifications will be established for delivery of "dry gas" from ELP to WAGP such that liquid hydrocarbon, water, and impurities are minimized during WAGP gas transportation operations. A minimum heating value of the gas will also be included in the gas specification. Gas transported in the ELP itself may have varying characteristics regarding liquid hydrocarbon content, water percentage, etc, depending on who supplies gas to the ELP and the negotiated gas delivery specifications between NGC, WAGP and non-WAGP gas sellers, transporters or buyers. An export terminal, proposed for installation at the ELP connection point is required for custody transfer purposes and to ensure conformance with the WAGP "dry gas" specification. Potential components of the export terminal include: · Gas cleaning/ scrubbing facilities as may be determined during detailed design · Equipment for metering of the gas flow through the station for accounting purposes or custody transfer · Equipment for gas quality measurement to ensure conformance with the "dry gas" specification · Safety and shut down equipment Responsibilities for the export terminal will be established between WAPCo and NNPC/NGC by means of an interconnection agreement, which is currently being negotiated between the parties. Liquid handling and management facilities will also be installed at the Nigeria Beach "compression facility" and gas delivery R&M stations as a contingency for gas production March, 2003 Page 9 West African Final Scoping Report Gas Pipeline upsets from gas suppliers to WAGP. Other ancillary systems associated with the Pipeline include: X-likely to be installed, subject to additional design and analysis Ancillary System Nigeria Beach Delivery Point R&M Stations "Compression facility" Control Room/Facilities, X X including SCADA and MAIN FACILITY SCADA BACK UP FACILITY Communications Centre LOCATION TO BE DETERMINED Workshop, Offices, X Sanitary Facilities Gas Filtration, Cleaning, X X Scrubbing Equipment Compressor(s) X Mid Line Compressors Possible Subject to Gas Demand Fuel Gas Supply System X X (for compressors, gas IF GENERATOR IS heaters, Generators, and INSTALLED instrumentation, etc.) Air Compression X X for Instrumentation IF GAS IS NOT USED Gas Coolers X IF MID-LINE COMPRESSORS ARE INSTALLED Gas Heaters X Electrical Systems X X Emergency Shutdown, X X Flare/Vent, Fire & gas detection systems Gas Metering Run X(COULD BE REQUIRED X FOR CONTROL PURPOSES) Gas Quality Measurement X X (as required by trans. agreements) Pressure Regulating Run X X Odorization Optional Laboratory Facilities TO BE DETERMINED TO BE DETERMINED (if appropriate) No effluent discharge systems are anticipated for long term pipeline operations, other than possibly sanitary waste discharge from the Nigeria Beach "compression facility" and possibly metering stations if toilets are provided for personnel. Effluent discharge may occur during pipeline hydro-testing following construction. March, 2003 Page 10 West African Final Scoping Report Gas Pipeline The principal components of the R&M station will be installed in two parallel equipment runs to provide 100% operational back-up. These components are described as follows: · Filters to separate coarse particles and condensate droplets. The filter elements are periodically replaced or may be washable. At set liquid levels in the filter vessel, volumes of liquid or condensate are automatically removed to a liquid collection facility. · Line-heaters to compensate for temperature drop caused by the pressure reduction of the gas (Joule Thompson Effect). · Regulating runs to reduce the high gas pressure of the upstream pipeline system to the lower pressure of the distribution line. · Meter runs to measure natural gas volume flow at the R & M station. The meter modules can be orifice, turbine, vortex, ultrasonic or other types. The meter shall be equipped with flow computers and must be approved or certified for custody transfer. · Safety and shutdown protective devices with appropriate backup 2.6 Operational Control and Safety Systems The control system will consist of three tiers: · Primary and backup Supervisory Control and Data Acquisition (SCADA) computers located in the central Dispatch Centre, most likely to be located at the Lagos Beach compressor station. The main function of the SCADA system will be operational interface to support operation of the complete pipeline network. The SCADA system will report pipeline system status to the central Dispatch and Backup Dispatch Centres, showing normal, abnormal or alarm conditions, so operators can monitor and take action if needed. Remote terminal units (RTU) at each field compressor, metering or pigging station to receive and execute commands from the Dispatch and Backup Dispatch Centres. · Communications/control computers also located in the Dispatching and Backup Dispatching Centres for the purpose of communications and issuing control commands and initiating corrective actions. Operators will be able to view the entire system and ensure that the demand for product flow is met and that pipeline operating conditions are safe and optimised. Corrective actions can be initiated, either automatically or with operator over-ride, if necessary. The Backup Dispatch Centre will likely be located at Tema, although final decisions have not been made. · The remote stations will have a degree of local automation and control which will ensure safe and continuous operation of the station independent of whether the operator is present on site and whether he will take the required corrective action. Similarly, the individual stations will be able to operate safely with or without communications from the central Dispatch or Backup Dispatch Centres. · Local control of the facilities from the plant for at least maintenance purposes The SCADA system will utilise VSAT telecommunications technology for data transmission and voice communications as it provides the lowest total cost of ownership. The system will be designed to serve only the pipeline's telecommunications needs. VSAT facilities will be March, 2003 Page 11 West African Final Scoping Report Gas Pipeline located at each pressure reduction, metering, and compressor station. Local and international communications system where available will also be utilized as a back up in minimum. 2.7 Project Implementation Description 2.7.1 Engineering The basic physical components of the pipeline include the following: · Steel pipeline materials Fabrication details to be determined during engineering & design. · A thin external coating layer of corrosion resistant material (example ­ fusion bond epoxy) Material application to the pipeline segments is anticipated to occur during fabrication, with details determined during engineering and design. · Application of weight coating to the pipeline (typically concrete based material) The purpose of weight coating is to reduce buoyancy impacts of an offshore pipeline or river/lagoon crossings. Options for weight coating operations will be assessed during engineering and design, including the possibility of local operations during construction. · Compressor stations with Compressors, generators and other equipment · Metering system and stations The technical standards for the engineering, design and construction of the WAGP system are proposed to be based on the ANSI, ASME and API systems. The primary design code of reference will be the ANSI/ ASME B31.8 "Gas Transmission and Distribution Piping Systems" design code. The ANSI/ ASME B31.8 design code is the only general pipeline code that covers both onshore and offshore gas pipeline systems as well as metering and compressor stations. The B31.8 code is a well-established design code and is the predominant code of reference for WAGP installations. The components of the pipeline system will be designed and installed using API, ASME or ANSI design codes that are specific for the component. The major design codes are listed in Appendix 1. Front End Engineering Design (FEED) is scheduled to start following a Preliminary Commercial Evaluation, with a duration of approximately 9-12 months. This design work will be done in a to-be-determined location under the direction of Commercial Group personnel knowledgeable in project execution and gas pipeline technology. In this phase of the engineering, the design will be progressed through the development of · Process designs · Piping and Instrumentation Diagrams (P& ID's) · System safety systems designs · Project equipment specifications as described above · Preliminary Drawings · Design Reports March, 2003 Page 12 West African Final Scoping Report Gas Pipeline · Other key Project documentation It is during this phase that the Commercial Group will proactively solicit stakeholder input and evaluate Best Available Technology (BAT) for incorporation into the designs, to ensure that the project minimizes health, safety and environmental (HSE) impacts. Several detailed reviews will commence during the engineering phase including: Conceptual & Early FEED Stage Late FEED and Detailed Design Stage · Concept Safety Evaluation Studies · PFD, P&ID, SAFE Chart Reviews · Qualitative Risk Assessment Review · Detailed HAZOPS, SAFOPS, IPF · Process Flow Diagram (PFD) Reviews Classification and/or HAZAN Reviews · Piping & Instrumentation Diagram (P&ID) · Quantitative Risk Assessment Reviews Review/Study · High Level HAZOP Review · Equipment Layout · High Level HAZID Review · Hazardous Area Classification · Project Specifications Review · Fire/Explosion Study · Project Safety Case/HSE Review · Fire Protection Analysis · Escape/Evacuation/Rescue Studies · Safety Review/Criticality Ranking of Major Equipment · Project Specification and Material Selection Review · Fabrication inspection at an offsite location During these and other reviews, it is anticipated that representatives from EIA and Permit/License Approval agencies in each of the countries will participate to provide relevant input and guidance on regulatory compliance issues and prudent protective measures. Development of the detailed information to support the EIA process will be a critical engineering and FEED activity to ensure timely EIA approval before the start of construction. An iterative process of stakeholder input, design adjustment, impact analysis and follow-up stakeholder consultations will be used to develop a detailed HSE plan during engineering and FEED and ultimately incorporated into the EIA Environmental Management Plan. A smooth transition will be made from FEED into detailed engineering while ensuring continuity is maintained. Detailed drawings, construction specifications, and the bulk of the procurement will be completed. Certain reviews (such as HAZOPS), which commenced during the preliminary and front end engineering phases, will be completed during this phase as the vendor engineering information is received at the project's office. 2.7.2 Other Pre Construction Activities In addition to design activities, the WAGP Commercial Group will conduct the following activities, integrated with the Environmental Impact Assessment processes and deliverables: March, 2003 Page 13 West African Final Scoping Report Gas Pipeline · Routing and Siting Surveys Onshore surveys will be conducted to determine ELP tie-in, pipeline routing, Nigeria Beach "Compression facility" and R&M location options in Benin, Togo and Ghana. Offshore surveys will also be conducted to determine appropriate marine routing of the pipeline. Relatively non-invasive survey techniques will be utilized, although soil and seabed coring operations are anticipated for geo-technical evaluation in both the onshore and offshore environments. Limited vegetative clearing may also be required in conjunction w/ onshore surveying operations. The commercial group intends to coordinate External Affairs, Engineering and EIA consulting resources in implementing the surveys, to ensure that all issues and impacts associated with routing and siting are comprehensively and consistently identified. An appropriately scoped HSE Management plan will be prepared prior to routing and survey work to minimize the impacts of these activities. · Estate Surveying and identification of real estate titles This activity will determine land tenure aspects of the project for the Nigerian onshore portion of the project and gas delivery points in Benin, Togo and Ghana. This determination will include assessments of land ownership and other existing rights associated with potential routing or siting options for the pipeline and facilities. · Land and Right of Way Acquisition Based on the estate surveying work, the Commercial Group will negotiate the acquisition of permanent land rights (for facilities such as the compressor and R & M stations) and rights of way (for the length of pipeline itself). Other temporary and permanent estate acquisitions (camps, staging areas, roads, etc.) will also be pursued either directly by the Commercial Group or through contractors or other 3rd parties, with appropriate compensation guidelines established. The Commercial Group has been advised that legal ownership and control of the offshore area which the pipeline will traverse is vested in each of the countries on the national government. Accordingly the Commercial Group expects that negotiations for rights of way over these offshore areas will be held with the governments concerned. Compensation for acquisition of permanent land rights and rights of way will be fair and in accordance with local and international best practice and the Commercial group will liaise closely with appropriate government, community and traditional leaders during negotiations to acquire land or rights of way. The Commercial Group does not anticipate significant, if any resettlement, associated with the construction of the pipeline. Resettlement plans will be developed, however, if necessary and included in the EIA submittal. The Commercial Group also recognizes that initial land and right of way target areas may not be suitable at the time of construction and that alternative routes should be considered as a contingency. Proposed and alternative sites and routes will be March, 2003 Page 14 West African Final Scoping Report Gas Pipeline pursued in a manner consistent with the description above and all agreements will include terms and conditions such as "...acquisition contingent on EIA approval, Permit issuance,..." etc. · Material Procurement, Staging and Transportation The pipeline itself, along with compressors, vessels, meter runs and pressure regulating equipment will be fabricated at an offsite fabrication yard. The locations of the fabrication yard(s) and staging areas have not been determined at this time. · Additional safety and operational reviews with EIA and Permitting agencies including - Critical Safety Equipment & Quality Assurance Inspection and Testing - Functional Testing of Corrosion & Fire Protection Equipment · Other activities like logistical planning, contracting for construction, cost minimization Studies and other EIA support activities. 2.7.3 Construction The project description for the WAGP EIA will focus on the following construction activities and tasks, projected to occur over a 2-year period, associated with civil, mechanical and electrical engineering implementation. · Onshore site clearance and preparation, including construction camps, access roads, river/lagoon crossings, the pipeline right-of-way, and ancillary facility sites (Nigeria Beach "Compression facility", R&M Stations in Benin, Togo and Ghana) · Temporary construction support operations including local camps for onshore construction personnel, staging areas for both onshore and offshore operations, transportation, and possibly weight coating operations · Pipeline trenching, particularly onshore and for near shore gas delivery laterals. Offshore trenching or directional drilling requirements, if any, to be determined during engineering and design. · Pipeline placement/stringing, cleaning and welding · Pipeline inspection and testing · Pipeline burial particularly onshore and for near shore gas delivery laterals. · Ancillary facility and equipment installation (R&M Stations and the Nigeria Beach "Compression facility") · Onshore soil management and right-of-way reinstatement All construction activities will be executed in accordance with a project specific HSE plan that will attempt to reduce impacts to the local community and environment. The details of this plan will be developed during FEED and continuously updated based on consultations with non-government stakeholders, EIA approval agencies, pipeline permitting/licensing agencies and local governments/communities. March, 2003 Page 15 West African Final Scoping Report Gas Pipeline 2.7.4 Training, Commissioning, and Start-up Hiring of commissioning/start-up contractors and pipeline operations personnel will commence during the latter stages of construction. An extensive training program will be conducted following personnel hiring. All training will be completed in time to support the commissioning and start-up schedule. The extent of personnel and other needs for commissioning and start up will be determined during FEED. EIA and Permitting Agency reviews and participation is expected to continue during this stage including: · Project Workshops · Training for Pre Commissioning and Commissioning · Joint Safety Inspections · Pre-Start Up Safety Audit · Review of specific operating permit requirements Commissioning will begin upon mechanical completion and `pre-commissioning' of the pipeline facilities. The pipeline will be cleaned, hydrotested, de-watered, dried through loading with air, inert gas or other non-flammable material. Compressors and other equipment will be lubricated, calibrated and tested as well as all control and telecommunications including the VSAT systems. Commissioning ends and start-up will begin when the pipeline is ready for introduction of hydrocarbons. 2.7.5 Pipeline Operations The pipeline operations component of the EIA Project Description will focus particularly on activities and facilities associated with health and safety of both the workers and nearby communities. Specific physical descriptions will include: · Ancillary Equipment, particularly monitoring and control systems. · Emergency shut down systems · Fire prevention, detection, and suppression · Corrosion control systems including cathodic protection and "pigging" operations · Support systems such as access roads, waste management (sanitary, non-hazardous and hazardous), and as appropriate, use of hazardous materials, including the nature, transportation, storage, intended use, treatment, and final disposition. 2.7.6 Decommissioning and Abandonment As described in the Concession Agreement, the Commercial Group intends to decommission and abandon the Pipeline consistent with prevailing accepted industry practices. Plans for facility decommissioning, abandonment and facility/ROW reinstatement will also be described in this section of the EIA. This section of the EIA will also address decommissioning of temporary construction facilities including staging, weight coating, camps. March, 2003 Page 16 West African Final Scoping Report Gas Pipeline 3.0 PROJECT ALTERNATIVES SUMMARY The WAGP EIA will contain two alternatives sections - an overall Project Alternatives Summary and a Detailed Alternatives Analysis (see below). In the Project Alternatives Summary, the No-Project Alternative will be explicitly assessed, drawing from the 1999 Feasibility Study and other sources. The Project Alternatives Summary will also address regional pipeline routing alternatives (example ­ all offshore, all onshore, etc.) and technological alternatives to a gas pipeline (example ­ gas to liquids technology, Compressed Natural gas (CNG) and Liquefied Natural Gas (LNG), etc.). The Project Alternatives Summary section will also review alternatives associated with significant impacts associated with the Proposed Alternative. In summarizing Project level alternatives, discussion will be focussed on the following: · Best Available/ Practicable Technologies · Feasibility · Regional health, safety, environmental and/or socio-economic benefits · Local and regional suitability, including stakeholder acceptance · Institutional requirements · Costs (capital and operating) Other more specific alternative scenarios will be provided in the Detailed Alternatives Analysis section as described below: 4.0 STAKEHOLDER CONSULTATIONS The legislative provisions of the various countries emphasize the participation of the parties having a stake in the environmental impact assessment. As described throughout this document, informal meetings, focus group discussions and public forums will be continuously utilized in the preparation of the EIA to: · Inform and educate stakeholders on all aspects of the project, including the Proposed Alternative and other alternatives considered · Gather relevant information and data · understand critical stakeholder issues and concerns · Make appropriate adjustments to design, construction, operational and environmental management plans · Communicate design, construction , operational and environmental management plan adjustments · elicit support for the project Geographic and social linking of issues will be part of the public involvement mechanisms that will allow WAPCo to concurrently manage project impacts locally and regionally across the four countries. These consultations shall include local and/or indigenous communities and businesses as well as regional, national and international non-governmental organizations and entities that may be significantly impacted by the construction or operation of the March, 2003 Page 17 West African Final Scoping Report Gas Pipeline Pipeline. The Commercial Group shall document the consultations and transmit a summary of these consultations as part of the EIA Report documentation. As a means to facilitate stakeholder consultations, a WAGP External Affairs Plan will identify and assist in managing community concerns and impacts associated with every aspect of the project. It seeks to respond to the organizational, economic, socio-cultural, technical, health, safety, environmental, political as well as international aspects of the project. This plan will be dynamic and will be localized for each of the four countries. It will also reflect the concerns and interests of the international community and will be regularly evaluated and amended to suit the dynamic nature of the project and its setting. Specific components of the External Affairs Plan as it relates to the EIA study include the following: · Workshop for Public Affairs Staff of Relevant Government and Regulatory bodies · Seminars for regulatory agencies, customs, immigration related government agencies to facilitate corridor surveys · Forums for traditional authorities and communities at large · Seminars for local authorities · Workshops for community education staffs · NGO's and Environmental journalist seminars · Seminars for registered fishing groups, companies, consultants, individuals and organizations involved in research in the fishing industry · Seminars for academia · Durbar for chief fishermen and the associated communities · Mass education in all fishing communities · Orientations for project contractors · Pipeline route tours Key issues that have already been identified and incorporated into the External Affairs Plan include: · Limited scientific and socio-economic baseline data on project communities · Community expectations · Peoples attitude towards, perception of, and knowledge about project · Socio-cultural intrusion in terms of physical contact with WAGP personnel, pressure to conform to different standards, and changes to cultural values · Cultural sensitivities · Environmental concerns Sensitive marine ecosystems Sensitive areas of bio-diversity · Health and Safety concerns for communities and workers · EIA requirements, timing and credibility · Land tenure and appropriate compensation for project impacts · Consultation/capacity building · Historical performance and perceptions of the Commercial Group · Fishing concerns March, 2003 Page 18 West African Final Scoping Report Gas Pipeline · Respect for traditional authorities · Interference with economic activity · Security and safety of navigation (accidents) · Impact of project personnel and/or contractors · The need for independent monitoring 4.1 Scoping Consultations Consistent with Regulation 11 of the LI 1652, the Commercial group carried out scoping consultations for the Environmental Impact Assessment. These consultations were meant as a means to focus the EIA on key issues, concerns and decision areas and to gather input on the appropriate assessment methodologies. Appendix A provides a summary of issues raised and also the detailed minutes of the various consultations conducted. This EIA document including the Terms of Reference in Section 10 below is structured in a manner consistent with the comments received. 5.0 EXISTING SITUATION 5.1 Existing Health Situation Studies to determine the existing health situation along the pipeline route will be conducted with particular emphasis on areas of poor health or sanitary conditions. Through our contracting processes and negotiations with contractors, the Commercial Group will also consider opportunities to establish health baselines and "fitness for duty" criteria for workers in the region. Studies will also focus on health services options in the region such that immediate care can be provided to those suffering health impacts from project activities. The Commercial Group recognizes that illness and disease could be an impact from project activities, particularly during construction. Baseline health considerations that are already under review include: · Illness and disease inherent to the region (example malaria) · Illness and disease associated with sanitary conditions (example dysentery) · Socially transmitted disease such as AIDS, venereal disease etc. due to the interactions of workers and the communities. 5.2 Existing Safety Situation The routing and siting survey work will provide baseline information in terms of geographic and site-specific safety issues. Project Security issues will also be identified in terms of the potential for community unrest, civil disobedience, theft, robbery, etc. Worker Safety issues will also be assessed and managed by the Commercial Group through the development of a specific Project Safety Management Plan (PSMP). The PSMP will be a stand alone plan developed under the umbrella of an HSE Management System. The specific PSMP will incorporate existing policies and procedures of the Commercial Group. Key elements of the PSMP will include: March, 2003 Page 19 West African Final Scoping Report Gas Pipeline · Management Leadership & Commitment · HSE Objectives · Safety Contracting Processes - Assessment of Contractor Safety Performance and Programs - Job Safety Analysis - Safety Orientation & Training - Integration of Contractors' Safety Management Plan into PSMP · HSE Roles and Responsibilities · Policy Development - Stop Work for Safety Policy - Alcohol & Substance Abuse Policies - Fitness for Duty Policies · Consistent Procedures & Practices - Emergency Response Plan - Community Awareness/Outreach Plan - Incident Investigation & Reporting - Field Safety Audits - Medical Treatment Procedures Existing community safety issues will also be assessed including knowledge of construction, natural gas and pipeline operations. The capability of the communities to manage safety related events effectively will also be reviewed. As discussed above, design standards and engineering best practices will be employed in the development of WAGP, and the Country's safety review and permitting processes will ensure that the communities are adequately protected. 5.3 Existing Environment and Resources The status of the environment and of its various components prior to the project will be set forth, where various sensitive points and constraints will identified and addressed. Appendix 2 provides a framework matrix of project locations and focus areas used to develop an environmental baseline studies workplan including: Biological Environment Physical Environment · Flora/Fauna · Land/Physical Characteristics · Areas of Ecological interest, including · Water Quality and surface water rare or endangered species, sensitive hydrology habitats · Air shed characteristics · commercially important species and · Land Capabilities and usage fishing zones · Potential Environmental Contaminants · Oceanographic Parameters · Rural & Regional Infrastructure along the pipeline route · Climatic and Weather Conditions March, 2003 Page 20 West African Final Scoping Report Gas Pipeline This matrix helped to identify areas of higher impact due to pipeline construction or operations. The Commercial Group intends to compile and analyze baseline data generally through literature review and empirical field analyses, using Geographic Information Systems (GIS) as a means to manage and communicate data. Appropriate literature research and field studies will be done for the Proposed Alternative and other scenarios, particularly in terms routing and siting of the pipeline and related facilities. The Commercial Group will rely on stakeholder consultations, academic efforts and public information (for example prior EIA efforts) in the literature review. Appendix 3 is a list of marine and near shore reference materials already collected for the WAGP EIA. Appendix B to this Scoping Report provides an Environmental Baseline Survey (EBS) Workplan. Prior to field data collection, the Commercial Group consulted with the Ministries and Agencies of the four countries on the fundamental study approach including sampling/analysis methodologies, data quality expectations, etc. Appendix B provides a plan for addressing the following questions for the offshore environment. a. What is the diversity of habitats in the study area for benthic and water column organisms? b. What is the existing abundance and species diversity of benthic macroinvertebrates, fish, plankton in the habitats that are encountered? c. What marine birds, mammals, reptiles, and amphibians tend to be present? d. Are threatened and/or endangered species, sensitive habitats, or commercially significant species/fishing zones present? e. What is the character of the seabed and is there existing sediment impairment with respect to or as indicated by: · Bulk Properties (grain size, total organic carbon (TOC)) · Organics (oil and grease, total petroleum hydrocarbons (TPH), polycyclic aromatic hydrocarbons (PAH), aliphatic hydrocarbons) · Trace Metals (aluminum (Al), cadmium (Cd), chromium (Cr), copper (Cu), iron (Fe), mercury (Hg), nickel (Ni), lead (Pb), vanadium (V), zinc (Zn)) · Nutrients and physicochemical properties (sulfate, ammonia nitrogen (N), orthophosphate phosphorous (P), total P, alkaline metals (calcium (Ca), magnesium (Mg), potassium (K), sodium (Na)) f. What is the character of the water column and is there water-quality impairment with respect to or as indicated by: · Trace metals (Al, Cd, Cr, Cu, Fe , Hg , Ni, Pb , Zn) · Water quality (dissolved oxygen (DO), total dissolved solids (TDS)) · Nutrients and physiochemical properties (alkalinity, chemical oxygen demand, ammonia N, nitrate N, total N, orthophosphate P, total P, sulfate, alkaline metals (Ca, Mg, K, Na)) · Temperature, pH, electrical conductivity, turbidity, salinity, chlorophyll-a · Contaminated fish tissue (specifically PAH and metals concentrations) March, 2003 Page 21 West African Final Scoping Report Gas Pipeline g. For all of the above is there significant seasonal variation that the EIA needs to consider? h. By combining biological, chemical, and physical sampling parameters derived from the sampling data, what is the existing environmental quality of the resource? i. Do meteorological and current patterns create concern with regard to exacerbating persistent, non-localized impacts? Similarly Appendix B provides a plan for addressing the following questions for the onshore environment: a. What is the diversity of terrestrial and aquatic habitats? b. What are the presence, abundance and species diversity of terrestrial trees, shrubs, understory plants, wildlife, and intertidal zone aquatic macrophytes? c. What are the presence and abundance of riverine (and adjacent water body) plankton, macrophytes, and macrobenthic infauna? d. What is the character of the riverine fisheries resources? e. Are threatened and/or endangered species, sensitive habitats, or commercially significant species/fishing zones present? f. What is the character of the soil and is there existing soil impairment with respect to or as indicated by: · Total petroleum hydrocarbons and PAH · pH, TOC, and particle size distribution · Trace metals · Microbiology · Macrobiology and soil ecology g. What is the character of the groundwater and soil borings and is there impairment at the proposed compressor station location with respect to or as indicated by: · TPH · PAH · Trace metals · pH · Grain size and porosity h. What is the character of the riverine (and adjacent water body) surface water and is there surface water-quality impairment with respect to or as indicated by: · Salinity · Conductivity · Turbidity · DO · TDS/TSS · Temperature · Oil and grease · Trace metals · BOD5 · Total Alkalinity · Anions · Plankton productivity and biomass March, 2003 Page 22 West African Final Scoping Report Gas Pipeline i. What is the character of the riverine (and adjacent water body) sediments and is there sediment-quality impairment with respect to or as indicated by: · TPH · Trace metal · TOC · pH, grain size, redox potential, and temperature · Macrobenthic infauna j. Are there important sources of air emissions, and what are the associated pollutant concentrations as indicated by: · PM · VOCs · NOx · SOx k. For all of the above is there significant seasonal variation that the EIA needs to consider? l. Would meteorological patterns likely exacerbate persistent, non-localized impacts? The EBS methodology and laboratory procedures shall be consistent with relevant established standard operating procedures (SOPs) and participating governments' guidelines. More specifically, the Commercial Group intends for the EBS to be conducted with the following sample methods and sample frequencies. Proposed Number of Water Testing- Offshore Technique Method Reference Ghana Samples In Situ Measurements (profiles with depth) pH electrode (YSI) APHA 4500-H B 78 Temperature electrode (YSI) APHA 2550 B 78 Electrical Conductivity electrode (YSI) APHA 2510 B 78 Turbidity electrode (YSI) APHA 2130 B 78 Dissolved Oxygen electrode (YSI) APHA 4500-O G 78 Salinity electrode (YSI) 78 Redox Potential (ORD) electrode (YSI) APHA 2580 A 78 Chlorophyll-a electrode (YSI) 78 Water Quality Sulfate turbidimetric (Hach) APHA-SO4 E 58 Alkalinity titration (Hach) APHA 2320 B 58 closed reflux, 58 COD titrimetric APHA 5220 C distillation, 58 Ammonia Nitrogen titrimetric APHA 4500-NH3 C cadmium reduction, 58 Nitrate Nitrogen colorometric APHA 4500-NO3 E Total Nitrogen macro kjedahl APHA 4500-Norg B 58 Orthophosphate ascorb acid, 58 Phosphorous colorometric APHA 4500-P E March, 2003 Page 23 West African Final Scoping Report Gas Pipeline Proposed Number of Water Testing- Offshore Technique Method Reference Ghana Samples persulfate digest, 58 ascorb acid, Total Phosphorous colorometric APHA 4500-P E Alkaline Metals flame photometric 58 (Ca, K, Na) detector APHA 3500 Trace Metals nitric acid digestion, 58 Cd - Cadmium AAS APHA 3111 B nitric acid digestion, 58 Cr - Chromium AAS APHA 3111 B nitric acid digestion, 58 Cu - Copper AAS APHA 3111 B nitric acid digestion, 58 Fe - Iron AAS APHA 3111 B nitric acid digestion, 58 Mg - Magnesium AAS APHA 3111 B nitric acid digestion, 58 Ni - Nickel AAS APHA 3111 B nitric acid digestion, 58 Pb - Lead AAS APHA 3111 B nitric acid digestion, 58 Zn - Zinc AAS APHA 3111 B nitric acid digestion, 58 Al - Aluminum AAS APHA 3111 D nitric acid digestion, 58 V - Vanadium AAS APHA 3111 D diathizone, 58 Hg - Mercury spectrophotometer APHA 3500-Hg C Biology Phytoplankton, 12 Zooplankton, Ichythio microscope APHA 10200 Sediment Testing- Proposed Number of Offshore Technique Method Reference Ghana Samples In Situ Measurements pH electrode APHA 4500-H B 29 Temperature electrode APHA 2550 B 29 Redox Potential electrode 29 Physicochemical distillation, 29 Ammonia Nitrogen titrimetric APHA 4500-NH3 C Orthophosphate ascorb acid, 29 Phosphorous colorometric APHA 4500-P E persulfate digest, 29 ascorb acid, Phosphorous colorometric APHA 4500-P E Sulfate turbidimetric APHA-SO4 E 29 Exchangable Acidity titration titration 29 Alkaline Metals flame photometric 29 (Ca, K, Na) detector APHA 3500 Bulk Properties March, 2003 Page 24 West African Final Scoping Report Gas Pipeline Sediment Testing- Proposed Number of Offshore Technique Method Reference Ghana Samples dichromated wet 29 Total Organic Carbon oxidation Walkley Black Grain Size sieve, hydrometer Bouyoucous 29 Organics hexane extr, UV 29 Oil and Grease Content spectrometer Nigeria DPR methylene chloride USEPA Method 29 Total Hydrocarbons extraction, GC/FID 8015 methylene chloride USEPA Method 29 Aliphatic Hydrocarbons extraction, GC/FID 8015 methylene chloride USEPA Method 29 PAH extraction, GC/FID 8100 Trace Metals nitric acid digestion, 29 Cd - Cadmium AAS APHA 3111 B nitric acid digestion, 29 Cr - Chromium AAS APHA 3111 B nitric acid digestion, 29 Cu ­ Copper AAS APHA 3111 B nitric acid digestion, 29 Fe ­ Iron AAS APHA 3111 B nitric acid digestion, 29 Mg ­ Magnesium AAS APHA 3111 B nitric acid digestion, 29 Ni ­ Nickel AAS APHA 3111 B nitric acid digestion, 29 Pb ­ Lead AAS APHA 3111 B nitric acid digestion, 29 Zn ­ Zinc AAS APHA 3111 B nitric acid digestion, 29 Al ­ Aluminum AAS APHA 3111 D nitric acid digestion, 29 V ­ Vanadium AAS APHA 3111 D diathizone, 29 Hg ­ Mercury spectrophotometer APHA 3500-Hg C Biology Macrobenthic Infauna microscope 38 Proposed Number of Soil Testing-Onshore Technique Method Reference Ghana Samples Point Samples Properties pH electrode APHA 4500-H B 28 dichromated wet 28 TOC oxidation Walkley Black Grain Size sieve, hydrometer Bouyoucous 28 Organics methylene chloride USEPA Method 28 Total Hydrocarbons extraction, GC/FID 8015 Trace Metals nitric acid digestion, 28 Cd - Cadmium AAS APHA 3111 B March, 2003 Page 25 West African Final Scoping Report Gas Pipeline Proposed Number of Soil Testing-Onshore Technique Method Reference Ghana Samples nitric acid digestion, 28 Cr - Chromium AAS APHA 3111 B nitric acid digestion, 28 Cu - Copper AAS APHA 3111 B nitric acid digestion, 28 Fe - Iron AAS APHA 3111 B nitric acid digestion, 28 Mg - Magnesium AAS APHA 3111 B nitric acid digestion, 28 Ni - Nickel AAS APHA 3111 B nitric acid digestion, 28 Pb - Lead AAS APHA 3111 B nitric acid digestion, 28 Zn - Zinc AAS APHA 3111 B nitric acid digestion, 28 Al - Aluminum AAS APHA 3111 D nitric acid digestion, 28 V - Vanadium AAS APHA 3111 D nitric acid digestion, 28 Hg ­ Mercury cold vapor AAS APHA 3112 B Composite Samples Organics methylene chloride USEPA Method 16 PAH extraction, GC/FID 8100 Biology Microbiology Plate count 16 Macrobiology/soil Berlese extraction 16 ecology microscope Proposed Number of Surface Water- Onshore Technique Method Reference Ghana Samples In Situ Measurements pH electrode APHA 4500-H B 21 Temperature electrode APHA 2550 B 21 Electrical Conductivity electrode APHA 2510 B 21 Salinity electrode 21 Dissolved Oxygen electrode APHA 4500-O G 21 TDS electrode 21 Nutrients Properties & Quality incubation, BOD5 electrode APHA 5210 B 10 closed reflux, COD titrimetric APHA 5220 C 21 distillation, Ammonia Nitrogen titrimetric APHA 4500-NH3 C 21 cadmium reduction, Nitrate Nitrogen colorometric APHA 4500-NO3 E 21 Total Nitrogen macro kjedahl APHA 4500-Norg B 21 Orthophosphate ascorb acid, Phosphorous colorometric APHA 4500-P E 21 March, 2003 Page 26 West African Final Scoping Report Gas Pipeline Proposed Number of Surface Water- Onshore Technique Method Reference Ghana Samples persulfate digest, ascorb acid, Total Phosphorous colorometric APHA 4500-P E 21 dichromated wet TOC oxidation Walkley Black 21 TSS gravimetric APHA 2540 D 21 Sulfate Turbidimetric APHA-SO4 E 21 Alkalinity Titration APHA 2320 B 21 Alkaline Metals (Ca, K, Na) flame photometric APHA 3500 21 Trace Metals nitric acid Cd - Cadmium digestion, AAS APHA 3111 B 21 nitric acid Cr - Chromium digestion, AAS APHA 3111 B 21 nitric acid Cu - Copper digestion, AAS APHA 3111 B 21 nitric acid Fe - Iron digestion, AAS APHA 3111 B 21 nitric acid Mg - Magnesium digestion, AAS APHA 3111 B 21 nitric acid Ni - Nickel digestion, AAS APHA 3111 B 21 nitric acid Pb - Lead digestion, AAS APHA 3111 B 21 nitric acid Zn - Zinc digestion, AAS APHA 3111 B 21 nitric acid Al - Aluminum digestion, AAS APHA 3111 D 21 nitric acid V - Vanadium digestion, AAS APHA 3111 D 21 nitric acid digestion, Cold Hg - Mercury Vapor AAS APHA 3112 B 21 Biology Microbiology plate count 21 Phytoplankton Zooplankton microscope APHA 10200 21 Phytoplankton white-dark oxygen Productivity bottle 21 Proposed Method Number of Onshore Sediment-Ghana Technique Reference Ghana Samples Properties pH electrode APHA 4500-H B 16 Temperature electrode APHA 2550 B 16 Redox Potential electrode 16 Bulk Properties dichromated wet TOC oxidation Walkley Black 16 Grain Size sieve, hydrometer Bouyoucous 16 March, 2003 Page 27 West African Final Scoping Report Gas Pipeline Proposed Method Number of Onshore Sediment-Ghana Technique Reference Ghana Samples Organics methylene chloride USEPA Method Total Hydrocarbons extraction, GC/FID 8015 16 Trace Metals nitric acid digestion, Cd - Cadmium AAS APHA 3111 B 16 nitric acid digestion, Cr - Chromium AAS APHA 3111 B 16 nitric acid digestion, Cu - Copper AAS APHA 3111 B 16 nitric acid digestion, Fe - Iron AAS APHA 3111 B 16 nitric acid digestion, Mg - Magnesium AAS APHA 3111 B 16 nitric acid digestion, Ni - Nickel AAS APHA 3111 B 16 nitric acid digestion, Pb - Lead AAS APHA 3111 B 16 nitric acid digestion, Zn - Zinc AAS APHA 3111 B 16 nitric acid digestion, Al - Aluminum AAS APHA 3111 D 16 nitric acid digestion, V - Vanadium AAS APHA 3111 D 16 nitric acid digestion, Hg - Mercury cold vapor AAS APHA 3112 B 16 Biology Berlese Macro Infauna extraction/microscope 16 The Commercial Group recognizes that wet and dry season investigations are appropriate to establish environmental baseline conditions. The initial draft EIA documents will include baseline results from the initial season of investigation. Information from the second season of investigation will be included in a subsequent EIA submittal or as a monitoring component of an approved Environmental Management Plan, following input received from the Countries. The Commercial Group intends to use the information associated with the existing environmental situation in a number of ways including: · identifying potential areas of high impact due to pipeline construction or operations, as described above · as material for WAGP personnel training and for stakeholder education and reference during construction and operations · as inputs to qualitative and quantitative risk assessments (example air dispersion modeling, potential receptors from catastrophic gas releases or fire hazards, etc.) March, 2003 Page 28 West African Final Scoping Report Gas Pipeline 5.4 Existing Socio-Economic Aspects The Commercial Group recognizes that socio-economic studies of existing conditions are critical to gaining public acceptance of the WAGP Project and minimizing project impacts and disruptions to communities and other stakeholders. Also, as described in the EIA Legal Framework section above, funding from international investors requires submission of socio- economic studies, appropriate compensation and mitigation plans and social reinvestment objectives in addition to environmental impact assessments. The Commercial Group intends to satisfy these requirements through the following efforts: · Stakeholder Consultations as described above · Knowledge, Attitudes, Acceptance and Perception (KAAP) studies · Existing Socio-Economic Characteristics of the areas impacted by the project · The current Local, National and Regional Economic Situation as it relates to WAGP The KAAP study will be conducted in Ghana, Togo, Benin and Nigeria to help in the implementation of the Pipeline Project. Specifically, the study will ascertain how much people in the region know about the project, what it intends to do and its impact on human livelihood. Given the knowledge of the people about the uses of gas and how it will be transported and distributed in the Project, the study will determine the attitudes and perceptions of people towards the project. The study will involve focus group discussions of the population, and the administration of a questionnaire through an in depth interview of a sample of people. One common questionnaire and survey guidelines will be designed and used in all 4 countries. A sample of individuals will be identified in communities along the proposed gas pipeline and those outside the pipeline. The study will be conducted by knowledgeable resource persons based in each country. Other socio-economic studies will focus on population density, infrastructure and life pattern studies for the land components of the pipeline. This data will be compiled with existing and potential employment opportunities, permanent and temporary housing situations and the social interactions of impacted communities to understand how the project might impact local communities and stakeholders. Similar studies will be conducted for fishing communities along the offshore route and near the gas delivery points in Benin, Togo and Ghana. The existing cultural setting of project areas will be appropriately assessed in terms of architecture, cultural events, native/tribal lands, villages, schools, hospitals, homes for the aged, country parks, agricultural areas, fishing camps, hunting reserves, and areas of archaeological, paleological and religious significance. Another significant area of interest to indigenous people and communities will be any real or perceived impacts to water usage including domestic, industrial, recreational, transportation, agricultural, and fisheries. As stated above, one of the primary socio-economic benefits of WAGP is the facilitation of regional economic integration and growth through the delivery of a reliable, cost-competitive, and cleaner burning energy source. Baseline socio-economic assessments will be conducted to quantify this expected benefit, including: · Existing economic activities i.e. local industries, cottage industries, etc. · Local business that could provide services to the project March, 2003 Page 29 West African Final Scoping Report Gas Pipeline · Potential industries that could be developed and the possible constraints in developing these industries · Potential employment opportunities to be generated by the project and the possible constraints in developing these opportunities? · Public expectations in terms of technology transfer, capacity building or social reinvestment? · "Compensation" expectations of the communities · What types of mechanisms would the communities like to see in terms of direct benefit, compensation, etc. · Tax income to the states, direct and indirect · People's perceptions of energy pricing, infrastructure situation, etc. · People's perceptions of Government Energy Policies and Growth Policies · Current Fuel Usage · Perceptions of how reliable energy sources will impact growth, policies, etc. · Perceptions of changing from wood based fuels to electricity and/or natural gas? · Growth projections in terms of GDP and other indicators · Other possible multiplier effects of the project in terms of local and regional economic development and cumulative impacts including possible constraints 6.0 IMPACT ASSESSMENT Generally, the EIA will address impacts in a comprehensive manner, determining whether the impacts are considered: Positive/beneficial or Negative/adverse, Primary/direct or Secondary/indirect, Short Term or Long Term, Reversible or Irreversible. The impacts assessment will incorporate an appropriate level of assessment beyond the immediate or isolated impacts of the WAGP project to put the project in the context of regional development and regional impacts. These impacts will be combined with the project impacts above to determine the cumulative impacts related to the WAGP Project. As an example, natural gas production from Nigeria and gas consumption in Benin, Togo and Ghana are potential areas of assessment ancillary to the West African Gas Pipeline. However, since these impacts are outside the immediate scope of the WAGP project, the EIA for the pipeline will only outline these ancillary impacts. It is expected that in accordance with the applicable laws in each of the countries those projects will undergo or have already undergone separate detailed impact assessments. More specifically, and in the context of the existing health, safety and environmental and socio-economic aspects of the project, the impact assessment will identify significant impacts associated with: March, 2003 Page 30 West African Final Scoping Report Gas Pipeline · Future land usage; · Health and safety impacts to both local · Impacts to existing features; communities and WAGP personnel · Historic land use; · Conditions and processes in the natural · Ways of life; environment; · Energy supply/demand; · Significant air quality and standards · Local, National and Regional violations; Economic Benefit Assessments · Ground and surface water quality/ quantity · WAGP Social Reinvestment changes; opportunities as appropriate for · Water uses; community and regional impacts · Encroachment issues (wetlands, coastal · Significant noise zones, fish habitat, wildlife habitat, wild and · Populations scenic rivers, areas of biodiversity) · Changes associated with imported pests, disease vectors, fish migration routes, and fish nursery areas. Screening criteria, including probability, magnitude, prevalence, risks, importance, and effectiveness of mitigation measures, will be used to assess the significance of project impacts. This screening will cover all activity phases of the project including site investigation/ preparation, construction, construction support, transportation, raw materials supply, operations and maintenance, future and related activities, and ultimately decommissioning of the facility. Expected areas of impact include the physical, chemical, biological, aesthetic, and socio-economic aspects of WAGP in addition to understanding the relationships between activities and areas. Methodology and approach are critical to developing impact assessments that are comprehensive and credible to stakeholders. As discussed above, specific measurable indicators of impact probability, magnitude and significance will be developed. In developing these indicators, the project will provide stakeholders a context and framework that includes the extent and quality of available data and sources of information, along with the assumptions, uncertainties and degrees of confidence associated with both explicit and risk based assessments. Appendix 4A and 4B outline the potential positive and negative aspects of the West African Gas Pipeline project in terms of health, safety, environmental and socio-economic impacts. As described above, the Commercial Group intends to quantify the probability and severity of these and other identified impacts during the course of the EIA. 7.0 MITIGATING AND AMELIORATING MEASURES This section of the EIA will focus on enhancing the positive impacts of the project and avoiding, reducing or mitigating negative impacts of WAGP. Potential benefit enhancement opportunities include: X-Potential Application to WAGP March, 2003 Page 31 West African Final Scoping Report Gas Pipeline Mitigation Measure Pre- Construction Construction Operations Decommissioning Additional commercial commitments to transport natural gas, further X reducing green house gas emissions Technology transfer X X X and/or capacity building Social reinvestment X X X Potential avoidance or mitigation measures could include: X-Potential Application to WAGP Mitigation Measure Pre- Construction Construction Operations Decommissioning Project location/siting X X Design adjustments and/or X X new technology application Early warning and X X emergency shut down controls Construction adjustments X X Schedule adjustments X X Environmental and socio- X X X economic education and orientation Notices and/or barriers X X X placed at strategic locations along the onshore pipeline route warning the public Notifications to local and X international cartographic, survey and marine authorities to update and publish nautical charts and topographic maps. For residual or X X unavoidable impacts, rehabilitation of impaired features or some type of offsite compensation or enhancement of similar resources. March, 2003 Page 32 West African Final Scoping Report Gas Pipeline Mitigation Measure Pre- Construction Construction Operations Decommissioning Erosion and sediment X X X X control Vegetation control X X HSE Management X X X Systems including · Compliance Assurance · Safe Operations · Pollution Prevention · Emergency Preparedness and Response In developing mitigation measures and the subsequent Environmental Management Plan, the Commercial Group recognizes that certain adjustments to mitigation measures may be needed due to · changes from baseline assessments · new information · ineffectiveness of mitigation measures As appropriate, and in consultation with the Countries and other stakeholders, the Commercial Group will modify proposed mitigation measures and other elements of the Environmental Management Plan. Appendix 5 provides a more detailed list of mitigation measures that the Commercial Group will consider in conducting the EIA and in developing it's project execution plans. 8.0 DETAILED ALTERNATIVES ANALYSIS The Detailed Alternatives Analysis section of the EIA will provide a bridge between the project impacts and the proposed mitigation measures and ultimately the Environmental Management Plan. It will be more specific in nature including explicit and risk based assessments of: · Best Available/ Practicable Technologies · Feasibility · Associated health/safety, environmental and/or socio-economic benefits · Monitoring requirements · Local and regional suitability, including stakeholder acceptance · Institutional requirements · Training requirements · Costs (capital and operating) Specific alternative scenarios will include: · Site Selection and Routing · Design Considerations March, 2003 Page 33 West African Final Scoping Report Gas Pipeline · Raw material sources · Project Implementation including site preparation, construction, construction support, personnel and material requirements, and commissioning/start-up · Pipeline Operations · Mitigation measures to avoid project impacts and measures associated with residual or unavoidable impacts Continuous stakeholder consultations will provide a critical input to the alternatives analysis, in terms of idea/scenario generation and acceptance of the Proposed Alternative. 9.0 PROPOSED TERMS OF REFERENCE In accordance with the legal and technical directives of the Countries, the Commercial Group commits to the following regarding Environmental Impact Assessment requirements: 9.1 Project Submission 9.1.1 Project Registration/Application This document is included in the EIA registration/application as a means to describe the project for the purposes of agency screening and to: Indicate the preliminary environmental, health and safety impacts of the project; Indicate a clear commitment, to the extent possible, to avoid adverse environmental, health and safety impacts during implementation of the project; Indicate a clear commitment, to the extent possible, to address unavoidable environmental, health and safety impacts and steps where necessary for their reduction; and Provide a summary of alternatives that will be considered in the EIA Report or Impact Statement submittal. 9.1.2 Registration/Application Fees and EIA Agency Resource Requests Consistent with each country's EIA process, the Commercial Group, as part of the application process, includes the appropriate application fees in the registration documents. Within a reasonable time frame following EIA registration/application, the EIA Agencies will formally advise the Commercial Group of estimated fees and charges necessary for Agency oversight and review of WAGP EIA documents. The Commercial Group requests in this EIA application/registration that appropriate EIA agency resources be identified and dedicated to the Commercial Group to: Ensure compliance with each country's EIA requirements. March, 2003 Page 34 West African Final Scoping Report Gas Pipeline Without sacrificing transparency or independence, ensure appropriate efficiency and comprehensiveness in the implementation of baseline studies, impact assessments, stakeholder consultations, agency review and agency decisions regarding approval of EIA submittals. 9.1.3 EIA Report Focus Areas (draft terms of reference) In submitting the EIA application/registration documents, the Commercial Group commits that subsequent environmental impact assessments, statements or reports will appropriately address the following A description of the project An analysis of the need for the undertaking Alternatives to the project including the "no project" alternative Matters on site selection including rationales for the choice of the proposed site and alternative site considerations An identification of existing, relevant health, safety and environmental conditions including social, economic and other aspects of potential concerns Information on potential, positive and negative impacts of the project from the environmental, social, economic and cultural aspects in relation to the different phases of development of the project The potential impact on the health of project personnel and the surrounding communities Proposals to mitigate potential negative socio-economic, cultural and public health impacts of the project Proposals to be developed to monitor predictable environmental impact and proposed mitigation measures Contingency plans (existing or to be evolved) to address any unpredicted negative health, environmental or safety effect Consultation with members of the public likely to be affected by WAGP operations Maps, plans, tables graphs, diagrams and other illustrative material that will assist with comprehension of environmental impact assessment documents A provisional environmental management plan Appropriate details regarding the payment of compensation for possible damage to land or property arising from WAGP Indications of potential regional, national, or international impacts March, 2003 Page 35 West African Final Scoping Report Gas Pipeline It is intended that this proposed Terms of Reference/Scoping document provides the detail necessary to demonstrate the commitment of the Commercial Group to submit EIA documents containing the areas of emphasis listed above. 9.1.4 Project Presentations As needed following project registration/application, the Commercial Group will provide summary presentations to appropriate agencies and approval authorities in each country. These presentations will introduce the project, include a summary of this Terms of Reference/Scoping document, and provide information regarding Project personnel and consultant experience in natural gas, pipeline operations and EIA preparation. 9.2 EIA Implementation and Document Preparation 10.2.1 Stakeholder Consultations Immediately following EIA registration, the Commercial Group commits to a Stakeholder Consultation and Engagement process consistent with Section 4 of this document. 10.2.2 WAGP/Agency Interaction and Collaboration As appropriate, and without sacrificing the transparency or independence of the EIA agencies or EIA consultants, WAGP and it's EIA consultants will interface and collaborate with the government agencies having EIA approval authority and other appropriate agencies in each country. Some interface and collaboration is expected to occur at a regional level (i.e. involving all 4 countries) to ensure harmonization and consistency across the 4 countries associated with WAGP. At other times, it will be more appropriate to interface at a National, State or local level. Areas of interface identified to date include: Work Plans for Environmental and Socio-economic baseline surveys Adjustments and evolution of the Stakeholder Consultation Plan Stakeholder Consultation participation by the Commercial Group, the Countries or both Results of Stakeholder Consultations Progress reports on the preparation of EIA documents Preliminary discussion of mitigation measures and environmental management plans (particularly in terms of trans-boundary issues) Health and Safety Design reviews with other agencies and competent authorities, as outlined in Section 2.7.1 (Engineering Activities). 10.2.3 Continuing EIA Support and Processing Fees March, 2003 Page 36 West African Final Scoping Report Gas Pipeline Consistent with the legal requirements in each country, the to-be-developed Concession Agreement, and as identified following EIA registration/application, the Commercial Group commits to timely payment of appropriate EIA support and processing fees and other costs that could include one or more of the following: Skills Reinforcement Workshops, Capacity Building and/or Technology Transfer EIA Agency Monitoring And Assisting The Promoter In The Field "Public Information and Sensitization" (i.e. Stakeholder Consultations) Regional Environmental & Permitting Group Meetings Regional EIA Report Review Workshops 9.3 EIA Document Submissions and Agency Review 9.3.1 EIA Document Content and Structure Consistent with the legal requirements in each country, the Commercial Group commits to submittal of the following EIA documents and supporting information: Benin Environmental Evaluation Dossier (Environmental Impact Studies) Ghana Environmental Impact Statement for the purposes of receiving a Environmental Permit. Nigeria EIA Report leading to an Environmental Impact Statement and Certification (FMEnv) EIA Report (DPR) Togo Environmental Evaluation Dossier (Environmental Impact Studies) The Commercial Group intends for these EIA documents to be concise and be confined to the most important environmental problems. The main text will focus on results, conclusions and recommendations with the support of tables summarizing the collected data and of the appropriate references. Detailed and un-interpreted data will be presented in the appendices or in a separate volume. The reports will be written in French and English and will be structured/formatted as follows: Title Page including Project Title, Promoter's Name, Author(s) of study, Competent Authority for the project, Authority to which the study is addressed, and Date Summary Table of Contents List of Tables, Figures, and Attachments, including a Table of Acronyms and Abbreviations EIA Preparers Acknowledgements Executive Summary Introduction, including the Project Proposal and Project Justification The Body of Report including 1. Project context and description 2. Description of receptor environments 3. Description and analysis of project alternatives March, 2003 Page 37 West African Final Scoping Report Gas Pipeline 4. Impact analysis of selected alternative from all standpoints (environment, natural resources, social, economic, health, safety, etc.) Proposed Mitigation Measures Technological Risks & Contingency Plan Environmental Management Plan Conclusions Bibliography and other references Attachments and Appendices This Terms of Reference/Scoping Document provides additional details on the intended EIA report contents, following the structure/format above. All information the Commercial Group considers confidential shall be presented in a separate report. The requisite number of copies of the complete study, both in electronic format and hard copy, will be provided to each country. 9.3.2 Environmental Management Plan Considerations The Environmental Management Plan (EMP) will be developed and used as a tool in the construction and operation of WAGP to minimize and mitigate significant negative impacts from the project. Components of the Environmental Management Plan include monitoring, documentation, evaluation, prediction, warning, prevention, control and reduction of impacts identified in the EIA. The Environmental Management Plan shall also include activities intended to enhance the positive environmental, safety and socio- economic aspects of the Pipeline. The Environmental Management Plan shall provide a means to ensure that legal air and water standards are complied with and that proper waste minimization and waste management processes are implemented. Ecological mitigation measures shall be included in the Environmental Management Plan addressing impacts to vegetation, wildlife, marine ecosystems and bio-diversity. The Environmental Management Plan will provide a means to assess the effectiveness of these mitigation measures. Socio- economic mitigation measures will be identified in the Environmental Management Plan to reduce negative impacts to communities and to enhance the positive benefits of the project to the communities, the States and the region. Particularly for surveillance and monitoring, specific measurement parameters will be recommended, including measurement methods, locations, frequency and action thresholds. Appropriate thresholds will include those that forewarn or immediately warn of unfavorable project impacts, but that also trigger project execution controls to eliminate or minimize the level of impact or that lead to governmental reporting/ enforcement. The following specific components will be included in the EMP. · Evolution of the erosion phenomena and reestablishment of natural drainage before and after pipeline layout and burial March, 2003 Page 38 West African Final Scoping Report Gas Pipeline · Restoration of vegetal cover and productivity of agricultural zones put back in exploitation after the work · Efficiency of actions taken to preserve sensitive areas · Follow-up of impact on marine biodiversity and fishing and maritime transportation activities · ROW Surveilance and other monitoring along the pipeline, particularly for any socio-economic encroachment · Notices at strategic locations along the pipeline (warnings, safety, etc.) · Other appropriate mitigation measures as identified in Section 7 and Appendix 5. Waste Management The general waste management philosophy adopted by the project to handle wastes can be summarized as; · Utilize processes that inherently generate less waste streams · Modify process as required to minimize waste quantities generated from source · Maximize recycle or re-use of waste streams after appropriate treatment · Utilize safe storage and handling procedures for hazardous waste streams · Effective monitoring and control of disposal units, with early warning systems · Inventory control, audit and post project evaluation of regulatory trend to ensure continued compliance Air Emissions During the front end engineering phase of the WAGP project, all air emissions, major & minor, resulting from continuous, intermittent or upset conditions of any of the pipeline equipment will be characterized. Each stream will be evaluated to ensure that there are no components which violate 'Air pollutant emission limits' standards. Emergency Prevention, Preparedness and Response The Commercial Group intends to develop an Emergency Preparedness and Response Plan for inclusion in the WAGP EIA and in line with permit requirements for each of the countries. The following steps are anticipated in the development of this plan; · Assessment of hazards and risks of an unplanned incident to both the communities and WAGP personnel; · Plan Development for managing those hazards and risks; · Communication of relevant information to employees, contractors, appropriate agencies and the public; · Barriers etc. to minimize exposure · Conducting emergency response exercises independently and in co-ordination with community support organisations; · Responding immediately and appropriately to incidents, providing the necessary financial, technical and personnel resources to effectively respond. March, 2003 Page 39 West African Final Scoping Report Gas Pipeline Energy and Resource Conservation The Commercial group will, to the extent possible, conserve and protect natural resources. As most of the negative impacts are likely to occur during construction, the Commercial Group will pay particular attention to ecological, water, and other natural resource issues during routing, siting and execution planning. Water resources are the most likely resource that could be affected during pipeline operations. This EIA and the development of a natural resources inventory will identify those natural resources most at risk. This EIA and subsequent monitoring and analyses during the construction and operational phase will be used to continuously identify potential pathways of exposure and potential or actual receptors affected by releases and emissions. Pathways may include air dispersion and contamination of surface water or groundwater. Receptors can be local communities and sensitive ecological habitats. The Commercial Group will also a natural resource damage assessment plan in the unlikely event of an unplanned, negative event, so that the response and post-incident mitigation is timely and effective. For unavoidable adverse impacts, the Commercial Group will develop and implement certain mitigation measures e.g., personnel training, activity scheduling, and reclamation. HSE Management Systems As discussed above in Mitigation Measures, HSE Management Systems will be established for WAGP construction and operations, including, but not limited to the following aspects: · Compliance Assurance · Safe Operations · Pollution Prevention · Prevention of gas leaks and subsequent environmental impact · Emergency Preparedness/Response In support of these and other components, the Commercial Group will establish policies, objectives, procedures, monitoring/reporting processes and responsibilities, in addition to providing the necessary resources (funding, people) for implementation. Additional details will be provided in the submitted EMP, including a schedule of implementation as the Project scope, associated impacts and proposed mitigation measure are better defined. 9.3.3 Public Notification, Display, and Review Consistent with each country's laws and regulations, the Commercial Group will adhere to the public notice, display and review procedures with particular attention paid to: Appropriate and timely advertisements and notices to interested parties either directly or through appropriate media (newspaper, radio, town hall etc.). Provisions made for additional copies of the EIA documents March, 2003 Page 40 West African Final Scoping Report Gas Pipeline The required durations of notices and display Commercial Group participation at public forums following notification and display periods. 9.3.4 Continuing EIA Support, Review Processing and Approval Fees Consistent with the legal requirements in each country, the to-be-developed Concession Agreement, and as identified following EIA registration/application, the Commercial Group commits to timely payment of appropriate EIA support and processing fees and other costs that could include one or more of the following: Continuing Skills Reinforcement Workshops, Capacity Building and/or Technology Transfer (particularly for Report Review Commissions, Panels, etc.) Administration Of Panel Review, Report Display, and Public Hearing Advertisement "Commission Study Evaluation Workshop", "Public Hearing" or "Public Meeting" Expenses for the purposes of information or debate. Appropriate "Media Coverage: Radio, Press, and Television Logistics arrangements for certain (appropriate?) attendees at Public Hearing Appropriate expenses associated with review, report validation and decision making by "Public Hearing Commissions", In-house Agency personnel or equivalent bodies. Administrative Charges, Processing and Permit Fees (for Clearance/Approval) Environmental Certification Fees (in Ghana, see 10.4 below) Appropriate Environmental Management Plan Monitoring Expenses (see 10.4 below) 9.4 Post EIA Approval After the EIA is approved, and consistent with the legal requirements in each country, and/or as established through the to-be-developed WAGP Concession Agreement, the Commercial Group intends to pursue the following with the continued support and input from the Countries EIA agencies and other Country government representatives: Obtain other authorities, licenses or approvals to Construct and Operate WAGP Implement the Environmental Management Plan in terms of pre-construction resource commitments (personnel, HSE funding, etc.) Begin pre-construction and construction activities. Implement the Environmental Management Plan as approved by the Countries. As detailed in the approved Environmental Management Plan, monitor HSE and socio-economic impacts and adjust the Environmental Management Plan accordingly. In Ghana, obtain an Environmental Certificate following evidence of commencing operations (assumed to include construction) and conformance with the approved Environmental Management Plan. WAPCo would then submit an Annual Environmental Report as required per Ghanaian law. March, 2003 Page 41 West African Final Scoping Report Gas Pipeline APPENDIX A GHANA EIA SCOPING CONSULTATIONS-SUMMARY OF ISSUES RAISED WEST AFRICAN GAS PIPELINE TEMA ACCRA TAKORADI PREVIOUS Scoping Consultations Issue (11/7/2002) 11/29/2002 (12/11/2002) CONSULTATIONS STAKEHOLDER CONSULTATIONS Past & Future consultations with other stakeholders. X X X (GHPA, GFZB, Ministry of Transport & Communications, after EIA reports, Env. NGO's) Publicity and Awareness Raising X (Move from Low Profile) COMMUNITY INTERACTIONS AND RELATIONSHIPS Community Development Benefits & Commitments X 2 X Project Education for & Partnership with the communities to X X X X prevent problems PROJECT INFORMATION Cost of the Project X Pipeline & Facility Location (proximity to communities) X Routing and Siting (advantages of offshore) X Specific details-onshore transportation routes X Status of Effasu as a Delivery Point X Extension/Expansion of the Pipeline (Cote d'Ivoire) X Depth of Pipeline X Onshore and Offshore Construction Details (blasting) X 3 Operational Life X Contingency Plans for Implementation X Implementation Timing and Durations X How do we intend to conduct underwater repairs X PROJECT ECONOMICS World Bank Funding, Guarantees X Revenue Allocation & Distribution X Gas Demands, Forecasts, Development of non-Power gas X utilization Competition with LPG, Other petroleum issues X X March, 2003 Page A-1 APPENDIX A GHANA EIA SCOPING CONSULTATIONS-SUMMARY OF ISSUES RAISED WEST AFRICAN GAS PIPELINE TEMA ACCRA TAKORADI PREVIOUS Scoping Consultations Issue (11/7/2002) 11/29/2002 (12/11/2002) CONSULTATIONS Impacts of gas use in Power Generation X Investment protection, liability management, etc. X Uniform Tariffs Affordable Cost of Gas X Assurances of Continuous Gas Supply X PROJECT BENEFITS Employment Opportunities X X X Impacts on Gas Flaring X Greenhouse Gas Impacts and Reduction X EIA IMPLEMENTATION EIA conducted independently Expectations for a Complete EIA (no cutting corners) X EIA Standards 2 World Bank, Countries Appropriate Duration for Studies Socio-Economic Studies X EIA Harmonization Efforts (and each country's requirements) X X EIA Alternatives Analysis (solar, downsides to pipelines) X X EIA Terms of Reference ­Document Distribution for Comment X EIA Timing (should be done from project inception) X POTENTIAL NEGATIVE IMPACTS & MITIGATION MEASURES Pipeline sabotage X X X Fires and Explosions X Impacts to Fishing X 3 X Offshore Mitigation Measures (marine charting, etc.) X Health Impacts X Safety Systems (shutdowns, etc.) X Emergency Response Plans (and compensation) X EMP-Post Construction Monitoring X Topsoil Management and Tree Replacement X March, 2003 Page A-2 APPENDIX A GHANA EIA SCOPING CONSULTATIONS-SUMMARY OF ISSUES RAISED WEST AFRICAN GAS PIPELINE TEMA ACCRA TAKORADI PREVIOUS Scoping Consultations Issue (11/7/2002) 11/29/2002 (12/11/2002) CONSULTATIONS Appropriate Land Compensation X Impact to Pipeline from Boat Abandonments X OTHER Relationship of the Project to Niger Delta Conflicts X March, 2003 Page A-3 APPENDIX A GHANA EIA SCOPING CONSULTATIONS-SUMMARY OF ISSUES RAISED WEST AFRICAN GAS PIPELINE REPORT ON THE FIRST ROUND OF SCOPING CONSULTATIONS WITH STAKEHOLDERS IN GHANA ON THE WAGP EIA PROCESS (NOVEMBER-DECEMBER, 2002) INTRODUCTION In line with the EIA Procedures of the Environmental Protection Agency of Ghana, the sponsors of the West African Gas Pipeline Project (WAGP) formally registered the Project with the Agency on 19th August 2002. This singular action launched the WAGP EIA programme in Ghana. Three (3) Scoping Consultation Meetings were organised by the External Affairs Group in Ghana to interact with stakeholders of the Project at Tema, Accra and Takoradi/Aboadze Site of the VRA Thermal Power Plant. These consultations with Host Communities, Institutional, Public Agencies and NGO stakeholders, provided a platform for WAGP to brief interested parties about the project and the EIA programme in Ghana. These consultations also provided opportunities for various stakeholders to openly express their views on any potential and significant environmental and socio-economic impacts which the construction and post-construction operations of the pipeline might have. The concerns expressed are to be factored into the EIA process and the WAGP Environmental Management Plan (EMP). The following is a report on the consultations at the various venues. It is planned to continue with the consultations in 2003. MODE OF INVITATION Separate adverts announcing the Scoping Consultation meetings were placed in the national widely-read newspapers and local FM Radio Stations inviting the interested parties and the general public to the meetings. March, 2003 Page A-4 APPENDIX A GHANA EIA SCOPING CONSULTATIONS-SUMMARY OF ISSUES RAISED WEST AFRICAN GAS PIPELINE Additionally, invitation letters with extracts from the Project's Preliminary EIA Scoping Report lodged with the EPA were sent to specific stakeholder institutions, public agencies, NGOs and other interest groups. Copies of the wording of the public adverts and invitation lists are included in this report. PRESENTATION FORMAT A programme was prepared for each forum and it consisted of presentations by the Project staff and local EIA Consultant on various aspects of the Project. Time was allowed for the participants to ask questions for which answers were provided. In the event that a participant made a comment or suggestion these were noted. The presentations made at each forum followed the following general order: · WAGP Overview: Current Status and Future Schedule · Considerations in Determination of WAGP Routing and Future EIA Submittal Milestones. · Review of Objectives/Terms of Reference of Preliminary EIA Scoping Report · Overview of Environmental Baseline Study · Evolution of Natural Gas Market in Ghana & Overview of Safety Aspects of Natural Gas Pipeline Systems. The principal speakers at each forum were the External Affairs Manager of the Project, Mr. Kofi Asante Okai and the Local EIA Consultant from the Department of Oceanography and Fisheries, University of Ghana, Mr. A. K. Armah. In his presentations at each of the venues, Mr Okai reminded the participants that the principal objective of the project is to enable customers in Benin, Togo and Ghana to access natural gas from Nigeria as fuel for power generation and industrial development. This will help accelerate regional economic growth and development, provide clean energy for the sub-region and stimulate private investment in West Africa. March, 2003 Page A-5 APPENDIX A GHANA EIA SCOPING CONSULTATIONS-SUMMARY OF ISSUES RAISED WEST AFRICAN GAS PIPELINE Participants were always reminded to feel free to ask any questions they had about the project since the essence of the meetings was to initiate a 2-way dialogue to facilitate the EIA process and to ensure that all legitimate views of as many stakeholders as possible are captured. On the advantages of the project, the following were articulated: · Gas will be a cheaper substitute for LCO, leading to about one third savings in fuel cost · There will be tax benefit accruals to the participating countries · Will reduce the incidence of gas flaring considerably in Nigeria · The project offers good opportunities for exchange of knowledge and experience among State Agencies, Project Developer, International and local contractors & consultants. On the characteristics of the pipeline, it was explained that it will be about 617 kilometres in total length. The 57 km stretch of the pipeline from the Alagbado- Tee to the Lagos Beach in Nigeria will be about 30" in diameter. There will be 18000 HP Compressor Station at Lagos Beach. From Lagos Beach, the Pipeline will be buried to a depth of about 33-100 meters over a distance of about 560 km to Takoradi in Ghana. From the Lagos Beach the pipeline will consist of an 18-20" diameter main trunkline and be laid offshore. There will be spur lines at Cotonou, Lome, Tema and Takoradi to bring the gas to the R&M stations on the shore lines at those locations. The overall project cost is expected to be in the region of $500 million with $70 million estimated as the pre-development cost. The Project Sponsors and their equity interests were given as follows: · Chevron - 36.7% · NNPC - 25% · SPDC - 18% · VRA - 16.3% · SOBEGAZ - 2.% · SOTOGAZ - 2% The key principles for the project development were also summarised as follows: · Funding of the project will be by equity from the sponsors March, 2003 Page A-6 APPENDIX A GHANA EIA SCOPING CONSULTATIONS-SUMMARY OF ISSUES RAISED WEST AFRICAN GAS PIPELINE · The project will be commercially driven · The project is committed to very high HSE standards · The project will make some contribution to the development of the host communities On the current status of the project, participants were informed that the EIA baseline data collection for the first season, both on-shore and off-shore Engineering Surveys and the Front- End Engineering Design of the project are in progress. Two documents, namely, the International Project Agreement and the West Africa Gas Pipeline Treaty will be laid before the countries early next year. The final investment decision on the project is expected to be taken in December 2003 and first gas expected mid 2005. The following were indicated as the routing considerations for the onshore segment of the pipeline: · Safety · Land availability · Population density · Environmental sensitivities · Ease of construction (i.e. swamp vrs dry land) · Ease of access for construction and operation · Routine maintenance issues · Cost-both initial capital investment and operational cost The following were also given as the routing considerations for the off--shore portion of the pipeline: · Avoid bottom hazards such as shallow gas, corals, deep canyons etc. · Minimize impact to local fishing and boating activities · Minimize impact to environment · Avoid mud- slide areas · Avoid active faults · Avoid high erosion areas · Minimize cost impacts · Avoid restricted areas( cables, security installations etc) March, 2003 Page A-7 APPENDIX A GHANA EIA SCOPING CONSULTATIONS-SUMMARY OF ISSUES RAISED WEST AFRICAN GAS PIPELINE On his part and at all the venues, the local EIA expert explained the overall objective of the WAGP EIA study as to evaluate and assess the potential benefits and impacts of the proposed pipeline construction and operations on the health, safety, environment and socio-economic conditions in the project work areas. More specifically, it is to determine if WAGP's construction activities and post- construction operations, including emergency situations may have persistent, non-localised adverse impacts on the environment. He then went on to explain at each of the venues the details of the studies being undertaken. March, 2003 Page A-8 APPENDIX A GHANA EIA SCOPING CONSULTATIONS-SUMMARY OF ISSUES RAISED WEST AFRICAN GAS PIPELINE THE CONSULTATION AT TEMA NEW TOWN ON THURSDAY 7TH NOVEMBER 2002 The programme was held at the Conference Room of the Tema Traditional Council within the palace of the Chief of Tema Manhean. In addition to the public invitation by way of adverts in the local newspapers, letters of invitation were sent to the following institutions, agencies and personalities: 1. Nii Adjei Kraku II Tema Traditional Council & various groups Tema Manheam 2. Nii Tetteh OTU II Kpone Traditional Council & various groups Kpone, Tema 3. Chief Executive Tema Metropolitan Assembly Tema. 4. Ag. Managing Director Tema Development Corporation Attn: Survey/Planning Dept Tema. 5. Managing Director Ghana Ports & Harbours Authority Tema 6. Managing Director/ Director of Energy VALCO Tema 7. Director Dept. of Fisheries Tema March, 2003 Page A-9 APPENDIX A GHANA EIA SCOPING CONSULTATIONS-SUMMARY OF ISSUES RAISED WEST AFRICAN GAS PIPELINE 8. Commander Eastern Naval Command Tema 9. Programmes Officer EPA Tema 10. Free Zones Authority Tema 11. NGOs Tema The actual attendance list can, however, be found in Appendix 1 of the report. After going through the various presentations as outlined above, the floor was opened for questions, comments and clarifications from the participants. QUESTIONS AND ANSWERS: Key Issues Arising Question (Mr. Fugah ­ GPHA) Wish to request that a full technical presentation of the project is made to some selected institutions like the GHPA additional to this forum intended for predominantly Community Stakeholders. Incidence of pipeline sabotage are frequently reported in Nigeria, what measures have you put in place to avoid this in Ghana? Oftentimes promises are made to communities during EIA stage of a project only to be forgotten after the project has been implemented. Make sure your promises are honoured as a safeguard against problems or sabotage of the pipeline. Answer Your request has been noted. March, 2003 Page A-10 APPENDIX A GHANA EIA SCOPING CONSULTATIONS-SUMMARY OF ISSUES RAISED WEST AFRICAN GAS PIPELINE Prevention of pipeline sabotage is being addressed in many fronts e.g. selection of routing, technical specification of pipe and public awareness creation and education. Being a natural gas pipeline there will be no product to be scooped if the pipeline is vandalized or broken through. The project is not making any promises beyond compensation payment for lands acquired and contribution to Community Development based on the level of impacts assessed & within budget limits. Indeed, the Tema & Kpone Traditional Councils may start thinking of priority areas where they need community development support. They may also start identifying Community Liaisons to facilitate interactions with the Project Personnel. Consultations will be held as often as is necessary to ensure that the right thing is done at all times. Question (Nii Abbey Adjeitey ­ Dzasetse) Which road will be used to convey equipment to the R&M site? I suggest you use the Southern Shore road because it links Tema and Kpone. Its development will enhance economic life in the area. Answer Your comment has been noted and will be passed on to the engineers for consideration. Question/Contribution (Thomas Manu-GNPC) On the issue of sabotage, when the community is involved in a project they feel partnership with the project and so will not wilfully sabotage it. The consultations with the community should be broad based eg. Chiefs, youth and other social groups because each has its own development agenda and some level of education and awareness creation is necessary. Answer Agreed. The project has planned programmes to this effect in all the communities and countries, Question (Tamara Quaye) We are always told that there are job avenues in this area but still the youth go round looking for jobs and find nothing. This project as explained will require both skilled and unskilled labour. In the case of those numerous youth without March, 2003 Page A-11 APPENDIX A GHANA EIA SCOPING CONSULTATIONS-SUMMARY OF ISSUES RAISED WEST AFRICAN GAS PIPELINE skills, what is the Traditional Council doing to ensure that some of them acquire some skills so as to get decent jobs on the project. Answer (Mr. Nortey-Kpone Traditional Council) The Traditional Councils of Tema and Kpone have in recent times become concerned about the way children abandon school during the fishing season to chase money at the expense of their education and also the incidence of teenage pregnancies. These are issues that they have set themselves to address by beginning a project of awareness creation for parents in the two Traditional areas. We believe that when we are successful our children may be able to focus on receiving some level of education which will spur them on to achieve greater things. But you must realise that this is not a short term undertaking and so those who are fortunate will still have to do the unskilled jobs that may be available on the project for now. The skilled jobs will require expertise that obviously may not be available in this area for now. Question (Asenso-Boakye, Ghana Free Zones Board) GFZB will be a beneficiary of this project because we are managing zones that will encourage manufacturing for export. One of the zones is operational now in Tema and also we are about to acquire 2000 acre space in Sekondi. The GFZB will want to be invited to the institutional presentation. Answer This request has been noted. Question (Edward Ashietey Armaah) Normally when people come to on projects they talk beautifully and make various promises. Let your yes be yes and at the point of implementation honour all your promises. Answer We have made no promises and in fact the project is not in a position to make promises. At every stage of the project we will do what is right by engaging and consulting with all stakeholders as often as is reasonable. March, 2003 Page A-12 APPENDIX A GHANA EIA SCOPING CONSULTATIONS-SUMMARY OF ISSUES RAISED WEST AFRICAN GAS PIPELINE Question (Ag. Dzasetse) The local EIA consultants must ensure that there are no cutting of corners by those to do the job and they must keep the community involved at all times. Answer (Mr. G. A. Dapaah) We will ensure that the right thing is done at all times. Rapporteur's notes 1. The traditional councils were informed that the EIA study around the Tema R&M would commence the following Monday, and they agreed to provide contact persons to assist the local consultants in the field. CONCLUSION The meeting came to an end at 2.35pm after lunch had been shared and a group picture of the participants had been taken. March, 2003 Page A-13 APPENDIX A GHANA EIA SCOPING CONSULTATIONS-SUMMARY OF ISSUES RAISED WEST AFRICAN GAS PIPELINE THE PUBLIC AGENCIES /INSTITUTIONAL STAKEHOLDERS /NGO CONSULTATION FORUM IN ACCRA HELD ON 29TH NOVEMBER 2002 The programme was held at the STEPRI auditorium in Accra. In addition to the adverts placed in the local newspapers to this effect, letters of invitation were sent specifically to the various institutions, agencies and personalities listed below: 1. Chief Executive VRA Accra 2. The President National Canoe Fishermen Association Headquarters Accra 3. The Executive Secretary Energy Commission Accra 4. The Executive Director EPA Accra 5. Chief Director Ministry of Environment & Science Accra 6. The Executive Secretary Energy Foundation Accra 7. Chief of Naval Staff Ghana Navy Headquarters Accra March, 2003 Page A-14 APPENDIX A GHANA EIA SCOPING CONSULTATIONS-SUMMARY OF ISSUES RAISED WEST AFRICAN GAS PIPELINE 8. The President Ghana Journalists Association Accra 9. The Executive Secretary Ghana Chamber of Commerce Accra 10. Chief Fire Officer Ghana Fire Service Headquarters, Accra 11. Executive Secretary Ghana Association of Industries Accra 12. Executive Secretary Lands Commission Accra 13. Chief Director Ministry of Energy Accra 14. Chief Director Ministry of Food & Agriculture Dept. of Fisheries Accra 15. Executive Secretary National Development Planning Commission Accra 16. Chief Director Ministry of Lands & Forestry Accra March, 2003 Page A-15 APPENDIX A GHANA EIA SCOPING CONSULTATIONS-SUMMARY OF ISSUES RAISED WEST AFRICAN GAS PIPELINE 17. Executive Secretary Ghana Shippers Council Accra 18. University of Ghana · Dept. of Geography & Resource Development · ISSER · Dept. of Oceanography & Fisheries 19. NGOs · Friends of the Earth · Network of Energy and Environment · Green Earth Organisation · Third World Network · CEPIL 20. Director-General Council for Scientific & Industrial Research Accra The actual attendance list can be found in Appendix 2 of this report. After going through the formal presentations by Messrs Asante Okai and A. K. Armah, the floor was declared opened for questions, comments and contributions from the participants. QUESTIONS AND ANSWERS: KEY ISSUES ARISING Question (Mr. Kuforgbe, Dept. of Geography Univ. of Ghana) What is the position of Effasu as an optional segment? Some explanation is needed. Answer No customer has made any commitment in respect of Effasu and no letter of intent for Gas Sales has been received from any interested party. It is a matter of public knowledge that the Government intends, for the time being, to develop the Tano Fields to provide the gas needed to fire the "Osagyefo Barge". The March, 2003 Page A-16 APPENDIX A GHANA EIA SCOPING CONSULTATIONS-SUMMARY OF ISSUES RAISED WEST AFRICAN GAS PIPELINE WAGP is a commercial project and if approached, the sponsors will evaluate the commercial viability of the segment and make the appropriate decision in the future. Question (Ben Sackey, VRA) You indicated that the project is being funded only by equity by the sponsors. Is there any role in the project for International Funding Agencies providing guarantees etc. because this will affect the EIA procedure? Answer The World Bank is giving assistance to VRA through MIGA as partial risk guarantee for the Gas Sales Agreement. The International Funding Agencies are not providing any direct funding for the project. This means that the EIA will have to be conducted in a much broader framework. But as you already are aware, the project is committed to conducting a world class EIA. Question (Mr. Michael Tsiagbe, CSIR/HSE) Why should the EIA be conducted to conform with World Bank Standards? What about the standards in the four participating countries? Afterall, the project in being conducted in the sub-region! Answer The EIA is being conducted in conformity with the laws and procedures pertaining to the four countries. However not all the countries have developed the needed guidelines for pipeline work. In fact, with the exception of Nigeria, none of the other countries has developed the necessary guidelines for natural gas pipeline regulations. There is a harmonized approach to the EIA given different countries with different EIA laws & regulations. Consultations are held constantly with officials of the agencies responsible for the environment in the participating countries to ensure that all their concerns are taken on board. There are even local EIA consultants from the individual countries working with the International EIA Consultants to undertake the impact assessment exercise. Question (Dr. Wayo Seini, ISSER-Legon) Why is the sharing of tax revenue for the countries based only on the length of pipeline in each country? You may consider also using the volume of gas sold in each country or the equity contributions by each country. March, 2003 Page A-17 APPENDIX A GHANA EIA SCOPING CONSULTATIONS-SUMMARY OF ISSUES RAISED WEST AFRICAN GAS PIPELINE Answer Should the revenue be based only on gas sales then Nigeria will not obtain anything. Secondly, the equity contributions are coming from the sponsor companies and not the governments. More importantly, the sharing of the revenue is an issue within the domain of the governments to resolve amongst themselves. It is not an issue for the sponsors to decide. Question (Dr. Ofosu-Ahenkora, Energy Foundation) Gas demand in Tema overtime changes from 7mmscf/d to over 200mmscf/d. However, the Sekondi figure remains constant at 130mmscf/d. Could you explain this? Also the use of gas gives Ghana a savings of about $20m over the operational life of the project. This is insignificant considering the fact that VRA alone needs about $130m/year for its fuel cost. There is the need to consider the non-power sector in determining the gas demand for the country. Perhaps the project needs to go back to the drawing board to do this, especially, for the Takoradi Area as the Western Region is the most mineral-rich region in Ghana. Answer In Sekondi, the demand is basically for power generation at the thermal plant and volume required for both the VRA and TICO plants is fairly constant. In the case of Tema, several developers have shown the desire in putting up extra plants e.g. AES, KMR, etc. They are not sure of fuel. It is hoped that they will come back if the gas arrives. This has been factored into the gas demand. The $20m figure is based on a low world oil price when it was computed. At a higher world oil price, the figure will definitely be bigger. The Tema gas demand includes the non power sector gas demand too. But there have been new studies that have established your concerns. As we have always stated, the project is being developed on commercial lines. Pipeline will be built to supply gas anywhere that the market exists, but on sound commercial lines. Comment/Question (Cdr. Appiah Mensah, Ghana Navy) March, 2003 Page A-18 APPENDIX A GHANA EIA SCOPING CONSULTATIONS-SUMMARY OF ISSUES RAISED WEST AFRICAN GAS PIPELINE The stakeholder list I have seen does not include the Ministry of Transport and Communication. This Ministry is responsible for Shipping activities and cable laying in the sea and must be invited to future functions of this nature. GHPA should also be invited. How deep will the pipeline be laid? How will the pipe joints be joined together? Answer GHPA was invited and participated in the Tema session. The pipeline will be laid at depth of one meter along the on-shore route and at between 30-100 meter depth offshore on the sea floor. This will be about 12-15 kilometers from the shore line. In October/ November this year, there has been offshore engineering survey to determine & map out the on-shore & off-shore route. Routing maps can be provided once the survey reports are finalized. The pipeline will be joined by welding and covered with special cement to make it secure on the sea floor. This will be undertaken on the lay barge. All the necessary safety procedures for such an activity will be followed. Observation/Question (Mr. Noble Wadjah, Friends of the Earth) Putting an end to gas flaring in Nigeria which you mentioned as a benefit from the WAGP cannot actually be considered a benefit since it is an obligation for companies in Nigeria to stop gas flaring. In terms of regional integration, there are conflicts in the oil/gas industry in Nigeria. How are these conflicts being resolved before the introduction of WAGP, because our consumption pattern here will help inflame the conflicts in Nigeria? Answer Yes, there are social tensions in the Escravos area. But the WAGP as a physical structure does not reach Escravos even though the product may be coming from there. The problems are traceable to inequity in the sharing of oil & gas profits between the State Governments and the Federal Governments. The solution is may be March, 2003 Page A-19 APPENDIX A GHANA EIA SCOPING CONSULTATIONS-SUMMARY OF ISSUES RAISED WEST AFRICAN GAS PIPELINE come through dialogue between ECOWAS, the participating States and the Nigeria Governments. This dialogue is going on and we hope this will lead ultimately to the apportionment of more revenue from the States and Federal Government to the communities. Question (Mr. M. H. Duku, Min. of Environment & Science) How is the gas going to compete with LPG? What will be the impact of the gas on Power generation? Are there any plans to extend the pipeline to the other land-locked countries of West Africa? Answer Natural gas will neither substitute nor compete with LPG. They have different compositions .Each is suitable for specific heating needs. The propane and butane which make up the LPG would have been stripped from the Natural gas before transportation. The expected supplies required to meet the ever- growing market for power will be from thermal sources rather than hydro. Hence the impact of gas on power generation is expected to rise over the years since it will be cheaper than liquid fuels. The extension of the pipeline to the other land locked countries is possible but will be done on a commercial basis. Question (Nii Abeo Kyerekwanda IV, Ghana National Canoe Fishermen Association) Will there be closed fishing periods in the fishing areas during the laying of the pipeline? Answer No, this is not envisaged and indeed the local environmental experts will be available to ensure that fishing activities are not disrupted unduly. Question (Mr. Wilson Tamakloe, EPA-Accra) What is the width of the pipeline corridor as envisaged in the baseline study programme? March, 2003 Page A-20 APPENDIX A GHANA EIA SCOPING CONSULTATIONS-SUMMARY OF ISSUES RAISED WEST AFRICAN GAS PIPELINE Answer 25-50 metre. Comment/Question (Letitia Acquah, Lands Commission) There appears to be little publicity on the project. It was in the media sometime back but suddenly died off and appeared again just recently. All Ghanaians are stakeholders and they must all help publicise the project. Response There was a deliberate action to maintain a low profile on the project until major commercial term sheets had been agreed. Now PCE has been taken and there is a new impetus to go ahead with the Project that is why EIA Study is on and consultations, education & awareness program has resumed. There will be measured publicity till the Final Investment Decision (FID) is reached. After the submittal of the EIA and Final Investment Decision (FID) to construct has been taken, publicity & pubic education will be heightened. Question (Mr. Isaac Oduro, EPA-Accra) What is the minimum distance of the pipeline from heavy population areas? What educational programmes are you putting in place to raise the awareness of the population? Answer One of the criteria for routing the pipeline is the avoidance of human habitations. The education programme has been designed for all the countries and will be scaled up in Ghana during next year (2003). Question (Mr. M. H. Duku, Min. of Environment & Science) Looking at the duration of the baseline studies, are we not rushing to come out with a document which will not be representative of the facts? Answer The studies are being conducted to cover the seasons and the days you see are those meant for data collection. There will be time for data analysis. Question (Mr. Ben Sackey, VRA) Nothing has been said so far about the Socio-economic study. Is there a document or summary of the study so that stakeholders can also comment on it? March, 2003 Page A-21 APPENDIX A GHANA EIA SCOPING CONSULTATIONS-SUMMARY OF ISSUES RAISED WEST AFRICAN GAS PIPELINE Answer A knowledge, attitude, acceptance and perception study was undertaken by the sponsors. This report is rather weak on the socio-economic issues. The EIA process will seek to expatiate further on the KAAPS, more specifically on the socio-economic aspects. QUESTION (Mr. Mike Tsiagbe, CSIR) Explain further the harmonization of the EIA process-How was work allocated and on what basis? Answer This is intended to provide a reasonably common approach to the EIA while recognizing/complying with the statutory requirements of the different states. Sharing of EIA work load among the local country sub-contractors was based on the volume of work, expertise and budgetary constraints. Question (Mr. Kuforgbe, Univ. of Ghana) In terms of project alternative analysis, are you prepared to consider Solar for example? Answer No, the Strategic National Energy Plan being put together by the Energy Commission is considering the renewable. This is outside the purview of WAGP. March, 2003 Page A-22 APPENDIX A GHANA EIA SCOPING CONSULTATIONS-SUMMARY OF ISSUES RAISED WEST AFRICAN GAS PIPELINE Rapporteur's Notes 1. Dr. Ofosu-Ahenkorah drew the meeting's attention to two documents that had been left on some tables during the coffee break and seek to smear the WAGP. The documents were circulated by the Participant from the Friends of the Earth prior to his departure midway through the programme. Dr. Ahenkorah remarked that it appeared the authors of the articles lacked the right information about Africa's quest for development. He was of the opinion that academics from Harvard should spend their time more constructively by writing about intentions to drill in Alaska and leave the WAGP alone. 2. Mr. Kuforgbe of the Dept. of Geography and Resource Development of the University of Ghana, indicated his department's ability to use the Sediment Profile Imagery Tool for analysis of GIS data collected for the project. 3. Mr. Mike Tsiagbey of the CSIR was of the opinion that circulation the whole of the scoping document to some selected interested agencies and organisations for their comments and input will improve the document. Participants who were interested in receiving the full scoping document were asked to request for it by giving their names. The programme ended after lunch at 3.00pm. March, 2003 Page A-23 APPENDIX A GHANA EIA SCOPING CONSULTATIONS-SUMMARY OF ISSUES RAISED WEST AFRICAN GAS PIPELINE STAKEHOLDER CONSULTATIONS HELD AT TAKORADI/ABOADZE ON WEDNESDAY, 11TH DECEMBER 2002 This programme was held at the VRA Club Complex Building at Aboadze. In addition to the newspaper adverts placed in the media in compliance with Ghana's EIA Regulation 15(i) of LI 1652, specific letters of invitation were also sent to the institutions, agencies and personalities listed below: 1. Chief Executive a. SAEMA b. Sekondi 2. Regional Programmes Officer i. EPA ii. Sekondi 3. Regional Head a. Fisheries Dept b. Sekondi 4. Omanhene i. Shama Traditional Council & various groups ii. Shama 5. The President i. Western Region Branch ii. National Canoe Fishermen Association iii. Sekondi 6. General Manager i. VRA Thermal Power Station ii. Sekondi 7. Executive Secretary i. Association of Ghana Industries ii. Sekondi March, 2003 Page A-24 APPENDIX A GHANA EIA SCOPING CONSULTATIONS-SUMMARY OF ISSUES RAISED WEST AFRICAN GAS PIPELINE 8. Commander i. Western Naval Command ii. Ghana Navy iii. Sekondi 9. Director i. Takoradi Port ii. GPHA iii. Takoradi 10. Chief, Elders & Youth i. Aboesi Town 11. Chief, Elders & Youth i. Aboadze Town 12. Chief, Elders & Youth i. Dwomo Town 13. President i. Western Region Branch ii. Chamber of Commerce iii. Sekondi 14. Regional Coordinating Director i. Ministry of Transport & Communications ii. Sekondi-Takoradi 15. President i. Network of NGOs ii. Sekondi-Takoradi 16. Director, Public Health Ministry of Health Sekondi March, 2003 Page A-25 APPENDIX A GHANA EIA SCOPING CONSULTATIONS-SUMMARY OF ISSUES RAISED WEST AFRICAN GAS PIPELINE 17. Secretary i. Western Region Branch ii. Ghana Journalists Association iii. Sekondi 18. Regional Fire Office i. Ghana National Fire Service ii. Western Region iii. Sekondi-Takoradi 19. Paramount Chief i. Essikado 20. Paramount Chief i. Sekondi The actual list of participants is shown in Appendix 3 of this report. After the presentations had been made to explain the various phases and aspects of the project by the resource persons, the floor was opened for questions, comments and contributions from the participants. QUESTIONS AND ANSWERS: KEY ISSUES ARISING Question (Yakubu Kwame Eshun, Fisherman) There are some creatures in the sea that grow around hard objects like concrete and they tear fishing nets and gears when they get hooked to them. Concrete coating of the pipeline is likely to bring about the increase of these creatures which will affect the fishing industry. What are the project sponsors going to do about this? Answer The main pipeline will be in depths of about 30-100 meters and at the shore approaches it will be buried. The pipeline route will be charted. The EIA will study the possible impacts and offer the mitigation measures to deploy. March, 2003 Page A-26 APPENDIX A GHANA EIA SCOPING CONSULTATIONS-SUMMARY OF ISSUES RAISED WEST AFRICAN GAS PIPELINE Question (Capt. Felix Gbogbo, Ag. Harbourmaster) What kind of gear is Mr. Eshun talking about? If it is trawling, trawlers are not allowed at that distance from the shore. Intervention (Naval Capt. Anku, Commander-Western Naval Command) The question raised by Mr. Eshun is relevant. He is referring to banacles. The Minister from time to time is allowed by law to grant rights for fishing of specific species close to shore eg. Octopus. I think however that, with time, the pipeline will be buried by the movement of sand caused by the action of the waves/sea currents and so the issue raised by Mr. Eshun may not arise. Intervention (Capt. Gbogbo) Where there are marine installations, international law makes fishing within 500 meters of these installations illegal. Using markers and maps could help ward off intruders. Question (Kobina Essandoh, Aboadze) Will there be trenching and filling with cement, or will the pipeline be laid before cement is poured on it? Will the laying of the pipeline bring any health hazards and what studies have been done to find this out. What benefits will the coastal communities obtain from the project. Answer The pipeline will be coated with cement before laying. This will add weight to the pipe and make it sink onto the sea floor. As part of the EIA process any possible impact of the project will be investigated and mitigative measures suggested. The project will not begin till these studies are done and the reports are acceptable to the countries and all necessary permits required have been obtained from the countries asserting the environmental acceptability of the project. The project will consult with the communities on how they could be helped via community development. The project refers to this as social capital. Question (Cdr. Anim, Ghana Navy) March, 2003 Page A-27 APPENDIX A GHANA EIA SCOPING CONSULTATIONS-SUMMARY OF ISSUES RAISED WEST AFRICAN GAS PIPELINE What is the advantage of having the pipeline under the sea? Answer Basically to minimise disturbances to settlements and decrease construction time. Question (E. K. Kumi, Regional Economic Planning Officer) An export processing zone is being planned for the region and this will include export of processed petroleum products. There is the need to keep this in view whilst planning the gas pipeline route. What is the contingency plan against sabotage in Nigeria since this will definitely disrupt supplies. What lessons have the sponsors learnt from the CIMAO failure that will help them better execute this project. Answer These will be considered. The permit system will allow the various projects to be examined by the appropriate agencies. We note that no time frame was quoted for the Essipon Project. The Export Free Zone people were invited during the consultations in Accra. We intend to keep up the consultations. On the sabotage issue, natural gas pipeline is different from petroleum pipeline. There will be nothing to scoop when you sabotage a gas pipeline. Local communities are being engaged in dialogue to make them partners with a view to avoiding such situations. As compared with the CIMAO project, there is a great deal of cooperation among the countries with respect to the WAGP. In January 2003 an International Project Agreement will be signed among the countries. These are all meant to create the enabling environment for the project to move ahead smoothly. Question (Mr. Edwin Phillips, Presiding Member-SAEMA) Will there be a self-shutting mechanism incorporated into the pipeline design to shut the system down when there is a problem? When you get to telegram cables etc. in the sea, are you going to go over them or around them? March, 2003 Page A-28 APPENDIX A GHANA EIA SCOPING CONSULTATIONS-SUMMARY OF ISSUES RAISED WEST AFRICAN GAS PIPELINE Answer Yes, and the system will be under observation at all times. The pipeline route will avoid cables and other obstruction in the marine environment. Question (Mr. Alfred Ayah, EPA-Sekondi) What is the operational life of the project? Answer The operational life is 20 years and various agreements are anchored around this time frame. Question (Rep. From Dwomo) We cannot rule out disaster in our undertakings. What plans have you to pay compensations if it should occur? Projects are usually painted in very bright colours during the planning phase. But at the implementation phase, things go amok. What steps are you taking to make things better? Answer There will be an EMP in place to take care of disaster. There are also laws in Ghana to apply when there are impacts. WAGP will not be an exception when it comes to adherence to the law. The project is committed to make inputs to community development in a proportionate manner taking into account potential impacts. In 2003, there will be sessions with Project-affected community leadership to determine their priorities and needs for community development assistance. Question (Mr. Atta-Peters) $500 million is not a small investment. After September 11, things of this nature cannot be left to chance. What have you put in place to protect this investment? Answer There are agreements being put in place for the countries to have roles/responsibilities(ie liabilities) regarding the protection of the pipeline against March, 2003 Page A-29 APPENDIX A GHANA EIA SCOPING CONSULTATIONS-SUMMARY OF ISSUES RAISED WEST AFRICAN GAS PIPELINE seizure, nationalisation etc. There are dialogues going on with the World Bank for MIGA guarantees for the gas sales agreement for Ghana. In the agreement, liabilities and responsibilities have been clearly identified. Every body has a part to play in protecting the pipeline assets from sabotage: the Navy, communities as partners too are obliged to help safeguard the installations. Question (Mr. Augustine Nyamekye, Assemblyman-Aboadze) When the project takes off, I hope there will be job openings for the people here. There is declining fish catch from the sea due to projects of this nature. Will your project bring about further decline in our fish stocks that will affect the livelihood of our people? Answer There is likely, during construction, to be some job avenues for non-skilled and casual labour. For skilled jobs, there will be competitive selection of required staff because jobs will be limited. Suitable qualifications will determine success in competing for job openings during operations. Declining fish stock is due to over-population resulting in greater demand for fish and over-fishing. Fishermen are catching immature fish and thereby not giving them the chance to grow and multiply. Question (Cdr. Anim, Ghana Navy) This pipeline is coming all the way from Nigeria. Are you going to satisfy all the communities along the route? Answer The Project will make contribution to community development on basis of assessed level of impact on host communities apart from direct or indirect compensation for lands acquired for Project purposes. The Project will engage in dialogue with host communities and relevant umbrella organisations such as the National Canoe Fishermen Association to design , implement & manage the social capital program. Question (Cdr. Aboagye, Ghana Navy) How often will you collect data after construction to compare with baseline data? March, 2003 Page A-30 APPENDIX A GHANA EIA SCOPING CONSULTATIONS-SUMMARY OF ISSUES RAISED WEST AFRICAN GAS PIPELINE Answer The EMP will take care of this. There will be both construction monitoring and post construction monitoring. Question (Nana Kobina Atta III, chief of Aboadze) During the construction of the Takoradi Thermal Station, some explosives were used by VRA for blasting and peoples buildings were cracked. VRA has refused to accept responsibility for this. Will blasting be done during construction works on the WAGP? Answer There will be no blasting. The pipeline approach to shore will be by directional drilling. Rapporteur's Notes 1. Mr. Ekow Abudu of Aboadze drew attention to some old P&T cables offshore Sekondi that is affecting the fishermen in their work. He appealed to the Local Environmental Expert to help bring this to the attention of the appropriate authorities. 1. Mr. Alfred Ayah suggested there was a discrepancy in the Scoping Report, noting that Chapter 6- methodology was absent in the said report although presented in the Baseline Study Overview. He suggested the baseline study is enhanced to do some specific things in addition to what it is doing now. He was advised to, apart from making these remarks on the floor, submit his written concerns to the External Affairs Manager of the project. 2. Mr. Ameko , Environmental Chemist of the VRA Takoradi thermal Plant appealed to the fishermen to observe the 500 meter distance from marine installations when fishing. 3. Naval Capt. Anku suggested that the project did a study to establish a relationship between the project and fish stocks. 4. Capt. Gbogbo offered to assist the canoe fishermen in the Project- impact area in understanding the various regulations at sea, if they would organise themselves and invite him. March, 2003 Page A-31 APPENDIX A GHANA EIA SCOPING CONSULTATIONS-SUMMARY OF ISSUES RAISED WEST AFRICAN GAS PIPELINE 5. Nana Konduah, the Chief Fisherman of Aboesi indicated that they will invite Capt. Gbogbo to help them in the New Year. CONCLUSION The meeting came to an end at 3.40pm. Participants dispersed after lunch. March, 2003 Page A-32 APPENDIX A GHANA EIA SCOPING CONSULTATIONS-SUMMARY OF ISSUES RAISED WEST AFRICAN GAS PIPELINE APPENDIX - 1 ATTENDANCE LIST: TEMA CONSULTATION FORUM # NAME JOB TITLE ORGANISATION/INSTITUTION LOCATION 1 Cdr. M. K. Lovi Navy (Eastern Command) TEMA 2 Hawa Buie Fisheries Officer Fisheries Dept. TEMA 3 S. N. K. Quartey Assistant Director Marine Fisheries Res. Division TEMA 4 Tetteh Agbo Annan Fisherman Tema Traditional Council TEMA 5 Africano Adjei Trader " TEMA 6 C. A. Mensah Trader " TEMA 7 Nii Mator Chief Fisherman Chief Fisherman " TEMA 8 A. A. Annang Cooperative Member Kpone Traditional Council Kpone 9 Nii Narh Botchwey Cooperative Member " Kpone 10 Nii Leno III Member " Kpone 11 Nii Dun IV Member " Kpone 12 Nii Adeiso Member " Kpone 13 N. T. Nortey Cooperative Member " Kpone 4 S. Essah EPA EPA, Tema Tema 15 Thomas Manu Dir. Exploration & G. N. P. C. Tema Production. 16 F. Asenso-Boakye Assist. Planning Officer Ghana Free Zones Board Accra 17 Dr. A. Essel President Geocore & Env. Services (GH). Tema Ltd. 18 Ivan Doku Project Dir. Hydro " Tema March, 2003 Page A-33 APPENDIX A GHANA EIA SCOPING CONSULTATIONS-SUMMARY OF ISSUES RAISED WEST AFRICAN GAS PIPELINE 19 Enoch Abo Fisherman Tema Traditional Council Tema 20 Nii Kokroko " Tema 21 A. K. Armah Consultant E. S. L. Accra 22 G. A. Dapaah Consultant E. S. L. Accra 23 Edith Osankwei Tema Tema 24 Nii Larbie Adjeitey Ag. Osaste Tema Traditional Council Tema 25 A. Y. Jim-Fugar Est. & Corp. Manager G. P. H. A. Tema 26 Adjeitey Mensah Linguist Tema (Linguist) Tema 27 Tawiah Abolo Elder Tema (Elder) Tema 28 Asafoanye Kortu Tema (Elder) Tema 29 Gary Stauffer Director Energy Supply VALCO Tema 30 Abdel Rahman Glover Tema Tema 31 Justine Shirley Seyire Asst. Prog. Officer EPA, Tema Tema 32 Letitia A. K. Tvelope Asst. Prog. Officer EPA, Tema Tema 33 Capt. Victor Jonah Harbour Master Tema Port Tema 34 Jeffrey Adjei Electrician Tema Tema 35 Tamara Quaye Teacher Tema Tema 36 E. A. Tetteh Mechanic Tema Tema 37 Akoi Arthur Driver Tema Tema 38 Asafoatse Oshieso Elder Tema Traditional Council Tema 39 Y. Safo-Afriyie Senior Programme. EPA, Tema Tema Officer 40 Ernest Adjei Elder Tema Traditional Council Tema 41 E. A. Quaye- Foli Head, Petroleum Min of Energy Accra March, 2003 Page A-34 APPENDIX A GHANA EIA SCOPING CONSULTATIONS-SUMMARY OF ISSUES RAISED WEST AFRICAN GAS PIPELINE APPENDIX - 2 ATTENDANCE LIST ­ CSIR/STEPRI CONSULTAION FORUM # NAME JOB TITLE ORGANISATION/INSTITUTION LOCATION 1 Nii Abeo Kyerekwanda IV Executive Secretary Ghana National Canoe Fishermen James Town Council Beach 2 Cynthia Omaboe Accra 3 Wilson Tamakloe Programme Officer EPA Accra 4 Albert Abasi Programme Officer EPA Accra 5 Cdr. Seth Appiah-Mensah Deputy Director Ghana Navy, Burma Camp Accra 6 Irene Nyantekyi Public Affairs Mgr. Energy Commission Accra 7 Martin Asare CPO " Accra 8 Grant Hilton Regional Manager Chevron West Africa Gas Accra 9 Noble Wadjah Prog. Coordinator Friends of the Earth, Accra 10 Mike Tsiagbey Head, Env. Section CSIR/ Env. & Health Sector Accra 11 J. Amoako-Baah Prod. Engineer VRA Akuse 12 Dr. Ofosu Ahenkorah Exec. Director Energy Foundation Accra 13 S. K. Kuforgbe Head Geography Dept. Univ. of Ghana Accra 14 Dr. Wayo- Seini Snr. Research Fellow ISSER, Univ. of Ghana Accra 15 M. H. Duku Deputy Director Min. of Environment & Science Accra 16 Letitia Acquah PLO Lands Commission Accra 17 A. K. Armah Consultant E. S. L. Accra 18 F. Asenso-Boakye Free Zones Officer Ghana Free Zones Board Accra March, 2003 Page A-35 APPENDIX A GHANA EIA SCOPING CONSULTATIONS-SUMMARY OF ISSUES RAISED WEST AFRICAN GAS PIPELINE 19 Ben. A. Sackey Environmental Officer V. R. A. Akosombo 20 Isaac Oduro PPO E. P. A., Accra 21 J. W. Sutherland Director, SSD V. R. A. Akosombo 22 A. Diez Project Control Mgr. WAGP/HOUSTON USA 23 E. A. Quaye-Foli MoEn Tema March, 2003 Page A-36 APPENDIX A GHANA EIA SCOPING CONSULTATIONS-SUMMARY OF ISSUES RAISED WEST AFRICAN GAS PIPELINE APPENDIX - 3 ATTENDANCE LIST ­ TAKORADI/ABOADZE CONSULTATION FORUM # NAME JOB TITLE ORGANISATION/INSTITUTION LOCATION 1 Capt. Felix Gbogbo Ag. Harbour Master Harbour Master/Takoradi Port Takoradi 2 Nana Kweku Kum Rep. Nana Ekuntan Chief Dwomo Dwomo 3 Safohene K. Gyepi Safohen " Dwomo 4 John Jomo Eshun Secretary " Dwomo 5 Sam Arku Tandoh Secretary " Dwomo 6 Eric Odoom Linguist " Dwomo 7 Nana Kondua IV Chief Fisherman Aboesi Aboadze 8 Opanyin K.Awer Elder Aboesi Aboadze 9 Yakubu Essuon Elder " Aboadze 10 Kweku Mborah Elder " Aboadze 11 Kobina Manso Elder " Aboadze 12 Noble Nkrumah Elder " Aboadze 13 Ekow Bosomefie Elder " Aboadze 14 Kobina Ekom Elder " Aboadze 15 Kweku Akyer Elder " Aboadze 16 Ekow Essuman Elder " Aboadze 17 Kofi Yaya Elder " Aboadze 18 J. Amoako-Baah Engineer VRA Akuse 19 E. A. Quaye-Foli Engineer MoEn Tema 20 Kingsley Atta- Peters Opinion Leader Better Life Construction Aboadze March, 2003 Page A-37 APPENDIX A GHANA EIA SCOPING CONSULTATIONS-SUMMARY OF ISSUES RAISED WEST AFRICAN GAS PIPELINE 21 Augustine Nyamekye Assemblyman S.E.A.M.A Aboadze 22 Nana Kobena Sam Chief Fisherman Chief Fisherman Aboadze 23 Abudu Kojo Nyame Elder Aboadze Aboadze 24 Egya Kwesi Ansakoh Elder " Aboadze 25 Ekow Abudu Elder " Aboadze 26 Issah T.99 Elder " Aboadze 27 Papa Karikari Youth " Aboadze 28 Peter E. Essel Youth " Aboadze 29 S. A. Osei-Bonsu AGI Takoradi 30 Theodora Nartey Regional Secretary " Takoradi 31 James Kainyah Regional Chairman Chamber of Commence Takoradi 32 John Prah Farmer Dwomo Dwomo 33 Alex Owoo Driver VRA Akuse 34 Tony Nzeh Driver VRA Akuse 35 Phillip Nkrumah MCE SAEMA Sekondi 36 Edwin Phillips P. M " Sekondi 37 G. A. Dapaah Consultant ESL Accra 38 Dan Onny Civil Eng. VRA Takaradi 39 Mrs. Ayittey Administrative Officer " Takoradi 40 E. K. Kumi Economic Planning Western Region Coordinating Sekondi Council 41 Maxwell Mensah O I S SAEMA Sekondi 42 M. K. Brown-Orleans Service Personnel SAEMA Sekondi 43 Geneveive Essilfie Chemical Engineer VRA Aboadze March, 2003 Page A-38 APPENDIX A GHANA EIA SCOPING CONSULTATIONS-SUMMARY OF ISSUES RAISED WEST AFRICAN GAS PIPELINE 44 Yvonne Marfo Chemical Engineer " Aboadze 45 E. M. R. Ameko Snr. Environmental Off. " Aboadze 46 J. Hyde-Cooper Principal Est. Officer GPHA Takoradi 47 E. R. Okyere Prog. Officer EPA Sekondi 48 Alfred Ayah Programme Officer EPA Sekondi 49 Kofi Eshun Edmund Ag. Programme Officer " Sekondi 50 George Tawiah Ag. Programme Officer " Sekondi 51 Albert A. Akinnuntan EPA NSP " Sekondi 52 Kwesi Kwakwa Port Civil Engineer GPHA Takoradi 53 Stephen Ampiaw Civil Engineer " Takoradi 54 I. Nkrumah EPA EPA Sekondi 55 Thomas Insaidoo Fisheries Officer Fisheries Dept Sekondi 56 Cdr. B. F. Asante C O Ghana Navy/ Sekondi 57 Naval Capt. G. Anku " Sekondi 58 Cdr. G.K. Anim C O " Sekondi 59 Cdr. S. A. Aboagye C T O " Sekondi 60 G. M. Lawe ZIC Ghana Fire Service/ Sekondi 61 Ebow Simpson Divisional Officer " Sekondi 62 Emmanuel Hackman ADO " Sekondi 63 Matthew Nuamah Photographer Sekondi 64 J. K. Arthur Secretary Aboadze Palace Aboadze 65 A. K. Armah Consultant ESL Accra March, 2003 Page A-39 APPENDIX B TO FINAL SCOPING REPORT WEST AFRICAN GAS PIPELINE OFFSHORE AND ONSHORE ENVIRONMENTAL BASELINE SURVEY WORK PLAN March 26, 2003 Table of Contents Page 1.0 Introduction and Project Background Information............................................................. 1 2.0 Environmental Baseline Survey Work Plan Purpose and Objectives................................. 3 3.0 Scope of Field Work........................................................................................................... 7 3.1 Time Frame............................................................................................................. 7 3.1.1 Offshore Sampling...................................................................................... 7 3.1.2 Onshore Sampling....................................................................................... 8 3.2 Proposed Pipeline Route, Offshore Sampling Stations, and Onshore Transects................................................................................................... 8 3.2.1 Offshore Sampling Stations........................................................................ 8 3.2.2 Onshore Sampling Transects ...................................................................... 9 3.2.3 Rationale for the Sampling Design........................................................... 10 3.3 Offshore Field Sampling­Seabed ......................................................................... 11 3.3.1 Chemical and Physical Characterization .................................................. 11 3.3.2 Biological Characterization ...................................................................... 13 3.3.3 Biological Analysis of the Seabed............................................................ 13 3.4 Offshore Field Sampling--Water......................................................................... 16 3.4.1 Chemical Characterization........................................................................ 16 3.4.2 In-Situ Conductivity-Temperature-Depth Measurements ........................ 16 3.4.3 Trawl Sampling and Stations.................................................................... 16 3.5 Offshore Field Sampling­Marine Birds, Mammals, and Reptiles........................ 18 3.6 Offshore Field Sampling­Meteorological Conditions.......................................... 19 3.7 Characterization of Ocean Currents...................................................................... 19 3.8 Offshore Sampling­Documentation of Sampling Activities................................ 19 3.9 Onshore Field Sampling­Vegetation.................................................................... 20 3.9.1 Vegetation Quadrats.................................................................................. 20 3.10 Onshore and Intertidal Field Sampling­Aquatic Macrophytes ............................ 22 3.10.1 Measures of Vegetation Abundance......................................................... 22 3.10.2 Measure of Vegetation Species Diversity................................................. 23 3.11 Onshore Field Sampling­Soil............................................................................... 23 3.11.1 Soil Sample Handling and Preservation ................................................... 24 3.12 Onshore Field Sampling­Wildlife and Animal Resources................................... 25 3.13 Onshore Field Sampling­Surface Water Quality, Sediment Quality, and Hydrobiology ................................................................................................. 25 3.13.1 Plankton Standing Crop and Primary Productivity................................... 26 3.13.2 Sediments and Macrobenthic Fauna......................................................... 26 3.13.3 Aquatic Sampling Handling...................................................................... 27 3.14 Onshore Field Sampling­Fish and Fisheries Resources....................................... 27 3.15 Onshore Field Sampling­Climate and Meteorology ............................................ 27 3.16 Onshore Field Sampling­Air Quality................................................................... 27 3.17 Onshore Sampling­Documentation of Sampling Activities................................. 28 ICF Consulting Appendix B-WAGP EBS Work Plan i 3.18 Onshore Field Sampling--Soil and Groundwater at the Compressor Station Site (Nigeria Only)............................................................... 28 3.18.1 Electrical Soundings ................................................................................. 28 3.18.2 Soil Borings .............................................................................................. 29 3.18.3 Soil Sampling and Analysis...................................................................... 29 3.18.4 Monitoring Well Construction.................................................................. 29 3.18.5 Groundwater Analysis .............................................................................. 29 3.18.6 Hydraulic Conductivity............................................................................. 30 3.19 Summary of Planned Onshore and Offshore Biological and Meteorological Sampling...................................................................................... 30 4.0 Laboratory Procedures...................................................................................................... 32 4.1 Relying on Regional Cooperation for Laboratory Sample Analysis .................... 32 4.2 Chemical and Physical Analysis of the Seabed.................................................... 33 4.3 Chemical Analysis of the Offshore Water Column.............................................. 33 4.4 Offshore Fish Tissue Analysis.............................................................................. 33 4.5 Chemical Analysis of Onshore Soil Samples ....................................................... 33 4.5.1 Total Petroleum Hydrocarbons................................................................. 33 4.5.2 PAH........................................................................................................... 33 4.5.3 TOC........................................................................................................... 37 4.5.4 pH.............................................................................................................. 37 4.5.5 Trace Metals.............................................................................................. 37 4.5.6 Microbiology............................................................................................. 37 4.5.7 Macrobiology and Soil Ecology ............................................................... 37 4.5.8 Particle Size Distribution.......................................................................... 37 4.6 Chemical Analysis of Onshore Compressor Station Site Groundwater Samples........................................................................................... 38 4.7 Physiochemical Analysis of Onshore Borehole Cuttings..................................... 38 4.7.1 TPH and Heavy Metals............................................................................. 38 4.7.2 Grain Size and Effective Porosity............................................................. 38 4.8 Chemical and Biological Analysis of Onshore Aquatic Environment ................. 42 4.8.1 Chemical Analysis of Surface Water........................................................ 42 4.8.2 Analysis of Plankton Biology and Community Metabolism.................... 43 4.9 Analysis of Sediment............................................................................................ 43 4.9.1 Chemical Analysis .................................................................................... 43 4.9.2 Biological Analysis................................................................................... 44 5.0 Data Analysis and Reporting ............................................................................................ 45 5.1 Purpose.................................................................................................................. 45 5.2 Data Storage and Treatment.................................................................................. 45 5.3 Raw Data Evaluation ............................................................................................ 46 5.4 Reporting............................................................................................................... 46 6.0 Quality Assurance and Control......................................................................................... 48 6.1 Purpose.................................................................................................................. 48 6.2 Study Design......................................................................................................... 48 6.3 Field Procedures.................................................................................................... 48 ICF Consulting Appendix B-WAGP EBS Work Plan ii 6.4 Laboratory Analysis.............................................................................................. 49 6.5 Detailed Field Quality Control Measures ............................................................. 50 6.5.1 Equipment Blanks..................................................................................... 50 6.5.2 Field Blanks .............................................................................................. 50 6.5.3 Replicate Samples (Field Duplicates)....................................................... 51 6.5.4 Control of Data Storage and Treatment.................................................... 51 6.5.5 Data Interpretation Control....................................................................... 51 7.0 Health and Safety Plan...................................................................................................... 52 7.1 ICF Health and Safety Policy ............................................................................... 52 7.2 Responsibilities..................................................................................................... 53 7.3 Training................................................................................................................. 53 7.4 Site Hazard Characterization (Job Safety Analysis)............................................. 53 7.4.1 Physical Hazards....................................................................................... 53 7.4.2 Chemical Hazards..................................................................................... 54 7.5 Personal Protection Equipment............................................................................. 55 7.6 Personnel and Equipment Decontamination......................................................... 56 7.7 Emergency Procedures.......................................................................................... 56 7.8 Shipboard Safety and Policies .............................................................................. 57 8.0 Vessel and Crew Requirements ........................................................................................ 59 8.1 Vessel Specifications ............................................................................................ 59 8.2 Cruise Personnel Required.................................................................................... 59 8.3 Roles And Responsibilities................................................................................... 59 8.3.1 Chief Field Scientist.................................................................................. 59 8.3.2 Shift Leader............................................................................................... 59 8.3.3 Field Sampling Technician ....................................................................... 60 8.3.4 Field Chemist............................................................................................ 60 8.3.5 Field Technician........................................................................................ 60 8.3.6 Support Staff............................................................................................. 61 8.3.7 Navy Representatives................................................................................ 61 8.3.8 Spi Operators ............................................................................................ 61 8.3.9 Other Staff................................................................................................. 61 Attachment A: WAGP Study Area Map Attachment B: Schedule of Milestones Attachment C: Vessel and Equipment Specifications Attachment D: Station Coordinate Table Attachment E: SPI Documentation Attachment F: Sample Chain of Custody Record Attachment G: Offshore EBS Fish Trawl and Plankton Station Log Attachment H: Station Log ICF Consulting Appendix B-WAGP EBS Work Plan iii Attachment I: Daily (Shift) Activity Report Attachment J: Onshore EBS Data Collection Forms in French and English Attachment K: ICF EBS Scientific Team Attachment L: WAGP's Job Safety Analysis Worksheet Attachment M: Vessel Introduction and Safety Attachment N: TDI-Brooks Vessel Audit Checklist ICF Consulting Appendix B-WAGP EBS Work Plan iv WEST AFRICAN GAS PIPELINE OFFSHORE AND ONSHORE ENVIRONMENTAL BASELINE SURVEY WORK PLAN EXECUTIVE SUMMARY Introduction and Objectives The West African Gas Pipeline (WAGP) consortium intends to construct a 617-km, offshore- and-onshore gas pipeline from Nigeria to Ghana. The WAGP consortium is a joint venture partnership between Chevron Nigeria Limited (CNL), Volta River Authority (VRA), Nigerian National Petroleum Corporation (NNPC), The Shell Petroleum Development Company (SPDC) of Nigeria Limited, Societe Beninoise de Gaz S.A. (SOBEGAZ), Societe Togolaise de Gaz S.A (SOTOGAZ). These organizations form the Membership of the "Joint Venture". The Joint Venture intends to form a project company to be known as WAPCo for constructing, maintaining and operating the pipeline. After screening several potential pipeline routes the Joint Venture is considering a pipeline route that extends from a proposed connection to the existing Escravos-Lagos Pipeline (ELP) at the Alagbado "Tee" near Itoki, Nigeria. From the ELP connection, the pipeline route would proceed to a Nigerian beach location on land and continue offshore from the Nigerian beach location across the territorial waters of Nigeria, Benin, Togo, and Ghana, terminating at Takoradi, Ghana. Offshore pipeline installation is anticipated to be in water depths up to 75m and at distances ranging from 5 to 30km from shore. The corrosion-resistant pipe, encased in concrete to provide ballast and protection, will be laid unburied on the floor of the Gulf of Guinea. When the pipeline comes onshore it will be buried at an appropriate depth to avoid shoreline erosion. Gas delivery laterals from the main pipeline route would extend into Cotonou (Benin), Lome (Togo) and other gas delivery target locations in Ghana (Tema and Takoradi). The Joint Venture proposes to carry out an Environmental Impact Assessment (EIA) of the pipeline project consistent with the laws, regulations, and guidelines of the Republic of Benin, the Republic of Ghana, the Federal Republic of Nigeria, and the Republic of Togo. The purpose of the WAGP EIA is to determine if WAGP construction activities and/or post-construction operations, including emergency situations, may have persistent, non-localized adverse impacts to the environment. The Environmental Baseline Survey (EBS) is a critical component in the preparation of a comprehensive EIA. Results of the offshore and onshore EBS will be essential for pipeline design and routing, impact assessment, formulation of any necessary mitigation measures, and environmental monitoring post-construction. EBS sampling will emphasize environmental parameters that are of particular significance to the proposed project. The sampling will provide physical, chemical and biological characterizations of the seabed, water column, terrestrial vegetation, terrestrial soil, groundwater, onshore surface water, and onshore sediment environments. The EBS will be based on two seasons of offshore and two seasons of onshore environmental field data sampling, analysis, and interpretation and will be augmented by a thorough review of the relevant literature. The EBS will be conducted so as to demonstrate that the system of field sampling, ICF Consulting Appendix B-WAGP EBS Work Plan v laboratory testing, data analysis, and results interpretation has been designed suitably and performed adequately. This EBS work plan describes the data that will be collected within the offshore and onshore environments of the study area. It describes the methods for collecting the samples, handling the samples, analyzing the samples, and interpreting the results. Offshore Plan The offshore EBS fieldwork will begin the first week of December, 2002. The plan for offshore sampling will be for the research vessel , leaving Takoradi, to begin sampling in the waters of Ghana, followed by Togo, Benin, and Nigeria. This first season data collection period, which will last 15 days, will represent, if acceptable to the involved regulatory agencies, the "dry season." Based on the first season results, findings in the literature, regulatory requirements and/or other determining factors, the second season offshore fieldwork will be planned. This second season of sampling will be timed so to occur during the "wet season," i.e. sometime between May and July, 2003. The second season sampling will be designed to further explore results from the first season, collect data during the "wet season," and investigate significant impacts that could result from project construction and operation. There will be a total of 50 offshore sampling stations, of these 35 are stations placed randomly along the main pipeline route: Nigeria (3), Benin (7), Togo (5), and Ghana (20). The remaining 15 stations are on the laterals that bring the pipeline onshore in Nigeria (3), Benin (3), Togo (3), and Ghana (6). Sampling points on the lateral routes will be located by means of stratified randomisation. The sampling plan will be refined as the EIA team expands its knowledge of study area geomorphology, bathymetry, and country boundaries, which it will do by means of additional literature review and results from the geophysical survey. Water sampling will be carried out at each of the 50 offshore sampling stations on the proposed pipeline route, as close as practical to the locations where the sediments are taken. In situ measurements will be made and water samples will be collected at two depths--near the water surface (<1m) and at 1m above the bottom. Trawl sampling at 25 stations in the study area will be conducted for fish, ichthyoplankton, phytoplankton, and zooplankton. Trawls will be conducted at approximately the same locations as the sediment sampling stations described above. In addition, 10 trawls will be conducted at approximately 50km intervals along the main pipeline route. Trawl depths have been chosen to collect representative samples of fish and plankton assemblages. Selected tissue samples from fish commonly used for human consumption will be obtained from the trawls for PAH and metals analyses. Onshore Plan The onshore EBS will be based on two seasons of environmental field data collection. Each field session will last about 21 days, the first one will be during December, 2002 and the second is scheduled for the first week of May, 2003. Onshore field observation and sampling design ICF Consulting Appendix B-WAGP EBS Work Plan vi will document existing conditions in each of the major habitat types (e.g., beach/inter-tidal, strand, emergent wetlands, wet prairie, short mangrove forest, palm plantation) found in the study area. Each vegetation community will serve as a mapping "unit," or habitat type. Ground reconnaissance and satellite imagery (when available) will be used to define as many as 17 habitats along the onshore route and landfall locations. Each habitat will be sampled along a 60m transect or in the case of vegetation near the shoreline, a shorter, 10m transect. Stratified random sampling will be used to locate each transect. There will be four sampling points spaced at 20m intervals along the longer transects (0m, 20m, 40m, and 60m) and the shorter transects will have three sampling points a closer intervals (0m, 5m, and 10m). Sampling at shorter intervals in the near shore transects reflects rapid habitat transitions that can be expected in this zone. At each sampling point along a transect, information leading to plant species diversity and abundance for trees, saplings, and understory plants will be collected. Soil samples will be collected at the same sampling points used for vegetation sampling. Additional samples will be collected as composites for each transect. Soils will be assessed in terms of regional and local characteristics, susceptibility to erosion, physical and chemical characteristics and soil biota. Field observations on animal and wildlife resources will be carried out during early morning walks along beaches and footpaths and slow boat rides along creeks and around landfalls in each of the 17 habitat locations. An assessment of the baseline physical and chemical characteristics of the uppermost groundwater bearing layer(s) including information regarding aquifer hydraulic properties beneath the compressor station in Nigeria will be performed. The monitoring wells and their installation are intended to provide direct measurement of the chemical and physical properties of soil and water-bearing layers. Based on a current understanding of the location and depth of near coastal groundwater systems in the project area, the planned depth of the monitoring wells is 10m. To estimate the aquifer hydraulic conductivity, slug tests will be carried out at each monitoring well. Three soil samples will be retained from each borehole for laboratory analyses. Both during the dry and wet season, one groundwater sample from each monitoring well plus one duplicate sample from one monitoring well will be retained for analysis in the laboratory. Surface water bodies, such as rivers and marshes/estuaries, will be characterized. Water sampling will be done during both dry and wet season periods. In-situ measurements and samples for the laboratory will be collected at each station, during both dry and wet season sampling periods. Water samples will be collected at the water surface and at the water-sediment interface; sediment samples will also be collected. Fisheries observations will be carried out for surface water bodies within 17 selected habitat sampling areas. Fish studies will be based on observations of fisherman landings. The entire catch will be observed for its composition. Fish species will be taxonomically identified and fishing gear, tools, and technology commonly used by local fishermen will be noted. A survey for the occurrence and abundance of marine algae in the rocky tidal zone that occurs on the pipeline route in Ghana will be carried out along the laterals using a 60m transect that ICF Consulting Appendix B-WAGP EBS Work Plan vii extends seaward from the high-tide mark with sampling point locations at 0m, 20m, 40m, and 60m. A mobile meteorological station will be set-up near the proposed compressor station site to provide information on current meteorological conditions, e.g. wind speed and direction, temperature, humidity, barometric pressure and precipitation. Data retrieved from the meteorological station in Nigeria will be used during subsequent air quality characterization. Baseline survey information in Ghana, Togo, and Benin will be collected from existing sources of meteorological information such as from nearby airports. A limited air quality study will be conducted in the vicinity of the proposed compressor site. One portable air sampler equipped with 6L Tedlar bags will be stationed at the site to collect ambient air grab samples. Three sample periods per day will be collected over a two-week period. The elements of the air samples to be analyzed will be analogous to compressor facility potential pollutants of concern (particulate matter (PM), volatile organic compounds (VOCs), carbon monoxide (CO), and oxides of nitrogen (NOx). Important sources of air emissions will be identified and characterized during the literature review (including estimated emission rates, pollutant concentrations, and dispersion conditions), and sensitive receptors will be identified and characterized during field observations. In addition to the objectives and plans described above, the work plan provides detailed methods and scope of work for field sampling, laboratory analysis, and EBS reporting. It also provides study area maps, sampling locations, data collection forms, a comprehensive health and safety plan, a quality assurance and control plan, detailed lists of equipment needed for the EBS, sampling vessel specifications, and matrices assigning in-country responsibilities for the required tasks. ICF Consulting Appendix B-WAGP EBS Work Plan viii 1.0 INTRODUCTION AND PROJECT BACKGROUND INFORMATION The West African Gas Pipeline (WAGP) consortium intends to construct a 30.5cm to 76.2cm diameter, 617km long, offshore and onshore gas pipeline from Nigeria to Ghana. The WAGP consortium is a joint venture partnership between Chevron Nigeria Limited (CNL), Volta River Authority (VRA), Nigerian National Petroleum Corporation (NNPC), The Shell Petroleum Development Company (SPDC) of Nigeria Limited, Societe Beninoise de Gaz S.A. (SOBEGAZ), Societe Togolaise de Gaz S.A (SOTOGAZ). Members of the Joint Venture intend to form a project company to be known as WAPCo for constructing, maintaining and operating the pipeline. The Joint Venture is considering a pipeline route that extends from a proposed connection to the existing Escravos-Lagos Pipeline (ELP) at the Alagbado "Tee" near Itoki, Nigeria. The ELP is owned by Nigerian National Petroleum Corporation (NNPC) and operated by the Nigerian Gas Company (NGC), a subsidiary of NNPC. From the ELP connection, the pipeline route would proceed to a Nigerian beach location on land and continue offshore from the Nigerian beach location across the territorial waters of Nigeria, Benin, Togo, and Ghana, terminating at Takoradi, Ghana. Gas delivery laterals from the main pipeline route will extend into Cotonou (Benin), Lome (Togo) and other gas delivery target locations in Ghana (Tema and Takoradi). With regard to the delivery points, these locations should achieve an equilibrium between the concerns of their acceptance by coastal communities, safety and environmental vulnerability. Installation of the main offshore pipeline is anticipated to be in water depths up to 75m and at distances ranging from 5km to 30km from shore. The corrosion-resistant pipe, encased in concrete to provide ballast and protection, will be laid unburied on the floor of the Gulf of Guinea at depths of greater than 30m. At depths of less than 30m, a trench will be excavated and the pipeline will be installed in this trench and buried. At depths less than 30m, a trench will be excavated and the pipeline will be installed in this trench. When the pipeline comes onshore it will be buried at an appropriate depth to avoid shoreline erosion. Targeted gas delivery points at Lome, Tema, and Takoradi are anticipated to extend onshore only to the degree necessary to install Regulating and Metering (R&M) Stations approximately 1km to 5km onshore. For the purposes of this EIA, the pipeline land crossing at Lome is assumed to extend to the CEB power plant approximately 0.9km from the shoreline crossing. Likewise, for the purposes of this EIA the pipeline land crossing at Takoradi is assumed to deliver gas feed directly to the power plant. In Cotonou, the onshore portion of the pipeline for purposes of this EIA is assumed to extend 4.8km onshore, due north from the shoreline crossing, to connect to the R&M Station installed near Cococodji. In Tema, for purposes of this EIA the onshore portion of the pipeline will terminate at the R&M Station, approximately 1km from the shoreline crossing. The depth to which the pipe will be buried will be in the range of 1m to 2m, but will depend on existing topography and grades. ICF Consulting Appendix B-WAGP EBS Work Plan 1 From the Alagbado "Tee" near Itoki, Nigeria, estimated segment lengths (onshore and offshore) of the proposed pipeline are as follows: Alagbado "T" to Lagos Beach (30in dia (76cm)) 57km Lagos Beach to Benin Border (16-22in dia (40cm to 56cm)) 50km Benin Border to Cotonou 44km Cotonou to Lome 98km Lome to Tema 160km Tema to Takoradi 208km Total offshore portion 560km Total 617km The Joint Venture proposes to carry out the Environmental Impact Assessment (EIA) of the pipeline project consistent with the laws, regulations, and guidelines of the Republic of Benin, the Republic of Ghana, the Federal Republic of Nigeria, and the Republic of Togo. The Environmental Baseline Survey (EBS) is a critical component to the production of a comprehensive EIA. Results of the offshore and onshore EBS are essential for pipeline design and routing, impact assessment, formulation of any necessary mitigation measures, and environmental monitoring post-construction. The design of the offshore and onshore EBS is presented here to illustrate the proposed methods for data collection, laboratory analysis, and quality assessment, thereby ensuring a successful EIA process overall. ICF Consulting Appendix B-WAGP EBS Work Plan 2 2.0 ENVIRONMENTAL BASELINE SURVEY WORK PLAN PURPOSE AND OBJECTIVES A thorough Environmental Baseline Survey (EBS) shall be conducted to characterize relevant parameters of the offshore and onshore environments within the defined WAGP study area (See Map, Attachment A). The purpose of the EBS is to provide an analytical basis for the WAGP EIA. It will be based on two seasons of offshore and onshore environmental field data sampling, analysis, and interpretation and will be augmented by a thorough review of the relevant literature. The objective of the EBS is to provide an adequate scientific basis for the WAGP EIA. The purpose of the WAGP EIA is to determine if WAGP construction activities and/or post- construction operations, including emergency situations, may have persistent, non-localized adverse impacts to the environment. The results of the EBS will be used by project engineers during the design phase to avoid, minimize, and mitigate potential negative impacts that might occur. Also, it will provide information for deciding how to minimize impacts to the environment where there is a choice between different pipeline route options and design measures. EBS sampling will emphasize environmental parameters that are of particular significance to the proposed project. The sampling shall provide physical, chemical and biological characterizations of the seabed, water column, terrestrial vegetation, terrestrial soil, groundwater, onshore surface water, and onshore sediment environments. Proper sampling of the seabed environment will be particularly valuable because laying the pipeline will directly impact it and because the benthic environment, the sediments, and infauna that reside there indicate the effects of past physical disturbances and contamination. Because the EBS information will be used to make predictions of potential adverse environmental impacts posed by the project, or substantiate claims of no significant impact, it is necessary to demonstrate that the system of field sampling, laboratory testing, data analysis, and results interpretation has been designed suitably and performed adequately. This EBS work plan describes the data that will be collected within the offshore and onshore environments of the study area. It describes the methods for collecting the samples, handling the samples, analyzing the samples, and interpreting the results. It provides a plan for addressing the following questions for the offshore environment: a. What is the diversity of habitats in the study area for benthic and water column organisms? b. What is the existing abundance and species diversity of benthic macroinvertebrates, fish, plankton in the habitats that are encountered? c. What marine birds, mammals, reptiles, and amphibians tend to be present? d. Are threatened and/or endangered species, sensitive habitats, or commercially significant species/fishing zones present? ICF Consulting Appendix B-WAGP EBS Work Plan 3 e. What is the character of the seabed and is there existing sediment impairment with respect to or as indicated by: Bulk Properties (grain size, total organic carbon (TOC)) Organics (oil and grease, total petroleum hydrocarbons (TPH), polycyclic aromatic hydrocarbons (PAH), aliphatic hydrocarbons) Trace Metals (aluminum (Al), cadmium (Cd), chromium (Cr), copper (Cu), iron (Fe), mercury (Hg), nickel (Ni), lead (Pb), vanadium (V), zinc (Zn)) Nutrients and physicochemical properties (sulfate, ammonia nitrogen (N), orthophosphate phosphorous (P), total P, alkaline metals (calcium (Ca), magnesium (Mg), potassium (K), sodium (Na)) f. What is the character of the water column and is there water-quality impairment with respect to or as indicated by: Trace metals (Al, Cd, Cr, Cu, Fe , Hg , Ni, Pb , Zn) Water quality (dissolved oxygen (DO), total dissolved solids (TDS)) Nutrients and physiochemical properties (alkalinity, chemical oxygen demand, ammonia N, nitrate N, total N, orthophosphate P, total P, sulfate, alkaline metals (Ca, Mg, K, Na)) Temperature, pH, electrical conductivity, turbidity, salinity, chlorophyll-a Contaminated fish tissue (specifically PAH and metals concentrations) g. For all of the above is there significant seasonal variation that the EIA needs to consider? h. By combining biological, chemical, and physical sampling parameters derived from the sampling data, what is the existing environmental quality of the resource? i. Do meteorological and current patterns create concern with regard to exacerbating persistent, non-localized impacts? Similarly it provides a plan for addressing the following questions for the onshore environment: a. What is the diversity of terrestrial and aquatic habitats? b. What are the presence, abundance and species diversity of terrestrial trees, shrubs, understory plants, wildlife, and intertidal zone aquatic macrophytes? c. What are the presence and abundance of riverine (and adjacent water body) plankton, macrophytes, and macrobenthic infauna? d. What is the character of the riverine fisheries resources? ICF Consulting Appendix B-WAGP EBS Work Plan 4 e. Are threatened and/or endangered species, sensitive habitats, or commercially significant species/fishing zones present? f. What is the character of the soil and is there existing soil impairment with respect to or as indicated by: Total petroleum hydrocarbons and PAH pH, TOC, and particle size distribution Trace metals Microbiology Macrobiology and soil ecology g. What is the character of the groundwater and soil borings and is there impairment at the proposed compressor station location with respect to or as indicated by: TPH PAH Trace metals pH Grain size and porosity h. What is the character of the riverine (and adjacent water body) surface water and is there surface water-quality impairment with respect to or as indicated by: Salinity Conductivity Turbidity DO TDS/TSS Temperature Oil and grease Trace metals BOD5 Total Alkalinity Anions Plankton productivity and biomass i. What is the character of the riverine (and adjacent water body) sediments and is there sediment-quality impairment with respect to or as indicated by: TPH Trace metal TOC pH, grain size, redox potential, and temperature Macrobenthic infauna j. Are there important sources of air emissions, and what are the associated pollutant concentrations as indicated by: ICF Consulting Appendix B-WAGP EBS Work Plan 5 PM VOCs NOx SOx k. For all of the above is there significant seasonal variation that the EIA needs to consider? l. Would meteorological patterns likely exacerbate persistent, non-localized impacts? The EBS methodology and laboratory procedures shall be consistent with relevant established standard operating procedures (SOPs) and participating governments' guidelines. ICF Consulting Appendix B-WAGP EBS Work Plan 6 3.0 SCOPE OF FIELD WORK 3.1 Time Frame 3.1.1 Offshore Sampling In addition to a thorough literature review, the offshore EBS will be based on two seasons of environmental field data collection; the first of which will begin December, 2002 (see Schedule of Milestones, Attachment B). The WAGP geophysical crew will have finished their engineering survey at the end of October. Therefore, more detailed bathymetric information will be available to assist in final planning of the EBS cruise. The GPS data from the geophysical survey boat will be transferred to the EBS boat to ensure that the location of sampling is consistent with the exact pipeline route. The plan for offshore sampling shall be for the vessel to leave Takoradi and begin sampling in the waters of Ghana, followed by Togo and Benin. Togolese Navy security personnel will be ferried to and fro each day onto the boat if required while it is working in Togolese waters. When in Nigerian waters, the vessel shall pick-up two Nigerian Navy security personnel as required and complete the sampling there. Details of the vessel that will be employed for the EBS work (the GeoExplorer) are provided in Attachment C. This first season data collection period, which will last 15 days, will represent, if acceptable to the involved regulatory agencies, the "dry season." Based on the first season results, findings in the literature, regulatory requirements and/or other determining factors, a second season of offshore field sampling will be planned. This sampling will be timed so that sampling will occur during the "wet season," i.e. sometime between May and July, 2003. Second season sampling would be designed to fill in gaps, document "wet season" conditions, further explore results from the first season, and investigate significant impacts that could occur from project construction and operation activities. There is some concern that the EBS offshore sampling activities, scheduled for the first two weeks of December 2003, might affect feeding and reproductive activities of whales and dolphins in the waters off Benin and Togo. It is the ICF EBS Scientific Team's intention to explore any potential impact in an effort to proactively avoid incurring one. From an investigation into this issue, we conclude that there will be no adverse impact from the EBS field sampling. Prof. Sikirou Kola Adam, Executive Secretary of the Center for Environment and Development in Africa, gathered relevant information from Mssrs. Baglo, Issa, and Sohou, with Agence Beninoise Pour l'Environment. Another primary information source was the office of Dr. Adote Blivi, Head of Oceanographic Sciences at the University of Lome. The conclusions of Drs. Adam and Blivi were corroborated by Dr. Brent S. Stewart, Senior Research Biologist at the Hubbs-SeaWorld Research Institute in San Diego, California USA. Offshore Benin does serve as habitat, at least for parts of the year, to several species including large baleen whales, e.g. humpback, minke, Bryde's, sei, fin and blue; to large toothed whales, e.g. sperm, pigmy and dwarf sperm, Cuvier's beaked, Blainville's beaked, Gervais beaked, killer, and short-finned pilot; and to smaller toothed whales, dolphins and porpoises, e.g. common bottlenose dolphin, pantropical spotted dolphin, Atlantic spotted dolphin, spinner dolphin, Clymene dolphin, Fraser's dolphin, short and long-beaked common dolphins, false killer whale, pygmy killer whale, Atlantic humpbacked dolphin, rough-toothed dolphin, Risso's dolphin ICF Consulting Appendix B-WAGP EBS Work Plan 7 (grampus), and melon headed whale. Probably the most common ones that would be seen close to shore would be the rough-toothed, Atlantic humpbacked, and bottlenose dolphins. However, the reproductive period of the species visiting these waters occurs from August, until the end of November at the very latest, and therefore does not coincide with the EBS sampling activities scheduled for December. In addition, the sampling activities that are planned for Benin waters will only last a few days and will be scattered relatively sparsely over a large expanse of marine territory. Therefore, even in a case where the sampling activities would have overlapped with the breeding period of these mammals, the likelihood of adversely affecting their activities would have been very minute. 3.1.2 Onshore Sampling The onshore portion of the EBS will be based on literature review and two seasons of environmental field data collection. Each field session will last about 21 days, the first one is planned for December ­ January, 2002 and the second is scheduled for May or June, 2003 3.2 Proposed Pipeline Route, Offshore Sampling Stations, and Onshore Transects 3.2.1 Offshore Sampling Stations The proposed pipeline route and offshore sampling stations are shown in Attachment A. The protocol for naming offshore stations is as follows: Country letter--station number (ascending west to east)--if Sediment Profile Imagery (SPI) station, 1-km from route, then the direction from pipeline, examples are N-01 (Nigeria Station 1, on pipeline route), G-02-N (Ghana, Station 2, north of pipeline route). The offshore sampling station locations, position, depth and types of samples to be collected are summarized in Attachment D. There will be a total of 50 offshore sampling stations, of these 35 are stations placed randomly along the main pipeline route: Nigeria (3), Benin (7), Togo (5), and Ghana (20). In order to perform statistical analysis of the collected data, it is necessary that there be an element of randomisation in the placement of sampling points. Sampling points will be located using a stratified random method as follows: For the main pipeline, the route will be divided into 18km segments. Then a random number generator will be used to select a number between one and 36. This random number will indicate at which half-kilometer interval along the route, starting at the beginning of the 18km segment, the sampling point shall be placed. The remaining 15 stations are on the laterals that bring the pipeline onshore in Nigeria (3), Benin (3), Togo (3), and Ghana (6). For the laterals a similar approach to sampling station placement will be used; however, in these cases the length of the segments will depend upon the water contour depth. Sampling points on the lateral routes will correspond to the following: the 15m contour depth; a water depth 15m deeper than the water depth at the intersection with the main pipeline route or 5km south of the intersection with the principal pipeline route, whichever is the shorter distance; ICF Consulting Appendix B-WAGP EBS Work Plan 8 the depth-midpoint between the intersection with the main pipeline route and the 15m contour depth. As described in Section 4.1 Relying on Regional Cooperation for Laboratory Sample Analysis, samples will be distributed to qualified laboratories across the four countries. However, an additional five percent of the samples in Ghanaian waters not already planned for analysis in Ghana, shall be sent to laboratories in Ghana. The Ghana Environmental Protection Agency requests the duplicate samples for analysis in Ghanaian laboratories so as to ensure that the current EBS samples would be valid when compared to future samples that may be taken in Ghana and analyzed later in Ghana (during pipeline construction or operation monitoring activities). In this case, the results from the laboratory that analyzed the EBS samples can be compared to future results (e.g., from monitoring) from that same laboratory. The result is the ICF EBS Scientific Team will take duplicate samples for one main pipeline station and one lateral station in Ghanaian waters. These samples will be chosen at random. The sampling plan and placement of offshore sampling stations presented in this work plan will be refined as the ICF EBS Scientific Team expands their knowledge of the study area, by means of additional literature review and the geophysical survey that will precede the EBS sampling, with respect to coastal geomorphology, bathymetry, and country boundaries. In cases where there are no explicit criteria, the professional judgement of the Chief Field Scientist will be used to refine the sample station locations. 3.2.2 Onshore Sampling Transects Onshore field observation and sampling design shall be planned to document existing conditions in each of the major habitat types (e.g., upland dry thicket, strand vegetation, mangrove forest, grass and sedge dominated wetlands) found in the study area. Attachment A shows the approximate onshore location of the pipeline. Because vegetation is strongly indicative of soil type and hydrology, the major habitat types and vegetation communities within the defined study area will be identified and mapped. Each vegetation community will serve as a mapping "unit," or habitat type. Satellite imaging (when available) with rapid field survey verification ("groundtruthing") shall be used to define as many as 17 habitats (project-wide) along the onshore route and landfall locations. At least five habitat areas in Nigeria, five in Benin, four in Ghana, and three in Togo shall be sampled. The ICF EBS Scientific Team will concentrate its onshore sampling in Nigeria on the part of the pipeline route that is not coincident with the Shell right-of-way (ROW). To characterize the Shell ROW portion, the team can reference results provided in the Shell EIA and previous baseline sampling. Two seasons (wet and dry) of vegetation and soil studies will be carried out in each of the habitat types. Each habitat shall be sampled along a 60m transect or, in the case of vegetation near the shoreline, a shorter, 10m transect. The transect shall be placed randomly in the habitats by means of identifying on a map or aerial photograph the boundaries of the habitat, overlaying the habitat with the 25m wide a pipeline ROW. The beginning of each transect should start at least 10m inside of where the previous (seaward) habitat ended, however, the final judgment for placing the transect so as to best represent the habitat over the entire transect length, will be left to the team leader. The lateral placement of the beginning of each transect within the 25 m breadth of the ROW will be by random number generation (between 1 and 50). This random ICF Consulting Appendix B-WAGP EBS Work Plan 9 number will indicate at which half-meter interval along the route, starting at the western edge of the ROW, the sampling transect shall begin and then traverse inland. There will be four sampling points spaced at 20m intervals (0m, 20m, 40m, 60m) along the longer transects and the shorter transects will have three sampling points at closer intervals (0m, 5m, and 10m). Sampling at shorter intervals in the near shore transects reflects rapid habitat transitions that can be expected in this zone. For planning purposes there will be six near-shore transects that have three sampling points each, for a subtotal of 18 sampling points and 11 inland transects that have four sampling points each for a subtotal of 44 sampling points. The total number of sampling points is therefore expected to be 62 (Nigeria: three upland transects and two beach transects for a total of 18; Benin: four upland transects and one beach transect for a total of 19; Togo: two upland and one beach for a total of 11; and Ghana: two upland and two beach for a total of 14). The geographical co-ordinates of each transect shall be determined using the most accurate means available. Use of a survey-quality GPS receiver, such as the Trimble PathFinder series (http://www.trimble.com/pathfindersys.html) is preferred. However, the use of a GPS receiver such as the Trimble GeoExplorer (http://www.trimble.com/environmental. html) or equivalent can be used to determine sampling locations to within 15m. Better precision is possible if real-time or post-processing differential correction is available. Each sample location should be photographed in a manner that accurately depicts the location. For example, if a sampling crew is returning to a location previously sampled, but can determine the location only to within 15m, a photograph can distinguish between the actual location and one with different soil characteristics. All locations, regardless of the survey method used, should be thoroughly documented in a waterproof field notebook, including both a narrative description of the location and a hand-draw map or sketch. Descriptions of nearby landmarks that can assist in relocating the position in the future should be included. 3.2.3 Rationale for the Sampling Design The ICF EBS Scientific Team has planned the sampling design described above based on its scientific expertise and the experience it has derived from past experience and surveys in West Africa and elsewhere. As always, the objective of the sampling design is to provide the most accurate and comprehensive analysis of the existing environment, as it relates to the proposed construction and operation of the project, and to do so in the most efficient and cost-effective manner. As indicated in Sections 3.0 and 4.0 below, the chosen sampling design will generate over 14,000 data points to analyzed and interpreted. In designing the sampling plan, the ICF EBS Scientific Team has assessed whether in each case there is the provision for sufficient data collection so that significant statistical results can be produced. Post-data collection, we will validate that assessment by plotting the data points in a way that will indicate whether the addition of new sampling points would add significantly new information to the survey results. If inadequate data conditions arise, a mitigation plan will be implemented to alleviate the inadequacy. ICF Consulting Appendix B-WAGP EBS Work Plan 10 3.3 Offshore Field Sampling­Seabed Sediment grab samples shall be collected at each of the 50 sampling stations using methods described below. Also, the benthic community and seabed homogeneity will be evaluated using SPI. The SPI equipment shall have digital or photographic capability that allows for nearly instant monitoring while at sea of sediment features such as sediment reduction/oxidation (redox) potential, sediment type and overburden, and biological community composition. The SPI operators are benthic specialists, trained to interpret the information collected by the equipment while in the field. SPI shall be taken at three points per sampling station, one on the pipeline route and two off the pipeline route--one at each end of a 2km transect that is perpendicular to the pipeline route and bisected in half by it. These off pipeline stations will be called SPI stations. Information on the parameters from the SPI shall be used to determine whether the grab samples that are being taken on the pipeline or laterals route are representative of the larger area in the vicinity of the route. If the grab samples, as indicated by SPI, are not representative, then additional grab samples shall be taken at the SPI station where images indicate a non-homogenous condition. If necessary, this work plan allows for five additional SPI station grabs. SPI will also be used for later comparison and interpretive support of physical, chemical and biological data. The SPI experts on the ICF EBS scientific team shall provide WAGP with Organism-Sediment Index (OSI) summary mapping statistics. These statistics are calculated on the basis of four independently measured SPI parameters: apparent mean redox potential discontinuity (RPD) depth, presence of methane gas, low/no dissolved oxygen at the sediment- water interface, and infaunal successional stage. SPI data collection capabilities and documentation are provided as Attachment E. 3.3.1 Chemical and Physical Characterization Sediment sampling shall be performed with a Young-modified Van Veen grab sampler or a box core sampler attached to a wire, deployed and retrieved with a winch and A-frame or crane. After retrieval, a grab sample shall be inspected for disturbance, such as washout and low volume, and a description of the sample shall be recorded in the station log. The sample shall be discarded if significant disturbance or poor retrieval is observed and another one taken. If the sample is acceptable, the sediment for chemical analyses shall be removed from the grab with a Kynar coated scoop and Teflon spatula. Sediment from only the top 2cm of the grab shall be used for chemical analyses. For metals, prior to laboratory analysis, sub-samples of each sediment sample shall be air-dried, gently crushed with pestle in agate mortar and passed through 2mm sieve. The less than 2mm fraction will be retained for analysis in appropriately labeled polyethylene bags. The portion of the sample not processed for metals analysis shall be stored frozen in appropriate pre-labeled sampling containers. Polyethylene bags shall be used for storing sediment samples, except those requiring hydrocarbon analyses, these shall be collected and stored in QC Class, pre-cleaned glass jars with Teflon lined lids. ICF Consulting Appendix B-WAGP EBS Work Plan 11 Decontaminated sampling equipment shall not be allowed to become re-contaminated prior to sampling. To avoid this, equipment shall be decontaminated immediately prior to use or otherwise wrapping it securely in aluminum foil shall protect decontaminated equipment. "Clean" equipment must never come in contact with anything other than the sample, air, or other "cleaned" equipment. This precludes contact with the ground (except for the actual sampling area), hands, clothing, plastic bags, buckets, trays, etc. Chemistry grabs shall be taken first, followed by a scrubbing with filtered site seawater in preparation for taking the first of a series of replicate samples that will be analyzed for biological characterization of the seabed. These sediment samples shall be measured immediately using electrodes for: pH Temperature Redox potential and results recorded in the station log. Sample container information shall be recorded on Chain of Custody forms (see Attachment F). Three grab samples for each of the 35 main pipeline stations and five grab samples for each of the 15 lateral stations for a total of 180 grab samples shall be collected. Of these, 50 of these will be analyzed for physical and chemical parameters. In addition, for quality control and assurance purposes, four field duplicates and one deck blank will be analyzed for physical and chemical parameters. The remaining samples (approximately 50) will be characterized for biological parameters, or archived for contingency purposes (see Section 3.3.3, below). All sampling equipment shall be cleaned and scrubbed between stations and equipment shall be decontaminated prior to use as described below: Physically scrub equipment with brushes and liquid soap-and-water mixture (or Alconox non-phosphate powder) to remove any accumulated sediment. Rinse with filtered seawater (from hose or buckets, as appropriate), then rinse with distilled water, then rinse with isopropanol solvent (other acceptable solvents1 are methanol and hexane), and then optionally rinse with de-ionized water. Wipe clean with an absorbent pad, paper towel, or rag, if necessary. Use disposable nitrile gloves during sampling and change them after each sample collection. Equipment blanks will be generated by rinsing and collecting decontaminated equipment with clean laboratory grade de-ionized water. Deck blanks will be generated by exposing QC class, pre-lined glass jars with Teflon-lined lids during operations at the sampling stations in locations 1Note that the GeoExplorer vessel does adhere to a Waste Management Plan that ensures safe disposal of such potentially hazardous materials, as well as non-hazardous materials. ICF Consulting Appendix B-WAGP EBS Work Plan 12 where contamination might be expected to occur, i.e. down wind of vessel exhaust and in sample shipping containers. Sediment samples shall be analyzed in the laboratory for the following parameters: Bulk Properties (grain size, TOC) Organics (oil and grease, TPH, PAH) Trace Metals (Al, Cd, Cr, Cu, Fe, Hg, Mg, Ni, Pb, V, Zn) Nutrients and physicochemical properties (sulfate, ammonia N, orthophosphate P, total P, exchangeable acidity, alkaline metals (Ca, K, Na) 3.3.2 Biological Characterization As discussed above, two replicate samples for benthic infaunal community analysis shall be taken at each of the 35 main pipeline stations. Only one of the replicate samples collected along the main pipeline route will be analyzed in the laboratory. On the laterals, four replicate samples shall be taken at each of the 15 stations; only one of the replicate samples collected along the pipeline laterals will be analyzed in the laboratory. At the discretion of the Chief EBS Field Scientist, additional samples may be collected. The replicate samples will be archived for contingency purposes. As determined by the SPI results, additional replicates may be analyzed to account for seabed heterogeneity. In addition, for quality control and assurance purposes, four field duplicates will be analyzed for biological parameters. The sample must pass the same acceptance criteria as for a chemical sample, with a minimum of 50 percent of the sediment retrieved from the grab. When a grab is determined to be acceptable, observations shall be noted in the station log, and then sediment from the entire grab will be collected into a bucket. The sediment for benthos and benthic organism studies shall then be carefully spread and sieved through a 0.5mm mesh-size aluminum sieve using a low pressure filtered seawater hose system. During the sieving process, all macro invertebrate organisms shall be carefully collected using forceps and preserved in 10 percent buffered formalin solution. Sample handling is the same as for chemical analysis, except that samples shall be refrigerated, rather than frozen. 3.3.3 Biological Analysis of the Seabed Macrobenthic infauna shall be identified taxonomically using a binocular microscope to the lowest possible taxon and from this shall be determined abundance (number of individuals of each taxon per grab sample) and frequency (as proportion of how many times that taxon occurred in the grab samples out of the total number of grab samples analyzed). Initially we intend to only analyze (i.e., taxonomically characterize) the first replicate grab sample (50 samples) unless that grab sample is an outlier relative to other samples taken at that depth in the offshore study area or as indicated by the SPI information. If it were to be an outlier, as determined by SPI analysis and the ICF EBS scientific team, then we would additionally analyze the second replicate grab sample. For the stations on the laterals, if analysis of the second replicate grab added more than 50 percent new species to the total, then the third replicate grab would be analyzed. Likewise, if the third replicate grab added 25 percent more species to total species for grabs one and two, then the fourth replicate grab would also be analyzed. See ICF Consulting Appendix B-WAGP EBS Work Plan 13 Figure 1 for illustration of this approach. For planning purposes we estimate about 10 percent more grab samples would be analyzed over and above the 55 that would be done if there were a single grab sample analysis per station. The remaining samples (i.e., those not needing analysis for WAGP) would be archived in case the information might be needed later. The justification for this approach stems from the main purpose of the benthic infauna analysis, which is to describe the biological community types across the project area. Secondarily, we would like the information to serve as a statistical baseline in the event perturbations later occur. However, in that case we would be limited to making deductions only at the level of the whole pipeline route (or on the basis of distinctly different communities or substrates that might after- the-fact be designated as subcategories of the pipeline route). That is to say, we might use statistical analysis to test whether or not there have been changes in benthic infauna species diversity after an incident has occurred. Even if we were to conduct an up-front analysis of all grabs at a single station, we likely would not have enough information to do such a comparison for only a small portion of the pipeline area, say where a blowout occurs. Thus, if we were to do an "after" study looking for a finding of no significant impact on benthic infauna, then we would be relegated to an approach that replicates our previous sampling methodology for the whole route (or the subcategory if established) and compares species diversity measurements for all 55 stations, before and after. This is similar to an approach suggested by E.C. Pielou in "Ecological Diversity" (published by John Wiley, 1975). Thus, we are intending to define broad regional conditions and the range of regional variability and, given a fixed budget, doing so by using a large spatial coverage and non-replicated samples. Our approach follows Cuff and Coleman "Optimal Survey Design: Lessons from a Stratified Random Sample of Macrobenthos" (J. Fish. Res. Bd. Can. 36: 351-361, 1975) and optimizes our sampling effort. Cuff and Coleman found that preferable results were derived from the same total number of grab samples by increasing the number of stations at the expense of the number of grabs per station. They concluded the optimum number of grabs, given the regional objective, was one per station to maximize the area covered. Macrobenthic infauna sampling data also shall be analyzed to derive measures of species diversity and evenness. Species diversity indices to be useful must address both the measures of abundance and evenness of species present. The Shannon diversity index (H), which takes both into account, shall be calculated. In the Shannon index, the proportion of species i relative to the total number of species (pi) is calculated, and then multiplied by the natural logarithm of this proportion (lnpi). The resulting product is summed across species, and multiplied by -1: S H = - pi ln pi j=1 Evenness (J) shall be determined using the following formula: J=H/ln(S) Where H is the Shannon index, ln is the log base (e), and S is equal to the number of taxa. This index expresses H relative to the maximum value that H can obtain when all the species in the sample are perfectly even with one individual per species. ICF Consulting Appendix B-WAGP EBS Work Plan 14 Figure 1 ICF Consulting Appendix B-WAGP EBS Work Plan 15 3.4 Offshore Field Sampling--Water Water sampling shall be carried out at each of the 50 offshore sampling stations (see map, Attachment A) on the proposed pipeline route, as close as practical to the locations where the sediments are taken. Samples shall be collected at two depths--near the water surface (< 3m) and at 1m above the bottom. Water samples shall be collected with Teflon lined 5-l Niskin bottle samplers. Samples shall be transferred into clean plastic or glass bottles and stored in coolers with ice, and preserved appropriately. The same COC and shipping requirements that pertain to sediment chemical analysis samples pertain to these water samples. 3.4.1 Chemical Characterization The portion of the samples to be tested for trace metals, 1L, shall be acidified to approximately pH 2 using 4N nitric acid. The following wet chemistry parameters shall be determined in the laboratory (See Section 4, Laboratory Procedures): Trace metals (Al, Cd, Cr, Cu, Fe, Hg, Mg, Ni, Pb, V, Zn) Water Quality (alkalinity, COD) Nutrients (ammonia N, nitrate N, total N, orthophosphate P, total P, sulfate) Alkaline Metals (Ca, K, Na) 3.4.2 In-Situ Conductivity-Temperature-Depth Measurements At each of the 50 offshore sampling stations, using a water quality meter of equal or better quality as the Coastal Leasing Micro-conductivity-temperature-depth (CTD) probe, which internally records the data, in-situ measurements shall be made of: pH Temperature DO Salinity Turbidity Electrical conductivity Chlorophyll-a Redox potential Data shall be collected by the CTD continuously through all water depths for each cast. Data on each cast will be stored on internal instrument memory, and downloaded to a laptop computer after each cast. The instrument shall be calibrated prior to the cruise and checked again after sampling is complete. For dissolved oxygen measurements, Winkler titration equipment and solutions shall be available as a back up to the electronic sensor on the CTD. 3.4.3 Trawl Sampling and Stations Trawl sampling at a maximum of 25 stations in the study area (see Attachment A) shall be conducted using the methods described below for fish, ichthyoplankton, phytoplankton, and zooplankton. Along the laterals, 15 trawls will be conducted at approximately the same locations as the sediment sampling stations described above. In addition, 10 trawls will be conducted at ICF Consulting Appendix B-WAGP EBS Work Plan 16 approximately 50km intervals along the main pipeline route. Trawl depths have been chosen to collect representative samples of fish and plankton assemblages. Selected tissue samples (not to exceed eight samples) from fish commonly used for human consumption will be obtained from the trawls for PAH and metals analyses. This will result in the following number of trawl stations in each country: Country Nigeria Benin Togo Ghana Coastline Length (km) 50 120 50 330 Trawl Locations 4 5 4 12 The EBS trawl methods shall attempt to replicate the trawl methods of those fisheries department trawls so that results can later be correlated and the actual data set would then be much larger. 3.4.3.1 Fish Population Characterization Fish and macro invertebrates will be collected with a 25ft Marinovich Otter Trawl sampler. The net shall have a cod-end mesh size of 2cm. The trawl will be deployed along the predetermined transects with a scope of at least 3:1 ratio (wire:depth) and the starting position initiated when the net is fully deployed near the bottom (GPS Coordinates recorded on station log). The net will be towed on the bottom at a rate of 3 knots for 10 minutes. The net will be retrieved while the vessel maintains a speed between 5 knots and the endpoint will be recorded as the position when retrieval is begun.2 If underwater hazards in the study area restrict this trawling plan, the chief scientist can amend the methodology in the field and then record notes on the daily log sheet that indicate how to normalize the changes during analysis. The net contents will be emptied into plastic tubs. Fish will be sorted by species, identified to as low a taxon as possible, photographed, counted, measured for length, width, weight, and sex if possible. Representatives of each species shall be preserved for future reference and further identification, if taxonomic identification cannot be completed while on the boat. The fish trawls shall be coincident with the plankton stations. The stations along the pipeline route shall be designated with this naming protocol: country letter­number of trawl­TR. For example, B-02-TR would be a second trawl off of Benin. This naming scheme may be further modified as necessary. Selected tissue samples, eight in total, from fish commonly used for human consumption shall be obtained from the trawls for PAH analyses. The fish tissue analysis may incorporate composites of individuals depending on the size and numbers of individual fish collected in the field. Only edible tissues shall be sub-sampled in the lab and analyzed. Further details regarding which species and tissues to collect for these samples will be provided during the trawls by the Chief Field Scientist. 2Details of fish trawl methodology will be verified with the fisheries department in each country, to achieve the maximum consistency with existing data. ICF Consulting Appendix B-WAGP EBS Work Plan 17 Whole fish for tissue chemistry analysis shall be double wrapped in pre-cleaned (baked) aluminum foil, placed into a labeled polyethylene bag, and frozen. Individual specimens shall be assigned labels based upon the station name-species code-###. For example, B-02-TR-GD-005 would be from the second Benin trawl, a Galeodes decadactylus, number 005). Fish species codes will be designated and recorded in Fish Trawl logs (Attachment G) in the field by the Shift supervisor and Chief Field Scientist. Sensitive habitats such as sea turtle foraging sites will be identified prior to sampling and these shall be avoided during trawling. 3.4.3.2 Plankton Community Characterization Step oblique plankton tows shall be conducted sequentially with fish trawls. Samples for plankton (ichthyoplankton, phytoplankton, and zooplankton) analysis shall be collected from approximately the same sources as for water quality. Optional vertical or nocturnal trawls may be conducted to determine diurnal migration at the discretion of the Chief Field Scientist. Plankton tows will be conducted using following net specifications: Ichthyoplankton: Bongo net; mesh size 330um/Model WP3, ring radius 50cm Zooplankton: Nason net; mesh size 200um/Model WP2, ring radius 28.5cm Phytoplankton: Nason net; mesh size 60um/ModelP200, ring radius 27cm Each net system will incorporate an appropriate flow meter. Plankton tow positions and deployment will be conducted in a similar fashion to fish trawls and with station log documentation (see Attachment G). Pertinent tow data will be recorded to determine estimated collection volume and depth of tow collection (i.e. tow speed, opening and mesh size of net, time of deployment at determined depth etc.). Samples will be concentrated after towing with a filtered seawater rinse. Phytoplankton samples will be treated with Lugol solution (1:100) in the laboratory and allowed adequate time (about 1 week) to ensure adequate sedimentation. The ichthyoplankton and zooplankton will be fixed in 10 percent mentholated-formaldehyde solution. After carefully removing the supernatant, a resulting volume of about 5 ml shall be surveyed in a counting chamber at different magnifications of the compound microscope. Scaled drawings of recorded plankton shall be made based on the measurement features of taxonomic importance. Drawings can be supplemented with micrographs where possible. Identification will be based on scale drawings/micrographs and diagnoses, using relevant keys from texts and journal references, especially those for Nigeria and the Afro-tropical region. Individuals shall be identified to the lowest possible taxon and the community structure determined using appropriate statistical indices. (See Section 5.0, Data Analysis and Reporting). 3.5 Offshore Field Sampling­Marine Birds, Mammals, and Reptiles Information on these animals shall be obtained primarily from literature. However, deliberate observations of species distributions, estimated numbers, and behavior, if relevant, shall be recorded during field operations. Special attention will be paid to making observation of whales, ICF Consulting Appendix B-WAGP EBS Work Plan 18 dolphins, sea turtles, and West African manatee that we know are of concern and could be encountered in the study area. Records shall be made in the comments section of the appropriate station log sheet, trawl log sheet, or daily shift reports. 3.6 Offshore Field Sampling­Meteorological Conditions Measurements of air temperature, wind speed and direction, current speed and direction, and wave height shall be carried out during field sampling and trawling operations. These shall be monitored while on station using calibrated instrumentation. These data shall be recorded on the appropriate station log sheet. 3.7 Characterization of Ocean Currents Review of the Environmental Guidelines and Standards for the Petroleum Industry in Nigeria (EGASPIN), issued by the Department of Petroleum Resources, Lagos, 1991 (revised edition 2002)3 reveals two places where characterization of currents is relevant. Under Part VIII, Section 4.0 Significant Effects/Impacts on Fish Migration Routes and Nursery Areas and Section 5.4 Baseline Description of the Existing Environment and Resources Used, Subsection 5.4.2 Water, where it states the following should be considered and discussed: oceanographic parameters/factors and their seasonal variability that can characterize pollution impact. This work plan recommends a thorough review of the literature to determine whether adequate current characterization for preparing the EIA for the study area already exists. If adequate information exists in the literature, or an existing dataset can be purchased, then field sampling of currents would likely not be justified. Current data will be used to justify the environmental impact assessment of potential "upset conditions" during pipeline construction (e.g., fuel spills that result from accidents involving vessels and other construction equipment). Because WAGP cannot completely exclude such potential "upset conditions" from the EIA, some estimates of current conditions­desktop or other­will likely be needed. ICF's initial assessment is that impacts that might result from re-suspension of sediments during construction would probably not predicate current sampling/modeling because the effects would be too minimal or localized to be elucidated by the limited sampling that WAGP could undertake, e.g. eight current meters spaced at roughly 75km intervals. If WAGP decides to deploy currents near river mouths to assess the river discharge, then electro- magnetic current meters, rather than ADCP, should be used. 3.8 Offshore Sampling­Documentation of Sampling Activities Station Logs, Fish Trawl and Plankton Station Logs, and Daily (Shift) Activity Reports (Attachments G, H, and I) shall be printed on water resistant paper and maintained in a 3-ring 3Hereafter referred to as DPR, 2002. ICF Consulting Appendix B-WAGP EBS Work Plan 19 binder. This logbook shall be maintained by each Shift Leader and signed at the completion of each station. All field data shall be recorded in ink. Photo documentation information, including assigned film roll number/data file folder, exposures and topic, and any miscellaneous comments should be recorded in each field scientists (photographers) field notebook starting at the end of the field book working towards the front. All original field notebooks, navigation and instrument electronic files, film or photographs, Chains of Custody (copies) shall be turned into the Chief Field Scientist at the end of cruise operations for review and appropriate processing. These shall be returned upon completion of the audit or demobilization process. The following forms shall be maintained by all shift leaders, field scientists, and reviewed on a daily basis by the Chief Field Scientist: Chain of Custody Form (Attachment F) Offshore EBS Fish Trawl and Plankton Station Log (Attachment G) Station Log (Attachment H) Daily (Shift) Activity Report (Attachment I) The Chief Field Scientist shall also provide a comprehensive cruise report within 30 days of demobilization. 3.9 Onshore Field Sampling­Vegetation 3.9.1 Vegetation Quadrats At each sampling point along a transect, information leading to plant species diversity and abundance shall be collected (See Section 3.2.2). The sampling quadrats shall be 10m circular radius for trees greater than 7.5cm diameter at breast height (dbh) (trees), 5m radius for shrubs and saplings greater than 1m tall but less than 7.5cm dbh (saplings) and five randomly placed 1m x 1m square quadrats for herbaceous plants and trees less than 1m tall (understory plants). See Figure 2 for an illustration of the transect and quadrat design. Within the 10 m radius quadrats, the dbh measurements for each tree and its species name will be recorded. In the 5m radius plots, the number of saplings of each species will be recorded. In the 1m x 1m quadrats, plant species cover will be estimated by species and recorded using the following abundance categories: 90-100% = 10 80-89% = 9 70-79% = 8 60-69% = 7 50-59% = 6 40-49% = 5 30-39% = 4 20-29% = 3 10-19% = 2 0-9% = 1 The approximate height of the tree canopy, sapling canopy, and understory stratum will be recorded at each sampling point. Also recorded at each sampling point shall be the phenology of the dominant vegetation and any abnormal senescence, yellowing, insect/fungal damage, or shedding of leaves. ICF Consulting Appendix B-WAGP EBS Work Plan 20 Figure 2 ROW (50 m WIDE) HABITAT BOUNDARY VEGETATION QUADRANT 1 3 20 m 2 4 5 1m 1m E UT RANDOM TRANSECT 20 m PLACEMENT WITHIN RO PIPELINE ROW AT 0.5 m INTERVALS ENIL PEIP 20 m 10 m HABITAT BOUNDARY SEAWARD VEGETATION QUADRANT STRAND TRANSECT FOR HERBS/UNDERSTORY EE S ( > 7.5 TR cm d b 1 3 h ) ENIL 2 (> 1 m PE SHR1 UBS PI 4 5 1m TALL) 1m 3 5 m 2 5 m SOIL 10 m POINT SAMPLE 4 5 1m 1m HERBS/UNDERSTORY 10 m ONE FROM EACH POINT SAMPLE DEPTH COMPOSITED FOR ALL 4 SAMPLE POINTS COMPOSITE SAMPLE 15 cm SEA COMPOSITE 15 cm A 20 cm 50 cm COMPOSITE 2 ICF Consulting Appendix B-WAGP EBS Work Plan 21 In the beach/inter-tidal habitat type, transects shall be established perpendicular to the shoreline in order to reveal gradients in vegetation type. Only the five randomly placed 1m x 1m quadrats shall be used at each of the three sampling points per transect. Plant species cover shall be estimated by species and recorded. Plant health status shall be visually assessed and noted as described above. Plant species that cannot be identified in the field will be taken to a herbarium for identification. Onshore EBS Data Collection Forms in French and English that will be used for vegetation sampling are provided in Attachment J. The equipment list for onshore sampling can be found in Attachment C. 3.10 Onshore and Intertidal Field Sampling­Aquatic Macrophytes A survey for the occurrence and abundance of marine algae in the rocky intertidal zone shall be carried out along transects that are coincident with the laterals. Initial reconnaissance suggests these habitats are only present on the two Ghanaian laterals. The other sites have sandy bottom substrates. It is recommended that, even though this habitat is an offshore one, the sampling be done in association with the onshore fieldwork. Two of the 60m onshore transects with four sampling points each at 20m intervals, starting at the high tide mark, but randomly located laterally in the pipeline ROW, can be used to sample these two habitats in Ghana. Algae observed while sampling will be collected, photographed, preserved, and dried with an herbarium press, and identified to as low a taxon as possible. Algal samples may also be collected from trawls or from the surface of sediment chemistry grabs, e.g. if sediment grabs and other observations indicate aquatic macrophyte sites along the lateral routes, a decision will be made in the field to conduct more detailed sampling for these macrophytes. Algae thus observed will be collected, photographed, preserved, and dried with an herbarium press, and identified to as low a taxon as possible. Their abundance shall be estimated and noted on the appropriate data collection form. 3.10.1 Measures of Vegetation Abundance The abundance of trees in each habitat (for those habitats with trees) shall be expressed in terms of average stand basal area. Stand basal area, denoted by the symbol G, is a useful parameter for quantifying a forest stand. It is a summary of the number and the size of trees in a stand. As individual tree basal area is related to tree volume, biomass, crown parameters, etc., so too stand basal area is related to stand volume, and biomass. G is also correlated with competition or the density of a stand. G is the sum of the basal area of all (living) trees in a stand, expressed in m2/ha. Basal area for a single sampling point on a transect will be calculated from measurements of the diameter (dbh incm) of all trees in the area of the 10 m radius quadrat (a shall be expressed in square hectares) using the following formula: 2 G = * dbh2 = 0.0000785398* dbh 40000 a a Average basal area of the habitat shall be derived by averaging the sample point basal areas across the four sampling points along the transect. ICF Consulting Appendix B-WAGP EBS Work Plan 22 The abundance of saplings in each habitat shall be expressed as average number of stems, which shall be calculated by adding the number of stems for all species of saplings at a sampling point and then averaging that number across the four sampling points along the transect. The abundance of understory in each habitat shall be expressed as average cover of understory species, which shall be calculated by adding the total cover for all species of understory vegetation at a sampling point and then averaging that number across the three or four sampling points along the transect. 3.10.2 Measure of Vegetation Species Diversity Species diversity indices to be useful must address both the measures of abundance and evenness of species present. The Shannon diversity index (H), which takes both into account, shall be calculated for each habitat. In the Shannon index, the proportion of species i relative to the total number of species (pi) is calculated, and then multiplied by the natural logarithm of this proportion (lnpi). The resulting product is summed across species, and multiplied by -1: S H = - pi ln pi j=1 For determining the proportion of species the number of stems shall be used for trees and saplings and the abundance category (1-10) shall be used for understory species. Average species diversity of the habitat will be derived by averaging the sample point species diversity across the three or four sampling points along a transect. 3.11 Onshore Field Sampling­Soil Soil samples shall be collected along the same transects in the 17 habitats and sampling points used for vegetation sampling. A total of approximately 62 soil point samples (44 inland and 18 nearshore) per season shall be collected from approximately a 15-20cm depth. Soils in each of the habitat types identified in the study areas shall be assessed in terms of regional and local characteristics, susceptibility to erosion, physical and chemical characteristics and biota (soil organisms). The 62 soil point samples per season shall be analyzed for the following parameters: pH Total hydrocarbons TOC Trace metals (Al, Cd, Cr, Cu, Fe, Hg, Mg, Ni, Pb, V, Zn) Particle size distribution Coordinates for soil samples shall be reported using decimal degrees as indicated on the Onshore EBS Data Collection Forms that are provided in Attachment J. Additional samples shall be collected as composites for each transect. The necessary number of additional samples needed to create a composite sample shall depend upon the heterogeneity of soil on the transect. Team leaders shall make this judgment in the field. There shall be two composite samples per transect--one composite sample shall be for soil collected at a depth of 0- ICF Consulting Appendix B-WAGP EBS Work Plan 23 15cm and the other at 15-50cm depth (see Figure 2). A total of 34 composite samples per season shall be collected and analyzed for the following parameters: PAH Microbiology Macrobiology/soil ecology 3.11.1 Soil Sample Handling and Preservation Soil sample collection and handling shall be carried out in accordance with DPR, 2002 (Part VIII D (2): Sampling and handling of samples). The methods of analyses used shall be those specified in DPR guidelines and standards (2002) and other international analytical standards such as in Methods of Soil Analysis (Page, et al. 1987), U.S. Agronomy No 9: Soil Survey Analytical Continuum (USDA/SSIR No 42 Version 3.0 of 1996) and Methods of Soils and Plant Tissue Analysis (International Institute for Tropical Agriculture (IITA), Ibadan, 1979). The equipment list for onshore sampling can be found in Attachment C. For in-situ field measurements and sample collection, practices such as regular, periodic calibration of the instruments and standardized observational procedures shall be instituted to reduce the likelihood of errors. The soil auger and sampling tube shall be decontaminated before and after each sampling event. Pre-cleaned aluminum foil sheets shall be used to line sampling buckets and disposable hand-gloves shall be changed after each bulk/composite sample. Whenever possible, sample compositing shall be done in the laboratory to reduce the likelihood of contamination. Field and equipment blanks shall be collected to document sterile collection and decontamination methodology. All soil samples for chemical analysis shall be inventoried and stored in a secure area immediately after collection. The inventory includes counting samples to ensure that all samples were collected and placed in the custody area in the vehicle, documenting all samples, and preparing a Chain of Custody form (Attachment F) for all samples. The Chief Field Scientist, his designee, and subcontractors are responsible for arranging sample delivery and pickup. Soil samples meant for TPH and PAH analysis shall be kept on ice immediately after collection. In the laboratory, the samples shall be refrigerated at all times, and may be stored frozen for TPH and PAH analysis. At all times after collection, sample integrity and custody must be maintained. Custody seals shall be used on all shipping containers (i.e., coolers) to maintain custodial security while the samples are in the possession of a third party (e.g., air freight courier). Samples shall be shipped or transported to the appropriate analytical laboratories either frozen packed on dry ice, or refrigerated packed with frozen blue ice. When shipping samples with dry ice, the container shall be vented (coolers should have a vent at the bottom on one end) and must possess a label clearly stating that the cooler contains dry ice and the number of kilograms of ice. Materials that are considered hazardous shall be shipped with the appropriate paperwork and labeling. Every effort shall be made to deliver samples to the analytical laboratory in a timely manner. In the laboratory, the samples shall be kept in the freezer prior to laboratory analyses. ICF Consulting Appendix B-WAGP EBS Work Plan 24 3.12 Onshore Field Sampling--Wildlife and Animal Resources Field observations shall be carried out in each of the 17 habitat locations to obtain information on the animal and wildlife resources within the study area. Observations during evening and early morning for three days in each habitat shall be made while walking along beaches and footpaths and slowly riding in boats along creeks and around landfalls in the study area. Animal and wildlife resources shall be taxonomically identified. Wherever possible, pictures of the wildlife, their parts, footprints, nesting sites, and fecal droppings shall be taken as evidence of their presence. In addition, information shall be obtained through interviews, focus group discussions and other interactive sessions. These interactions should involve hunters, trappers, traders in wildlife materials and farmers from the settlement and village locations within the study area. 3.13 Onshore Field Sampling­Surface Water Quality, Sediment Quality, and Hydrobiology Water sampling shall be conducted during both dry and wet season periods, in study areas that contain surface water bodies. In-situ water sampling at each station (one sampling station per water body), during both dry and wet season sampling periods, shall include measurements of: Salinity Conductivity Turbidity DO pH TDS Temperature In addition to in-situ measurements, wherever feasible water samples shall be collected at the water surface and at the water-sediment interface. Where water bodies may be tidally influenced samples will be collected during both high and low tide regimes. Samples shall be taken from each station by directly dipping the sampling container into the surface water or for subsurface water by using a Teflon lined 5-litre Niskin water sampler. Sampling containers shall meet the requirements indicated in DPR, 2002. Up to 40 samples (i.e., ten water bodies at two depths and at two tide regimes) each season should be collected. In Nigeria, it is estimated that 3 water bodies will be sampled, 3 in Benin, and 4 in Ghana. The samples will be analyzed in the laboratory for the following: Oil and grease Trace metals BOD5 Total alkalinity Anions (SO4-2, NO3, NH3+) Microbiology Primary productivity of phytoplankton (excluding macrophytes) Plankton (phytoplankton and zooplankton) biomass ICF Consulting Appendix B-WAGP EBS Work Plan 25 In situ measurements of ambient and water temperature values shall be taken using a mercury glass bulb or a digital thermometer. Total water depth and turbidity shall be sounded and measured using a lead line attached to a Secchi disc (a portable electronic multi-probe may be substituted). Water pH, conductivity and salinity shall be taken in situ on the collected samples using portable pH and combined conductivity ­ salinity meters. Samples for microbiology shall be collected in sterile pre-labeled containers and stored on ice until they can be transferred to refrigerated storage in the laboratory or field base. The geographical co-ordinates of each sampling station shall be determined using a portable GPS unit. The equipment list for onshore sampling can be found in Attachment C. 3.13.1 Plankton Standing Crop and Primary Productivity For plankton analysis, 5L samples of surface water shall be collected at each sampling point. The water shall be strained through a phytoplankton net (mesh size of about 45µm) to a concentrate volume of about 25ml to 30ml. The sample shall be preserved in 5 percent formalin solution by the addition of appropriate volume of 40 percent formaldehyde (100 percent formalin). Separate samples shall be collected for the ex situ determination of respiration and productivity under natural light conditions in the laboratory. 3.13.2 Sediments and Macrobenthic Fauna Five sediment samples shall be collected from the benthic environment at each of the surface water sampling stations. The loose surface accumulation should be removed and then samples taken from approximately 30cm to 50cm depth. Measurements of the sediments shall be taken in-situ of: pH Redox potential Temperature after which the sample shall be split. One half shall be sieved and macrobenthic organisms collected and preserved in 10 percent buffered formalin solution. The other half shall be stored on ice and transported to the laboratory for microbiology and chemical analyses. Given an estimated ten water surface sampling points, up to 50 sediment samples shall be collected during each sampling season. Tests to be carried out on the sediments shall include the following: Grain size TPH TOC Trace metals Macrobenthic infauna The water bottom sediment shall be sampled using a Van Veen grab. One portion of each sample shall be used to determine in situ the temperature, pH, and redox potential. One half of each ex situ sample shall be placed in a glass jar (QC class) and transported on ice to the laboratory for other physico-chemical and microbial analysis. The remaining half of the grab sample will be sieved for macrobenthic analysis. Each processed sieve sample will be preserved ICF Consulting Appendix B-WAGP EBS Work Plan 26 in 10 percent buffered formalin solution. Photographs for unknown or questionable identification of specimens shall be taken. 3.13.3 Aquatic Sampling Handling All samples shall be collected using an appropriate and clean sampler or containers. All determinations without holding times shall be carried out in situ on the field. Samples that must be transported from the field to the laboratory shall be well-preserved, following the guidelines of DPR, 2002. All samples shall be properly labeled in accordance with the same guidelines described previously in this work plan. 3.14 Onshore Field Sampling­Fish and Fisheries Resources Fisheries observations shall be carried out within 17 selected habitat-sampling areas (project- wide). Fish studies shall be based on observations of fisherman landings and fish market surveys in the study area. The entire catch shall be observed for its composition and representative specimens. Fish species shall be taxonomically identified and fishing gear, tools, and technology commonly used by local fishermen shall be noted on fisheries log sheets. Information on the collected fish shall include the species name, the length, weight, and health status, among other characteristics. 3.15 Onshore Field Sampling­Climate and Meteorology A mobile meteorological station shall be set-up near the proposed compressor station site to provide information on current meteorological conditions. Data retrieved from the meteorological station in Nigeria will be used during subsequent air quality characterization. Baseline survey information in Ghana, Togo, and Benin shall be collected from existing sources of meteorological information such as from nearby airports. 3.16 Onshore Field Sampling­Air Quality The ICF EBS Scientific Team shall undertake a limited air quality study focused on the vicinity of the proposed compressor site. One portable air sampler equipped with 6L Tedlar bags will be stationed at the site to collect ambient air grab samples. Three sample periods per day will be collected over a two-week period. The elements of the air samples to be analyzed shall be analogous to compressor facility potential pollutants of concern: particulate matter (PM), volatile organic compounds (VOCs), carbon monoxide (CO), and oxides of nitrogen (NOx). Particulate matter is collected on a filter and then measured in the laboratory. Gaseous samples will be analyzed in the laboratory for CO and NOx concentrations. Because oxides of sulfur (SOx) are expected to be absent in the WAGP supply, they will not be analyzed in these samples. Important sources of air emissions shall be identified and characterized during the drafting of the literature review and the technical project description (including estimated emission rates, pollutant concentrations, and dispersion conditions), and sensitive receptors will be identified and characterized during field observations. ICF Consulting Appendix B-WAGP EBS Work Plan 27 3.17 Onshore Sampling­Documentation of Sampling Activities Vegetation, Soil, Wildlife, and Surface Water Forms (Attachment J) shall be printed on water resistant paper and maintained in a 3-ring binder. This logbook shall be maintained by each Field Team Leader and signed at the completion of each station. All field data shall be recorded in ink. Photo documentation information, including assigned film roll number/data file folder, exposures and topic, and any miscellaneous comments should be recorded in each field scientists (photographers) field notebook starting at the end of the field book working towards the front. All original copies of field notebooks, navigation and instrument electronic files, film or photographs, Chains of Custody (copies) shall be turned into the Field Team Leader at the end of sampling operations for review and appropriate processing. 3.18 Onshore Field Sampling--Soil and Groundwater at the Compressor Station Site (Nigeria only) An assessment of the baseline physical and chemical characteristics of the uppermost groundwater bearing layer(s) in the vicinity of the compressor station site, including information regarding aquifer hydraulic properties beneath the construction site, will be performed. Electrical reconnaissance geophysical methods (vertical electrical sounding) will be used and coupled with the installation, sampling and testing of three groundwater monitoring wells. These geophysical methods are intended to produce a quick and efficient indication of the depth to water bearing layers, direction of groundwater flow, and gross groundwater quality (conductivity) over a large area. This information is intended to aide in the final design and placement of the monitoring wells. Once calibrated to the borehole sediment types, the results from the vertical electrical sounding (VES) will indicate subsurface conditions over a much broader area than that provided by either method alone. The monitoring wells and their installation are intended to provide direct measurement of the chemical and physical properties of soil and water-bearing layers. Based on our current understanding of the location and depth of near coastal groundwater systems in the project area, the planned depth of the monitor wells is 10m. 3.18.1 Electrical Soundings Geophysical prospecting methods involving the use of electrical resistivity principles are planned as a precursor and aide to monitoring well installation. The methods are intended to provide a quick and efficient depiction of shallow groundwater resources at the site on a reconnaissance basis. They do so by detecting the responses in subsurface resistively to an applied electrical field. Variation in responses both horizontally and vertically due to variations in lithology, the presence of groundwater, and changes in groundwater quality due to salts or other pollutants are discernable. To conduct the survey, collinear arrays such as Schlumberger arrays configured for vertical electrical soundings (VES) shall be employed over the study area. Array configuration shall be employed so that a profile depth of at least 30m is achieved. Electrical current sources shall be provided by portable generating equipment. Interpretive methods shall employ commercially available software packages. ICF Consulting Appendix B-WAGP EBS Work Plan 28 3.18.2 Soil Borings Based on the outcome of the electrical soundings, the final locations of three monitoring wells shall be determined. To install the wells, rotary drilling equipment that employs auger or air drilling systems shall be mobilized to the project site and used to create soil borings. Soil core samples shall be obtained in the soil borings on a continuous basis following applicable ASTM protocols using split-spoon or Shelby tube sampling systems. Borehole sediment shall be classified in the field as to type and texture using the USCS soil classification system. Borehole logs shall be prepared based on the soil classifications. The boreholes shall be drilled to a diameter sufficient to accept a 10cm diameter PVC well casing and screen placed in a centralized position in the borehole. 3.18.3 Soil Sampling and Analysis At certain depths to be selected in the field, cores samples shall be retained from each borehole for laboratory analyses. The depths sampled shall be based on the occurrence of staining or major lithologic changes but no fewer than three depths shall be sampled. Each sample shall be placed in glassware containers supplied by the analytical laboratory, and transported in chilled coolers to the analytical laboratory under standard chain-of-custody control. The samples shall be analyzed for the following parameters: TPH Trace metals (Al, Cd, Cr, Cu, Fe, Hg, Mg, Ni, Pb, V, Zn) Grain size/porosity Soil sample handling procedures described in Section 3.11.1 shall be observed. The analytical methods are more fully discussed in Section 4.4, below. 3.18.4 Monitoring Well Construction Once completed, the boreholes shall be converted into monitoring wells. The wells shall be constructed of 10cm diameter PVC casing and screen configured so that the screen is aligned adjacent to the water bearing layer to be tested and monitored. Once inserted, the annular space in the borehole between the screen and wall of the boring shall be gravel-packed from the bottom of the borehole to a depth of 1m above the screened interval. The remainder of the annular space shall receive a 1m bentonite plug and cement grouted to the surface. Protective, lockable surface casing shall be placed over the wellhead and a cement pad and bollard posts placed around the protective surface casing. The horizontal locations of the monitor wells shall be determined using a portable GPS unit. The ground surface and top of each monitoring well casing shall be determined on a relative basis to the nearest 0.010ft by legal survey referenced to a permanent retrievable construction datum. Proper capping of wells and installation of custody seals should be emphasized at the end of each sampling season. 3.18.5 Groundwater Analysis The wells shall be sampled no sooner than 48 hours after their installation. In preparation for sampling the wells shall be developed to remove drilling residuum. To determine development progress, development fluids shall be removed by bailing or with a pump and tested in the field for pH, specific conductance, turbidity and temperature. Consistent, sequential measurements of ICF Consulting Appendix B-WAGP EBS Work Plan 29 these parameters will be an indication that development is complete. If any drilling fluids are used during the advancement of the soil augur, then a volume of ground water equal or greater than three times the volume of any lost drilling fluids must be removed during development of the well. Both during the dry and wet season, one groundwater sample from each monitoring well plus one duplicate sample from one monitoring well shall be retained for analysis in the laboratory. Sampling shall be carried out with clean, unused sampling implements at each well. Each sample shall be placed in glassware containers supplied by the analytical laboratory and transported in chilled coolers to the analytical laboratory under standard chain-of-custody control. The samples shall be analyzed in the laboratory for the following parameters: pH PAH Trace metals (Al, Cd, Cr, Cu, Fe, Hg, Mg, Ni, Pb, V, Zn) The analytical methods are more fully discussed in Sections 4.5 and 4.7.1, below. 3.18.6 Hydraulic Conductivity To estimate the hydraulic conductivity, single well tests (slug tests) shall be carried out at each monitoring well. The results will be entered into a database for future assessment needs. Tests shall be conducted using both falling and rising head methods. Portable battery powered water level indicators and data loggers shall be employed during the tests. Test analysis incorporating methods appropriate for the aquifer type (confined or unconfined) shall be employed using commercially available software packages. 3.19 Summary of Planned Onshore and Offshore Biological and Meteorological Sampling Planned Biological and Meteorological Sampling Parameter Sample Quantity Vegetation Individual Species Abundance Individual Species Frequency 124 (62/season) Species Diversity Fish Individual Species Abundance Individual Species Frequency 25 trawl catches Species Diversity Plankton Individual Species Abundance 75 trawl catches (25 each of ichtyo-, zoo-& Individual Species Frequency phyto-plankton) Species Diversity Aquatic Macrophytes Individual Species Abundance 80 (2 transects x 4 sample points x 5 quadrats x Individual Species Frequency 2 seasons) Species Diversity ICF Consulting Appendix B-WAGP EBS Work Plan 30 Planned Biological and Meteorological Sampling Parameter Sample Quantity Offshore Benthic Infauna Individual Species Abundance Individual Species Frequency 56 (51 sample stations + 10% double sample Species Diversity analysis) Species Evenness Onshore Benthic Infauna Individual Species Abundance Individual Species Frequency 100 (10 water bodies x 5 samples x 2 seasons) Species Diversity Marine Birds, Mammals, Reptiles Individual Species Abundance Individual Species Frequency Observations as encountered Species Diversity Onshore Wildlife and Animal Resources Individual Species Abundance Individual Species Frequency 102 (17 habitats x 3 days x 2 times/day) Species Diversity Offshore Meteorological Conditions Air temperature Wind speed and direction 105 (55 pipeline stations & 25 fish trawl station Atmospheric pressure & 25 plankton trawl stations) Doppler current Wave Height ICF Consulting Appendix B-WAGP EBS Work Plan 31 4.0 LABORATORY PROCEDURES 4.1 Relying on Regional Cooperation for Laboratory Sample Analysis The WAGP pipeline project crosses international borders and offers great opportunity for regional cooperation. In terms of laboratory analyses, the ICF EBS Scientific Team sees great potential for sharing of technical knowledge and experience, and for organizations to take advantage of the opportunity to develop new capabilities thus adding to the regional capacity for these services for future environmental programs. This goal needs to be balanced with the complex logistics and schedule of the field program, but more importantly, any program design needs to consider the over-riding need to produce data of the highest quality so that the EBS can be used as a tool to accurately assess the potential future impacts to the environment arising from the proposed project. To balance these goals, the team is following a multi-step evaluation process of in-region laboratory capabilities. In the initial phase, a preliminary assessment of the available resources and capabilities in the participating countries was conducted. This assessment resulted in a preliminary assignment of laboratory analyses to support the offshore survey. Based on the team's experience with these types of programs and the schedule for the marine survey, there was a decision made to assign tests rather than individual samples. Each country's laboratories will conduct all of one type of analysis (e.g., metals). The Gulf of Guinea spans all four countries, and this approach has been pursued to ensure consistency in analysis and results and to reduce the potential for errors in data management. An oceanographic research vessel has been leased and will be deployed for two weeks to collect offshore baseline data. The ICF EBS Scientific Team is very sensitive to the time and investment in this effort. It would be very expensive and time-consuming to deploy the vessel a second time if, for instance, the results of the metals analysis conducted in Ghana was very different from the results of the metals analysis conducted in Togo. The cooperative approach that has been chosen, allows the team to be efficient in sample collection and timely delivery of samples to the laboratories as well as ensuring data integrity. An on-site inspection of the participating laboratories and organizations was recently conducted by ICF as part of the planning and quality assurance process. It was done to verify the capabilities within each organization, as well as to gauge the capacity for sample analysis with respect to overall project schedule. It also allowed a more informed assessment of the areas that would benefit from technology exchange, i.e. ideally the managers of the laboratories in one country will open their doors to the other countries' scientists to share knowledge and experience, and vice versa For the onshore portion of the EBS, all of the samples collected during the EBS field events will be conducted in that country, at least as best possible given the country's existing capabilities. This will afford another opportunity for capability development in those countries with limited services. In addition, because the onshore fieldwork will overlap with the offshore survey, this type of distribution of the laboratory analysis workload throughout the project team will help ensure that the project schedule will not be adversely affected by capacity limitations. ICF Consulting Appendix B-WAGP EBS Work Plan 32 4.2 Chemical and Physical Analysis of the Seabed The sediment samples will be analyzed for the physical and chemical parameters using the methods4 listed in the table on page 34. 4.3 Chemical Analysis of the Offshore Water Column The laboratory analyses of the physical-chemical parameters of water quality will be based on the methods as presented in the table on page 35. 4.4 Offshore Fish Tissue Analysis The eight fish tissue samples shall be analyzed for PAH using the methods specified below. The fish tissue analysis involve "whole body" analysis and may incorporate composites of individuals, depending on the size and numbers of individual fish collected in the field. 4.5 Chemical Analysis Of Onshore Soil Samples The soil samples will be analyzed for the physical and chemical parameters using the methods listed in the table on page 36. 4.5.1 Total Petroleum Hydrocarbons A standard curve of the absorbance at 420nM in spectrophotometer of different known concentrations of petroleum hydrocarbon in extractant shall be plotted to serve as a reference for determining the concentrations of total petroleum hydrocarbon (TPH) in the soil samples. Concentrations of TPH in the soils shall be determined by shaking 10g of a representative soil sample with 20ml of n-hexane, separating the solvent, and then measuring the absorbance of the extract in the spectrophotometer. The TPH concentrations the soil samples shall be estimated by locating the absorbances for these samples on the reference graph for absorbances for known TPH concentrations. 4.5.2 PAH Samples for analysis of PAH will be extracted in organic solvent using ultrasonic disruption. Concentrations of target compounds will be determined using a gas chromatography (GC) fitted with FID. The column temperature shall start at 60°C and end at 300 °C with an increase of 12°C per minute. Nitrogen shall be used as a carrier gas with a flow rate of 30ml/min. Hydrogen and air flow rates shall be 30ml/min and 300ml/min respectively. Injector part and detector temperature shall be 230°C and 320°C respectively. A 1.5µL of sample shall be injected. 4All methods and/or references will be updated and then verified during the laboratory audits. ICF Consulting Appendix B-WAGP EBS Work Plan 33 Planned Seabed Primary Sample Laboratory Analyses Proposed Technique Method Reference Holding Time Preservative Volume Required In Situ Measurements pH electrode APHA 4500-H B immediately in situ in situ Temperature electrode APHA 2550 B immediately in situ in situ Redox Potential electrode immediately in situ in situ Physicochemical Ammonia Nitrogen distillation, titrimetric APHA 4500-NH3 C 28d cool, 4C 100g Orthophosphate Phosphorous ascorb acid, colorometric APHA 4500-P E 28d cool, 4C 50g Phosphorous persulfate digest, ascorb acid, colorometric APHA 4500-P E 28d cool, 4C 50g Sulfate turbidimetric APHA-SO4 E 28d cool, 4C 50g Exchangable Acidity titration titration 14d cool, 4C 50g Alkaline Metals (Ca, K, Na) flame photometric detector APHA 3500 180d none 100g Bulk Properties Total Organic Carbon dichromated wet oxidation Walkley Black 28d cool, 4C 20g Grain Size sieve, hydrometer Bouyoucous 28d cool, 4C 100g Organics Oil and Grease Content hexane extr, UV spectrometer Nigeria DPR 28d (1yr frozen) cool, -2C 250g Total Hydrocarbons methylene chloride extraction, GC/FID USEPA Method 8015 14d (1yr frozen) cool, -2C 250g Aliphatic Hydrocarbons methylene chloride extraction, GC/FID USEPA Method 8015 14d (1yr frozen) cool, -2C 250g PAH methylene chloride extraction, GC/FID USEPA Method 8100 14d (1yr frozen) cool, -2C 250g Trace Metals Cd - Cadmium nitric acid digestion, AAS APHA 3111 B 180d none 100g Cr - Chromium nitric acid digestion, AAS APHA 3111 B 180d none 100g Cu - Copper nitric acid digestion, AAS APHA 3111 B 180d none 100g Fe - Iron nitric acid digestion, AAS APHA 3111 B 180d none 100g Mg - Magnesium nitric acid digestion, AAS APHA 3111 B 180d none 100g Ni - Nickel nitric acid digestion, AAS APHA 3111 B 180d none 100g Pb - Lead nitric acid digestion, AAS APHA 3111 B 180d none 100g Zn - Zinc nitric acid digestion, AAS APHA 3111 B 180d none 100g Al - Aluminum nitric acid digestion, AAS APHA 3111 D 180d none 100g V - Vanadium nitric acid digestion, AAS APHA 3111 D 180d none 100g Hg - Mercury diathizone, spectrophotometer APHA 3500-Hg C 28d none 100g Biology Macrobenthic Infauna microscope preserve immediately ICF Consulting Appendix B-WAGP EBS Work Plan 34 Summary of Planned Water Sample Analyses Proposed Technique Method Reference Holding Time Preservative Volume Required In Situ Measurements pH electrode (YSI) APHA 4500-H B immediately in situ in situ Temperature electrode (YSI) APHA 2550 B immediately in situ in situ Electrical Conductivity electrode (YSI) APHA 2510 B immediately in situ in situ Total Dissolved Solids electrode (YSI) immediately in situ in situ Turbidity electrode (YSI) APHA 2130 B immediately in situ in situ Dissolved Oxygen electrode (YSI) APHA 4500-O G immediately in situ in situ Salinity electrode (YSI) immediately in situ in situ Redox Potential (ORD) electrode (YSI) APHA 2580 A immediately in situ in situ Chlorophyll-a electrode (YSI) immediately in situ in situ Water Quality Sulfate turbidimetric (Hach) APHA-SO4 E 28d cool, 4C 100mL Alkalinity titration (Hach) APHA 2320 B 14d cool, 4C 200mL COD closed reflux, titrimetric APHA 5220 C 28d H2SO4<2, cool, 4C 100mL Ammonia Nitrogen distillation, titrimetric APHA 4500-NH3 C 28d H2SO4<2, cool, 4C 100mL Nitrate Nitrogen cadmium reduction, colorometric APHA 4500-NO3 E 28d H2SO4<2, cool, 4C 100mL Total Nitrogen (delete?) macro kjedahl APHA 4500-Norg B 28d H2SO4<2, cool, 4C 500mL Orthophosphate Phosphorous ascorb acid, colorometric APHA 4500-P E 28d H2SO4<2, cool, 4C 100mL Total Phosphorous persulfate digest, ascorb acid, colorometric APHA 4500-P E 28d H2SO4<2, cool, 4C 100mL Alkaline Metals (Ca, K, Na) flame photometric detector APHA 3500 180d H2SO4<2, cool, 4C 500mL BOD5 (delete?) incubation, electrode APHA 5210 B 48h cool, 4C 1L TSS (delete?) gravimetric APHA 2540 D 7d cool, 4C 500mL Trace Metals Cd - Cadmium nitric acid digestion, AAS APHA 3111 B 180d HNO3<2 1000mL Cr - Chromium nitric acid digestion, AAS APHA 3111 B 180d HNO3<2 1000mL Cu - Copper nitric acid digestion, AAS APHA 3111 B 180d HNO3<2 1000mL Fe - Iron nitric acid digestion, AAS APHA 3111 B 180d HNO3<2 1000mL Mg - Magnesium nitric acid digestion, AAS APHA 3111 B 180d HNO3<2 1000mL Ni - Nickel nitric acid digestion, AAS APHA 3111 B 180d HNO3<2 1000mL Pb - Lead nitric acid digestion, AAS APHA 3111 B 180d HNO3<2 1000mL Zn - Zinc nitric acid digestion, AAS APHA 3111 B 180d HNO3<2 1000mL Al - Aluminum nitric acid digestion, AAS APHA 3111 D 180d HNO3<2 1000mL V - Vanadium nitric acid digestion, AAS APHA 3111 D 180d HNO3<2 1000mL Hg - Mercury diathizone, spectrophotometer APHA 3500-Hg C 28d HNO3<2 1000mL Biology Phytoplankton/Zooplankton microscope APHA 10200 preserve ICF Consulting Appendix B-WAGP EBS Work Plan 35 Planned Onshore Soil Sample Laboratory Analyses Proposed Technique Method Reference Holding Time Preservative Volume Required Point Samples Properties pH electrode APHA 4500-H B immediately in situ in situ TOC dichromated wet oxidation Walkley Black 28d cool, 4C 20g Grain Size sieve, hydrometer Bouyoucous 28d Organics Total Hydrocarbons methylene chloride extraction, GC/FID USEPA Method 8015 14d (1yr frozen) cool, -2C 250g Trace Metals Cd - Cadmium nitric acid digestion, AAS APHA 3111 B 180d none 100g Cr - Chromium nitric acid digestion, AAS APHA 3111 B 180d none 100g Cu - Copper nitric acid digestion, AAS APHA 3111 B 180d none 100g Fe - Iron nitric acid digestion, AAS APHA 3111 B 180d none 100g Ni - Nickel nitric acid digestion, AAS APHA 3111 B 180d none 100g Pb - Lead nitric acid digestion, AAS APHA 3111 B 180d none 100g Zn - Zinc nitric acid digestion, AAS APHA 3111 B 180d none 100g Al - Aluminum nitric acid digestion, AAS APHA 3111 D 180d none 100g V - Vanadium nitric acid digestion, AAS APHA 3111 D 180d none 100g Hg - Mercury nitric acid digestion, cold vapor AAS APHA 3112 B 180d none 100g Composite Samples Organics PAH methylene chloride extraction, GC/FID USEPA Method 8100 14d (1yr frozen) cool, -2C 250g Biology Microbiology Plate count Macrobiology/soil ecology Berlese extraction/microscope ICF Consulting Appendix B-WAGP EBS Work Plan 36 4.5.3 TOC TOC shall be determined by the loss on ignition method. 4.5.4 pH Soil pH shall be determined in 1:1 soil-to-water suspension with a glass electrode pH meter. For soil samples high in organic matter, a soil-water ratio of 1:5 can be used. 4.5.5 Trace Metals The air-dried soil sample shall be further crushed using agate mortar and pestle until the sample passes through a mesh screen. The sieved samples shall be digested using nitric acid and the digestate taken up in dilute HCl. The trace metals in the extract shall be determined by atomic absorption spectrophotometer (AAS). 4.5.6 Microbiology Microbiological determinations will be made utilizing a variety of plate count methods. 4.5.7 Macrobiology and Soil Ecology The soil samples shall inventoried in the laboratory for soil fauna. Extraction of the soil fauna shall use a Berlese ­ Tullgren extractor (where a metal cylinder is used to concentrate heat and light from a 40-Watt bulb onto the soil core in a sample container whose base is a 2mm wire mesh. The sample container rests on a steep sided funnel whose angle of inclination to the horizontal is about 600. This ensures unhindered journey of the arthropods through the funnel into the collecting tube below.) The collecting tube shall contain a 70 percent ethanol solution, which will preserve the specimens for a fairly long period without altering the taxonomic features of the specimen. A few drops of lactic acid can be added to the ethanol in other to prevent the growth of fungi. The extraction should last approximately one week, after which time the specimens shall be removed. The contents of the collecting tubes shall be sorted and identified by qualified entomologists. Identified specimens can be taxonomically grouped in labeled bottles containing 70 percent ethanol, and counted. 4.5.8 Particle Size Distribution The particle size distribution analysis shall be carried out using the combination of wet sieving and pipette methods. Following the dispersion of the soil samples with Calgon (5 percent), the total sand fractions shall be removed by sieving through a 0.050mm sieve. The sand fractions shall be subsequently oven dried at 1050°C and then fractioned into very coarse (VC), Coarse, (C), medium (M), fine (F) and very fine (VF) sand fractions, using a set of sieves with appropriate mesh sizes i.e. 1000mm, 500mm, 250mm and 100mm sieves respectively. The silt and clay in suspension shall be re-stirred at room temperature and oven dried in a crucible to estimate the mass of silt and clay particles. After allowing the suspension to stand for the time it ICF Consulting Appendix B-WAGP EBS Work Plan 37 would require particles of 2mm equivalent spherical diameter (e.s.d.) to settle over a distance of 10cm, the second pipette samples shall be taken at not more than from below 5cm of the surface of the suspensions. The sample aliquot shall be dried and the mass of clay in it computed. From there, the mass of total clay shall be estimated. 4.6 Chemical Analysis of Onshore Compressor Station Site Groundwater Samples A total of 12 groundwater samples (6 per season) samples shall be collected from the boreholes in the wet and dry season and during both high and low tide regimes, and analyzed using methods described for surface water (see Section 4.7.1, below) for the following parameters: TPH Trace metals pH 4.7 Physiochemical Analysis of Onshore Borehole Cuttings 4.7.1 TPH and Heavy Metals Samples of cuttings from the boreholes (15 total) shall be analyzed for TPH and heavy metals using methods described for soil. 4.7.2 Grain Size and Effective Porosity Samples of cuttings from the boreholes (9 total) shall be also be analyzed for Grain size/effective porosity (n) using the following formula: n = 100 1 - apparent density % real density where real density is assumed to be 2.70mg/m3. The apparent density shall be determined by the mechanical sieve method. About 300 gm of air- dried sample shall be passed through a stack of sieves of different mesh sizes to determine the amount of the particles retained in each sieve. A typical example of results obtained from such mechanical analysis is presented as follows: ICF Consulting Appendix B-WAGP EBS Work Plan 38 Example of Grain-size Distribution of Sand Samples from a Borehole within the Niger Delta Aperture Cumulative Cumulative Size of Sieve Size Weight Percentage Percentage Number Retained (g) Retained Finer Than 0.600 1 8.12 2.7 97.3 0.500 2 29.34 9.8 90.2 0.425 3 257.1 66.1 13.9 0.355 4 281.2 94.2 5.8 0.250 5 296.3 97.3 0.7 Bottom pan. 6 298.5 100 0 The mechanical sieve analysis data shall be plotted in the form of a gradation curve of grain size distribution. The abscissas of the curve are diameter in millimeters of the particles plotted on a logarithmic scale with corresponding linear coordinates showing the percentage of particles "finer than" a given size. Uniformity coefficient the d60 1 = 0.46/0.425 = 1.42 d10 The effective grain size of a given sample is the maximum diameter of the smallest 10 per cent (d10); the uniformity coefficient is ratio obtained by dividing the maximum size of the smallest 60 per cent d60 by the effective size d10. In a sample whose grain size distribution is such that Uniformity coefficient the d60 2 = 0.46/0.425 = 1.42 d10 The effective grain size d10 is 0.423mm and the coefficient of uniformity is 1.42. It is important to note that the uniformity coefficient is greater for fine sand and clay than for coarse sand. This example of Table 2.2 is that of medium, poorly sorted sand, which implies good permeability. ICF Consulting Appendix B-WAGP EBS Work Plan 39 Summary of Compressor Station Analysis Planned Onshore Compressor Station Groundwater Sample Laboratory Analyses Proposed Technique Method Reference Holding Time Preservative Volume Required Properties Grain Size sieve, hydrometer Bouyoucous 28d Soil Porosity Organics Total Hydrocarbons methylene chloride extraction, GC/FID USEPA Method 8015 14d (1yr frozen) cool, -2C 250g Trace Metals Cd - Cadmium nitric acid digestion, AAS APHA 3111 B 180d none 100g Cr - Chromium nitric acid digestion, AAS APHA 3111 B 180d none 100g Cu - Copper nitric acid digestion, AAS APHA 3111 B 180d none 100g Fe - Iron nitric acid digestion, AAS APHA 3111 B 180d none 100g Ni - Nickel nitric acid digestion, AAS APHA 3111 B 180d none 100g Pb - Lead nitric acid digestion, AAS APHA 3111 B 180d none 100g Zn - Zinc nitric acid digestion, AAS APHA 3111 B 180d none 100g Al - Aluminum nitric acid digestion, AAS APHA 3111 D 180d none 100g V - Vanadium nitric acid digestion, AAS APHA 3111 D 180d none 100g Hg - Mercury nitric acid digestion, cold vapor AAS APHA 3112 B 180d none 100g ICF Consulting Appendix B-WAGP EBS Work Plan 40 Planned Onshore Compressor Station Borehole Cutting Laboratory Analyses Proposed Technique Method Reference Holding Time Preservative Volume Required In Situ Measurements pH electrode APHA 4500-H B immediately in situ in situ Trace Metals Cd - Cadmium nitric acid digestion, AAS APHA 3111 B 180d HNO3<2 1000mL Cr - Chromium nitric acid digestion, AAS APHA 3111 B 180d HNO3<2 1000mL Cu - Copper nitric acid digestion, AAS APHA 3111 B 180d HNO3<2 1000mL Fe - Iron nitric acid digestion, AAS APHA 3111 B 180d HNO3<2 1000mL Mg - Magnesium nitric acid digestion, AAS APHA 3111 B 180d HNO3<2 1000mL Ni - Nickel nitric acid digestion, AAS APHA 3111 B 180d HNO3<2 1000mL Pb - Lead nitric acid digestion, AAS APHA 3111 B 180d HNO3<2 1000mL Zn - Zinc nitric acid digestion, AAS APHA 3111 B 180d HNO3<2 1000mL Al - Aluminum nitric acid digestion, AAS APHA 3111 D 180d HNO3<2 1000mL V - Vanadium nitric acid digestion, AAS APHA 3111 D 180d HNO3<2 1000mL Hg - Mercury nitric acid digestion, cold vapor AAS APHA 3112 B 28d HNO3<2 1000mL Organics PAH methylene chloride extraction, GC/FID USEPA Method 8100 14d cool, -2C 1000mL Planned Onshore Compressor Station Air Quality Sample Laboratory Analyses Proposed Technique Method Reference Holding Time Preservative Volume Required Particulate Matter tedlar bag, meter Carbon Monoxide tedlar bag, meter Nitrogen Oxides tedlar bag, meter ICF Consulting Appendix B-WAGP EBS Work Plan 41 4.8 Chemical and Biological Analysis of Onshore Aquatic Environment 4.8.1 Chemical Analysis of Surface Water The laboratory analyses of the physico-chemical parameters of water quality shall be based on the standard methods presented below: Planned Onshore Surface Water Sample Laboratory Analyses Proposed Technique Method Reference Holding Time Preservative Volume Required In Situ Measurements pH electrode APHA 4500-H B immediately in situ in situ Temperature electrode APHA 2550 B immediately in situ in situ Electrical Conductivity electrode APHA 2510 B 28d in situ in situ Turbidity electrode APHA 2130 B 4h in situ in situ Dissolved Oxygen electrode APHA 4500-O G 8h in situ in situ TDS electrode in situ in situ Nutrients/Properties/Quality BOD5 incubation, electrode APHA 5210 B 48h cool, 4C 1L COD closed reflux, titrimetric APHA 5220 C 28d H2SO4<2, cool, 4C 100mL Ammonia Nitrogen distillation, titrimetric APHA 4500-NH3 C 28d H2SO4<2, cool, 4C 100mL Nitrate Nitrogen cadmium reduction, colorometric APHA 4500-NO3 E 28d H2SO4<2, cool, 4C 100mL Total Nitrogen macro kjedahl APHA 4500-Norg B 28d H2SO4<2, cool, 4C 500mL Orthophosphate Phosphorous ascorb acid, colorometric APHA 4500-P E 28d H2SO4<2, cool, 4C 100mL Total Phosphorous persulfate digest, ascorb acid, colorometric APHA 4500-P E 28d H2SO4<2, cool, 4C 100mL TOC dichromated wet oxidation Walkley Black 28d H2SO4<2, cool, 4C 100mL TSS gravimetric APHA 2540 D 7d cool, 4C 500mL Sulfate turbidimetric APHA-SO4 E 28d cool, 4C 100mL Alkalinity titration APHA 2320 B 14d cool, 4C 200mL Alkaline Metals (Ca, K, Na) flame photometric APHA 3500 180d HNO3<2 500mL Trace Metals Cd - Cadmium nitric acid digestion, AAS APHA 3111 B 180d HNO3<2 1000mL Cr - Chromium nitric acid digestion, AAS APHA 3111 B 180d HNO3<2 1000mL Cu - Copper nitric acid digestion, AAS APHA 3111 B 180d HNO3<2 1000mL Fe - Iron nitric acid digestion, AAS APHA 3111 B 180d HNO3<2 1000mL Mg - Magnesium nitric acid digestion, AAS APHA 3111 B 180d HNO3<2 1000mL Ni - Nickel nitric acid digestion, AAS APHA 3111 B 180d HNO3<2 1000mL Pb - Lead nitric acid digestion, AAS APHA 3111 B 180d HNO3<2 1000mL Zn - Zinc nitric acid digestion, AAS APHA 3111 B 180d HNO3<2 1000mL Al - Aluminum nitric acid digestion, AAS APHA 3111 D 180d HNO3<2 1000mL V - Vanadium nitric acid digestion, AAS APHA 3111 D 180d HNO3<2 1000mL Hg - Mercury nitric acid digestion, Cold Vapor AAS APHA 3112 B 28d HNO3<2 1000mL Biology Microbiology plate count Phytoplankton/Zooplankton microscope APHA 10200 preserve Phytoplankton Productivity white-dark oxygen bottle Water sampling data shall be tracked and reported using a standardized format. An example of that format can be found below: Sample Station GPS Grid Position Sampling Total Tide Regime Sampling Period No. No. River System Site Description N E Depth Depth (m) HT LT Date Time (GMT) 1 1 Madaho Creek mid stream, mid 50 35' 29" 50 12' 50" S 8.5 X 02/26 930 reach 2 1 ,, ,, 50 35' 29" 50 12' 50" B 8.5 X ,, 935 3 2 Escravos estuary mid stream, mid 50 36' 21" 50 12' 18" S 19.0 X ,, 1030 reach 5 2 ,, ,, 50 36' 21" 50 12' 18" B 19. X ,, 1115 6 1 Madaho Creek ,, 50 35' 29" 50 12' 50" S 8.0 X ,, 1430 7 1 ,, ,, 50 35' 29" 50 12' 50" B 8.0 X ,, 1445 8 2 Escravos estuary ,, 50 36' 13" 50 12' 12" S 18.0 X ,, 1600 9 3 Ogidigben Creek 0.5kt North of 50 33' 59" 50 11' 46" S 2.1 X 02/27 0945 Ogidigben Jetty 10 3 ,, ,, 50 33' 59" 50 11' 46" S 2.1 X ,, 1000 11 4 ,, Ajudiagbo Jetty 50 34' 37" 50 12' 5" S 3.3 X ,, 1020 S = Surface; B = Bottom depth. ICF Consulting Appendix B-WAGP EBS Work Plan 42 4.8.2 Analysis of Plankton Biology and Community Metabolism Plankton samples shall be treated with Lugol solution (1:100) in the laboratory and allowed adequate time (about 1 week) to complete sedimentation. After carefully removing the supernatant the concentrate volume (of about 5ml) shall be surveyed in a counting chamber at different magnifications of the compound microscope. Scaled drawings of recorded plankton shall be made based on the measurements of features of taxonomic importance. Drawings can be supplemented with micrographs. Identification shall be based on the scaled drawings/micrographs and diagnoses, using relevant keys from texts and journal references. Community respiration and primary (photosynthetic) productivity (net and gross productivity) will be assessed using a white-dark oxygen bottle method under natural light illumination ex situ for approximately 12 hours (7am - 6pm). Daily production rates shall be calculated on a 12- hourly basis while daily respiration shall be based on 24 hours. 4.9 Analysis of Sediment 4.9.1 Chemical Analysis Prior to laboratory analysis and after determination of moisture content, subsamples of sediments shall be air-dried, gently crushed with pestle in agate mortar and passed through 2mm sieve. The less than 2mm fractions shall be retained for the following analysis. Physico-chemical determinations shall be the same as for soil (see Section 4.4 above). The laboratory analyses of the physical-chemical parameters of surface water sediments will be based on the methods as presented below: Planned Onshore Surface Water Sediments Laboratory Analyses Proposed Technique Method Reference Holding Time Preservative Volume Required Properties pH electrode APHA 4500-H B immediately in situ in situ Temperature electrode APHA 2550 B immediately in situ in situ Redox Potential electrode immediately in situ in situ Bulk Properties TOC dichromated wet oxidation Walkley Black 28d cool, 4C 20g Grain Size sieve, hydrometer Bouyoucous 28d Organics Total Hydrocarbons methylene chloride extraction, GC/FID USEPA Method 8015 14d (1yr frozen) cool, -2C 250g Trace Metals Cd - Cadmium nitric acid digestion, AAS APHA 3111 B 180d none 100g Cr - Chromium nitric acid digestion, AAS APHA 3111 B 180d none 100g Cu - Copper nitric acid digestion, AAS APHA 3111 B 180d none 100g Fe - Iron nitric acid digestion, AAS APHA 3111 B 180d none 100g Ni - Nickel nitric acid digestion, AAS APHA 3111 B 180d none 100g Pb - Lead nitric acid digestion, AAS APHA 3111 B 180d none 100g Zn - Zinc nitric acid digestion, AAS APHA 3111 B 180d none 100g Al - Aluminum nitric acid digestion, AAS APHA 3111 D 180d none 100g V - Vanadium nitric acid digestion, AAS APHA 3111 D 180d none 100g Hg - Mercury nitric acid digestion, cold vapor AAS APHA 3112 B 180d none 100g Biology Macro Infauna Berlese extraction/microscope ICF Consulting Appendix B-WAGP EBS Work Plan 43 4.9.2 Biological Analysis The macrobenthic organisms shall be identified and counted under a binocular microscope. Scaled drawings/photographs of recorded benthic organisms shall be used in their identification. Identifications can be based on voucher samples using relevant keys in text and journal references. Estimated frequency of occurrence of species shall be derived from counting the organisms. ICF Consulting Appendix B-WAGP EBS Work Plan 44 5.0 DATA ANALYSIS AND REPORTING 5.1 Purpose Data and observations from the EBS field sampling shall be analyzed to accurately and thoroughly characterize the WAGP study area and provide an analytical basis for the WAGP EIA. Data and observations from the first season of environmental field data sampling shall be scientifically interpreted and augmented by literature review. One objective of data analysis will be to demonstrate that the system of field sampling has been designed suitably and performed adequately. A combination of using species-areas curves, habitat-area curves, and corroboration with the literature shall be used to address the field sampling adequacy. With respect to lab analysis, the approach shall be guided by the country- specific or regional regulatory requirements where they exist. ASTM/ APAH/USEPA guidelines and the scientific expertise of the ICF EBS scientific team (Section 8.3 and Attachment K) will augment the methodology where the regulations are silent. 5.2 Data Storage and Treatment The data obtained from the study area sampling and investigation shall be summarized and analyzed using an appropriate set of statistical approaches. The following statistics and indices may be employed: Graphic representations and descriptive statistics to show relative magnitudes and distribution of data points Analysis of variance to test for differences between mean values of data of different groups Linear regression and correlation analysis to test for relationships between a dependent variable and a single independent variable Multiple regression analysis and correlation to test for relationships between a dependent variable and several different independent variables Species diversity, dominance, and evenness indices (See Section 3.3.4) Coastal environment quality indices that combine biological, chemical, and physical sampling parameters Data analysis will consist of graphics and statistics used to support interpretation of project data. Graphical displays of data may be performed using other software (e.g., SAS Graph, Surfer) as appropriate. Computer output of statistical results will be presented in appendices included with the final report. A master database shall be designed, populated, and maintained by the ICF EBS scientific team (Section 8.3 and Attachment K) and transferred into a database that shall be delivered to the ICF Consulting Appendix B-WAGP EBS Work Plan 45 WAGP client. Chemical, physical, and biological data shall be provided electronically by in- country team leaders in a predefined format (e.g., Excel 5.0) to ICF. When the data has been entered into the database, summaries of the data shall be sent to in- region country team leaders (Attachment K). They will review the data and present short write- ups for inclusion in the report. The report preparation will be managed by the in-region country team leaders. The reports will contain input from the ICF project scientists including Dr.Will Gibson, Dr. Andrei Nikitin, Mr. Henry Camp, Mr. Frank Querzoli and Mr. Ted Coogan (for Geographical Information Systems (GIS) issues). Please refer to Attachment B for schedule of milestones. 5.3 Raw Data Evaluation Raw data obtained from analytical instrument and titration measurements shall be converted using standardized formulas. Outliers will be identified and, if spurious, shall be deleted prior to calculation of mean concentrations. Typed results shall be crossed checked to identify typographical errors. 5.4 Reporting The EBS field sampling and literature review for both the offshore and onshore portions of the project shall be presented in a scientific report that includes text, graphs, summary tables, and maps. Detailed data tables shall be provided as appendices. The report shall contain the following elements: Executive summary that includes a brief summary of major findings Introduction that includes a very brief summary and background for the WAGP project, the EBS purpose and objectives, and the content structure of the report Methodology that describes how the EBS was conducted including field party composition, field sampling methods, on-board processing, field QA/QC, chain of custody procedures, sample handling and transportation, analytical procedures, data management, and statistical methods Results that will present the analytical and statistical results of the EBS, and map- based graphical representations using GIS. Detailed analytical results and results of QC analyses will be attached as appendices to the report Discussion that will focus on four issues: Data quality objectives Variability within the study area Results of physical, chemical, and biological data analysis Identification of sensitive habitats and threatened or endangered species ICF Consulting Appendix B-WAGP EBS Work Plan 46 References that contain the list of scientific references and other literature that was used to prepare the report Appendices that contain data summary tables, statistical results summaries and raw data, field cruise logs The EBS report shall be presented as hard copy and electronic versions (disk copy) prepared in Microsoft Word 2000 on a PC compatible CD-ROM disk. The draft report shall be submitted to the WAGP client. The final report will be submitted after incorporation of comments provided by WAGP client. ICF Consulting Appendix B-WAGP EBS Work Plan 47 6.0 QUALITY ASSURANCE AND CONTROL 6.1 Purpose Quality assurance/quality control shall form an integral part of all aspects of the project and it will be used to address the variance associated with both the samples and analytical methods. Sample chain of custody forms shall be used for the registration and tracking of samples from the field to the laboratory. The adopted QA/QC strategy employs the extensive usage of 'blank' and 'spiked' samples. The quality assurance program will be put in place to prevent sample contamination and deterioration, and covered all aspects of the study, including sample collection, handling laboratory analysis, data coding, and manipulation, statistical analysis, presenting and communicating results. The work shall be carried out in accordance with the terms of reference and the specification given by WAGP. The study methodology will be consistent with those approved by the appropriate certifying authorities in each participating country Only standard and commonly accepted field procedures and laboratory methods shall be used The study shall adequately encompass the project area with sufficient buffer to capture the extreme boundaries of environmental influence the project may possibly have 6.2 Study Design Before the study is implemented, the study design shall be critically re-evaluated and presented to WAGP and regulatory bodies. The following shall then be evaluated: Whether the design meets the study objectives and tests the appropriate hypothesis The technical elements of the design The statistical elements of the design. 6.3 Field Procedures All field procedures shall be in accordance with general QA/QC requirements, specifically: The contamination of samples will be avoided by use of "clean" field sampling techniques In-situ measurements of parameters with very short or no-holding analytical time shall be transported out of the field on a daily basis Separate samples shall be collected for parameters requiring different treatment/preservation before analysis ICF Consulting Appendix B-WAGP EBS Work Plan 48 A minimum of one selected field duplicate (sediment and water) will be collected to assess field variability Field blanks and equipment blanks will be collected, as appropriate, for sediment and water Samples shall be adequately preserved and labeled. An example of the chain of custody is provided in Appendix E. 6.4 Laboratory Analysis All laboratory analysis shall be in accordance with general QA/QC requirements, specifically: Analysis shall be carried out within the holding time of the respective parameters Laboratory blanks and blank spikes will be analyzed for organic and inorganic instrumental analyses Only functional and calibrated equipment shall be employed Only experienced staff shall be involved in the analytical work. To preserve the integrity of samples taken, the following measures are required: Cold storage facilities for microbial and TPH samples, e.g. refrigerators and freezers to preserve, in the ship laboratory and coolers with ice to preserve samples in transit to company laboratory Appropriate packing material to prevent breakage and a trip blank/temperature blank within each cooler Chain of custodies accompanying and custody seals on coolers Oven to dry samples Disposable rubber hand gloves will be used Twenty percent (ten samples) of the 50 main pipeline stations will be sampled and analyzed for Quality Control purposes and confirmation of methodology by ICF's Organic Laboratory ICF's laboratory may also sub-sample aliquots for metals analysis as a quality control measure. The eight fish samples will be analyzed by the ICF Organic Laboratory. Species selection will be decided in the field jointly by the Chief Field Scientists and selected experts. Species will have to be representative of typical commercial importance, review of total trawl collection and species numbers (populations), and species sensitivity to required pollutants of concern. All appropriately preserved and documented samples will be hand delivered to the ICF Cambridge Laboratory by the ICF field Scientist. ICF Consulting Appendix B-WAGP EBS Work Plan 49 6.5 Detailed Field Quality Control Measures Quality assurance/quality control (QA/QC) samples will be collected in the sampling program to assess data quality. The survey team will be briefed by the Chief Field Scientist prior to conducting the first sampling on quality assurance measures of the sampling activities. All field personnel will be briefed on the potential for contamination and cross-contamination of samples and will be given guidance on techniques to avoid such problems. This includes the use of pre- cleaned sample containers; use of clean sampling equipment; use of the decontamination protocol described above; and good laboratory practices in general. It also includes following specified sampling procedures and protocols in accordance with SOPs as referenced below: ICF Consulting, Inc. Standard Operating Procedures: ICF 1016 - Documentation and Field Reporting Requirements for Marine Sampling ICF 1017 - Sample Labeling and Chain of Custody Requirements ICF 1018 - Operation of the Modified Van-Veen Grab Sampler ICF 1019 - Collection and Handling of Subtidal Sediment Chemistry Samples from the Modified Van-Veen Grab Sampler ICF 1021 - Collection and Handling of Chemistry Quality Control Samples Several types of field quality control samples will be collected during the survey, including equipment blanks, field blanks, and replicate samples. For both equipment blank and field blank samples, two jars will be used to analyze for metals and organics respectively. Field quality control procedures should include the collection of equipment blanks. 6.5.1 Equipment Blanks Equipment blanks are collected when sampling involves use of collection equipment that comes into direct contact with the sample (i.e., the modified Van-Veen grab) during or following the collection of sediment chemistry samples. The equipment blank is representative of potential contamination associated with the equipment. To collect the equipment blanks, the grab is first decontaminated according to the procedure outlined above. Then the inside of the bucket is rinsed with high-purity, deionized water and the rinsate is collected directly into a clean, pre- labeled water sample container. A stainless-steel funnel can be used to assist in the collection; the funnel must be decontaminated prior to use by the same procedure used for the grab sampler. The rinsate is the equipment blank and is refrigerated at 4°C. For each equipment blank sample, two jars will be collected, one for metals analysis and one for organics analysis. 6.5.2 Field Blanks Field blanks are collected, which are representative of any atmospheric or other contamination that the field samples may be subject to and also of any potential contamination associated with the glassware. A clean, pre-labeled sample jar of the same batch used for sample collection is carried into the field, opened during the collection of one sample, and returned to the laboratory ICF Consulting Appendix B-WAGP EBS Work Plan 50 with the field samples. For each field blank, two sample containers will be used to be analyzed for metals and organics, respectively. This blank will be stored under the same conditions as the field samples it is representative of. Field blank samples will be taken during the collection of sediment samples as well as in the processing of suspended sediment samples. 6.5.3 Replicate Samples (Field Duplicates) The collection frequency and station designation for replicate samples will be at the request of the Chief Field Scientist and Shift Leaders in conjunction with the senior scientist recommendations and project requirements. The number and type of samples will be based on site observations, daily sampling method frequency and analytical aliquots collected. 6.5.4 Control of Data Storage and Treatment Every data-handling step poses an additional opportunity for errors to be introduced. To reduce such errors, direct electronic recording and data transfer processes shall be used whenever possible. In cases where data must be manually transcribed, they shall be checked against the original for errors. To avoid the possible loss of data from computer malfunction, raw, unprocessed data shall be kept on a master file, controlled by the use of a password system. Back-up files shall be created and regularly updated. 6.5.5 Data Interpretation Control The form and level of data presentation is crucial for proper understanding of results and recommendations. Two types of reports shall be produced: A comprehensive, detailed report containing all relevant data and interpretations thereof An executive summary, in a user-friendly language for highlighting the major findings ICF Consulting Appendix B-WAGP EBS Work Plan 51 7.0 HEALTH AND SAFETY PLAN The Health and Safety plan for the EBS is designed to provide the best possible protection for staff during the field and laboratory operations. All personnel are required to comply with the minimum standards as stated in the WAGP Independent Contractor Health, Safety and Environment Guidelines.5 In addition, during shipboard operations all personnel are expected to comply with shipboard safety policy and practices, as well as the ship's regulations. The EBS team will use the nearest WAGP or CNL facilities and directed logistics to supplement the default health and safety plan in case of emergency. 7.1 ICF Health and Safety Policy It is the policy of ICF to provide a safe and healthful workplace for all employees. As a minimum, we will comply with all laws and regulatory agency requirements. It is both a moral obligation, and a sound business practice, to prevent occupational injuries and illnesses. As a condition of employment, each employee must assume responsibility for working safely at all times. All levels of management are directly responsible for safety; and providing a safe and healthy work environment is an essential measure of managerial performance. Every worker shall receive the appropriate training, equipment, and other resources necessary to complete their assigned tasks in a safe and efficient manner. If an operation cannot be performed safely, it will not be conducted until safeguards that allow operations to continue safely are in place. Managers are expected to be cognizant of the safety and health criteria applicable to their operations, and to be fully aware of the status of their operations in relation to these criteria. With the assistance of safety and health professionals, managers will assess the effectiveness of the safety programs in place, and identify areas for improvement. All identified deficiencies will be corrected promptly. All occupational injuries, illnesses, vehicle accidents, and incidents with potential for injury or loss will be investigated. Appropriate corrective measures will be taken to prevent recurrence. The prevention of injury and illness is of paramount importance. Safety takes precedence over expediency or short-cuts. Each of us, through personal example, and concern for the well-being of our colleagues, commit to putting SAFETY FIRST. The safety policy will be kept in a location accessible to all personnel at all times while in field locations. This location will be identified in the initial safety training session. 5Exhibit C of ICF subcontractor agreements ICF Consulting Appendix B-WAGP EBS Work Plan 52 7.2 Responsibilities The Chief Field Scientist will serve as the Safety Officer and will be responsible for implementing the safety policy and procedures. The ICF Project Manager shall be notified of all incidents. The ICF Project Manager will then notify WAGP of all incidents. 7.3 Training It is required that all field personnel have safety training prior to beginning any field work incompliance with this safety policy and applicable local, state or federal occupational safety requirements. There will be a site orientation meeting provided by the Chief Field Scientist, which will cover all aspects of this health and safety plan. One team exercise conducted during this orientation will be the completion of WAGP's Job Safety Analysis Worksheet (Attachment L). Prior to departure, all personnel will be briefed by the ship's designated officer concerning the safety procedures and protocols of the vessel. A Vessel Introduction and Safety sheet, provided by TDI-Brooks, will be completed by each person boarding the ship (Attachment M). Additionally, a Vessel Audit Checklist will be competed by the ship's chief officer (Attachment N). The audit includes items under the following general categories: certification and documentation; crew qualifications; safety; bridge and navigation equipment; pollution control; vessel integrity; mooring equipment; communications and electronics; back deck equipment; and general vessel condition. Daily Briefings concerning safety and health will be conducted prior to starting ships operations and tasks to ensure safe practices. For example, this may include reminders to personnel on the proper use and decontamination of personal protective equipment (PPE), orientation of dangerous hardware being used, procedures for emergency notification, reporting mechanisms, transferring personnel from vessels, reviews of incidents and near misses, and any modifications to the health and safety plan. 7.4 Site Hazard Characterization (Job Safety Analysis) Personnel involved in site activities may be exposed to a wide variety of hazards that can be classified as either physical or chemical. This section describes the types of hazards that may be encountered and the control measures used to mitigate the hazards. 7.4.1 Physical Hazards Drowning: Personal Flotation Devices (PFDs) are required to be worn at all times on deck and all personnel are to remain in view of at least one other crew member. Working surfaces: The boat deck may become wet and slippery. All personnel are required to wear footwear with adequate traction and to remain in view of at least one other crewmember. All work surfaces are to be kept clear of obstructions. Falls: Climbing or working on elevated surfaces, such as ladders, requires the use of harnesses to protect against falls. ICF Consulting Appendix B-WAGP EBS Work Plan 53 Night operations: Require PFDs with appropriate reflective tape and a submersible flashing light. A small flashlight is strongly suggested while on the exterior deck for night operations. Appropriate deck lighting will be required for all work occurring after dark. Travel to upper exterior decks during night operations require notification and permission of the shift leader. Falling objects: Elevated sampling equipment provides the risk of impact. Personnel are to wear hard hats and steel-toed shoes or boots when in the working area. Fire: The specific fire safety plan as provided by the ship's captain is to be followed. All fire exits are to be kept clear of obstruction and operable at all times. In the event of fire, WAGP's Form GO-106, Report of Fire, will be completed and submitted to the ICF Project Manager. Inclement weather: Rainstorms are quite frequent. It is the captain and the crew's responsibility to provide regular weather forecasts. Personnel are not to work or remain on decks during electrical storms. Sun exposure: Appropriate heat and UV protection (hats, waterproof sunscreen, lightweight clothing where applicable, etc) is strongly advised in addition to proper hydration throughout working operations. Insect bites: For protection against insect bites, especially those that may transmit diseases, personnel should use repellants containing DEET, and wear long-sleeved shirts and pants from dusk till dawn. Boarding by unauthorized personnel: Notify member of ship's crew and comply with directives of boarding party. Do not challenge the boarding party. See Section 7.7. 7.4.2 Chemical Hazards The Chief Field Scientist will brief all personnel on the nature of chemicals, the hazards they present, proper handling procedures, and appropriate personal protective equipment prior to the initiation of any sampling efforts. All chemicals are to be marked with labels designating content and hazard. Material Safety Data Sheets (MSDS) will be provided for all chemicals brought on board the vessel and made available to all personnel. The MSDS will be stored in a designated location available during all work hours. For example, the following is a list of some chemicals that would be used on-board (this list is not meant to be all-inclusive): Nitric acid Formalin (dilute formaldehyde) Methanol Isopropanol ICF Consulting Appendix B-WAGP EBS Work Plan 54 All chemicals will be stored in the appropriate storage area with the proper spill response kits provided. Personnel should avoid direct contact with all chemicals and avoid breathing fumes. Contact with solvents will cause irritation of eyes, nose, throat, and skin. Formalin is a strong irritant and a suspected human carcinogen. Inhalation of low concentrations of formaldehyde may cause eye, nose, and throat irritation. Inhalation of higher concentrations may promote burning sensations and difficulty breathing. Dermal contact may cause smarting, stinging, discoloration, anaesthesia, or first degree burns. Isopropanol is an extremely flammable organic solvent that may be used for equipment decontamination. Appropriate PPE will be used when handling all chemicals. Follow these general guidelines when handling chemicals: Wear rubber gloves (nitrile when handling samples). Wear safety glasses (most sunglasses and corrective glasses are not safety glasses). Work in a well-ventilated area (on the open deck, if possible). Secure all chemicals in a locked cabinet and well-padded location. Store chemicals away from living quarters and away from heat and ignition sources. Waste solvents must be collected and disposed of separately from other waste streams. Waste streams may be generated by decontamination procedures. All waste solvents will be collected in a compatible container that is clearly labeled as waste solvents. Hazardous waste should be stored safely on board, just as other chemicals are and can be offloaded and disposed of on shore. Where applicable, protective B-jackets will be provided for large solvent bottles. In the event of an accidental chemical release, WAGP's Form CNL-140a, Spill and Release Report, will be completed and submitted to the ICF Project Manager. The Chief Field Scientist will be notified immediately of all spills or chemical releases. 7.5 Personal Protection Equipment All personnel will use PPE according to the task performed during the survey. Work vests or float coats must be worn at all times while working on the deck of the ship and on small boats. Rain gear, hard hats, boots, and will be provided to all personnel by each contractor's or subcontractor's employer. PFDs will be made available on the vessel but for evacuation purposes primarily. Due to long working hours and climate, it is strongly suggested that approved and comfortable PFDs be provided by the individual's employer, and appropriate PFDs for night operations are supplied. Safety glasses are to be worn during appropriate activities, when launching or retrieving any equipment that contains hazardous materials, when decontaminating equipment, working in the laboratory, or when using any chemicals. Nitrile gloves will be worn during sampling activities ICF Consulting Appendix B-WAGP EBS Work Plan 55 or when handling any samples. Hard hats are to be worn when working under elevated equipment. 7.6 Personnel and Equipment Decontamination All equipment, materials, and PPE will be evaluated for contamination upon leaving each station. Equipment and materials will be decontaminated and/or disposed, and PPE will be decontaminated as necessary. Decontamination will be performed in the contamination reduction area or any designated area such that the exposure of uncontaminated employees, equipment, and materials will be minimized. All sampling equipment shall be washed with alconox detergent, rinsed with water, and followed by the designated solvent rinses (i.e. methanol, isopropyl alcohol, hexane, etc.). All personnel will wash their hands and face with soap and potable water and should shower at the end of each work shift. PPE must be cleaned or disposed of dependant upon decontamination procedures and suspected contamination. Personnel shall place contaminated clothing and gloves in plastic bags for disposal. 7.7 Emergency Procedures Emergency Procedures will be posted throughout the ship. These Procedures will designate types of alarms, and emergency response personnel and their contact information. Emergency escape routes will be posted throughout the ship and emergency escape routes will be marked. The ship's physician and first aid kits will be available on board in case of minor injuries. In cases of emergency, the Chief Field Scientist or Shift Leader must notify the ship's safety officer and the ICF Project Manager. The ICF Project Manager will contact WAGP if the situation warrants notification. Procedures concerning security and hostile third parties can be found in TDI-Brooks' Hazard Register (to be provided to the team prior to commencement of survey). These procedures will be presented and explained to the ship's personnel during the health and safety orientation. In addition, the following medical evacuation procedures shall be followed during the EBS: Assess situation, remain calm and do not panic. Assemble people at muster point. Alert people and avoid crowding around victim. Contact the SSO, first aider, or ship's physician. Ship's SSO will contact designated nearest WAGP treatment facility. The SSO will assist in Medivac operations or logistics. Provide the following primary information with the injured victim: Your name/company's name and contact information Type/time of accident Location of victim Type of help required Condition of victim Any medical records or medic-alert notifications ICF Consulting Appendix B-WAGP EBS Work Plan 56 Obtain destination information. WAGP's Form GO-42, Report of Occupation Injury or Illness will be completed and submitted to the WAGP HES Advisor. The following WAGP guidelines will be provided prior to EBS fieldwork and will be followed in case of an emergency or accident: Incident Reporting Guidelines (HSE-1) Emergency Notification Guidelines (HSE-5) 7.8 Shipboard Safety and Policies Specific safety requirements include the following: Learn the location of all fire equipment, life rings, life preservers, and survival suits. Know their proper use. In the event of an emergency, know your muster station and your duties. Smoking in bunks is strictly prohibited and only allowed in designated smoking areas. No open-toed shoes or sandals will be worn when working on the deck. No equipment will be deployed over the side without permission from the deck watch officer. All gear must be aboard and secured before moving between stations. When working on deck at night, use the buddy system. During rough weather do not go out unless necessary, and always tell someone if you must go out. All sampling gear (including PPE) must be stored in an orderly fashion in designated areas that will not interfere with ship's operations or impede passage throughout any part of the vessel. Other shipboard guidelines to be followed include: Water is limited and must be reasonably conserved. The use of any non-prescribed drugs or alcohol on-board is strictly prohibited. Boots and rain gear are not to be worn inside the vessel except in the wet and dry labs. The ship's radios may not be used without the permission of the ship's master or the chief mate. The washing machine may only be used at sea when permission is posted in the mess room. ICF Consulting Appendix B-WAGP EBS Work Plan 57 Lead Scientific personnel may visit the bridge only after asking permission of the crew on duty. Scientific personnel are responsible for the cleanliness of their lab areas. The engine room is off-limits to non-crew members, unless on a pre-arranged tour. Deck hatches and portholes are not to be left open without obtaining permission from the deck watch officer. Watertight doors are marked and must be dogged completely at all times. Marine toilets (heads) are only for human waste and toilet paper. Due to close living quarters, personnel should be quiet and considerate of their shipmates who may be sleeping. Socializing should be kept to the library/lounge and mess room. ICF Consulting Appendix B-WAGP EBS Work Plan 58 8.0 VESSEL AND CREW REQUIREMENTS 8.1 Vessel Specifications The Vessel Specifications of the GeoExplorer can be found in Attachment C. The GeoExplorer is currently the proposed vessel for the offshore baseline studies for seabed and water column characterization. The GeoExplorer adheres to extensive health and safety policies and a formal Waste Management Plan (all available upon request). 8.2 Cruise Personnel Required Title Number Required Chief Field Scientist 1 Shift Leader 2 (1 per 12-hour shift) Field-Sampling Technician 4 (2 per 12-hour shift) Field Chemist 2 (1 per 12-hour shift) Field Technician 2 (1 per 12-hour shift) Support Staff 4 (2 per 12-hour shift) Navy Representatives 2 SPI Operators 2 (1 per 12-hour shift) Other Staff As Needed 8.3 Roles and Responsibilities 8.3.1 Chief Field Scientist A person appointed to be Chief Field Scientist must be an experienced seagoing scientist. The Chief Field Scientist is responsible for the accomplishment of the planned work of a cruise or segment of a cruise. The Chief Field Scientist generally has an advanced degree in the natural sciences. The Chief Field Scientist has overall charge of the scientific objectives of the cruise leg, is responsible for assigning duties to members of the scientific party and for ensuring that all members of the scientific party obey rules for shipboard behavior. The Chief Field Scientist is responsible for the safety of the scientific party. The Chief Field Scientist is responsible for the preparation of the cruise and technical sampling plans. The Chief Field Scientist must approve any deviations from these plans. The Chief Field Scientist is responsible for maintaining a daily log of scientific activities and the preparation of a post-cruise report. There is one Chief Field Scientist per cruise. Chief Field Scientist for WAGP EBS: Linos Cotsapas (RPI) 8.3.2 Shift Leader A person appointed to be a shift leader must be an experienced seagoing scientist. The shift leader reports to the Chief Field Scientist. Shift leaders typically have a degree in the natural sciences, have strong mechanical skills, and 5 to 10 years of marine field sampling experience. Shift leaders must be completely familiar with the scientific objectives of the cruise. Shift ICF Consulting Appendix B-WAGP EBS Work Plan 59 leaders must be completely familiar with the set-up, maintenance, and operations of all sampling equipment and must be able to direct the ship winch operators to deploy sampling gear. The shift leader is responsible for determine the adequacy of a sample and must be able to direct any sample processing and shipboard testing. The shift leader is responsible for supervising all other members of the scientific party. The shift leader is responsible for the safety of the scientific party under his supervision. There is one shift leader per shift. Shift Leaders for WAGP EBS: Henry Camp and Ted Coogan (ICF) S.N.K. Quaatey (ESL)-for fish trawling 8.3.3 Field Sampling Technician A person appointed to be a field-sampling technician must be an experienced seagoing scientist. Field-sampling technicians must be familiar with the operation of all sampling equipment and with the procedures necessary to collect an adequate sample. Field-sampling technicians generally have a formal training in the natural sciences, typically in biology or chemistry. Field technician should be capable of either: 1) collecting samples for chemical analyses or 2) be capable of sorting and identifying benthic organisms under the direction of the shift leader. There are typically two field-sampling technicians per shift. Field Sampling Technicians for WAGP EBS: Zacharie Sohou (CEDA), expertise: marine biology, biostatistics Catherine Isebor (ERML), expertise: fisheries Emmanuel Lamptey (ESL), expertise: fisheries Dr. Edorh (Universite de Lome), expertise: plankton 8.3.4 Field Chemist A person appointed to be a field chemist technician must be an experienced seagoing scientist. Field chemists are responsible for the chemical testing of samples and must be experienced with the set-up, maintenance, and operation of all shipboard chemical testing equipment. Field chemists are responsible for sample processing and preservation. Field chemists must have sufficient technical training to perform typical shipboard testing, such as pH, turbidity, and dissolved oxygen measurements. There is typically one field chemist per shift. Field Chemist for WAGP EBS: Dr. Houenokapo Soclo (CEDA), expertise: organic chemistry Selorn Ababio (ESL), expertise: water quality chemistry 8.3.5 Field Technician A person appointed to be a field technician must be familiar with general seagoing sample collection activities. Field technicians assist in the deployment and recovery of sampling equipment. The field technician is responsible for sample labeling, preparation of chain-of- custody documents, and sample handling and storage. There is typically one field technician per shift. ICF Consulting Appendix B-WAGP EBS Work Plan 60 Field Technician for WAGP: Paul Bannerman (ESL) Michael Okunomo (ERML) 8.3.6 Support Staff Support staff are required to assist in the deployment and recovery of scientific equipment. These personnel may or may not have formal training but should be comfortable working on a marine research vessel and be aware of all safety requirements. There are typically two support staff per shift. It is expected that each country consultancy will provide a junior scientific staff member for the cruise, to build their own internal capacity for future environmental baseline study work. Support Staff for WAGP EBS: One support staff per country represented Samuel Addo (ESL) Mr Sédjro (Universite de Lome) Ibrahim Attach (ERML) M. Georges Degbe (CEDA) 8.3.7 Navy Representatives Due to Nigerian survey permit requirements, two Nigerian Navy representatives will be onboard the vessel while the EBS vessel is sampling in Nigerian waters. Upon finishing sampling in Ghana, Togo, and Benin, the vessel will travel directly to Lagos and the Nigerian Navy representatives will board. The EBS survey will then recommence, throughout Nigerian waters. Once the EBS vessel has completed sampling in Nigerian waters, the Navy representatives will disembark in Lagos. 8.3.8 SPI Operators A company with a proven track record of SPI operation and data interpretation (benthic specialty) experience will be subcontracted for participation in the EBS cruise. Typically, two SPI operators are needed for 24-hour sampling. 8.3.9 Other Staff As with the SPI, other staff may be required for the use and deployment of specialized equipment. The providers of the specialized equipment provide the personnel to operate the equipment. At this time, no additional staff is anticipated. ICF Consulting Appendix B-WAGP EBS Work Plan 61 West African Gas Pipeline EIA Final Scoping Report Appendix 1 Agreed Design Standards OFFSHORE PIPELINE CODES AND SPECIFICATIONS Governing design code ANSI/ASME B31.8 ­ 2000 Edition (or latest) "Gas Transmission and Distribution Piping Systems". Supplemental recommended practices API RP 1111 ­ 1999 Edition (or latest) "Design, Construction, Operation, and Maintenance of Offshore Hydrocarbon Pipelines". API RP 14C ­ 6th edition (or latest) "Recommended Practice for Analysis, Design, Installation and Testing of Basic Surface Safety Systems for Offshore Production Platforms". DNV Offshore Standard OS-F101 "Submarine Pipeline Systems" January 2000 Edition (or latest). Major offshore pipeline component specifications as referenced in B31.8 Line Pipe Specification ­ API 5L ­ 42nd Edition (or latest) "Specification for Line Pipe". Welding Specification ­ API 1104 ­ 1999 Edition (or latest) "Standard for Welding Pipelines and Related Facilities". Corrosion Protection ­ NACE RP0675 (latest edition) "Control of External Corrosion on Offshore Steel Pipelines". Pipeline Valves ­ API 6D ­ 21st Edition (or latest) "Specification for Pipeline Valves". Pipeline Flanges ­ ASME B16.5 ­ 1996 Edition (or latest) "Pipe Flanges and Flanged Fittings NPS 1/2 Through NPS 24". Pipeline Fittings ­ ASME B16.9 ­ 2001 Edition (or latest) "Factory-Made Wrought Butt- welding Fittings". ONSHORE PIPELINE CODES AND SPECIFICATIONS Governing design code ANSI/ASME B31.8 ­ 2000 Edition (or latest) "Gas Transmission and Distribution Piping Systems". Major onshore pipeline component specifications as referenced in ANSI/ASME B31.8 Line Pipe Specification ­ API 5L ­ 42nd Edition (or latest) "Specification for Line Pipe". Welding Specification ­ API 1104 ­ 1999 Edition (or latest) "Standard for Welding Pipelines and Related Facilities". Corrosion Protection ­ NACE RP0169 (latest edition) "Control of External Corrosion on Underground or Submerged Steel Pipelines". West African Gas Pipeline Page 1- 1 March, 2003 West African Gas Pipeline EIA Final Scoping Report Appendix 1 Agreed Design Standards Pipeline Valves ­ API 6D ­ 21st Edition (or latest) "Specification for Pipeline Valves". Pipeline Flanges ­ ASME B16.5 ­ 1996 Edition (or latest) "Pipe Flanges and Flanged Fittings NPS 1/2 Through NPS 24". Pipeline Fittings ­ ASME B16.9 ­ 2001 Edition (or latest) "Factory-Made Wrought Butt- welding Fittings". ONSHORE COMPRESSOR STATION CODES AND SPECIFICATIONS Governing design code ANSI/ASME B31.8 ­ 2000 Edition (or latest) "Gas Transmission and Distribution Piping Systems". Major compressor station component specifications as referenced in ANSI/ASME B31.8 Piping Materials -ASTM materials in accordance with B31.8. Welding Specification ­ In accordance with ASME Section IX requirements as provided in ANSI B 31.8. Pipeline Valves ­ API 6D ­ 21st Edition (or latest) "Specification for Pipeline Valves". Pipeline Flanges ­ ASME B16.5 ­ 1996 Edition (or latest) "Pipe Flanges and Flanged Fittings NPS 1/2 Through NPS 24". Pipeline Fittings ­ ASME B16.9 ­ 2001 Edition (or latest) "Factory-Made Wrought Butt- welding Fittings". Other component codes or specification for compressor station Electrical Code ­ British Standards, CENELEC, IEC, ISO, NEMA. Instrument Code ­ ISA, API RP 551, IEC, NEMA. Fire Protection Code ­ NFPA. Compressor Code ­ API Standard 617 ­ 1995 Edition (or latest) "Centrifugal Compressors for Petroleum, Chemical, and Gas Service Industries". Power turbines ­ API 616. Gas Measurement Code ­ API MPMS 14.3 - 1995 Edition (or latest) "Manual of Petroleum Measurement Standards Chapter 14 ­ latest edition "Natural Gas Fluids Measurement Section 3 - Concentric, Square-Edged Orifice Meters Part 1 - General Equations and Uncertainty Guidelines" or ISO 5167. Pressure Vessel Code ­ ASME Sec VIII D1 ­ 1998 Edition (or latest) "BPVC SECTION VIII Rules for Construction of Pressure Vessels DIVISION 1". West African Gas Pipeline Page 1- 2 March, 2003 West African Gas Pipeline EIA Final Scoping Report Appendix 1 Agreed Design Standards ONSHORE REGULATION AND METERING STATIONS AND TERMINALS CODES AND SPECIFICATIONS Governing design code ANSI/ASME B31.8 ­ 2000 Edition (or latest) "Gas Transmission and Distribution Piping Systems". Major R&M station component specifications as referenced in ANSI/ASME B31.8 Materials : ASTM/API in line with the requirements of ANSI B31.8. Welding Specification ­ API 1104 ­ 1999 Edition (or latest) "Standard for Welding Pipelines and Related Facilities". Pipeline Valves ­ API 6D ­ 21st Edition (or latest) "Specification for Pipeline Valves". Pipeline Flanges ­ ASME B16.5 ­ 1996 Edition (or latest) "Pipe Flanges and Flanged Fittings NPS 1/2 Through NPS 24". Pipeline Fittings ­ ASME B16.9 ­ 2001 Edition (or latest) "Factory-Made Wrought Butt- welding Fittings". Other component codes or specification for R&M stations Electrical Code ­ British Standards (BS), CENELEC, IEC, ISO, NEMA. Instrument Code ­ ISA, API RP 551, IEC, NEMA. Fire Protection Code ­ NFPA. Gas Measurement Code ­ API MPMS 14.3 - 1995 Edition (or latest) "Manual of Petroleum Measurement Standards Chapter 14 ­ latest edition "Natural Gas Fluids Measurement Section 3 - Concentric, Square-Edged Orifice Meters Part 1 - General Equations and Uncertainty Guidelines" or ISO 5167. Pressure Vessel Code ­ ASME Sec VIII D1 ­ 1998 Edition (or latest) "BPVC SECTION VIII Rules for Construction of Pressure Vessels DIV1". OTHER MISCELLANEOUS FACILITIES Buildings Local Building codes in each country shall be applicable. Civil works British Standards, EN, ISO. OTHER DESIGN REQUIREMENTS DNV will be used as a supplement in areas of deficiency of ANSI B31.8 with emphasis on stability calculations and its verifications. West African Gas Pipeline Page 1- 3 March, 2003 West African Gas Pipeline EIA Final Scoping Report Appendix 1 Agreed Design Standards Anodes shall be utilised to ensure maintenance design life for the offshore pipeline of between 40 and 50 years. Pig traps will be provided for internal intelligent pigging inspection, including on spur lines. The WAGP Regulations shall provide for the use of intelligent pigging and remotely operated vehicles for inspection, at periods to be agreed which shall not adversely affect Project economics. A maintenance philosophy and emergency management plan shall be established in accordance with this Agreement, covering maintenance and emergency response and repair procedures. The Company shall maintain stocks of spare parts and training of staff consistent with the agreed maintenance philosophy and plan. To the extent practicable and as agreed to between the Company and the WAGP Authority, maintenance standards as contained in the design standards above will be followed. West African Gas Pipeline Page 1- 4 March, 2003 APPENDIX 2 FOCUS AREAS FOR ENVIRONMENTAL BASELINE ASSESSMENT Nigeria Offshore Cotonou Lome Tema Takoradi Effasu Environmental Data Onshore Marine Environment Gas Delivery Point Gas Delivery Point Gas Delivery Point Gas Delivery Point Gas Delivery Point Land/Physical Characteristics. Climate/Meteorological Factors XX X X X X X X Terrain XXX XXX X X XX XX X Geo surface materials XX XX X X X X X Relief/topographic characteristics XXX XXX X X X X X Environmental Contaminants XX XX XX X X Land Capabilities Agriculture XXX X X X X Forestry XX X XX Wildlife XXX X XX XXX Fisheries XXX XXX XXX XXX XXX XXX Significant Geographic Areas. XX XX XX XX XX XX XX Environmental Field Data Airsheds XX X XX XX XX XX XX Overall Air Quality Assessments XX XX XX XX XX XX Noise Level Assessments XXX XX XX X X Water Quantity/Quality Assessments Hydrology XX XX XX XX XX XX Ground Water Studies XX Stream/Lagoon Characteristics XXX XX XX XX XX XX Watershed Characteristics XXX X X X X X Oceanographic Parameters XXX XX XX XX XX XX (Geomorphology, Waves & Currents) Flora/Fauna Types/distribution XXX XX Vegetative Cover Characteristics XXX XX X X XX XX XXX Soil Studies XX XXX XX XX XX XX XX Biological Descriptions via Maps Ecological Zones XX XX X X XX XXX XXX Sensitive Areas XX Unique Ecosystems XX XXX XX XX XXX Areas of ecological interest XX XXX XX XX XXX Areas of scientific interest XX XXX XX XX XXX Areas of High Economic Concern XX X XX XX XX XX X Aquatic Studies Hydrobiology X XXX XX XX XX XX XX (plankton, benthic fauna, etc.) Fisheries X XXX XXX XXX XXX XXX XXX Freshwater & Marine Wildlife X XXX XXX XXX XXX XXX XXX X-Limited description necessary XX- Routine description anticipated to appropriately describe the existing situation, including potential for secondary impacts XXX- Detailed description needed due to an anticipated higher level of impact WEST AFRICAN GAS PIPELINE Page 2-1 March, 2003 APPENDIX 3 CURRENT EIA REFERENCE MATERIALS 1. Perspectives in Integrated Coastal Areas Management in the Gulf of Guinea (UNIDO Large Marine Ecosystem Project for the Gulf of Guinea) 2. Nearshore Dynamics and Sedimentology of the Gulf of Guinea (UNIDO Large Marine Ecosystem Project for the Gulf of Guinea) 3. State of the Coastal and Marine Environment of the Gulf of Guinea (UNIDO Large Marine Ecosystem Project for the Gulf of Guinea) 4. Towards Integrated Coastal Zone Management in the Gulf of Guinea A Framework Document 5. Coastal Profile of Nigeria (UNIDO Large Marine Ecosystem Project for the Gulf of Guinea) 6. Profil de la zone cotiere du Benin (UNIDO Grand Ecosysteme Marin de Golfe de Guinee) 7. Cote D'Ivoire Profil environmental de la zone cotiere (UNIDO Grand Ecosysteme Marin de Golfe de Guinee) 8. Profil Environmental du Littoral du Togo (UNIDO Grand Ecosysteme Marin de Golfe de Guinee) 9. Zonation of Ghanaian Fishing Grounds 10. Coastal Zone Profile of Ghana 11. Towards an integrated Coastal Zone Management Strategy for Ghana (Ghana EPA and World Bank) 12. The Coastal Zone of West Africa: Problems and Management 13. African Perspectives on the Clean Development Mechanism 14. An Overview of the Environmental Impact of the Shrimp and Prawn Industry in Ghana 15. Draft Report of the Wetland Typology Working Group West African Gas Pipeline Page3-1 March, 2003 APPENDIX 4A PRELIMINARY IMPACT SUMMARY - POTENTIALLY POSITIVE IMPACTS X- probability and severity to be determined Environmental Impact Location Pre-Construction Construction* Operations Decommissioning Reduced greenhouse gas emissions from Nigerian Regional X oilfield flaring Reduced greenhouse gas emissions from the use of natural gas as an alternative energy source in Benin, Togo and Ghana Potential for reduced deforestation/desertification Socio-Economic Impacts National and Regional industrial or economic Regional X benefits facilitated by the delivery of reliable, competitively priced, cleaner burning fuel WAGP social reinvestment opportunities including Regional X X X technology transfer and capacity building Stakeholder reactions to perceptions and actual Regional X X X X performance of the Commercial Group Proposed compensation schemes Nigeria Onshore X X and Gas Delivery Points Temporary employment opportunities All X X *Pre-Construction and Construction Impacts includes support activities such as camps for onshore construction personnel, staging areas for both onshore and offshore operations, land and marine transportation, and possibly weight coating operations APPENDIX 4B PRELIMINARY IMPACT SUMMARY - POTENTIALLY NEGATIVE IMPACTS X- probability and severity to be determined Health and Safety Impacts Location Pre-Construction Construction* Operations Decommissioning Transfer of disease and illness due to Onshore Pipeline X X Limited X · initial health conditions of workers and local Route communities · interactions between project personnel and Nigeria Beach the communities Compression · sanitary conditions of work, housing and feeding locations Gas Delivery · R&M Locations Injuries due to construction equipment selection All above plus X X X and/or operation Marine Injuries or illness due to the use of hazardous All above plus X X X materials Marine Injuries or Illness due to improper waste management All above plus X X X (sanitary, non-hazardous or hazardous wastes) Marine Environmental Impacts Location Pre-Construction Construction* Operations Decommissioning Cumulative impacts to areas of ecological concern due Regional X to regional economic growth. Examples include the Gulf of Guinea Marine Ecosystem and areas of high biodiversity between Effasu and Takoradi. Changes to historical/traditional land usage Nigeria Onshore and X X X X Gas Delivery Points Vegetative clearing Nigeria Onshore and Camps X Gas Delivery Points Access roads Weight Coating Right of Way And Facility Site Preparation Loss of habitat and related impacts to flora and fauna Nigeria Onshore and X X X from vegetative clearing Gas Delivery Points *Pre-Construction and Construction Impacts includes support activities such as camps for onshore construction personnel, staging areas for both onshore and offshore operations, land and marine transportation, and possibly weight coating operations APPENDIX 4B PRELIMINARY IMPACT SUMMARY - POTENTIALLY NEGATIVE IMPACTS X- probability and severity to be determined Environmental Impacts Location Pre-Construction Construction* Operations Decommissioning Erosion associated with vegetative clearing, pipeline Nigeria Onshore and X X Limited Limited trenching/backfilling and right of way reinstatement Gas Delivery Points Material handling impacts from vegetative clearing Nigeria Onshore and X X and excess soil excavation Gas Delivery Points River, stream or lagoon crossings or dredge/fill Nigeria Onshore and X X activities possibly the Benin (erosion, water quality impacts in terms of pollution Gas Delivery Points and/or disruptions to water supply, etc.) Coastal and wetland ecological issues Nigeria Beach X X X "Compression facility" and R&M Stations Coastal stability issues Nigeria Beach X X "Compression facility" and R&M Stations Temporary (short duration) impacts from traffic, Nigeria Onshore X X X noise, and waste generation management and Gas Delivery Points Temporary air emissions from equipment and All X X activities including dust and other air pollutants such as SOX, NOX, and particulates Intermittent air pollutant emissions Nigeria Onshore X and Gas Delivery Points Fires Nigeria Onshore Limited Limited X Limited and Gas Delivery Points *Pre-Construction and Construction Impacts includes support activities such as camps for onshore construction personnel, staging areas for both onshore and offshore operations, land and marine transportation, and possibly weight coating operations APPENDIX 4B PRELIMINARY IMPACT SUMMARY - POTENTIALLY NEGATIVE IMPACTS X- probability and severity to be determined Environmental Impacts Location Pre-Construction Construction* Operations Decommissioning Commercial Group approach to existing land Nigeria Onshore X X contamination and Gas Delivery Points Temporary impacts to fisheries, aquatic Offshore Route ­ Limited X vegetation/wildlife and benthic fauna from survey and Main Pipeline and construction activities Laterals Temporary impacts from marine traffic, noise, and Offshore Route ­ Limited X waste generation management Main Pipeline and Laterals Pipeline stability impacts associated with Offshore Route ­ X X oceanographic parameters such as geomorphology, Main Pipeline and currents and waves. Laterals Water column impacts from pipeline disruptions and Offshore Route ­ X natural gas releases Main Pipeline and Laterals Effluent discharge from pipeline hydrotesting Offshore Route ­ X operations Main Pipeline and Laterals Socio-Economic Impacts Location Pre-Construction Construction* Operations Decommissioning Stakeholder reactions to perceptions and actual Regional X X X X performance of the Commercial Group Physical changes to communities along the Nigeria Onshore and X X X pipeline route, including aesthetics Gas Delivery Points Changes to historical/traditional land usage Proposed compensation schemes Nigeria Onshore and X X Gas Delivery Points *Pre-Construction and Construction Impacts includes support activities such as camps for onshore construction personnel, staging areas for both onshore and offshore operations, land and marine transportation, and possibly weight coating operations APPENDIX 4B PRELIMINARY IMPACT SUMMARY - POTENTIALLY NEGATIVE IMPACTS X- probability and severity to be determined Socio-Economic Impacts Location Pre-Construction Construction* Operations Decommissioning River, stream or lagoon crossings or Nigeria Onshore and X X dredge/fill activities possibly Benin gas (erosion, water quality impacts in terms of delivery point pollution and/or disruptions to water supply, etc.) Temporary (short duration) impacts from Nigeria Onshore and X X traffic, noise, and waste generation Gas Delivery Points management Physical/social interactions between WAGP All X X Limited personnel and local communities Community health and safety impacts due to Nigeria Onshore and X operational disruptions or natural gas releases Gas Delivery Points Fires resulting from disruptions to pipeline operations Nigeria Onshore and X or natural gas releases Gas Delivery Points Impacts to local and commercial fishing Offshore Route ­ X X Limited Main Pipeline and Laterals *Pre-Construction and Construction Impacts includes support activities such as camps for onshore construction personnel, staging areas for both onshore and offshore operations, land and marine transportation, and possibly weight coating operations APPENDIX 5 DETAILED LIST-POTENTIAL MITIGATION MEASURES · As agreed between the Countries and WAGP, observe protective perimeters around the following sensitive zones, and avoid and/or reinstate deforestation or the elimination of vegetation cover, including: - Shorelines, - Known wildlife habitats, - Water supply basins, - Steep and erosion-sensitive gradients, - Wet areas, · Conserve and reuse topsoil during the burial of the pipe, · Establish a work calendar in keeping with those periods of time that are sensitive to wildlife elements, · Plan to allow for considerable flexibility in the means of crossing sensitive habitats (e.g., waterways, wet areas) or protected habitats (e.g., the habitat of a rare plant species), · Reduce to a minimum the length of the work in sensitive areas, · Control access to work sites, · Use adequate road signs on the routes leading to the work sites, · Establish adequate personnel training procedures with regard to the protection of the environment, · Limit the expropriation of right-of-ways, fragmentation of properties, agricultural and forestry areas, · Coordinate the work with other land users, · Encourage the employment of the local workforce, · At the end of the work, clean and return the elements of the environment that were affected to their original condition. Use species indigenous and suitably adapted to the host environment, · Compensate for major residual impacts, · Formulate an emergency action plan in coordination with the interested authorities in the event of an accidental spill during the construction and operational phases. Specific Measures Protection of the quality of surface waters · Control traffic in order to avoid leaks and spills of hazardous materials (hydrocarbons, etc.), . Conserve vegetation near waterways and wet areas, · Measures to be taken in the event of the accidental contamination of the ground, air, and water, · Avoid moving machinery near potable water connections. A security perimeter should be established and identified on the sites by marking them or by closing them in by whatever means necessary, · When necessary to cross waterways: - Implement all necessary measures (wire fences, nets, protective paneling, etc.) to avoid having construction materials, wastes, or wood residues fall into waterways, - Place filtration berms and sediment barriers in the ditches that drain the work sites, . Cross perpendicularly where the embankments are stable and the waterways are narrow, . Use methods that minimize perturbations to aquatic environments and wet areas, . Show preference for existing structures or plan for the installation of culverts whose bearing capacity is sufficient for the machinery being used, · At the end of the work, remove all temporary installations used to cross waterways. Reestablish, if necessary, the normal flow of the waterways and restore the original bed and banks, · Take all necessary precautions during the refueling of transport vehicles and machinery at the work site to avoid accidental spills. Prohibit the refueling of machinery near waterways. Protection of the water table · Properly seal wells and bore holes prior to abandonment, · Use appropriate drilling practices. Modification of the flow of surface water · Schedule intervention periods in areas subject to flooding or in which there is the likelihood of heavy runoffs at times other than the high water season or heavy rains, · avoid blocking the drainage of surface water and provide for the means of restoration, · Restrict to a minimum vehicular traffic beyond the right of way in order to avoid the creation of ruts, and consequently, runoff, · Be mindful of surface drainage at all times. West African Gas Pipeline Page5-1 March, 2003 APPENDIX 5 DETAILED LIST-POTENTIAL MITIGATION MEASURES · Avoid blocking waterways, trenches, or any other channel. · Remove any debris that blocks the normal flow of surface water, · Provide accommodations for vehicular traffic anytime there is a risk of compaction or alteration of wet areas. Soil erosion and destabilization · Mechanically stabilize the soil in order to reduce the potential of erosion, · Avoid excavation and burial in steeply sloped ground and avoid creating grade breaks, · Provide for the placement of siltation ponds in areas subject to heavy erosion, · Obtain the necessary authorizations for work in wet areas, · Provide for the rehabilitation of the site after the work, · Limit activities in erodible soils. Select vehicles suited to the nature of the soil, · Avoid the creation of access ways along the axis of long, continuous descending grades in favor of a perpendicular or diagonal orientation, · At the completion of the work, level the disturbed soil and quickly undertake the sodding and planting of trees or brushes in order to control soil erosion. Modification of the soil characteristics · Scarify as needed damaged sites, regrade the sites, then replace the layer of topsoil that was previously put to the side during construction work, · Provide accommodations for vehicular traffic anytime there is a risk of compaction or alteration of the surface. · Restore the operational site by restoring the original profile of the topography and the soil, · Strictly regulate heavy machinery traffic. Restrict the number of traffic lanes and limit the movement of the machinery to the work sites and to marked access ways, · Maintain transportation vehicles and machinery in good working order so as to avoid oil and fuel leaks and all other pollutants. Changes to air quality and noise exposure · Near inhabited areas, avoid heavy truck traffic and carrying out loud work outside of normal working hours, · Maintain transportation vehicles and machinery in good working order in order to minimize gaseous emissions and noise, · Use dust-control liquids and dust-recovery machinery. Destruction or modification of the vegetation cover · Clearly define the cut zones in order to limit the deforestation thereto, · Protect trees from the machinery on the edge of the right-of-ways, · Restore the vegetation at end of the work, · Avoid the deforestation and the destruction of bordering vegetation, · During cutting operations, provide for wood stacking areas beyond wet areas, · Prohibit the digging of trenches within a meter of a tree. Destruction or modification of wildlife habitats · Obtain special authorization to perform work within wildlife or ecological preserves, · No work will be done in breeding grounds during breeding seasons. Schedule work and set the calendar of activities taking into account the use the wildlife makes of the land, · Protect known productive habitats, wet areas and spawning beds, · Avoid restricting the movement of fish by paying attention to the size of culverts, the speed of the flow of water, and the water level at the point of minimum flow. Perturbation to customs and traditions · Provide for a work schedule that will avoid disturbing the traditional life of communities, · Establish a communication program to inform communities of on-going work and establish appropriate measures to minimize the disturbance caused by the work. Population displacement · Reach an agreement with communities with regard to the ways and means of resettlement and respect those commitments, West African Gas Pipeline Page5-2 March, 2003 APPENDIX 5 DETAILED LIST-POTENTIAL MITIGATION MEASURES · Negotiate, if necessary, for the acquisition of land or the right of passage and provide for the adequate compensation, · Guarantee access to private property and the safety of residents and passersby during the course of the work by enacting the appropriate measures (fencing, guards, etc.). Service interruptions during the work · During service interruptions, notify the concerned jurisdictions and take the appropriate measures to keep interruptions to a minimum for the residents of the affected area. Disturbances caused by construction or maintenance work · Minimize the accumulation of waste produced by the use of construction materials, · Insure the appropriate management of chemical products used in the placement of pipe (handling, storage, installation, disposal, etc.), · Avoid the storage of machinery in areas other than those identified as essential to the work. Provide for a clear definition of the boundaries of said areas, · Avoid the accumulation of all types of wastes on and off the work site; remove the wastes to waste disposal sites provided for that purpose. Damages caused to roads, risks of accidents, and traffic caused in connection with construction work · Avoid blocking public access, · Use road signs to notify work in progress, · Comply with road bearing capacity and repair damage caused to roads at the end of the work, · Circumvent gathering places. Public safety and management of hazardous materials · Heighten the safety of workers and of the surrounding communities by establishing safety and emergency action plans, · Insure that all employees adhere to the safety program, · Provide for the establishment of emergency plans and action plans in the event of an accidental spill of contaminants or of a gas leak. Post in a location visible to the workers a poster showing the names and telephone numbers of the people in charge and describing the alert protocol, · Keep on hand a supply of absorbent materials as well as properly designated recipients designed to contain petroleum residue and wastes in the event of a spill, · Inform the drivers and operators of machines of the security standards to be followed at all times, · When action is necessary to remove or contain pollutants or contaminated substances, solid or liquid, the site selection and the disposal method must observe applicable standards, · Provide for storage areas for contaminated products and equip them with devices designed to protect against any accidental spills. Modification of a known historical site or building · Obtain the necessary authorizations prior to the execution of the work. Disruption of known or potential cultural or archeological sites · Prior to the commencement of the work, undertake archeological assessments in identified potential sites and encourage the appropriate analysis and reclamation of archeological artifacts, or avoid these sites altogether. · Complete the gathering of inventory data by means of mapping and photographic surveys, · During the work, scrutinize the work site for artifacts of archeological importance, and in the event of any discovery, suspend all activities and notify the competent authorities, · In order to prevent theft or vandalism, refrain from letting the general public know the exact location of archeological or exceptional sites, · Identify or protect culturally or religiously significant sites. Visual changes to known historical sites and monuments · Provide for facilities that are in harmony with the historical heritage, Optimize the placement and the architecture of facilities in such a way as to integrate them into the landscaping. West African Gas Pipeline Page5-3 March, 2003 APPENDIX 5 DETAILED LIST-POTENTIAL MITIGATION MEASURES Location of facilities · In urban area, seek out those sites that present characteristics that are compatible with the facilities to be built, · Set a premium on the use of small-footprint facilities to minimize the loss of space, · Demonstrate a preference for areas where the facilities will be less visible, · Select sites located near the edge of a property or at the far end of a street block, · Install as necessary noise barriers in order to lessen the acoustic impact. Impeding road traffic and community activities · Adjust work schedules so as not to disturb traffic. Establish an adequate system of road signs and detours. · Notify communities of pending work: scope, duration and location, · In urban areas, clean the streets used by trucks and machinery so as to keep them clean and clear. Disruption of farming activities · Prior to the start of work, check with farmers regarding the use that they intended for their land, · Perform the work in such a fashion as to harm as little as possible existing farming practices (duration, timing, magnitude), · Keep to a minimum areas in which farming will be impossible during and after the work and compensate for losses, · Maintain at all times access to isolated areas, · Enter the right of way by the use of existing routes or move about at the edge of cultivated land and coordinate the creation of access roads in cooperation with farmers, · Place the facilities, to whatever degree possible, at the edge of lots or cultivated land or distribute them in such a way as to occupy as little as possible cultivated land, · Loosen soil compacted by machinery and put disturbed production areas back into production. Disruption to forestry activities · Notify the owners of the occupied land of work duration, · Provide for coordination mechanisms with the competent authorities for the disposal of merchantable timber harvested from private lands or with private owners for the recovery of firewood. Disruption of tourist activities · Avoid encumbering tourist and recreation areas or take the necessary measures to insure access and safe use during and after the work, · Devise arrangements that insure compatibility between tourist and recreative activities and the operation of the gas pipeline. West African Gas Pipeline Page5-4 March, 2003 Preliminary Scoping Report Nigeria WEST AFRICAN GAS PIPELINE PRELIMINARY SCOPING REPORT Prepared For: Nigeria Federal Ministry of the Environment August, 2002 Table of Contents OBJECTIVES ..........................................................................................................................3 1.0 PROJECT SUMMARY....................................................................................................4 1.1 Project Proposal ................................................................................................................. 4 1.2 Project Background............................................................................................................ 5 1.3 Project Purpose & Need..................................................................................................... 6 1.4 EIA Legal Framework ....................................................................................................... 6 1.5 Agency Support and Harmonization.................................................................................. 7 2.0 PROJECT DESCRIPTION.............................................................................................8 2.1 Scope of EIA...................................................................................................................... 8 2.2 Natural Gas Sources ("Upstream" of WAGP)................................................................... 9 2.3 Natural Gas Consumption ("downstream" of WAGP)...................................................... 9 2.4 General Layout & Physical Description .......................................................................... 10 2.5 Permanent Ancillary Systems & Facilities ...................................................................... 11 2.6 Operational Control and Safety Systems......................................................................... 13 2.7 Project Implementation Description ................................................................................ 14 3.0 PROJECT ALTERNATIVES SUMMARY.................................................................19 4.0 STAKEHOLDER CONSULTATIONS........................................................................19 5.0 EXISTING SITUATION ...............................................................................................21 5.1 Existing Health Situation................................................................................................. 21 5.2 Existing Safety Situation.................................................................................................. 22 5.3 Description of the Environmental Status (Existing Environment and Resources).......... 23 5.4 Existing Socio-Economic Aspects................................................................................... 24 6.0 IMPACT ASSESSMENT...............................................................................................25 7.0 MITIGATING AND AMELIORATING MEASURES ..............................................27 8.0 DETAILED ALTERNATIVES ANALYSIS................................................................29 9.0 ENVIRONMENTAL MANAGEMENT PLAN CONSIDERATIONS......................29 9.1 Waste Management.......................................................................................................... 30 9.2 Air Emissions................................................................................................................... 31 9.3 Emergency Preparedness and Response.......................................................................... 31 9.4 HSE Management Systems.............................................................................................. 31 10.0 PROPOSED TERMS OF REFERENCE ...................................................................32 10.1 Project Submission......................................................................................................... 32 10.2 EIA Implementation and Document Preparation........................................................... 34 10.3 EIA Document Submissions and Agency Review........................................................ 35 10.4 Post EIA Approval......................................................................................................... 37 West African Preliminary Terms of Reference Gas Pipeline and Scoping Report APPENDIX 1 AGREED DESIGN STANDARDS APPENDIX 2 FOCUS AREAS FOR ENVIRONMENTAL BASELINE ASSESSMENT APPENDIX 3 CURRENT EIA REFERENCE MATERIALS APPENDIX 4 PRELIMINARY IMPACT SUMMARIES APPENDIX 5 DETAILED LIST-POTENTIAL MITIGATION MEASURES ATTACHMENT 1 Regional Map-West African Gas Pipeline ATTACHMENT 2 Nigeria Onshore Pipeline Route Map-West African Gas Pipeline ATTACHMENT 3 Compression Facility Layout Drawing-West African Gas Pipeline ATTACHMENT 4 Regulating & Metering Station Layout Drawing-West African Gas Pipeline ATTACHMENT 5 Benin Onshore Delivery Site Map-West African Gas Pipeline ATTACHMENT 6 Togo Onshore Delivery Site Map-West African Gas Pipeline ATTACHMENT 7 Tema (Ghana) Onshore Delivery Site Map-West African Gas Pipeline ATTACHMENT 8 Takoradi (Ghana) Onshore Delivery Site Map-West African Gas Pipeline August, 2002 Page 2 West African Preliminary Terms of Reference Gas Pipeline and Scoping Report OBJECTIVES The overall objectives of this proposed Preliminary EIA Scoping Report include the following: · Provide a framework leading to an appropriate regional harmonization of EIA expectations, review and timely approval of the submitted EIA documents for Benin, Ghana, Nigeria and Togo. · Satisfy Initial Project Proposal requirements for the 4 countries prior to formal application or registration of the project. · Satisfy Preliminary Impact Assessment requirements for the 4 countries. · Assist the 4 countries in Project Screening deliberations, following formal EIA application or registration. · Assist the 4 countries in EIA Scoping deliberations, following formal EIA application or registration., focusing the EIA on significant potential impacts associated with pipeline construction and operation. · Provide a framework such that the WAGP Joint Venture (Commercial Group) and the 4 countries can consistently inform and educate stakeholders, understand stakeholder concerns and solicit input from relevant interest groups and those who may be directly impacted by the Project. · Assist the Commercial Group with project planning, design and decision making. More specifically, the objective of this EIA Scoping/Terms of Reference document is to establish a comprehensive EIA approach leading to the following documents contained in the final EIA Report: · Project background, purpose & need · Detailed project descriptions, including general layout & physical descriptions, ancillary systems & facilities, operational control systems, and project implementation descriptions · Detailed descriptions of the existing environmental and socio-economic situation that incorporates stakeholder consultations, literature reviews and field studies. · Health & safety, environmental and socio-economic impact assessments that include qualitative and quantitative risk assessments among other tools and techniques. · Proposed mitigating and ameliorating measures as applied to pipeline routing, design, construction and operations impacts. · Alternatives Analysis, including the No-Project Alternative · Environmental Management Plans that appropriately incorporate monitoring, mitigation and management systems that are consistent with identified impacts and that provide a contingency for unforeseen impacts August, 2002 Page 3 West African Preliminary Terms of Reference Gas Pipeline and Scoping Report In preparing the final EIA reports and documents, the Commercial Group intends to use all of the deliverables described above to continuously modify and improve construction and operational plans to: · enhance the benefits of the project · reduce the potential for, or consequences of, negative impacts · satisfy the cost and schedule expectations of the 4 countries and project investors 1.0 PROJECT SUMMARY 1.1 Project Proposal Chevron Nigeria, Ltd. on behalf of the West African Gas Pipeline (WAGP) Joint Venture intends to construct a 12-30 inch (30.5-76.2 cm), 617 km (383 mile), onshore and offshore gas pipeline from Nigeria to Ghana. The WAGP consortium is a joint venture partnership between Chevron Nigeria Limited (CNL), Nigerian National Petroleum Corporation (NNPC), The Shell Petroleum Development Company (SPDC) of Nigeria Limited, Societe Beninoise de Gaz S.A. (SOBEGAZ), Societe Togolaise de Gaz S.A (SOTOGAZ) and the Volta River Authority (VRA). Members of the Commercial Group intend to form a project company to be known as WAPCo for constructing, maintaining and operating the pipeline. The Commercial Group is considering a proposed pipeline route that extends from a proposed connection to the existing Escravos-Lagos Pipeline (ELP) at the Alagbado "Tee" near Itoki, Nigeria. The ELP is owned by Nigerian National Petroleum Corporation (NNPC) and operated by the Nigerian Gas Company (NGC), a subsidiary of NNPC. From the ELP connection, the pipeline route would proceed to a Nigerian beach location on land and continue offshore from the Nigerian beach location across the territorial waters of Nigeria, Benin, Togo and Ghana, terminating at Takoradi, Ghana. Gas delivery laterals from the main pipeline route will extend into Cotonou (Benin), Lome (Togo) and other gas delivery target locations in Ghana (Tema and Takoradi). With regard to the delivery points, these locations should achieve an equilibrium between the concerns of their acceptance by coastal communities, safety and environmental vulnerability. Offshore pipeline installation is anticipated to be in 30-100 m (100-300 feet) water depths at an approximate distance of 15 km (9 miles) from shore. Targeted gas delivery points at Cotonou, Lome, Tema, and Takoradi are anticipated to extend onshore only to the degree necessary to install Regulating and Metering Stations (1-2 km (0.6-1.2 miles) onshore), although in the case of Benin, gas delivery points could extend 5-9 km (3.1- 5.6 miles) inland. August, 2002 Page 4 West African Preliminary Terms of Reference Gas Pipeline and Scoping Report 1.2 Project Background On 5th September, 1995 a Heads of Agreement (HOA) was signed by the Governments of The Republic of Benin, The Republic of Ghana, The Federal Republic of Nigeria, and The Republic of Togo to construct a pipeline to transport natural gas from Nigeria to Ghana through Benin and Togo. The HOA also required that an independent feasibility study be conducted to determine the viability of the pipeline. The Engineering Feasibility Study was carried out by Pipeline Engineering GmbH, PLE, of Germany and documented in a report issued in March 1999. This study determined that a West African Gas Pipeline (WAGP) was technically and commercially feasible, pending additional evaluation. In May 1999, the Governments of the Republic of Benin, the Republic of Ghana, the Federal Republic of Nigeria, and the Republic of Togo (collectively referred to as "the Countries"), appointed Chevron Nigeria Limited, Ghana National Petroleum Corporation, Nigerian National Petroleum Corporation, The Shell Petroleum Development Company of Nigeria Limited, Société Béninoise de Gaz S.A., and Société Togolaise de Gaz S.A., (collectively referred to as the "Commercial Group") Project Developer for the WAGP. In May 2001, the Ghana National Petroleum Corporation advised the Commercial Group of a proposal to assign their interest in the WAGP to the Volta River Authority. This assignment is completed.. On 11th August 1999, the Countries further entered into a Definitional Phase Memorandum of Understanding ("MOU") with the Commercial Group on the development of the WAGP. In the MOU, the Countries confirmed the designation of the Commercial Group as the Project Developer and granted the Commercial Group an exclusive right to establish the West African Gas Pipeline Company ("WAPCo") which would enter into a Concession Agreement with the Countries, granting to WAPCo an exclusive franchise to build, own and operate the WAGP. Further to the MOU, the project has now moved into a Definitional Phase. This phase is intended to fully establish the commercial viability of the Pipeline and execute certain technical studies, including a detailed Environmental Impact Assessment. In Abuja, Nigeria, on 4th February, 2000, the Countries signed the Inter-Governmental Agreement ("IGA") with the intention of maintaining a uniformity of approach (or "harmonization") to give effect to the undertakings they intend to make to WAPCo through the Concession Agreement. The Countries and the Commercial Group are currently engaged in negotiating the Concession Agreement for the Pipeline. August, 2002 Page 5 West African Preliminary Terms of Reference Gas Pipeline and Scoping Report 1.3 Project Purpose & Need The 1995 HOA recognized that "there exists ample resources of natural gas in Nigeria to satisfy the energy requirements of West Africa (and the Countries of West Africa have stated their strong interest to use natural gas resources of Nigeria to satisfy their energy needs.)" The purpose of the West African Gas Pipeline, therefore, is to transport natural gas from Nigeria to consumers in the countries of Benin, Togo, and Ghana. The benefits to all WAGP stakeholders include the following: 1.3.1 Environment · Reduce Flaring, resulting in lower green house gas emissions · Displacing certain liquid fuels with natural gas, also reducing green house gas emissions. Electrical power producers and industries with the capability to use natural gas are the primary consumers that could immediately benefit from the construction of the pipeline. Other public and private sectors could also use the natural gas provided by WAGP, but this scenario would require separate development of infrastructure, energy policies, etc. 1.3.2 Socio-Economic · More secure energy supply via power generation or direct gas use by industries and others · Enables sustainable development and regional integration · Local and regional technology growth/transfer In compliance with the legislative and regulatory provisions of the affected countries, the project will be subject to an environmental impact assessment. The WAGP EIA will further quantify the benefits described above and will identify additional benefits as appropriate. 1.4 EIA Legal Framework The Commercial Group proposes to carry out the Environmental Impact Assessment of the pipeline project consistent with the following: · Compliance with the laws, regulations, and guidelines of the Republic of Benin, the Republic of Ghana, the Federal Republic of Nigeria, and the Republic of Togo. For Nigeria, this includes, but is not limited to: - Environmental Impact Assessment Decree No.86 of 1992, (Nigeria) - Federal Environmental Protection Agency (now Federal Ministry of Environment) Act, Cap. 131, Laws of the Federal Republic of Nigeria, 1990 as amended. - The Nigeria Department of Petroleum Resources (DPR) Environmental Guidelines & Standards for the Petroleum Industry on Environmental Impact Assessment for Oil and Gas Production Facilities (onshore & offshore); - Oil Pipelines Act, Cap. 338, Laws of the Federal Republic of Nigeria, 1990 August, 2002 Page 6 West African Preliminary Terms of Reference Gas Pipeline and Scoping Report - Oil and Gas Pipelines Regulations, 1995 (Nigeria) - Appropriate State regulations (Lagos State EPA, Ogun State) - The international agreements and conventions to which the Federal Republic of Nigeria is a Party · Commercial Group corporate policies regarding responsible social and ethical behavior, incorporation of safety, health and environmental protection measures and responsiveness to community issues and concerns. · International investment criteria, particularly in terms of socio-economic assessments, transparent and effective stakeholder engagement, appropriately designed environmental management and social reinvestment, and technology transfer/capacity building opportunities. · As appropriate, environmental and socio-economic guidelines, standards, conventions and treaties, established at the local, national and international levels including: - The Nigeria Department of Petroleum Resources (DPR) Environmental Guidelines & Standards for the Petroleum Industry on Environmental Impact Assessment for Oil and Gas Production Facilities (onshore & offshore); - Oil Pipelines Act, Cap. 338, Laws of the Federal Republic of Nigeria, 1990 - Oil and Gas Pipelines Regulations, 1995 (Nigeria) Following this framework and incorporating the best practices and lessons learned from other pipeline projects enhances stakeholder perceptions of the Countries and Commercial Group and reduces the potential for delays due to investor, NGO or community concerns. 1.5 Agency Support and Harmonization As described above, one of the intents of this document is to provide a framework leading to an appropriate regional "harmonization" of EIA expectations, review and timely approval of EIA reports for Benin, Ghana, Nigeria and Togo. The Commercial Group has identified the following "harmonization" opportunities and hopes to work with the Countries on these opportunities following review of this Proposed Terms of Reference/Scoping document. · Collaboration with Environmental and other agencies regarding EIA implementation. See Section 10 below for preliminary proposals for collaboration. · Methodologies of Study and Assessment · Report(s) Format - Dual Language Translation - Balance of Local, Regional and International contexts · Environmental Management Plans August, 2002 Page 7 West African Preliminary Terms of Reference Gas Pipeline and Scoping Report - Impact Avoidance and/or Mitigation - Monitoring - HSE Management Systems · Common Trans-Boundary Issues (i.e. the Gulf of Guinea Marine Environment) · Agency Review 2.0 PROJECT DESCRIPTION The WAGP Commercial Group will supplement the Project Description provided below to include a complete description of the Proposed Alternative, including details regarding siting of facilities, pipeline routing, and the project schedule. The EIA will also document significant project information for construction and pipeline operations including, but not limited to the following: · Raw Material Inputs/Product Output · Storage and emission inventories · Traffic generation · Effluents & Discharges · Noise · Air Emissions and energy use from · Aesthetics construction and operations · Night time operations · Storage/disposal of hazardous goods · Dedicated land use associated with long · Waste and /or byproducts generated term facilities · Spoil materials from dredging 2.1 Scope of EIA The WAGP EIA will focus on the project description and related impacts associated with building the pipeline and operations associated with the transportation of natural gas. Sources of transported natural gas ("Upstream" of WAGP) and end uses of natural gas ("Downstream" of WAGP) will also be described to provide a proper regional context to the WAGP EIA and as an input to an appropriate level of assessment beyond the immediate or isolated impacts of the WAGP project. As discussed in the Impacts Section below, however, since these secondary impacts are outside the immediate scope of the WAGP project, the EIA for the pipeline will only outline these ancillary impacts and provide a framework for future consideration. It is expected that in accordance with the applicable laws in each of the countries those projects will undergo or have already undergone separate detailed impact assessments. The Commercial Group intends to demonstrate by means of the EIA that variations in the volume of transported gas, up to the design capacity of 400 million standard cubic feet per day (MMSCFD- 11.3 million cubic meters per day-MMm3D), will not significantly change the identified impacts associated with the gas pipeline. August, 2002 Page 8 West African Preliminary Terms of Reference Gas Pipeline and Scoping Report 2.2 Natural Gas Sources ("Upstream" of WAGP) The "base case" Project Description for WAGP will detail the facilities and activities associated with a pipeline system designed to transport and deliver up to 400 MMSCFD (11.3 MMm3D) of natural gas. To date the commercial group has identified 250 MMSCFD (7.1 MMm3D) in gas volume available for transport from oil and gas operations in Nigeria. Most of this available natural gas will be "associated gas", i.e. produced with oil from the same source. As associated gas reserves are depleted the delivery requirements will be supplemented with "non-associated" gas. Oil and gas facilities associated with the 150 MMSCFD (7.1 MMm3D) described above are already in place or are anticipated to be installed before the end of WAGP construction. The sources for gas volumes above 150 MMSCFD (4.2 MMm3D) are not specifically known at this time and could involve existing or new oil and gas facilities. 2.3 Natural Gas Consumption ("downstream" of WAGP) As stated above in the Project Summary, electrical power producers and industries with the capability to use natural gas are the primary consumers that could immediately benefit from the construction of the pipeline. Negotiations have started with potential gas transportation customers, and to date the Takoradi Thermal Power Station has signed a letter of intent NGas to purchase natural gas. Additional gas transportation opportunities will be pursued until the gas supply is exhausted "upstream" of the pipeline or when the 400 MMSCFD (11.3 MMm3D) design capacity is reached. When gas demand reaches the 400 MMSCFD (11.3 MMm3D) design capacity, gas delivery volumes are anticipated as follows, based on current market analyses: Outlet Anticipated Delivery Cotonou, Benin 10 MMSCF/d 0.3 MMm3D Lomé, Togo 80 MMSCF/d 2.3 MMm3D Tema, Ghana 230 MMSCF/d 5.3 MMm3D Takoradi, Ghana 120 MMSCF/d 3.4 MMm3D The scope of the WAGP EIA includes gas transportation of up to 400 MMSFD (11.3 MMm3D). Beyond a qualitative, cumulative impact assessment in this EIA, the Commercial Group intends to address any project expansion over 400 MMSFD (11.3 MMm3D) via a supplementary EIA or equivalent mechanism. August, 2002 Page 9 West African Preliminary Terms of Reference Gas Pipeline and Scoping Report 2.4 General Layout & Physical Description The WAGP Commercial Group intends to construct a 12-30 inch (30.5-76.2 cm), 617 km (383 mile), onshore and offshore gas pipeline from Nigeria to Ghana. From the Alagbado "Tee" near Itoki, Nigeria, estimated segment lengths of the proposed pipeline are as follows: Alagbado "T" to Lagos Beach 57 Km 35 mile 30 in (76 cm) pipeline Lagos Beach to Benin Border 50 Km 31 mile 16-22 in (40-56 cm) pipeline Benin Border to Cotonou 44 Km 27 mile " " " " Cotonou to Lome 98 Km 61 mile " " " " Lome to Tema 160 Km 99 mile " " " " Tema to Takoradi 208 Km 129 mile " " " " Total 617Km 383 mile Other tie in points to the ELP system and different Nigeria land routing scenarios are currently under consideration - See Maps ­ Attachments 1 (regional) and 2 (onshore Nigeria). NOTE: The Environmental Impact Assessment will only focus on new construction associated with the West African Gas Pipeline. The existing ELP in Nigeria, "upstream" of WAGP and gas delivery systems "downstream" of WAGP will only be described and referenced in terms of secondary, indirect or cumulative impacts. A gas transmission "compression facility" is anticipated at a to-be-proposed Nigeria beach location with an estimated 140 m by 185 m (460 ft. by 607 ft.) footprint - see Attachment 3. Primary and Back-up Control Centers will also be constructed with similar footprints with final locations to be determined. Offshore Pipeline installation is anticipated to be in 30-100 m (98-328 feet) water depths at an approximate distance of 15 km (9 miles) from shore. Gas delivery points at Cotonou, Lome, Tema, and Takoradi will extend onshore via 12"-20" (30-50 cm) laterals only to the degree necessary to install Regulating and Metering Stations (1-2 km (0.6-1.2 miles) onshore). Estimated footprint for the Regulating and Metering Stations is 68m by 68 m (223 x 223 ft.), although larger 30-100 m (98-328 feet) may be pursued to accommodate future mid-line compression to ensure delivery of the 400 MMSCFD (11.3 MMm3D).­ see Attachment 4. When commercial conditions demand the installation of mid-line compression, more than likely in Lome, a parallel 12"-20" (30-50 cm) lateral pipeline would be installed from the mid-line compressor station. Siting alternatives for gas delivery points are currently being considered. Proposed locations will reflect a balance of community acceptance, safety, environmental sensitivity, access, cost, operational considerations and other issues. Maps and drawings showing site locations currently under review include the following: August, 2002 Page 10 West African Preliminary Terms of Reference Gas Pipeline and Scoping Report Cotonou, Benin Attachment 5 Lomé, Togo Attachment 6 Tema, Ghana Attachment 7 Takoradi, Ghana Attachment 8 Some of these drawings show additional potential infrastructure development in terms of gas distribution system routing. As discussed below under impact analysis, this infrastructure development is considered an indirect impact of WAGP that ultimately will be addressed by project proponents other than the Commercial Group as defined above. If gas demand exceeds the 400 MMSCFD (11.3 MMm3D) "base case design capacity", one or two gas delivery locations may be considered for additional mid-line compression facilities with footprints similar to the Nigeria beach compression facility described above. Specific locations for additional mid-line compression will be examined during Front End Engineering and Design (FEED). Pipeline "looping" where additional parallel pipelines are installed offshore may also be considered for gas demand greater than 400 MMSCFD (11.3 MMm3D). 2.5 Permanent Ancillary Systems & Facilities Gas specifications will be established for delivery of "dry gas" from ELP to WAGP such that liquid hydrocarbon, water, and impurities are minimized during WAGP gas transportation operations. A minimum heating value of the gas will also be included in the gas specification. Gas transported in the ELP itself may have varying characteristics regarding liquid hydrocarbon content, water percentage, etc, depending on who supplies gas to the ELP and the negotiated gas delivery specifications between NGC, WAGP and non-WAGP gas sellers, transporters or buyers. An export terminal, proposed for installation at the ELP connection point is required for custody transfer purposes and to ensure conformance with the WAGP "dry gas" specification. Potential components of the export terminal include: · Gas cleaning/ scrubbing facilities as may be determined during detailed design · Equipment for metering of the gas flow through the station for accounting purposes or custody transfer · Equipment for gas quality measurement to ensure conformance with the "dry gas" specification · Safety and shut down equipment Responsibilities for the export terminal will be established between WAPCo and NNPC/NGC by means of an interconnection agreement, which is currently being negotiated between the parties. Liquid handling and management facilities will also be installed at the Nigeria Beach "compression facility" and gas delivery R&M stations as a contingency for gas production upsets from gas suppliers to WAGP. Other ancillary systems associated with the Pipeline include: August, 2002 Page 11 West African Preliminary Terms of Reference Gas Pipeline and Scoping Report X-likely to be installed, subject to additional design and analysis Ancillary System Nigeria Beach Delivery Point R&M Stations "Compression facility" Control Room/Facilities, X X including SCADA and MAIN FACILITY SCADA BACK UP FACILITY Communications Centre LOCATION TO BE DETERMINED Workshop, Offices, X Sanitary Facilities Gas Filtration, Cleaning, X X Scrubbing Equipment Compressor(s) X Mid Line Compressors Possible Subject to Gas Demand Fuel Gas Supply System X X (for compressors, gas IF GENERATOR IS heaters, Generators, and INSTALLED instrumentation, etc.) Air Compression X X for Instrumentation IF GAS IS NOT USED Gas Coolers X IF MID-LINE COMPRESSORS ARE INSTALLED Gas Heaters X Electrical Systems X X Emergency Shutdown, X X Flare/Vent, Fire & gas detection systems Gas Metering Run X(COULD BE REQUIRED X FOR CONTROL PURPOSES) Gas Quality Measurement X X (as required by trans. agreements) Pressure Regulating Run X X Odorization Optional Laboratory Facilities TO BE DETERMINED TO BE DETERMINED (if appropriate) No effluent discharge systems are anticipated for long term pipeline operations, other than possibly sanitary waste discharge from the Nigeria Beach "compression facility" and possibly metering stations if toilets are provided for personnel. Effluent discharge may occur during pipeline hydro-testing following construction. August, 2002 Page 12 West African Preliminary Terms of Reference Gas Pipeline and Scoping Report The principal components of the R&M station will be installed in two parallel equipment runs to provide 100% operational back-up. These components are described as follows: · Filters to separate coarse particles and condensate droplets. The filter elements are periodically replaced or may be washable. At set liquid levels in the filter vessel, volumes of liquid or condensate are automatically removed to a liquid collection facility. · Line-heaters to compensate for temperature drop caused by the pressure reduction of the gas (Joule Thompson Effect). · Regulating runs to reduce the high gas pressure of the upstream pipeline system to the lower pressure of the distribution line. · Meter runs to measure natural gas volume flow at the R & M station. The meter modules can be orifice, turbine, vortex, ultrasonic or other types. The meter shall be equipped with flow computers and must be approved or certified for custody transfer. · Safety and shutdown protective devices with appropriate backup 2.6 Operational Control and Safety Systems The control system will consist of three tiers: · Primary and backup Supervisory Control and Data Acquisition (SCADA) computers located in the central Dispatch Centre, most likely to be located at the Lagos Beach compressor station. The main function of the SCADA system will be operational interface to support operation of the complete pipeline network. The SCADA system will report pipeline system status to the central Dispatch and Backup Dispatch Centres, showing normal, abnormal or alarm conditions, so operators can monitor and take action if needed. Remote terminal units (RTU) at each field compressor, metering or pigging station to receive and execute commands from the Dispatch and Backup Dispatch Centres. · Communications/control computers also located in the Dispatching and Backup Dispatching Centres for the purpose of communications and issuing control commands and initiating corrective actions. Operators will be able to view the entire system and ensure that the demand for product flow is met and that pipeline operating conditions are safe and optimised. Corrective actions can be initiated, either automatically or with operator over-ride, if necessary. The Backup Dispatch Centre will likely be located at Tema, although final decisions have not been made. · The remote stations will have a degree of local automation and control which will ensure safe and continuous operation of the station independent of whether the operator is present on site and whether he will take the required corrective action. Similarly, the individual stations will be able to operate safely with or without communications from the central Dispatch or Backup Dispatch Centres. · Local control of the facilities from the plant for at least maintenance purposes August, 2002 Page 13 West African Preliminary Terms of Reference Gas Pipeline and Scoping Report The SCADA system will utilise VSAT telecommunications technology for data transmission and voice communications as it provides the lowest total cost of ownership. The system will be designed to serve only the pipeline's telecommunications needs. VSAT facilities will be located at each pressure reduction, metering, and compressor station. Local and international communications system where available will also be utilized as a back up in minimum. 2.7 Project Implementation Description 2.7.1 Engineering The basic physical components of the pipeline include the following: · Steel pipeline materials Fabrication details to be determined during engineering & design. · A thin external coating layer of corrosion resistant material (example ­ fusion bond epoxy) Material application to the pipeline segments is anticipated to occur during fabrication, with details determined during engineering and design. · Application of weight coating to the pipeline (typically concrete based material) The purpose of weight coating is to reduce buoyancy impacts of an offshore pipeline or river/lagoon crossings. Options for weight coating operations will be assessed during engineering and design, including the possibility of local operations during construction. · Compressor stations with Compressors, generators and other equipment · Metering system and stations The technical standards for the engineering, design and construction of the WAGP system are proposed to be based on the ANSI, ASME and API systems. The primary design code of reference will be the ANSI/ ASME B31.8 "Gas Transmission and Distribution Piping Systems" design code. The ANSI/ ASME B31.8 design code is the only general pipeline code that covers both onshore and offshore gas pipeline systems as well as metering and compressor stations. The B31.8 code is a well-established design code and is the predominant code of reference for WAGP installations. The components of the pipeline system will be designed and installed using API, ASME or ANSI design codes that are specific for the component. The major design codes are listed in Appendix 1. Front End Engineering Design (FEED) is scheduled to start following a Preliminary Commercial Evaluation, with a duration of approximately 9-12 months. This design work will be done in a to-be-determined location under the direction of Commercial Group personnel knowledgeable in project execution and gas pipeline technology. In this phase of the engineering, the design will be progressed through the development of August, 2002 Page 14 West African Preliminary Terms of Reference Gas Pipeline and Scoping Report · Process designs · Piping and Instrumentation Diagrams (P& ID's) · System safety systems designs · Project equipment specifications as described above · Preliminary Drawings · Design Reports · Other key Project documentation It is during this phase that the Commercial Group will proactively solicit stakeholder input and evaluate Best Available Technology (BAT) for incorporation into the designs, to ensure that the project minimizes health, safety and environmental (HSE) impacts. Several detailed reviews will commence during the engineering phase including: Conceptual & Early FEED Stage Late FEED and Detailed Design Stage · Concept Safety Evaluation Studies · PFD, P&ID, SAFE Chart Reviews · Qualitative Risk Assessment Review · Detailed HAZOPS, SAFOPS, IPF · Process Flow Diagram (PFD) Reviews Classification and/or HAZAN Reviews · Piping & Instrumentation Diagram (P&ID) · Quantitative Risk Assessment Reviews Review/Study · High Level HAZOP Review · Equipment Layout · High Level HAZID Review · Hazardous Area Classification · Project Specifications Review · Fire/Explosion Study · Project Safety Case/HSE Review · Fire Protection Analysis · Escape/Evacuation/Rescue Studies · Safety Review/Criticality Ranking of Major Equipment · Project Specification and Material Selection Review · Fabrication inspection at an offsite location During these and other reviews, it is anticipated that representatives from EIA and Permit/License Approval agencies in each of the countries will participate to provide relevant input and guidance on regulatory compliance issues and prudent protective measures. Development of the detailed information to support the EIA process will be a critical engineering and FEED activity to ensure timely EIA approval before the start of construction. An iterative process of stakeholder input, design adjustment, impact analysis and follow-up stakeholder consultations will be used to develop a detailed HSE plan during engineering and FEED and ultimately incorporated into the EIA Environmental Management Plan. A smooth transition will be made from FEED into detailed engineering while ensuring continuity is maintained. Detailed drawings, construction specifications, and the bulk of the procurement August, 2002 Page 15 West African Preliminary Terms of Reference Gas Pipeline and Scoping Report will be completed. Certain reviews (such as HAZOPS), which commenced during the preliminary and front end engineering phases, will be completed during this phase as the vendor engineering information is received at the project's office. 2.7.2 Other Pre Construction Activities In addition to design activities, the WAGP Commercial Group will conduct the following activities, integrated with the Environmental Impact Assessment processes and deliverables: · Routing and Siting Surveys Onshore surveys will be conducted to determine ELP tie-in, pipeline routing, Nigeria Beach "Compression facility" and R&M location options in Benin, Togo and Ghana. Offshore surveys will also be conducted to determine appropriate marine routing of the pipeline. Relatively non-invasive survey techniques will be utilized, although soil and seabed coring operations are anticipated for geo-technical evaluation in both the onshore and offshore environments. Limited vegetative clearing may also be required in conjunction w/ onshore surveying operations. The commercial group intends to coordinate External Affairs, Engineering and EIA consulting resources in implementing the surveys, to ensure that all issues and impacts associated with routing and siting are comprehensively and consistently identified. An appropriately scoped HSE Management plan will be prepared prior to routing and survey work to minimize the impacts of these activities. · Estate Surveying and identification of real estate titles This activity will determine land tenure aspects of the project for the Nigerian onshore portion of the project and gas delivery points in Benin, Togo and Ghana. This determination will include assessments of land ownership and other existing rights associated with potential routing or siting options for the pipeline and facilities. · Land and Right of Way Acquisition Based on the estate surveying work, the Commercial Group will negotiate the acquisition of permanent land rights (for facilities such as the compressor and R & M stations) and rights of way (for the length of pipeline itself). Other temporary and permanent estate acquisitions (camps, staging areas, roads, etc.) will also be pursued either directly by the Commercial Group or through contractors or other 3rd parties, with appropriate compensation guidelines established. The Commercial Group has been advised that legal ownership and control of the offshore area which the pipeline will traverse is vested in each of the countries on the national government. Accordingly the Commercial Group expects that negotiations for rights of August, 2002 Page 16 West African Preliminary Terms of Reference Gas Pipeline and Scoping Report way over these offshore areas will be held with the governments concerned. Compensation for acquisition of permanent land rights and rights of way will be fair and in accordance with local and international best practice and the Commercial group will liaise closely with appropriate government, community and traditional leaders during negotiations to acquire land or rights of way. The Commercial Group does not anticipate significant, if any resettlement, associated with the construction of the pipeline. Resettlement plans will be developed, however, if necessary and included in the EIA submittal. The Commercial Group also recognizes that initial land and right of way target areas may not be suitable at the time of construction and that alternative routes should be considered as a contingency. Proposed and alternative sites and routes will be pursued in a manner consistent with the description above and all agreements will include terms and conditions such as "...acquisition contingent on EIA approval, Permit issuance,..." etc. · Material Procurement, Staging and Transportation The pipeline itself, along with compressors, vessels, meter runs and pressure regulating equipment will be fabricated at an offsite fabrication yard. The locations of the fabrication yard(s) and staging areas have not been determined at this time. · Additional safety and operational reviews with EIA and Permitting agencies including - Critical Safety Equipment & Quality Assurance Inspection and Testing - Functional Testing of Corrosion & Fire Protection Equipment · Other activities like logistical planning, contracting for construction, cost minimization Studies and other EIA support activities. 2.7.3 Construction The project description for the WAGP EIA will focus on the following construction activities and tasks, projected to occur over a 2-year period, associated with civil, mechanical and electrical engineering implementation. · Onshore site clearance and preparation, including construction camps, access roads, river/lagoon crossings, the pipeline right-of-way, and ancillary facility sites (Nigeria Beach "Compression facility", R&M Stations in Benin, Togo and Ghana) · Temporary construction support operations including local camps for onshore construction personnel, staging areas for both onshore and offshore operations, transportation, and possibly weight coating operations · Pipeline trenching, particularly onshore and for near shore gas delivery laterals. Offshore trenching or directional drilling requirements, if any, to be determined during engineering and design. August, 2002 Page 17 West African Preliminary Terms of Reference Gas Pipeline and Scoping Report · Pipeline placement/stringing, cleaning and welding · Pipeline inspection and testing · Pipeline burial particularly onshore and for near shore gas delivery laterals. · Ancillary facility and equipment installation (R&M Stations and the Nigeria Beach "Compression facility") · Onshore soil management and right-of-way reinstatement All construction activities will be executed in accordance with a project specific HSE plan that will attempt to reduce impacts to the local community and environment. The details of this plan will be developed during FEED and continuously updated based on consultations with non- government stakeholders, EIA approval agencies, pipeline permitting/licensing agencies and local governments/communities. 2.7.4 Training, Commissioning, and Start-up Hiring of commissioning/start-up contractors and pipeline operations personnel will commence during the latter stages of construction. An extensive training program will be conducted following personnel hiring. All training will be completed in time to support the commissioning and start-up schedule. The extent of personnel and other needs for commissioning and start up will be determined during FEED. EIA and Permitting Agency reviews and participation is expected to continue during this stage including: · Project Workshops · Training for Pre Commissioning and Commissioning · Joint Safety Inspections · Pre-Start Up Safety Audit · Review of specific operating permit requirements Commissioning will begin upon mechanical completion and `pre-commissioning' of the pipeline facilities. The pipeline will be cleaned, hydrotested, de-watered, dried through loading with air, inert gas or other non-flammable material. Compressors and other equipment will be lubricated, calibrated and tested as well as all control and telecommunications including the VSAT systems. Commissioning ends and start-up will begin when the pipeline is ready for introduction of hydrocarbons. 2.7.5 Pipeline Operations The pipeline operations component of the EIA Project Description will focus particularly on activities and facilities associated with health and safety of both the workers and nearby communities. Specific physical descriptions will include: · Ancillary Equipment, particularly monitoring and control systems. August, 2002 Page 18 West African Preliminary Terms of Reference Gas Pipeline and Scoping Report · Emergency shut down systems · Fire prevention, detection, and suppression · Corrosion control systems including cathodic protection and "pigging" operations · Support systems such as access roads, waste management (sanitary, non-hazardous and hazardous), and as appropriate, use of hazardous materials, including the nature, transportation, storage, intended use, treatment, and final disposition. 2.7.6 Decommissioning and Abandonment As described in the Concession Agreement, the Commercial Group intends to decommission and abandon the Pipeline consistent with prevailing accepted industry practices. Plans for facility decommissioning, abandonment and facility/ROW reinstatement will also be described in this section of the EIA. This section of the EIA will also address decommissioning of temporary construction facilities including staging, weight coating, camps. 3.0 PROJECT ALTERNATIVES SUMMARY The WAGP EIA will contain two alternatives sections - an overall Project Alternatives Summary and a Detailed Alternatives Analysis (see below). In the Project Alternatives Summary, the No- Project Alternative will be explicitly assessed, drawing from the 1999 Feasibility Study and other sources. The Project Alternatives Summary will also address regional pipeline routing alternatives (example ­ all offshore, all onshore, etc.) and technological alternatives to a gas pipeline (example ­ gas to liquids technology, Compressed Natural gas (CNG) and Liquefied Natural Gas (LNG), etc.). The Project Alternatives Summary section will also review alternatives associated with significant impacts associated with the Proposed Alternative. In summarizing Project level alternatives, discussion will be focussed on the following: · Best Available/ Practicable Technologies · Feasibility · Regional health, safety, environmental and/or socio-economic benefits · Local and regional suitability, including stakeholder acceptance · Institutional requirements · Costs (capital and operating) Other more specific alternative scenarios will be provided in the Detailed Alternatives Analysis section as described below: 4.0 STAKEHOLDER CONSULTATIONS The legislative provisions of the various countries emphasize the participation of the parties having a stake in the environmental impact assessment. As described throughout this document, August, 2002 Page 19 West African Preliminary Terms of Reference Gas Pipeline and Scoping Report informal meetings, focus group discussions and public forums will be continuously utilized in the preparation of the EIA to: · Inform and educate stakeholders on all aspects of the project, including the Proposed Alternative and other alternatives considered · Gather relevant information and data · understand critical stakeholder issues and concerns · Make appropriate adjustments to design, construction, operational and environmental management plans · Communicate design, construction , operational and environmental management plan adjustments · elicit support for the project Geographic and social linking of issues will be part of the public involvement mechanisms that will allow WAPCo to concurrently manage project impacts locally and regionally across the four countries. These consultations shall include local and/or indigenous communities and businesses as well as regional, national and international non-governmental organizations and entities that may be significantly impacted by the construction or operation of the Pipeline. The Commercial Group shall document the consultations and transmit a summary of these consultations as part of the EIA Report documentation. As a means to facilitate stakeholder consultations, a WAGP External Affairs Plan will identify and assist in managing community concerns and impacts associated with every aspect of the project. It seeks to respond to the organizational, economic, socio-cultural, technical, health, safety, environmental, political as well as international aspects of the project. This plan will be dynamic and will be localized for each of the four countries. It will also reflect the concerns and interests of the international community and will be regularly evaluated and amended to suit the dynamic nature of the project and its setting. Specific components of the External Affairs Plan as it relates to the EIA study include the following: · Workshop for Public Affairs Staff of Relevant Government and Regulatory bodies · Seminars for regulatory agencies, customs, immigration related government agencies to facilitate corridor surveys · Forums for traditional authorities and communities at large · Seminars for local authorities · Workshops for community education staffs · NGO's and Environmental journalist seminars · Seminars for registered fishing groups, companies, consultants, individuals and organizations involved in research in the fishing industry · Seminars for academia · Durbar for chief fishermen and the associated communities · Mass education in all fishing communities · Orientations for project contractors August, 2002 Page 20 West African Preliminary Terms of Reference Gas Pipeline and Scoping Report · Pipeline route tours Key issues that have already been identified and incorporated into the External Affairs Plan include: · Limited scientific and socio-economic baseline data on project communities · Community expectations · Peoples attitude towards, perception of, and knowledge about project · Socio-cultural intrusion in terms of physical contact with WAGP personnel, pressure to conform to different standards, and changes to cultural values · Cultural sensitivities · Environmental concerns Sensitive marine ecosystems Sensitive areas of bio-diversity · Health and Safety concerns for communities and workers · EIA requirements, timing and credibility · Land tenure and appropriate compensation for project impacts · Consultation/capacity building · Historical performance and perceptions of the Commercial Group · Fishing concerns · Respect for traditional authorities · Interference with economic activity · Security and safety of navigation (accidents) · Impact of project personnel and/or contractors · The need for independent monitoring 5.0 EXISTING SITUATION 5.1 Existing Health Situation Studies to determine the existing health situation along the pipeline route will be conducted with particular emphasis on areas of poor health or sanitary conditions. Through our contracting processes and negotiations with contractors, the Commercial Group will also consider opportunities to establish health baselines and "fitness for duty" criteria for workers in the region. Studies will also focus on health services options in the region such that immediate care can be provided to those suffering health impacts from project activities. The Commercial Group recognizes that illness and disease could be an impact from project activities, particularly during construction. Baseline health considerations that are already under review include: · Illness and disease inherent to the region (example malaria) · Illness and disease associated with sanitary conditions (example dysentery) August, 2002 Page 21 West African Preliminary Terms of Reference Gas Pipeline and Scoping Report · Socially transmitted disease such as AIDS, venereal disease etc. due to the interactions of workers and the communities. 5.2 Existing Safety Situation The routing and siting survey work will provide baseline information in terms of geographic and site-specific safety issues. Project Security issues will also be identified in terms of the potential for community unrest, civil disobedience, theft, robbery, etc. Worker Safety issues will also be assessed and managed by the Commercial Group through the development of a specific Project Safety Management Plan (PSMP). The PSMP will be a stand alone plan developed under the umbrella of an HSE Management System. The specific PSMP will incorporate existing policies and procedures of the Commercial Group. Key elements of the PSMP will include: · Management Leadership & Commitment · HSE Objectives · Safety Contracting Processes - Assessment of Contractor Safety Performance and Programs - Job Safety Analysis - Safety Orientation & Training - Integration of Contractors' Safety Management Plan into PSMP · HSE Roles and Responsibilities · Policy Development - Stop Work for Safety Policy - Alcohol & Substance Abuse Policies - Fitness for Duty Policies · Consistent Procedures & Practices - Emergency Response Plan - Community Awareness/Outreach Plan - Incident Investigation & Reporting - Field Safety Audits - Medical Treatment Procedures Existing community safety issues will also be assessed including knowledge of construction, natural gas and pipeline operations. The capability of the communities to manage safety related events effectively will also be reviewed. As discussed above, design standards and engineering best practices will be employed in the development of WAGP, and the Country's safety review and permitting processes will ensure that the communities are adequately protected. August, 2002 Page 22 West African Preliminary Terms of Reference Gas Pipeline and Scoping Report 5.3 Description of the Environmental Status (Existing Environment and Resources) The status of the environment and of its various components prior to the project will be set forth, where various sensitive points and constraints will identified and addressed. Appendix 2 provides a matrix of project locations and focus areas of the environmental baseline studies including: Biological Environment Physical Environment · Flora/Fauna · Land/Physical Characteristics · Areas of Ecological interest, including · Water Quality and surface water rare or endangered species, sensitive hydrology habitats · Air shed characteristics · commercially important species and · Land Capabilities and usage fishing zones · Potential Environmental Contaminants · Oceanographic Parameters · Rural & Regional Infrastructure along the pipeline route · Climatic and Weather Conditions This matrix attempts to particularly identify areas of higher impact due to pipeline construction or operations. Environmental baseline studies will also identify, as much as possible, any existing environmental contamination. The Commercial Group intends to compile and analyze baseline data generally through literature review and empirical field analyses, using Geographic Information Systems (GIS) as a means to manage and communicate data. Appropriate literature research and field studies will be done for the Proposed Alternative and other scenarios, particularly in terms routing and siting of the pipeline and related facilities. The Commercial Group will rely on stakeholder consultations, academic efforts and public information (for example prior EIA efforts) in the literature review. Appendix 3 is a list of marine and near shore reference materials already collected for the WAGP EIA. Prior to field data collection, the Commercial Group will consult with the Ministries and Agencies of the four countries on the fundamental study approach including sampling/analysis methodologies, data quality expectations, etc. The Commercial Group recognizes that wet and dry season investigations are appropriate to establish environmental baseline conditions. The initial draft EIA documents will include baseline results from the initial season of investigation. Information from the second season of investigation will be included in a subsequent EIA submittal or as a monitoring component of an approved Environmental Management Plan, following input received from the Countries. August, 2002 Page 23 West African Preliminary Terms of Reference Gas Pipeline and Scoping Report The Commercial Group intends to use the information associated with the existing environmental situation in a number of ways including: · identifying potential areas of high impact due to pipeline construction or operations, as described above · as material for WAGP personnel training and for stakeholder education and reference during construction and operations · as inputs to qualitative and quantitative risk assessments (example air dispersion modeling, potential receptors from catastrophic gas releases or fire hazards, etc.) 5.4 Existing Socio-Economic Aspects The Commercial Group recognizes that socio-economic studies of existing conditions are critical to gaining public acceptance of the WAGP Project and minimizing project impacts and disruptions to communities and other stakeholders. Also, as described in the EIA Legal Framework section above, funding from international investors requires submission of socio- economic studies, appropriate compensation and mitigation plans and social reinvestment objectives in addition to environmental impact assessments. The Commercial Group intends to satisfy these requirements through the following efforts: · Stakeholder Consultations as described above · Knowledge, Attitudes, Acceptance and Perception (KAAP) studies · Existing Socio-Economic Characteristics of the areas impacted by the project · The current Local, National and Regional Economic Situation as it relates to WAGP The KAAP study will be conducted in Ghana, Togo, Benin and Nigeria to help in the implementation of the Pipeline Project. Specifically, the study will ascertain how much people in the region know about the project, what it intends to do and its impact on human livelihood. Given the knowledge of the people about the uses of gas and how it will be transported and distributed in the Project, the study will determine the attitudes and perceptions of people towards the project. The study will involve focus group discussions of the population, and the administration of a questionnaire through an in depth interview of a sample of people. One common questionnaire and survey guidelines will be designed and used in all 4 countries. A sample of individuals will be identified in communities along the proposed gas pipeline and those outside the pipeline. The study will be conducted by knowledgeable resource persons based in each country. Other socio-economic studies will focus on population density, infrastructure and life pattern studies for the land components of the pipeline. This data will be compiled with existing and potential employment opportunities, permanent and temporary housing situations and the social interactions of impacted communities to understand how the project might impact local communities and stakeholders. Similar studies will be conducted for fishing communities along the offshore route and near the gas delivery points in Benin, Togo and Ghana. August, 2002 Page 24 West African Preliminary Terms of Reference Gas Pipeline and Scoping Report The existing cultural setting of project areas will be appropriately assessed in terms of architecture, cultural events, native/tribal lands, villages, schools, hospitals, homes for the aged, country parks, agricultural areas, fishing camps, hunting reserves, and areas of archaeological, paleological and religious significance. Another significant area of interest to indigenous people and communities will be any real or perceived impacts to water usage including domestic, industrial, recreational, transportation, agricultural, and fisheries. As stated above, one of the primary socio-economic benefits of WAGP is the facilitation of regional economic integration and growth through the delivery of a reliable, cost-competitive, and cleaner burning energy source. Baseline socio-economic assessments will be conducted to quantify this expected benefit, including: · Existing economic activities i.e. local industries, cottage industries, etc. · Local business that could provide services to the project · Potential industries that could be developed and the possible constraints in developing these industries · Potential employment opportunities to be generated by the project and the possible constraints in developing these opportunities? · Public expectations in terms of technology transfer, capacity building or social reinvestment? · "Compensation" expectations of the communities · What types of mechanisms would the communities like to see in terms of direct benefit, compensation, etc. · Tax income to the states, direct and indirect · People's perceptions of energy pricing, infrastructure situation, etc. · People's perceptions of Government Energy Policies and Growth Policies · Current Fuel Usage · Perceptions of how reliable energy sources will impact growth, policies, etc. · Perceptions of changing from wood based fuels to electricity and/or natural gas? · Growth projections in terms of GDP and other indicators · Other possible multiplier effects of the project in terms of local and regional economic development and cumulative impacts including possible constraints 6.0 IMPACT ASSESSMENT Generally, the EIA will address impacts in a comprehensive manner, determining whether the impacts are considered: Positive/beneficial or Negative/adverse, Primary/direct or Secondary/indirect, Short Term or Long Term, Reversible or Irreversible. August, 2002 Page 25 West African Preliminary Terms of Reference Gas Pipeline and Scoping Report The impacts assessment will incorporate an appropriate level of assessment beyond the immediate or isolated impacts of the WAGP project to put the project in the context of regional development and regional impacts. These impacts will be combined with the project impacts above to determine the cumulative impacts related to the WAGP Project. As an example, natural gas production from Nigeria and gas consumption in Benin, Togo and Ghana are potential areas of assessment ancillary to the West African Gas Pipeline. However, since these impacts are outside the immediate scope of the WAGP project, the EIA for the pipeline will only outline these ancillary impacts. It is expected that in accordance with the applicable laws in each of the countries those projects will undergo or have already undergone separate detailed impact assessments. More specifically, and in the context of the existing health, safety and environmental and socio- economic aspects of the project, the impact assessment will identify significant impacts associated with: · Future land usage; · Health and safety impacts to both local · Impacts to existing features; communities and WAGP personnel · Historic land use; · Conditions and processes in the natural · Ways of life; environment; · Energy supply/demand; · Significant air quality and standards · Local, National and Regional violations; Economic Benefit Assessments · Ground and surface water quality/ quantity · WAGP Social Reinvestment changes; opportunities as appropriate for · Water uses; community and regional impacts · Encroachment issues (wetlands, coastal · Significant noise zones, fish habitat, wildlife habitat, wild and · Populations scenic rivers, areas of biodiversity) · Changes associated with imported pests, disease vectors, fish migration routes, and fish nursery areas. Screening criteria, including probability, magnitude, prevalence, risks, importance, and effectiveness of mitigation measures, will be used to assess the significance of project impacts. This screening will cover all activity phases of the project including site investigation/ preparation, construction, construction support, transportation, raw materials supply, operations and maintenance, future and related activities, and ultimately decommissioning of the facility. Expected areas of impact include the physical, chemical, biological, aesthetic, and socio- economic aspects of WAGP in addition to understanding the relationships between activities and areas. Methodology and approach are critical to developing impact assessments that are comprehensive and credible to stakeholders. As discussed above, specific measurable indicators of impact August, 2002 Page 26 West African Preliminary Terms of Reference Gas Pipeline and Scoping Report probability, magnitude and significance will be developed. In developing these indicators, the project will provide stakeholders a context and framework that includes the extent and quality of available data and sources of information, along with the assumptions, uncertainties and degrees of confidence associated with both explicit and risk based assessments. Appendix 4A and 4B outline the potential positive and negative aspects of the West African Gas Pipeline project in terms of health, safety, environmental and socio-economic impacts. As described above, the Commercial Group intends to quantify the probability and severity of these and other identified impacts during the course of the EIA. 7.0 MITIGATING AND AMELIORATING MEASURES This section of the EIA will focus on enhancing the positive impacts of the project and avoiding, reducing or mitigating negative impacts of WAGP. Potential benefit enhancement opportunities include: X-Potential Application to WAGP Mitigation Measure Pre- Construction Construction Operations Decommissioning Additional commercial commitments to transport natural gas, further X reducing green house gas emissions Technology transfer X X X and/or capacity building Social reinvestment X X X Potential avoidance or mitigation measures could include: X-Potential Application to WAGP Mitigation Measure Pre- Construction Construction Operations Decommissioning Project location/siting X X Design adjustments and/or X X new technology application Early warning and X X emergency shut down controls Construction adjustments X X Schedule adjustments X X August, 2002 Page 27 West African Preliminary Terms of Reference Gas Pipeline and Scoping Report Mitigation Measure Pre- Construction Construction Operations Decommissioning Environmental and socio- X X X economic education and orientation Notices and/or barriers X X X placed at strategic locations along the onshore pipeline route warning the public Notifications to local and X international cartographic, survey and marine authorities to update and publish nautical charts and topographic maps. For residual or X X unavoidable impacts, rehabilitation of impaired features or some type of offsite compensation or enhancement of similar resources. Erosion and sediment X X X X control Vegetation control X X HSE Management X X X Systems including · Compliance Assurance · Safe Operations · Pollution Prevention · Emergency Preparedness and Response In developing mitigation measures and the subsequent Environmental Management Plan, the Commercial Group recognizes that certain adjustments to mitigation measures may be needed due to · changes from baseline assessments · new information · ineffectiveness of mitigation measures As appropriate, and in consultation with the Countries and other stakeholders, the Commercial Group will modify proposed mitigation measures and other elements of the Environmental Management Plan. August, 2002 Page 28 West African Preliminary Terms of Reference Gas Pipeline and Scoping Report Appendix 5 provides a more detailed list of mitigation measures that the Commercial Group will consider in conducting the EIA and in developing it's project execution plans. 8.0 DETAILED ALTERNATIVES ANALYSIS The Detailed Alternatives Analysis section of the EIA will provide a bridge between the project impacts and the proposed mitigation measures and ultimately the Environmental Management Plan. It will be more specific in nature including explicit and risk based assessments of: · Best Available/ Practicable Technologies · Feasibility · Associated health/safety, environmental and/or socio-economic benefits · Monitoring requirements · Local and regional suitability, including stakeholder acceptance · Institutional requirements · Training requirements · Costs (capital and operating) Specific alternative scenarios will include: · Site Selection and Routing · Design Considerations · Raw material sources · Project Implementation including site preparation, construction, construction support, personnel and material requirements, and commissioning/start-up · Pipeline Operations · Mitigation measures to avoid project impacts and measures associated with residual or unavoidable impacts Continuous stakeholder consultations will provide a critical input to the alternatives analysis, in terms of idea/scenario generation and acceptance of the Proposed Alternative. 9.0 ENVIRONMENTAL MANAGEMENT PLAN CONSIDERATIONS The Environmental Management Plan (EMP) will be developed and used as a tool in the construction and operation of WAGP to minimize and mitigate significant negative impacts from the project. Components of the Environmental Management Plan include monitoring, documentation, evaluation, prediction, warning, prevention, control and reduction of impacts identified in the EIA. The Environmental Management Plan shall also include activities intended to enhance the positive environmental, safety and socio-economic aspects of the Pipeline. August, 2002 Page 29 West African Preliminary Terms of Reference Gas Pipeline and Scoping Report The Environmental Management Plan shall provide a means to ensure that legal air and water standards are complied with and that proper waste minimization and waste management processes are implemented. Ecological mitigation measures shall be included in the Environmental Management Plan addressing impacts to vegetation, wildlife, marine ecosystems and bio-diversity. The Environmental Management Plan will provide a means to assess the effectiveness of these mitigation measures. Socio-economic mitigation measures will be identified in the Environmental Management Plan to reduce negative impacts to communities and to enhance the positive benefits of the project to the communities, the States and the region. Particularly for surveillance and monitoring, specific measurement parameters will be recommended, including measurement methods, locations, frequency and action thresholds. Appropriate thresholds will include those that forewarn or immediately warn of unfavorable project impacts, but that also trigger project execution controls to eliminate or minimize the level of impact or that lead to governmental reporting/ enforcement. The following specific components will be included in the EMP. · Evolution of the erosion phenomena and reestablishment of natural drainage before and after pipeline layout and burial · Restoration of vegetal cover and productivity of agricultural zones put back in exploitation after the work · Efficiency of actions taken to preserve sensitive areas · Follow-up of impact on marine biodiversity and fishing and maritime transportation activities · ROW Surveilance and other monitoring along the pipeline, particularly for any socio- economic encroachment · Notices at strategic locations along the pipeline (warnings, safety, etc.) · Other appropriate mitigation measures as identified in Section 7 and Appendix 5. 9.1 Waste Management The general waste management philosophy adopted by the project to handle wastes can be summarized as; · Utilize processes that inherently generate less waste streams · Modify process as required to minimize waste quantities generated from source · Maximize recycle or re-use of waste streams after appropriate treatment · Utilize safe storage and handling procedures for hazardous waste streams · Effective monitoring and control of disposal units, with early warning systems · Inventory control, audit and post project evaluation of regulatory trend to ensure continued compliance August, 2002 Page 30 West African Preliminary Terms of Reference Gas Pipeline and Scoping Report 9.2 Air Emissions During the front end engineering phase of the WAGP project, all air emissions, major & minor, resulting from continuous, intermittent or upset conditions of any of the pipeline equipment will be characterized. Each stream will be evaluated to ensure that there are no components which violate 'Air pollutant emission limits' standards. 9.3 Emergency Prevention, Preparedness and Response The Commercial Group intends to develop an Emergency Preparedness and Response Plan for inclusion in the WAGP EIA and in line with permit requirements for each of the countries. The following steps are anticipated in the development of this plan; · Assessment of hazards and risks of an unplanned incident to both the communities and WAGP personnel; · Plan Development for managing those hazards and risks; · Communication of relevant information to employees, contractors, appropriate agencies and the public; · Barriers etc. to minimize exposure · Conducting emergency response exercises independently and in co-ordination with community support organisations; · Responding immediately and appropriately to incidents, providing the necessary financial, technical and personnel resources to effectively respond. 9.4 Energy and Resource Conservation The Commercial group will, to the extent possible, conserve and protect natural resources. As most of the negative impacts are likely to occur during construction, the Commercial Group will pay particular attention to ecological, water, and other natural resource issues during routing, siting and execution planning. Water resources are the most likely resource that could be affected during pipeline operations. This EIA and the development of a natural resources inventory will identify those natural resources most at risk. This EIA and subsequent monitoring and analyses during the construction and operational phase will be used to continuously identify potential pathways of exposure and potential or actual receptors affected by releases and emissions. Pathways may include air dispersion and contamination of surface water or groundwater. Receptors can be local communities and sensitive ecological habitats. The Commercial Group will also a natural resource damage assessment plan in the unlikely event of an unplanned, negative event, so that the response and post-incident mitigation is timely and effective. For unavoidable adverse impacts, the Commercial Group will develop and August, 2002 Page 31 West African Preliminary Terms of Reference Gas Pipeline and Scoping Report implement certain mitigation measures e.g., personnel training, activity scheduling, and reclamation. 9.5 HSE Management Systems As discussed above in Mitigation Measures, HSE Management Systems will be established for WAGP construction and operations, including, but not limited to the following aspects: · Compliance Assurance · Safe Operations · Pollution Prevention · Prevention of gas leaks and subsequent environmental impact · Emergency Preparedness/Response In support of these and other components, the Commercial Group will establish policies, objectives, procedures, monitoring/reporting processes and responsibilities, in addition to providing the necessary resources (funding, people) for implementation. Additional details will be provided in the submitted EMP, including a schedule of implementation as the Project scope, associated impacts and proposed mitigation measure are better defined. 10.0 PROPOSED TERMS OF REFERENCE In accordance with the legal and technical directives of the Countries, the Commercial Group commits to the following regarding Environmental Impact Assessment requirements: 10.1 Project Submission 10.1.1 Project Registration/Application This document is included in the EIA registration/application as a means to describe the project for the purposes of agency screening and to: Indicate the preliminary environmental, health and safety impacts of the project; Indicate a clear commitment, to the extent possible, to avoid adverse environmental, health and safety impacts during implementation of the project; Indicate a clear commitment, to the extent possible, to address unavoidable environmental, health and safety impacts and steps where necessary for their reduction; and Provide a summary of alternatives that will be considered in the EIA Report or Impact Statement submittal. August, 2002 Page 32 West African Preliminary Terms of Reference Gas Pipeline and Scoping Report 10.1.2 Registration/Application Fees and EIA Agency Resource Requests Consistent with each country's EIA process, the Commercial Group, as part of the application process, includes the appropriate application fees in the registration documents. Within a reasonable time frame following EIA registration/application, the EIA Agencies will formally advise the Commercial Group of estimated fees and charges necessary for Agency oversight and review of WAGP EIA documents. The Commercial Group requests in this EIA application/registration that appropriate EIA agency resources be identified and dedicated to the Commercial Group to: Ensure compliance with each country's EIA requirements. Without sacrificing transparency or independence, ensure appropriate efficiency and comprehensiveness in the implementation of baseline studies, impact assessments, stakeholder consultations, agency review and agency decisions regarding approval of EIA submittals. 10.1.3 EIA Report Focus Areas (draft terms of reference) In submitting the EIA application/registration documents, the Commercial Group commits that subsequent environmental impact assessments, statements or reports will appropriately address the following A description of the project An analysis of the need for the undertaking Alternatives to the project including the "no project" alternative Matters on site selection including rationales for the choice of the proposed site and alternative site considerations An identification of existing, relevant health, safety and environmental conditions including social, economic and other aspects of potential concerns Information on potential, positive and negative impacts of the project from the environmental, social, economic and cultural aspects in relation to the different phases of development of the project The potential impact on the health of project personnel and the surrounding communities Proposals to mitigate potential negative socio-economic, cultural and public health impacts of the project August, 2002 Page 33 West African Preliminary Terms of Reference Gas Pipeline and Scoping Report Proposals to be developed to monitor predictable environmental impact and proposed mitigation measures Contingency plans (existing or to be evolved) to address any unpredicted negative health, environmental or safety effect Consultation with members of the public likely to be affected by WAGP operations Maps, plans, tables graphs, diagrams and other illustrative material that will assist with comprehension of environmental impact assessment documents A provisional environmental management plan Appropriate details regarding the payment of compensation for possible damage to land or property arising from WAGP Indications of potential regional, national, or international impacts It is intended that this proposed Terms of Reference/Scoping document provides the detail necessary to demonstrate the commitment of the Commercial Group to submit EIA documents containing the areas of emphasis listed above. 10.1.4 Project Presentations As needed following project registration/application, the Commercial Group will provide summary presentations to appropriate agencies and approval authorities in each country. These presentations will introduce the project, include a summary of this Terms of Reference/Scoping document, and provide information regarding Project personnel and consultant experience in natural gas, pipeline operations and EIA preparation. 10.2 EIA Implementation and Document Preparation 10.2.1 Stakeholder Consultations Immediately following EIA registration, the Commercial Group commits to a Stakeholder Consultation and Engagement process consistent with Section 4 of this document. 10.2.2 WAGP/Agency Interaction and Collaboration As appropriate, and without sacrificing the transparency or independence of the EIA agencies or EIA consultants, WAGP and it's EIA consultants will interface and collaborate with the government agencies having EIA approval authority and other appropriate agencies in each August, 2002 Page 34 West African Preliminary Terms of Reference Gas Pipeline and Scoping Report country. Some interface and collaboration is expected to occur at a regional level (i.e. involving all 4 countries) to ensure harmonization and consistency across the 4 countries associated with WAGP. At other times, it will be more appropriate to interface at a National, State or local level. Areas of interface identified to date include: Work Plans for Environmental and Socio-economic baseline surveys Adjustments and evolution of the Stakeholder Consultation Plan Stakeholder Consultation participation by the Commercial Group, the Countries or both Results of Stakeholder Consultations Progress reports on the preparation of EIA documents Preliminary discussion of mitigation measures and environmental management plans (particularly in terms of trans-boundary issues) Health and Safety Design reviews with other agencies and competent authorities, as outlined in Section 2.7.1 (Engineering Activities). 10.2.3 Continuing EIA Support and Processing Fees Consistent with the legal requirements in each country, the to-be-developed Concession Agreement, and as identified following EIA registration/application, the Commercial Group commits to timely payment of appropriate EIA support and processing fees and other costs that could include one or more of the following: Skills Reinforcement Workshops, Capacity Building and/or Technology Transfer EIA Agency Monitoring And Assisting The Promoter In The Field "Public Information and Sensitization" (i.e. Stakeholder Consultations) Regional Environmental & Permitting Group Meetings Regional EIA Report Review Workshops 10.3 EIA Document Submissions and Agency Review 10.3.1 EIA Document Content and Structure Consistent with the legal requirements in each country, the Commercial Group commits to submittal of the following EIA documents and supporting information: Benin Environmental Evaluation Dossier (Environmental Impact Studies) Ghana Environmental Impact Statement for the purposes of receiving a Environmental Permit. Nigeria EIA Report leading to an Environmental Impact Statement and Certification (FMEnv) EIA Report (DPR) Togo Environmental Evaluation Dossier (Environmental Impact Studies) August, 2002 Page 35 West African Preliminary Terms of Reference Gas Pipeline and Scoping Report The Commercial Group intends for these EIA documents to be concise and be confined to the most important environmental problems. The main text will focus on results, conclusions and recommendations with the support of tables summarizing the collected data and of the appropriate references. Detailed and un-interpreted data will be presented in the appendices or in a separate volume. The reports will be written in French and English and will be structured/formatted as follows: Title Page including Project Title, Promoter's Name, Author(s) of study, Competent Authority for the project, Authority to which the study is addressed, and Date Summary Table of Contents List of Tables, Figures, and Attachments, including a Table of Acronyms and Abbreviations EIA Preparers Acknowledgements Executive Summary Introduction, including the Project Proposal and Project Justification The Body of Report including 1. Project context and description 2. Description of receptor environments 3. Description and analysis of project alternatives 4. Impact analysis of selected alternative from all standpoints (environment, natural resources, social, economic, health, safety, etc.) Proposed Mitigation Measures Technological Risks & Contingency Plan Environmental Management Plan Conclusions Bibliography and other references Attachments and Appendices This Terms of Reference/Scoping Document provides additional details on the intended EIA report contents, following the structure/format above. All information the Commercial Group considers confidential shall be presented in a separate report. The requisite number of copies of the complete study, both in electronic format and hard copy, will be provided to each country. 10.3.2 Public Notification, Display, and Review Consistent with each country's laws and regulations, the Commercial Group will adhere to the public notice, display and review procedures with particular attention paid to: Appropriate and timely advertisements and notices to interested parties either directly or through appropriate media (newspaper, radio, town hall etc.). August, 2002 Page 36 West African Preliminary Terms of Reference Gas Pipeline and Scoping Report Provisions made for additional copies of the EIA documents The required durations of notices and display Commercial Group participation at public forums following notification and display periods. 10.3.3 Continuing EIA Support, Review Processing and Approval Fees Consistent with the legal requirements in each country, the to-be-developed Concession Agreement, and as identified following EIA registration/application, the Commercial Group commits to timely payment of appropriate EIA support and processing fees and other costs that could include one or more of the following: Continuing Skills Reinforcement Workshops, Capacity Building and/or Technology Transfer (particularly for Report Review Commissions, Panels, etc.) Administration Of Panel Review, Report Display, and Public Hearing Advertisement "Commission Study Evaluation Workshop", "Public Hearing" or "Public Meeting" Expenses for the purposes of information or debate. Appropriate "Media Coverage: Radio, Press, and Television Logistics arrangements for certain (appropriate?) attendees at Public Hearing Appropriate expenses associated with review, report validation and decision making by "Public Hearing Commissions", In-house Agency personnel or equivalent bodies. Administrative Charges, Processing and Permit Fees (for Clearance/Approval) Environmental Certification Fees (in Ghana, see 10.4 below) Appropriate Environmental Management Plan Monitoring Expenses (see 10.4 below) 10.4 Post EIA Approval After the EIA is approved, and consistent with the legal requirements in each country, and/or as established through the to-be-developed WAGP Concession Agreement, the Commercial Group intends to pursue the following with the continued support and input from the Countries EIA agencies and other Country government representatives: Obtain other authorities, licenses or approvals to Construct and Operate WAGP Implement the Environmental Management Plan in terms of pre-construction resource commitments (personnel, HSE funding, etc.) Begin pre-construction and construction activities. Implement the Environmental Management Plan as approved by the Countries. As detailed in the approved Environmental Management Plan, monitor HSE and socio- economic impacts and adjust the Environmental Management Plan accordingly. August, 2002 Page 37 West African Gas Pipeline EIA Preliminary Scoping Report Appendix 1 Agreed Design Standards OFFSHORE PIPELINE CODES AND SPECIFICATIONS Governing design code ANSI/ASME B31.8 ­ 2000 Edition (or latest) "Gas Transmission and Distribution Piping Systems". Supplemental recommended practices API RP 1111 ­ 1999 Edition (or latest) "Design, Construction, Operation, and Maintenance of Offshore Hydrocarbon Pipelines". API RP 14C ­ 6th edition (or latest) "Recommended Practice for Analysis, Design, Installation and Testing of Basic Surface Safety Systems for Offshore Production Platforms". DNV Offshore Standard OS-F101 "Submarine Pipeline Systems" January 2000 Edition (or latest). Major offshore pipeline component specifications as referenced in B31.8 Line Pipe Specification ­ API 5L ­ 42nd Edition (or latest) "Specification for Line Pipe". Welding Specification ­ API 1104 ­ 1999 Edition (or latest) "Standard for Welding Pipelines and Related Facilities". Corrosion Protection ­ NACE RP0675 (latest edition) "Control of External Corrosion on Offshore Steel Pipelines". Pipeline Valves ­ API 6D ­ 21st Edition (or latest) "Specification for Pipeline Valves". Pipeline Flanges ­ ASME B16.5 ­ 1996 Edition (or latest) "Pipe Flanges and Flanged Fittings NPS 1/2 Through NPS 24". Pipeline Fittings ­ ASME B16.9 ­ 2001 Edition (or latest) "Factory-Made Wrought Butt- welding Fittings". ONSHORE PIPELINE CODES AND SPECIFICATIONS Governing design code ANSI/ASME B31.8 ­ 2000 Edition (or latest) "Gas Transmission and Distribution Piping Systems". Major onshore pipeline component specifications as referenced in ANSI/ASME B31.8 Line Pipe Specification ­ API 5L ­ 42nd Edition (or latest) "Specification for Line Pipe". Welding Specification ­ API 1104 ­ 1999 Edition (or latest) "Standard for Welding Pipelines and Related Facilities". Corrosion Protection ­ NACE RP0169 (latest edition) "Control of External Corrosion on Underground or Submerged Steel Pipelines". West African Gas Pipeline Page 1- 1 August, 2002 West African Gas Pipeline EIA Preliminary Scoping Report Appendix 1 Agreed Design Standards Pipeline Valves ­ API 6D ­ 21st Edition (or latest) "Specification for Pipeline Valves". Pipeline Flanges ­ ASME B16.5 ­ 1996 Edition (or latest) "Pipe Flanges and Flanged Fittings NPS 1/2 Through NPS 24". Pipeline Fittings ­ ASME B16.9 ­ 2001 Edition (or latest) "Factory-Made Wrought Butt- welding Fittings". ONSHORE COMPRESSOR STATION CODES AND SPECIFICATIONS Governing design code ANSI/ASME B31.8 ­ 2000 Edition (or latest) "Gas Transmission and Distribution Piping Systems". Major compressor station component specifications as referenced in ANSI/ASME B31.8 Piping Materials -ASTM materials in accordance with B31.8. Welding Specification ­ In accordance with ASME Section IX requirements as provided in ANSI B 31.8. Pipeline Valves ­ API 6D ­ 21st Edition (or latest) "Specification for Pipeline Valves". Pipeline Flanges ­ ASME B16.5 ­ 1996 Edition (or latest) "Pipe Flanges and Flanged Fittings NPS 1/2 Through NPS 24". Pipeline Fittings ­ ASME B16.9 ­ 2001 Edition (or latest) "Factory-Made Wrought Butt- welding Fittings". Other component codes or specification for compressor station Electrical Code ­ British Standards, CENELEC, IEC, ISO, NEMA. Instrument Code ­ ISA, API RP 551, IEC, NEMA. Fire Protection Code ­ NFPA. Compressor Code ­ API Standard 617 ­ 1995 Edition (or latest) "Centrifugal Compressors for Petroleum, Chemical, and Gas Service Industries". Power turbines ­ API 616. Gas Measurement Code ­ API MPMS 14.3 - 1995 Edition (or latest) "Manual of Petroleum Measurement Standards Chapter 14 ­ latest edition "Natural Gas Fluids Measurement Section 3 - Concentric, Square-Edged Orifice Meters Part 1 - General Equations and Uncertainty Guidelines" or ISO 5167. Pressure Vessel Code ­ ASME Sec VIII D1 ­ 1998 Edition (or latest) "BPVC SECTION VIII Rules for Construction of Pressure Vessels DIVISION 1". West African Gas Pipeline Page 1- 2 August, 2002 West African Gas Pipeline EIA Preliminary Scoping Report Appendix 1 Agreed Design Standards ONSHORE REGULATION AND METERING STATIONS AND TERMINALS CODES AND SPECIFICATIONS Governing design code ANSI/ASME B31.8 ­ 2000 Edition (or latest) "Gas Transmission and Distribution Piping Systems". Major R&M station component specifications as referenced in ANSI/ASME B31.8 Materials : ASTM/API in line with the requirements of ANSI B31.8. Welding Specification ­ API 1104 ­ 1999 Edition (or latest) "Standard for Welding Pipelines and Related Facilities". Pipeline Valves ­ API 6D ­ 21st Edition (or latest) "Specification for Pipeline Valves". Pipeline Flanges ­ ASME B16.5 ­ 1996 Edition (or latest) "Pipe Flanges and Flanged Fittings NPS 1/2 Through NPS 24". Pipeline Fittings ­ ASME B16.9 ­ 2001 Edition (or latest) "Factory-Made Wrought Butt- welding Fittings". Other component codes or specification for R&M stations Electrical Code ­ British Standards (BS), CENELEC, IEC, ISO, NEMA. Instrument Code ­ ISA, API RP 551, IEC, NEMA. Fire Protection Code ­ NFPA. Gas Measurement Code ­ API MPMS 14.3 - 1995 Edition (or latest) "Manual of Petroleum Measurement Standards Chapter 14 ­ latest edition "Natural Gas Fluids Measurement Section 3 - Concentric, Square-Edged Orifice Meters Part 1 - General Equations and Uncertainty Guidelines" or ISO 5167. Pressure Vessel Code ­ ASME Sec VIII D1 ­ 1998 Edition (or latest) "BPVC SECTION VIII Rules for Construction of Pressure Vessels DIV1". OTHER MISCELLANEOUS FACILITIES Buildings Local Building codes in each country shall be applicable. Civil works British Standards, EN, ISO. OTHER DESIGN REQUIREMENTS DNV will be used as a supplement in areas of deficiency of ANSI B31.8 with emphasis on stability calculations and its verifications. West African Gas Pipeline Page 1- 3 August, 2002 West African Gas Pipeline EIA Preliminary Scoping Report Appendix 1 Agreed Design Standards Anodes shall be utilised to ensure maintenance design life for the offshore pipeline of between 40 and 50 years. Pig traps will be provided for internal intelligent pigging inspection, including on spur lines. The WAGP Regulations shall provide for the use of intelligent pigging and remotely operated vehicles for inspection, at periods to be agreed which shall not adversely affect Project economics. A maintenance philosophy and emergency management plan shall be established in accordance with this Agreement, covering maintenance and emergency response and repair procedures. The Company shall maintain stocks of spare parts and training of staff consistent with the agreed maintenance philosophy and plan. To the extent practicable and as agreed to between the Company and the WAGP Authority, maintenance standards as contained in the design standards above will be followed. West African Gas Pipeline Page 1- 4 August, 2002 APPENDIX 2 FOCUS AREAS FOR ENVIRONMENTAL BASELINE ASSESSMENT Nigeria Offshore Cotonou Lome Tema Takoradi Effasu Environmental Data Onshore Marine Environment Gas Delivery Point Gas Delivery Point Gas Delivery Point Gas Delivery Point Gas Delivery Point Land/Physical Characteristics. Climate/Meteorological Factors XX X X X X X X Terrain XXX XXX X X XX XX X Geo surface materials XX XX X X X X X Relief/topographic characteristics XXX XXX X X X X X Environmental Contaminants XX XX XX X X Land Capabilities Agriculture XXX X X X X Forestry XX X XX Wildlife XXX X XX XXX Fisheries XXX XXX XXX XXX XXX XXX Significant Geographic Areas. XX XX XX XX XX XX XX Environmental Field Data Airsheds XX X XX XX XX XX XX Overall Air Quality Assessments XX XX XX XX XX XX Noise Level Assessments XXX XX XX X X Water Quantity/Quality Assessments Hydrology XX XX XX XX XX XX Ground Water Studies XX Stream/Lagoon Characteristics XXX XX XX XX XX XX Watershed Characteristics XXX X X X X X Oceanographic Parameters XXX XX XX XX XX XX (Geomorphology, Waves & Currents) Flora/Fauna Types/distribution XXX XX Vegetative Cover Characteristics XXX XX X X XX XX XXX Soil Studies XX XXX XX XX XX XX XX Biological Descriptions via Maps Ecological Zones XX XX X X XX XXX XXX Sensitive Areas XX Unique Ecosystems XX XXX XX XX XXX Areas of ecological interest XX XXX XX XX XXX Areas of scientific interest XX XXX XX XX XXX Areas of High Economic Concern XX X XX XX XX XX X Aquatic Studies Hydrobiology X XXX XX XX XX XX XX (plankton, benthic fauna, etc.) Fisheries X XXX XXX XXX XXX XXX XXX Freshwater & Marine Wildlife X XXX XXX XXX XXX XXX XXX X-Limited description necessary XX- Routine description anticipated to appropriately describe the existing situation, including potential for secondary impacts XXX- Detailed description needed due to an anticipated higher level of impact WEST AFRICAN GAS PIPELINE Page 2-1 August, 2002 APPENDIX 2 FOCUS AREAS FOR ENVIRONMENTAL BASELINE ASSESSMENT WEST AFRICAN GAS PIPELINE August, 2002 APPENDIX 3 CURRENT EIA REFERENCE MATERIALS 1. Perspectives in Integrated Coastal Areas Management in the Gulf of Guinea (UNIDO Large Marine Ecosystem Project for the Gulf of Guinea) 2. Nearshore Dynamics and Sedimentology of the Gulf of Guinea (UNIDO Large Marine Ecosystem Project for the Gulf of Guinea) 3. State of the Coastal and Marine Environment of the Gulf of Guinea (UNIDO Large Marine Ecosystem Project for the Gulf of Guinea) 4. Towards Integrated Coastal Zone Management in the Gulf of Guinea A Framework Document 5. Coastal Profile of Nigeria (UNIDO Large Marine Ecosystem Project for the Gulf of Guinea) 6. Profil de la zone cotiere du Benin (UNIDO Grand Ecosysteme Marin de Golfe de Guinee) 7. Cote D'Ivoire Profil environmental de la zone cotiere (UNIDO Grand Ecosysteme Marin de Golfe de Guinee) 8. Profil Environmental du Littoral du Togo (UNIDO Grand Ecosysteme Marin de Golfe de Guinee) 9. Zonation of Ghanaian Fishing Grounds 10. Coastal Zone Profile of Ghana 11. Towards an integrated Coastal Zone Management Strategy for Ghana (Ghana EPA and World Bank) 12. The Coastal Zone of West Africa: Problems and Management 13. African Perspectives on the Clean Development Mechanism 14. An Overview of the Environmental Impact of the Shrimp and Prawn Industry in Ghana 15. Draft Report of the Wetland Typology Working Group West African Gas Pipeline Page3-1 March, 2003 APPENDIX 4A PRELIMINARY IMPACT SUMMARY - POTENTIALLY POSITIVE IMPACTS X- probability and severity to be determined Environmental Impact Location Pre-Construction Construction* Operations Decommissioning Reduced greenhouse gas emissions from Nigerian Regional X oilfield flaring Reduced greenhouse gas emissions from the use of natural gas as an alternative energy source in Benin, Togo and Ghana Potential for reduced deforestation/desertification Socio-Economic Impacts National and Regional industrial or economic Regional X benefits facilitated by the delivery of reliable, competitively priced, cleaner burning fuel WAGP social reinvestment opportunities including Regional X X X technology transfer and capacity building Stakeholder reactions to perceptions and actual Regional X X X X performance of the Commercial Group Proposed compensation schemes Nigeria Onshore X X and Gas Delivery Points Temporary employment opportunities All X X *Pre-Construction and Construction Impacts includes support activities such as camps for onshore construction personnel, staging areas for both onshore and offshore operations, land and marine transportation, and possibly weight coating operations APPENDIX 4B PRELIMINARY IMPACT SUMMARY - POTENTIALLY NEGATIVE IMPACTS X- probability and severity to be determined Health and Safety Impacts Location Pre-Construction Construction* Operations Decommissioning Transfer of disease and illness due to Onshore Pipeline X X Limited X · initial health conditions of workers and local Route communities · interactions between project personnel and Nigeria Beach the communities Compression · sanitary conditions of work, housing and feeding locations Gas Delivery · R&M Locations Injuries due to construction equipment selection All above plus X X X and/or operation Marine Injuries or illness due to the use of hazardous All above plus X X X materials Marine Injuries or Illness due to improper waste management All above plus X X X (sanitary, non-hazardous or hazardous wastes) Marine Environmental Impacts Location Pre-Construction Construction* Operations Decommissioning Cumulative impacts to areas of ecological concern due Regional X to regional economic growth. Examples include the Gulf of Guinea Marine Ecosystem and areas of high biodiversity between Effasu and Takoradi. Changes to historical/traditional land usage Nigeria Onshore and X X X X Gas Delivery Points Vegetative clearing Nigeria Onshore and Camps X Gas Delivery Points Access roads Weight Coating Right of Way And Facility Site Preparation Loss of habitat and related impacts to flora and fauna Nigeria Onshore and X X X from vegetative clearing Gas Delivery Points *Pre-Construction and Construction Impacts includes support activities such as camps for onshore construction personnel, staging areas for both onshore and offshore operations, land and marine transportation, and possibly weight coating operations APPENDIX 4B PRELIMINARY IMPACT SUMMARY - POTENTIALLY NEGATIVE IMPACTS X- probability and severity to be determined Environmental Impacts Location Pre-Construction Construction* Operations Decommissioning Erosion associated with vegetative clearing, pipeline Nigeria Onshore and X X Limited Limited trenching/backfilling and right of way reinstatement Gas Delivery Points Material handling impacts from vegetative clearing Nigeria Onshore and X X and excess soil excavation Gas Delivery Points River, stream or lagoon crossings or dredge/fill Nigeria Onshore and X X activities possibly the Benin (erosion, water quality impacts in terms of pollution Gas Delivery Points and/or disruptions to water supply, etc.) Coastal and wetland ecological issues Nigeria Beach X X X "Compression facility" and R&M Stations Coastal stability issues Nigeria Beach X X "Compression facility" and R&M Stations Temporary (short duration) impacts from traffic, Nigeria Onshore X X X noise, and waste generation management and Gas Delivery Points Temporary air emissions from equipment and All X X activities including dust and other air pollutants such as SOX, NOX, and particulates Intermittent air pollutant emissions Nigeria Onshore X and Gas Delivery Points Fires Nigeria Onshore Limited Limited X Limited and Gas Delivery Points *Pre-Construction and Construction Impacts includes support activities such as camps for onshore construction personnel, staging areas for both onshore and offshore operations, land and marine transportation, and possibly weight coating operations APPENDIX 4B PRELIMINARY IMPACT SUMMARY - POTENTIALLY NEGATIVE IMPACTS X- probability and severity to be determined Environmental Impacts Location Pre-Construction Construction* Operations Decommissioning Commercial Group approach to existing land Nigeria Onshore X X contamination and Gas Delivery Points Temporary impacts to fisheries, aquatic Offshore Route ­ Limited X vegetation/wildlife and benthic fauna from survey and Main Pipeline and construction activities Laterals Temporary impacts from marine traffic, noise, and Offshore Route ­ Limited X waste generation management Main Pipeline and Laterals Pipeline stability impacts associated with Offshore Route ­ X X oceanographic parameters such as geomorphology, Main Pipeline and currents and waves. Laterals Water column impacts from pipeline disruptions and Offshore Route ­ X natural gas releases Main Pipeline and Laterals Effluent discharge from pipeline hydrotesting Offshore Route ­ X operations Main Pipeline and Laterals Socio-Economic Impacts Location Pre-Construction Construction* Operations Decommissioning Stakeholder reactions to perceptions and actual Regional X X X X performance of the Commercial Group Physical changes to communities along the Nigeria Onshore and X X X pipeline route, including aesthetics Gas Delivery Points Changes to historical/traditional land usage Proposed compensation schemes Nigeria Onshore and X X Gas Delivery Points *Pre-Construction and Construction Impacts includes support activities such as camps for onshore construction personnel, staging areas for both onshore and offshore operations, land and marine transportation, and possibly weight coating operations APPENDIX 4B PRELIMINARY IMPACT SUMMARY - POTENTIALLY NEGATIVE IMPACTS X- probability and severity to be determined Socio-Economic Impacts Location Pre-Construction Construction* Operations Decommissioning River, stream or lagoon crossings or Nigeria Onshore and X X dredge/fill activities possibly Benin gas (erosion, water quality impacts in terms of delivery point pollution and/or disruptions to water supply, etc.) Temporary (short duration) impacts from Nigeria Onshore and X X traffic, noise, and waste generation Gas Delivery Points management Physical/social interactions between WAGP All X X Limited personnel and local communities Community health and safety impacts due to Nigeria Onshore and X operational disruptions or natural gas releases Gas Delivery Points Fires resulting from disruptions to pipeline operations Nigeria Onshore and X or natural gas releases Gas Delivery Points Impacts to local and commercial fishing Offshore Route ­ X X Limited Main Pipeline and Laterals *Pre-Construction and Construction Impacts includes support activities such as camps for onshore construction personnel, staging areas for both onshore and offshore operations, land and marine transportation, and possibly weight coating operations APPENDIX 5 DETAILED LIST-POTENTIAL MITIGATION MEASURES · As agreed between the Countries and WAGP, observe protective perimeters around the following sensitive zones, and avoid and/or reinstate deforestation or the elimination of vegetation cover, including: - Shorelines, - Known wildlife habitats, - Water supply basins, - Steep and erosion-sensitive gradients, - Wet areas, · Conserve and reuse topsoil during the burial of the pipe, · Establish a work calendar in keeping with those periods of time that are sensitive to wildlife elements, · Plan to allow for considerable flexibility in the means of crossing sensitive habitats (e.g., waterways, wet areas) or protected habitats (e.g., the habitat of a rare plant species), · Reduce to a minimum the length of the work in sensitive areas, · Control access to work sites, · Use adequate road signs on the routes leading to the work sites, · Establish adequate personnel training procedures with regard to the protection of the environment, · Limit the expropriation of right-of-ways, fragmentation of properties, agricultural and forestry areas, · Coordinate the work with other land users, · Encourage the employment of the local workforce, · At the end of the work, clean and return the elements of the environment that were affected to their original condition. Use species indigenous and suitably adapted to the host environment, · Compensate for major residual impacts, · Formulate an emergency action plan in coordination with the interested authorities in the event of an accidental spill during the construction and operational phases. Specific Measures Protection of the quality of surface waters · Control traffic in order to avoid leaks and spills of hazardous materials (hydrocarbons, etc.), . Conserve vegetation near waterways and wet areas, · Measures to be taken in the event of the accidental contamination of the ground, air, and water, · Avoid moving machinery near potable water connections. A security perimeter should be established and identified on the sites by marking them or by closing them in by whatever means necessary, · When necessary to cross waterways: - Implement all necessary measures (wire fences, nets, protective paneling, etc.) to avoid having construction materials, wastes, or wood residues fall into waterways, - Place filtration berms and sediment barriers in the ditches that drain the work sites, . Cross perpendicularly where the embankments are stable and the waterways are narrow, . Use methods that minimize perturbations to aquatic environments and wet areas, . Show preference for existing structures or plan for the installation of culverts whose bearing capacity is sufficient for the machinery being used, · At the end of the work, remove all temporary installations used to cross waterways. Reestablish, if necessary, the normal flow of the waterways and restore the original bed and banks, · Take all necessary precautions during the refueling of transport vehicles and machinery at the work site to avoid accidental spills. Prohibit the refueling of machinery near waterways. Protection of the water table · Properly seal wells and bore holes prior to abandonment, · Use appropriate drilling practices. Modification of the flow of surface water · Schedule intervention periods in areas subject to flooding or in which there is the likelihood of heavy runoffs at times other than the high water season or heavy rains, · avoid blocking the drainage of surface water and provide for the means of restoration, · Restrict to a minimum vehicular traffic beyond the right of way in order to avoid the creation of ruts, and consequently, runoff, · Be mindful of surface drainage at all times. West African Gas Pipeline Page5-1 August, 2002 APPENDIX 5 DETAILED LIST-POTENTIAL MITIGATION MEASURES · Avoid blocking waterways, trenches, or any other channel. · Remove any debris that blocks the normal flow of surface water, · Provide accommodations for vehicular traffic anytime there is a risk of compaction or alteration of wet areas. Soil erosion and destabilization · Mechanically stabilize the soil in order to reduce the potential of erosion, · Avoid excavation and burial in steeply sloped ground and avoid creating grade breaks, · Provide for the placement of siltation ponds in areas subject to heavy erosion, · Obtain the necessary authorizations for work in wet areas, · Provide for the rehabilitation of the site after the work, · Limit activities in erodible soils. Select vehicles suited to the nature of the soil, · Avoid the creation of access ways along the axis of long, continuous descending grades in favor of a perpendicular or diagonal orientation, · At the completion of the work, level the disturbed soil and quickly undertake the sodding and planting of trees or brushes in order to control soil erosion. Modification of the soil characteristics · Scarify as needed damaged sites, regrade the sites, then replace the layer of topsoil that was previously put to the side during construction work, · Provide accommodations for vehicular traffic anytime there is a risk of compaction or alteration of the surface. · Restore the operational site by restoring the original profile of the topography and the soil, · Strictly regulate heavy machinery traffic. Restrict the number of traffic lanes and limit the movement of the machinery to the work sites and to marked access ways, · Maintain transportation vehicles and machinery in good working order so as to avoid oil and fuel leaks and all other pollutants. Changes to air quality and noise exposure · Near inhabited areas, avoid heavy truck traffic and carrying out loud work outside of normal working hours, · Maintain transportation vehicles and machinery in good working order in order to minimize gaseous emissions and noise, · Use dust-control liquids and dust-recovery machinery. Destruction or modification of the vegetation cover · Clearly define the cut zones in order to limit the deforestation thereto, · Protect trees from the machinery on the edge of the right-of-ways, · Restore the vegetation at end of the work, · Avoid the deforestation and the destruction of bordering vegetation, · During cutting operations, provide for wood stacking areas beyond wet areas, · Prohibit the digging of trenches within a meter of a tree. Destruction or modification of wildlife habitats · Obtain special authorization to perform work within wildlife or ecological preserves, · No work will be done in breeding grounds during breeding seasons. Schedule work and set the calendar of activities taking into account the use the wildlife makes of the land, · Protect known productive habitats, wet areas and spawning beds, · Avoid restricting the movement of fish by paying attention to the size of culverts, the speed of the flow of water, and the water level at the point of minimum flow. Perturbation to customs and traditions · Provide for a work schedule that will avoid disturbing the traditional life of communities, · Establish a communication program to inform communities of on-going work and establish appropriate measures to minimize the disturbance caused by the work. Population displacement · Reach an agreement with communities with regard to the ways and means of resettlement and respect those commitments, West African Gas Pipeline Page5-2 August, 2002 APPENDIX 5 DETAILED LIST-POTENTIAL MITIGATION MEASURES · Negotiate, if necessary, for the acquisition of land or the right of passage and provide for the adequate compensation, · Guarantee access to private property and the safety of residents and passersby during the course of the work by enacting the appropriate measures (fencing, guards, etc.). Service interruptions during the work · During service interruptions, notify the concerned jurisdictions and take the appropriate measures to keep interruptions to a minimum for the residents of the affected area. Disturbances caused by construction or maintenance work · Minimize the accumulation of waste produced by the use of construction materials, · Insure the appropriate management of chemical products used in the placement of pipe (handling, storage, installation, disposal, etc.), · Avoid the storage of machinery in areas other than those identified as essential to the work. Provide for a clear definition of the boundaries of said areas, · Avoid the accumulation of all types of wastes on and off the work site; remove the wastes to waste disposal sites provided for that purpose. Damages caused to roads, risks of accidents, and traffic caused in connection with construction work · Avoid blocking public access, · Use road signs to notify work in progress, · Comply with road bearing capacity and repair damage caused to roads at the end of the work, · Circumvent gathering places. Public safety and management of hazardous materials · Heighten the safety of workers and of the surrounding communities by establishing safety and emergency action plans, · Insure that all employees adhere to the safety program, · Provide for the establishment of emergency plans and action plans in the event of an accidental spill of contaminants or of a gas leak. Post in a location visible to the workers a poster showing the names and telephone numbers of the people in charge and describing the alert protocol, · Keep on hand a supply of absorbent materials as well as properly designated recipients designed to contain petroleum residue and wastes in the event of a spill, · Inform the drivers and operators of machines of the security standards to be followed at all times, · When action is necessary to remove or contain pollutants or contaminated substances, solid or liquid, the site selection and the disposal method must observe applicable standards, · Provide for storage areas for contaminated products and equip them with devices designed to protect against any accidental spills. Modification of a known historical site or building · Obtain the necessary authorizations prior to the execution of the work. Disruption of known or potential cultural or archeological sites · Prior to the commencement of the work, undertake archeological assessments in identified potential sites and encourage the appropriate analysis and reclamation of archeological artifacts, or avoid these sites altogether. · Complete the gathering of inventory data by means of mapping and photographic surveys, · During the work, scrutinize the work site for artifacts of archeological importance, and in the event of any discovery, suspend all activities and notify the competent authorities, · In order to prevent theft or vandalism, refrain from letting the general public know the exact location of archeological or exceptional sites, · Identify or protect culturally or religiously significant sites. Visual changes to known historical sites and monuments · Provide for facilities that are in harmony with the historical heritage, Optimize the placement and the architecture of facilities in such a way as to integrate them into the landscaping. West African Gas Pipeline Page5-3 August, 2002 APPENDIX 5 DETAILED LIST-POTENTIAL MITIGATION MEASURES Location of facilities · In urban area, seek out those sites that present characteristics that are compatible with the facilities to be built, · Set a premium on the use of small-footprint facilities to minimize the loss of space, · Demonstrate a preference for areas where the facilities will be less visible, · Select sites located near the edge of a property or at the far end of a street block, · Install as necessary noise barriers in order to lessen the acoustic impact. Impeding road traffic and community activities · Adjust work schedules so as not to disturb traffic. Establish an adequate system of road signs and detours. · Notify communities of pending work: scope, duration and location, · In urban areas, clean the streets used by trucks and machinery so as to keep them clean and clear. Disruption of farming activities · Prior to the start of work, check with farmers regarding the use that they intended for their land, · Perform the work in such a fashion as to harm as little as possible existing farming practices (duration, timing, magnitude), · Keep to a minimum areas in which farming will be impossible during and after the work and compensate for losses, · Maintain at all times access to isolated areas, · Enter the right of way by the use of existing routes or move about at the edge of cultivated land and coordinate the creation of access roads in cooperation with farmers, · Place the facilities, to whatever degree possible, at the edge of lots or cultivated land or distribute them in such a way as to occupy as little as possible cultivated land, · Loosen soil compacted by machinery and put disturbed production areas back into production. Disruption to forestry activities · Notify the owners of the occupied land of work duration, · Provide for coordination mechanisms with the competent authorities for the disposal of merchantable timber harvested from private lands or with private owners for the recovery of firewood. Disruption of tourist activities · Avoid encumbering tourist and recreation areas or take the necessary measures to insure access and safe use during and after the work, · Devise arrangements that insure compatibility between tourist and recreative activities and the operation of the gas pipeline. West African Gas Pipeline Page5-4 August, 2002 Appendix 1-B Nigeria Applicable Local and International Regulations West African Gas Pipeline Applicable Local and International Regulations This section deals with local and international regulations as they apply to the WAGP project. Local Regulations This section looks at the various local regulations and laws that apply to oil and gas development projects, with most emphasis on gas pipeline projects. NIGER-DELTA DEVELOPMENT COMMISSION (ESTABLISHMENT ETC) ACT NO. 6, 2000 OBJECTIVE: To provide for the repeal of the oil mineral producing Areas commission Decree 1998, and among other things, establish a new commission with a re-organized management and administrative structure for more effectiveness; and for the use of the sums received from the allocation of the federation account for tackling ecological problems which rise from the exploration of oil minerals in the Niger-Delta Area, and for connected purposes. HIGHLIGHTS OF ENVIRONMENTALLY RELATED PROVISONS Established the Niger-Delta Development Commission (NDDC) and charged it among other functions, with the responsibility to tackle ecological and environmental problems that arise form the exploration of oil mineral in the Niger-Delta area and advise the federal Government and member state on the prevention and control of oil spillages, gas flaring and environmental pollution, as well as liaise with the various oil mineral and gas prospecting and producing companies on all matters of pollution prevention and control. (Section 1.7(1) Empowers the Board to make rules and regulations for carrying out the functions of the commission. ­ (Section 8(b)). Set up various directorates in the head office, including the Directorate of Environmental protection and control ­ (Section 9(1)(d)). Repeals the OMPADEC Decree No 41 of 1998, and dissolves the commission, but vests on the NDDC all assets, funds resources and other movable and immovable property which immediately before the commencement of this Act were vested in the dissolved commissions -(Section 28(1)(2)). The funds of the commission are to be derived from the contribution of the federal Government of an amount equivalent of 15 percent of statutory Allocations due to member states from the federation Account 3 percent of the total annual budget of any oil producing company operating on-shore and off-shore in the Niger Delta Area including Gas processing companies; 50 per cent of the monies due to member states from the Ecological fund etc. 1 Member states of the NDDC and the chairmanship among them are: Abia, Akwa-Ibom, Bayelsa, Cross-River, Delta, Edo, Imo, Ondo and Rivers States. LAGOS URBAN AND REGIONAL PLANNING BOARD AND TOWN PLANNING AUTHORITY EDICT OF 1997 This edict is basically meant to provide for the control of urban and regional planning activities in Lagos State. The Board, by the edict, is empowered to perform among others, the following functions: i. Formulate state policies for urban and regional planning and the physical development of the state, including spatial location of infrastructural facilities. ii. Advise state government and initiate actions towards establishment of local planning authorities in the state. iii. The initiation of and preparation of: a. Regional and sub-regional plans for the state; b. Master plans for each of the divisions in the state; c. Urban master plans for major urban centres; d. District plans; e. Outline development plans f. Other physical development plans and schemes embracing spatial distribution of major roads, location of industrial, commercial, residential as well as recreational facilities. iv. The formulation and adoption of programmes for the co-ordination and progressive preparation and review of master plans as and when due; v. Publication in the gazette of the dates hen draft master plans will commence; vi. The scrutiny and amendment of draft master plans and their adoption for exhibition to the public; vii. Receipts of comments to draft master plans and hearing of objectors or their authorised representatives; viii. Determination of objections and directing amendments to be made to draft master plans thereto on the basis of the objections where it considers the amendments to be in the public interest; ix. Submission of draft master plan together with schedule of objections made and with or without amendments to the Chief Executive of the State for approval. x. The establishment and operation of an effective development control organ on state lands including control of out door advertisement. 2 xi. Ensuring that full and comprehensive record are kept of the plans and schedule of all applications for development permit and those which are conditionally approved or disapproved; xii. The conduct of research in urban and regional planning; xiii. The provision of technical assistance to the local government; xiv. The preparation and submission of annual progress report on the operation of the National Physical Plan to the National Urban and Regional Planning Commission; xv. The consultation and co-ordination with the federal government and local governments in the preparation of physical development plans; xvi. The acceptance and review of the annual report on the implementation of the National Physical and Regional Development Plans submitted to it by the local planning authorities; xvii. The review of such plans listed under sub-section (c) of this section; xviii. The supervision of the activities of local planning authorities in the state. According to the edict, local planning authorities are expected to be established in each local government area, and these authorities are expected to: i. Be responsible for preparing town, rural, local and subject plans subject to the approval of the Board ii. Prepare and submit to the Board an annual report on the implementation of the National Physical Development Plan and State Regional Plan. iii. Undertake development control within its area of jurisdiction. The Board, among other functions, is expected to take inventory of all objections to any proposed development plan, review such objections based on merit and make decisions on the validity or otherwise of such objections. The edict also stipulates that "a developer shall at the time of submitting his application for development, submit a detailed environmental impact assessment report in respect of applications for: i. A residential land in excess of half an hectare and/or development in excess of 4 floors or 8 family units. ii. Factory building or expansion of factory building iii. Office or other commercial buildings iv. Places of worship v. Major recreation development covering more than 2000 square meters vi. Institutional buildings vii. Petrol filling/service stations viii. Any other building(s) as specified in the buildings regulations made pursuant to the edict." 3 The authority is also empowered to make orders stopping a development, including a "stop-work" order. However, the edict provides that reasonable time limit must be given to a developer to comply with the stop-work order. NATIONAL INLAND WATERWAYS AUTHORITY DECREE NO 13, 1997 OBJECTIVE- To establish the National Inland water ways Authority, to among other things, improve develop and regulate Inland water ways for navigation and specify Navigable water HIGHLIGHTS OF ENVIRONMENTALLY RELATED PROVISIONS: Established national inland water ways Authority, to inter alia, provide regulation for inland navigation, grant permit and licences for sand dredging, pipeline construction, dredging of slots and crossing of waterways by utility lines, water in take, rock blasting and removal ­ (Section 8,9) The Authority may, subject to the approval of the minister, make regulations generally for the regulation of users of navigable water ways and such other regulations as appear to him to be expedient for giving full effect to the provisions of the Decree ­ (Section 29(10(2) The Rivers and their tributaries, distributaries, creeks, lakes, lagoons, and intra-coastal waterways specified in the 2nd schedule are declared Federal Navigable waterways. ­ (Section 10) LAGOS STATE ENVIRONMENTAL PROTECTION AGENCY (LASEPA) EDICT OF 1996 Objective: To establish the Lagos State Environmental Protection Agency (LASEPA) to oversee the protection and management of the Lagos environment. The edict establishing the Lagos State Environmental Protection Agency (LASEPA) was signed into law in November 1996. The edict spelt out clearly the functions of the Agency, the authority of the Agency, and acts that are prohibited within the State together with associated penalties for flouting such prohibitions. The functions of the Agency that are relevant to this present study include: (a) The monitoring and controlling of disposal of wastes generated within the State; (b) The monitoring and controlling of all forms of environmental degradation from agricultural, industrial and government operations; 4 (c) The monitoring of surface, underground and potable water, air, land and soils within the state, determine the pollution level as well as collect baseline data; (d) Co-operating with federal, state and local governments, statutory bodies and research agencies on matter and facilities relating to environmental protection (Section 7 b, g and i). In order to execute the functions effectively, the edict empowers the Agency to: (a) Apply enforcement measures to combat environmental degradations in manufacturing premises and government operations; (b) Enter and search vehicles, tents and structures in any premises engaged in carrying out manufacturing operations; (c) Perform tests and take samples of any substance found in any premises searched, etc. (Section 8, d-f). In addition to these, the Agency is empowered to make regulations on: (a) Acceptable standards or criteria to control the pollution level of water, air noise and land in line with the policy and guidelines of Federal Government; (b) Standards for effluent discharge; (c) Waste management strategy and alternatives etc. (Section 9; a, c and e). Apart for these, the edict in Section 2.1 prohibits the manufacturing or storage of chemicals, lubricants, petroleum products, cement other than that used for building, and radioactive materials or gases without a written permission from LASEPA. Similarly in Section 2.2, the edict clearly states that "as from the commencement of this edict, no person shall: (a) Carry on or run any manufacturing operation or business in any premises within the state except such waste generated in the process of such manufacturing operation or business is treated or purified to the satisfactory standards approved by the Agency before being discharged into the environment; (b) Discharge or cause to be discharged, raw untreated human waste into any public drain water-course, gorge, storm-water or on land within the State; (c) Discharge or cause to be discharged any form of oil, grease, spent oil including, trade waste, brought about in the course of any manufacturing operation or business into any, public drain, water-course, water gorge and road verge; 5 (d) Discharge into the air any inadequately filtered and purified gaseous waste; etc. The edict also makes it mandatory for all persons generating any waste listed in Section 2.2 to ensure adequate treatment according to the Agency standard before discharge to the environment. Also all emission from vehicles, plants and equipment within the State shall be within the limit set down by the Agency. For persons who contravene or fail to comply with any of the provision of the edict, a penalty or a fine ranging from N250, 000.00 to N2, 000,000.00 with/or a term of imprisonment ranging from 5 to 10 years awaits such persons. OIL AND GAS PIPELINE (REGULATIONS) 1995 OBJECTIVE: Made pursuant to Section 31 of Oil Pipelines Act of 1956. This regulation prescribes the procedure and guidelines for obtaining licences and approvals for the construction of oil and gas pipelines and the steps to be followed during the construction, commissioning operation and maintenance of pipelines and other auxiliary installations. HIGHLIGHTS OF ENVIRONMENTALLY RELATED PROVISIONS Requires that pipelines construction be carried out in a way that shall cause the least disturbance to the environment and that considerations for public safety shall be in accordance with the provisions of APIRP1102 or any other recognised equivalent standards. Prescribes the minimum soil coverage of a pipeline to be: Area Minimum meter coverage - Dry land 0.9m - River crossing and River beds 1m - Drainage ditch, rail road 1.2m - Rocky area 0.6m - Swamp 0.6m - Shipping channel 1.5m Where the pipeline crosses or passes within 100meters of a watercourse, the operator shall assure the Department of petroleum Resources (DPR) that adequate contingency plan have been made for protecting the environment. 6 ASSOCIATED GAS RE-INJECTION ACT 1979, CAP 26, LFN OBJECTIVE: To compel every company producing oil and gas in Nigeria to submit preliminary programmes for gas re-injection and detailed plans for implementation of gas re-injection. HIGHLIGHTS OF THE PROVISIONS: Compels every oil and gas producing company in Nigeria to submit to the minister of petroleum resources, not later than 1st April, 1980 a preliminary programme for its associated gas re-injection schemes and not later than 1st October, 1980, its detailed programmes and plans for either (a) the implementation of programmes relating to the re-injection of all produced associated gas; or (b) schemes for the viable utilization of all produced associated gas - (Section 1, 2) Prohibition with effect from 1st January 1984, flaring of gas produced in association with oil without the written permission of the minister. However, if after 1st January 1984, the minister is satisfied that utilization or re-injection of the produced gas is not appropriate or feasible in a particular field(s), he may issue a certificate permitting the company to continue to flare gas in the particular field(s) if it pays such sum as the minister may from time to time prescribe for every 28.317 standard cubic metres (scm) of the gas flared. ­ (Section3) Non compliance with the provisions of the Act relating to gas flaring is an offence which may lead to forfeiture of the concession granted to the company in the particular field(s) where the gas flaring was done, in addition to other penalties ­ (Section 4 (1) (2)). The Act contains subsidiary legislation: Associated Gas Re-injection (continued flaring of gas) Regulations 1985 (see below). ASSOCIATED GAS RE-INJECTION (CONTINUED FLARING OF GAS) REGULATIONS, 1985 OBJECTIVE:Made as a subsidiary legislation to Associated Gas Re-injection Act cap 26 LFN, pursuant to Section3 and 5, to regulate continued flaring of associated gas in Nigeria. HIGHLIGHTS OF THE PROVISIONS: Stipulates conditions for the minister pursuant to Section 3(2) to issue certificate for continued flaring of gas in a particular field(s). The conditions are: (a) Where more than 75% of the produced gas is effectively utilized or conserved. 7 (b) Where the produced gas contains more than 15% impurities, such as N2. H2S, CO2 etc, which render the gas unsuitable for industrial purposes. (c) Where an on-going utilization programme is interrupted by equipment failure, provided the minister does not consider such failures too frequent, and that the period of any one interruption is not more than 3 months. (d) Where the ratio of the volume of gas produced per day to the distance of the field from the nearest gas line or possible utilization point is less than 50,000 SCF/KM, provided that the gas to oil ratio of the field is less than 3,500 SCF/bbl, and that it is not technically advisable to re-inject the gas in that field. (e) Where the minister, in appropriate cases as he may deem fit, orders the production of oil from a field that does not satisfy any of the conditions specified in this regulation - (Regulation 1) The minister of petroleum resources is empowered to periodically review, amend, alter, add or delete any provision of the regulation as he may deem fit. - (Regulation 2) PETROLEUM REFINING REGULATIONS 1974 (AS AMENDED) COMMENCEMENT: 22nd July, 1974 OBJECTIVE:Made as a subsidiary legislation to petroleum Act cap 350 LFN, pursuant to s.9 of the Act, to regulate the construction and operation of petroleum refinery in Nigeria. HIGHLIGHTS OF ENVIRONMENTALLY RELATED PROVISIONS: Every permanently placed storage tank containing crude oil any of its products shall be installed within a bun-wall capable of retaining its contents should the tank be emptied by leakage or otherwise, in addition, such a tank, if located above water, must have provision made for containing any leakage to prevent oil from contaminating the water. ­ (Reg. 24) All residues, sludges, rusts and similar matter from tanks which may have contained leaded petroleum products must be disposed of in accordance with good refining practices and only to such place as have been approved of by the Director of petroleum Resources ­ (Reg. 27) Report must be made to the inspector appointed by the Director of petroleum Resources within 7 days of any unprogrammed spillage of crude oil, its products, or chemicals insider a refinery. The notice must contain information relating to the cause, nature, amount of the spillage, the amount of the spillage recovered, precautionary measures taken since the spillage to 8 prevent any hazard that may arise therefore, and precautionary measures taken to prevent such spillage in the future ­ (Reg. 38). The manager of a refinery in required to ensure that drainage and disposal of refinery effluent and drain water will conform to good refining practices, and makes the specification of the effluent and mode of disposal subject to the approval of Director of petroleum Resources ­ (Reg. 43(1)). Complete analysis of the effluent and drainage water shall be performed at such regular intervals as the Director may prescribe, and the results thereof entered in a register specifically kept for the purpose ­ (Reg. 43 (2)) The manager is enjoined to adopt all practicable precautions to prevent pollution of the environment by petroleum or petroleum products; and where it occurs, he shall take prompt steps to control and end it .(Reg. 43(3)) An inspector or officer authorised by the Director may withdraw samples of any effluent and drainage water at any time for analysis, and if the result of such analysis reveals that the approved specifications have not been complied with, the manager shall be guilty of an offence and liable on conviction to a fine of one hundred Naira or six months imprisonment. ­ (Reg. 43(4)). OIL TERMINAL DUES ACT 1969, CAP 339 LFN COMMENCEMENT 1st January, 1965 OBJECTIVE To provide for the levying and payment of terminal dues on any ship evacuating oil at any terminal in any port in Nigeria; and in respect of any services provided at those ports and for all other matters connected there with. HIGHLIGHTS OF ENVIRONMENTALLY RELATED PROVISIONS The Nigerian Ports authority (NPA) is obliged to provide navigational services and facilities including the installation of position fixing system, navigational aids and the setting up of sea lanes for the purposes of removing any navigational hazards ­ (s.2) It is an offence to discharge oil or mixture containing oil into the territorial waters of Nigeria from any vessel or apparatus used for transferring oil to any vessel in any oil terminal ­ (s.6) 9 All applicable laws and the provisions of the instruments made under any of the Laws in force, except laws or instruments whose provisions apply only in a state and within the authority of its government shall apply in the area of the sea within which the oil terminal is situated. Such, applicable Laws include: Territorial water Act, oil in Navigable waters Act and the convention on continental shelf ­ (Ss. 8, 6 (4), 11) The Act applies to all natural persons, whether Nigerian citizen or not, and whether resident in Nigeria or not, and to all corporation, whether incorporated or carrying on business in Nigerian or not ­ (s. 9) The Act contains the following subsidiary legislation - Pennnigton oil Terminal (Establishment) order - Idohos oil Terminal (Establishment) order - Qua Iboe oil Terminal (Establishment) order - Forcados oil Terminal (Establishment) order - Escravos oil Terminal (Establishment) order - Bonny Offshore oil Terminal (Establishment) order - Brass oil Terminal (Establishment) order PETROLEUM ACT 1969 (AS AMENDED) CAP 350 LFN OBJECTIVE: To provide for the exploration of petroleum from territorial waters and the continental shelf of Nigeria and to vest the ownership of, and all on shore and offshore revenue from petroleum resources derivable there from in the Federal Government and for all other incidental matters thereto. HIGHLIGHT OF ENVIRONMENTALLY RELATED PROVISIONS: The minister responsible for petroleum Resources is empowered to supervise all operations carried on under licences and leases granted under this Act ­ (S. 8(1) (a)). But he can delegate his powers under the Act except the power to make orders and Regulations ­ (s. 12(1)). The minister is empowered to make regulations, inter alia, concerning the prevention of pollution of watercourse and the atmosphere. And safe working conditions ­ (s. 9 (1)). Pursuant to this provision, the minister has made several environmentally related regulations, such as; petroleum (Drilling and production) Regulations, Petroleum Regulations, Petroleum Refining Regulations and crude oil (Transport and shipment) Regulations etc. 10 OIL IN NAVIGABLE WATERS ACT 1968, CAP 337, LFN COMMENCEMENT 22nd April, 1968 OBJECTIVE:The Act is aimed at reducing the incidence of oil pollution of the high seas and of Nigerian territorial waters and makes provisions for the implementation of the international convention for the prevention of pollution of the sea by oil 1954 to 1962 and make provisions for such prevention in the Navigable waters of Nigeria. HIGHLIGHTS OF THE PROVISIONS: Prohibition of discharge of crude oil, fuel oil, lubricating oil, heavy diesel oil, or any mixture containing not less than 100 parts of oil from a Nigerian ship into a part of the sea that is a prohibited sea area ­ (s.1) The prohibited sea areas are all sea areas within 50 miles from land and outside the territorial waters of Nigerian and the following seas: the western Canadian zone in the pacific ocean; North Atlantic Ocean, the North sea and the Baltic sea; the Mediterranean and Adriatic seas; the Black sea and the sea of Azov, the Red sea, the Persian Gulf, the Arabian sea, Bay of Bengal, Indian ocean and the Australian sea ­ (S. 2(2)). The prohibition is applicable to masters and owners of Nigeria ship. But it is not applicable to vessels of the Nigerian Navy ­ (s. 16 (1)). It is an offence to contravene this prohibition. But a charge relating to the offence can only be brought in Nigeria by the Federal Attorney General or with his consent ­ (s. 12). It is an offence to discharge oil or a mixture containing oil from vessel, whether Nigeria owned or not, or from any place on Land or from any apparatus used for transferring oil form or to any vessel into the territorial waters of Nigeria, and all other waters, including inland waters, which are within the territorial waters and are navigable by sea-going ships. ­ (s.3); A person charged for contravening the above prohibition will have a good defence if he could prove that the oil or its mixture in question was discharged for the purpose of securing the safety of any vessel, or of preventing damage to any vessel or cargo, or saving life. Or if he could establish that the oil or its mixture accidentally escaped because of damage to the vessel or leakage therefore, and that all urgent and reasonable steps were taken to contain the discharge and reduce it impact on the environment ­ (s. 4(1)(2)) 11 PETROLEUM REGULATIONS 1967 OBJECTIVE:Made pursuant to Section9 of the petroleum Act, cap 350, to regulate activities relating to petroleum products and liquefied petroleum gas, and matters connected thereto. HIGHLIGHTS OF ENVIRONMENTALLY RELATED PROVISIONS: Prohibits discharge of petroleum into the waters of any Nigerian Port ­ (Regulation 13) Provides security measures that must be complied with by an operator, in order to avoid the risk of breakage of receptacles containing petroleum ­ (Regulation 59) Prohibits escape of petroleum into any inlet or drain connected with a sewer ­ (Regulation 67) International Regulations A number of international regulations exist that are relevant to the WAGP project. These are summarized below: GULF OF GUINEA LARGE MARINE ECOSYSTEM PROJECT (GOG-LME), 1999 This is a regional treaty signed by Benin, Ghana, and Nigeria stating they would like to improve the status of the Large Marine Environment. There is no regulating or enforcing agency. The Gulf of Guinea Large Marine Ecosystem Project (GOG-LME) came into existence in December 1999. The objective of the project is to improve the marine environment along the western coast of Africa that is influenced by the Guinea current. Goals such as assessing and mitigating the pollution of the environment, and improving the biodiversity of the ecosystem are two focal points of the project. The sustaining of the living resources, ie fisheries, would ensure the continued economic prosperity and growth of those whom make a living utilizing this resource. A secondary goal of the project is to improve the health of the local population by means of increasing the cleanliness of the marine and estuarine environments. Another aim of the GOG-LME is to create a regional database and shared information source for the regional managers of the marine ecosystem, and to establish a more detailed Global Information System (GIS) database of the region. 12 CONVENTION ON THE CONSERVATION OF MIGRATORY SPECIES OF WILD ANIMALS, 1987 Animals listed as "endangered" by the Convention include four species of whales and six marine turtles. Several species of whales and dolphins breed in the project area. Recent observations from the geophysical surveys carried out by WAGP confirmed sightings of whales with claves as well as dolphins. Sea turtles also nest on the shores traversed by the pipeline route. In particular, the shoreline east of the Tema shore-crossing point is one of the prime sea turtle nesting sites in the sub-region. CONVENTION ON THE HIGH SEAS, GENEVA 1958 Objectives: To codify the rules of international law relating to the high seas HIGH LIGHTS OF ENVIRONMENTALLY RELATED PROVISIONS: States to draw up regulations to prevent pollution of the sea by oil from ships and pipelines or resulting from the exploration and exploitation of the sea- bed (Article 24); State to take measures to prevent pollution of the sea by dumping of radioactive waste and to cooperate with international agencies in taking such measure to prevent pollution of the seas or airspace above them resulting form radioactive materials or other harmful agents (Article 25). Status in Nigeria: Entered into force on 30th September, 1962 UNITED NATIONS CONVENTION ON THE LAW OF THE SEA (UNCLOS), MONTEGO BAY, 1982 Objectives: To set up a comprehensive new legal regime for the sea and oceans and as far as environmental provisions are concerned, to establish rules concerning environmental standards are well as enforcement provisions dealing with pollution of the marine environment. HIGHLIGHTS OF ENVIRONMENTALLY RELATED PROVISIONS: Definition of the territorial sea and the contiguous zone (Article3 and 33); Use of strait for international navigation (Article 34 to 45) and arch pelagic State (Article 46 to 54) ; Definition of the exclusive economic zone (Article 55). The parties to have sovereign rights therein for the purpose of exploring it and exploiting, preserving and managing its natural resources as well as other rights and duties (Article 56); 13 The coastal State to exercise over the continental shelf, defined in article 76) sovereign rights for the purpose of exploring it and exploiting, its natural resources (defined in Article 77); Freedom of the high seas to comprise (Part VII) freedom of navigation, of over-flight, of laying submarine cables and pipelines, subject to the provisions of part VI, of constructing artificial islands, etc, subject to the provisions of part VI, and of fishing and of scientific research, subject to the provisions of parts VI and XII; The regime of island described (Article 121), together with enclosed or semi- enclosed seas (Articles 122 and 123). Land-locked States to enjoy the right of access to and from the sea and freedom of transit (Article 124 to 132); The area (the sea bed and ocean floor and subsoil thereof, beyond the limits of national jurisdiction) and its resources to be the common heritage of mankind (Article 136). The resources of the Area to be developed (Article 150 to 155). An Authority to be established through which States Parties to the Convention shall organise and control activities in the area, particularly with a view to administering the resources of the Area (Article 157). A Sea Bed Disputes Chamber to be established, and the manner in which it shall exercise its jurisdiction specified (Article 186); International rules and national legislation to be developed for the prevention, reduction and control of pollution of the marine environment, and provisions set out concerning enforcement and responsibility and liability; Rules set out to govern marine scientific research, the development and transfer of marine technology and the settlement of disputes. The obligation to settle disputes by peaceful means specified (Article 279). Compulsory procedures set out entailing binding decisions; Uses of the seas for peaceful purpose (Article 301); · The Convention has the following annexes: i) Highly migratory species; ii) Commission on the Limits of the Continental Shelf; iii) Basic conditions of prospecting, exploration and exploitation; iv) Statute of the Enterprise v) Conciliation; vi) Statute of the International Tribunal of the Law of the Sea; vii) Arbitration; viii) Special arbitration; ix) Participation by international organization Status in Nigeria: Ratification ­ 14th August 1986, entered into force on 16th December 1994. 14 INTERNATIONAL CONVENTION FOR THE PREVENTION OF POLLUTION OF THE SEA BY OIL, LONDON 1954 (OILPOL) (AS AMENDED IN 1962 & 1969) HIGH LIGHTS OF THE PROVISIONS: Applies to all ships, except tankers of under 150 tons gross tonnage and other ships of under 500 tons gross tonnage, registered in the territory of, or having the nationality of, a Party. Naval ship and ships engaged in whaling are also excepted (Article 2); Prohibition of discharges, except when a ship proceeding en route or when the instantaneous rate or discharge does not exceed 60 litters per mile. The prohibition is not applicable when the following conditions are satisfied: in the case of a ship ­ the oil content of the discharge is less than 100 parts per million parts of the mixture, or the discharge is made as far as practicable from land; in the case of a tanker ­ the total quantity of oil discharged on a ballast voyage does not exceed one fifteen-thousandth of the total cargo carrying capacity, or the tanker is more than 50 mile from the nearest land (Article 3); Exceptions to article 3 in cases of necessity to secure safety of ships, save life or prevent damage to cargo, or where leakage is unavoidable and all measures have been taken to minimize it (Article 4); Ships to be fitted within 12 months to prevent escape of oil into the bilges (Article 7); Parties to provide appropriate facilities at ports and oil-loading terminals (Article 8); All ships covered by the Convention to carry an oil record book in a form specified in the annex, to be completed whenever certain operations take place (Article 9); Parties to send texts of laws, decrees, orders and regulation giving effect to the Convention to the United Nations. Status in Nigeria: Entered into force on 22nd April 1968. MARPOL 73/78 has superseded this convention. CONVENTION ON CONTINENTAL SHELF, GENEVA, 1958 Objectives: To define and delimit the rights of States to explore and exploit the natural resources of the continental shelf. HIGH LIGHTS OF ENVIRONMENTALLY RELATED PROVISIONS: Coastal States have sovereign and exclusive rights over the continental shelf for the purpose of exploration and exploitation (Article 1); 15 Such exploration or exploitation must not cause unjustifiable interference with navigation, fishing or the conservation of the living resources of the sea, or with oceanographic or other scientific research (art 5) Status in Nigeria: Ratification Accession (AC) - 28th April, 1971, entered into force on 28th May, 1971 CONVENTION FOR CO-OPERATION IN THE PREVENTION AND DEVELOPMENT OF THE MARINE AND COASTAL ENVIRONMENT OF THE WEST AND CENTRAL AFRICAN REGION, ABIDJAN, 1981 Objectives: To protect the marine environment, coastal zones and related internal water falling within the jurisdiction of the States of the West and Central African region. HIGHLIGHTS OF THE PROVISIONS: The parties shall: Take all necessary measures to prevent, reduce, combat and control pollution of the convention area (Article 4), particularly pollution from ships and aircraft (Article 5and 6), land ­based sources (Article 7) and activities relating to exploration and exploitation and of sea bed (Article 8) and pollution from or though the atmosphere (Article 9); Prevent, reduce, combat and control coastal erosion (Article 10); Protect and preserve rare or fragile ecosystems, as well as the habitat of depleted, threatened or endangered species and other marine life in specially protected areas (Article 11); Cooperate in dealing with pollution emergencies in the convention area (Article 12); and in exchanging data and other scientific information (Article 14); Develop technical and other guidelines regarding environmental impact assessment of their development data and other scientific information (Article 14); Establish rules and procedures for the determination of liability and the payment of adequate and prompt compensation for pollution damage of the Convention area (Article 15) Status in Nigeria: Entered into force ­ 5th August, 1984 UNTED NATIONS FRAMEWORK CONVENTION ON CLIMATE CHANGE, NEW YORK, 1992 Objectives: To regulate levels of greenhouse gas concentration in the atmosphere, so as to avoid the occurrence of climate change on a level that 16 would impede sustainable economic development, or compromise initiative in food production. HIGHLIGHTS OF THE PROVISIONS: Definition of the basic terminology the Convention, such as "climate change" climate system emissions greenhouse gases reservoir sink source (Article 1); Principles to guide the Parties in their pursuit of the Convention's objectives (Article 3). The Parties are to protect the climate system for present and future generations. Developing countries should be accorded appropriate assistance to enable them to fulfill the terms of the Convention. The Parties should work in cooperation so as to obtain maximum benefit from initiatives in the control of the climate system; Commitments assumed under the Convention (Article 4). Parties are to prepare national inventories on greenhouse gas emissions and on actions taken to remove them; formulate and implement programmes for the control of climate change; undertake cooperation in technology for the control change in the climate system; incorporate suitable policies for the control of climate change in national plans; undertake education and training policies that will enhance public awareness in relation to climate change. The developed country Parties (and other Parties listed in annex 1) commit themselves to take special measures to limit their anthropogenic emission of greenhouse gases; and to enhance the capacity of their sinks and reservoir for the stabilization of such gases. The developed country Parties (and other Parties listed in Annex ll) undertake to accord financial support to developing country Parties, to enable the latter to comply with the terms of the Convention; Cooperation by Parties in the established and promotion of network and programmes of research into and systematic observation of climate change (Article 5); Establishment of a Conference of Parties to the supreme body of the Convention and to oversee the implementation of the Convention (Article 7,8,9,and 10); establishment of a financial mechanism to provide resources on a grant or confessional basis, for the implement of the objectives of the Convention (Article 11); procedure for the settlement of disputes (Article 14) Status in Nigeria: Signature ­ 13th June 1992, entered into force on 27th November 1994 17 INTERNATIONAL CONVENTION ON THE ESTABLISHMENT OF AN INTERNATIONAL FUND FOR COMPENSATION FOR OIL POLLUTION DAMAGE (IOPC FUND), 1992 The Fund Convention was adopted to provide additional compensation for victims of oil pollution and to transfer some of the economic consequences to the owner of the oil cargo, as well as the ship owner. Compensation payable under the Fund is limited to 450 million francs per incident, and an aggregate of 450 million francs for pollution damage resulting from a natural phenomenon of an exceptional, inevitable and irresistible character CONVENTION ON BIOLOGICAL DIVERSITY, 1992 This convention recognizes the value of the need for international cooperation to protect biological diversity and the associated resources. It establishes three main goals: conservation of biological diversity, the sustainable use of the components of this diversity, and the fair and equitable sharing of the benefits from the use of genetic resources. INTERNATIONAL CONVENTION ON OIL POLLUTION PREPAREDNESS, RESPONSE AND CO-OPERATION (OPRC), 1990 This convention came into force in 1995. The convention recognizes the serious threat posed to marine environments as a result of oil pollution from ships, offshore facilities, seaports, and oil handling facilities. It also focuses on the need to take precautionary measures to avoid oil spills as well as effective combat and corrective action in the case of an oil pollution incident. The OPRC takes into account the polluter pays principle and the importance of international instruments on liability and compensation in case of oil damage. Each party to the convention is required to ensure that ships, operators of offshore units and seaports authorities under its jurisdiction, shall poses oil pollution emergency plans, report without delay, any event involving discharge or probable oil discharge at sea, assess the event to determine whether it is an oil pollution incident, and in the event of an established oil pollution incident, assess the nature, extent and environmental consequences, inform without delay all States whose interests are affected or likely to be affected. Each party shall also establish a national system for responding promptly and effectively to oil pollution incidents and this shall include also a national contingency plan for oil spill preparedness and response. CONVENTION ON THE CONTROL OF TRANS-BOUNDARY MOVEMENTS OF HAZARDOUS WASTES AND THEIR DISPOSAL, 1989 This convention was established to outlaw the practice of shipping hazardous waste to Eastern Europe and developing countries. During its first decade, it was largely devoted to setting up a framework for controlling the movement of hazardous wastes across international frontiers. In 1998, the Technical Working 18 Group agreed on specific lists of hazardous wastes. In 1999, rules on liability and compensation for spills of waste during import, export, and disposal were established. PROTOCOL ON SUBSTANCES THAT DEPLETE THE OZONE LAYER, 1987 This treaty, originally signed in 1987 and substantially amended in 1990 and 1992, stipulates that the production and consumption of compounds that deplete ozone in the stratosphere are to be phased out by 2000 (2005 for methyl chloroform). As a result, substances such as chlorofluorocarbons (CFCs), halons, carbon tetrachloride, and methyl chloroform, are being phased out. The United Nations Environment Programme (UNEP) has prepared a Montreal Protocol Handbook that provides additional detail and explanation of the provisions. CONVENTION FOR THE PREVENTION OF THE OZONE LAYER, 1985 This convention was a first step in the protection of the ozone layer. In it, nations agreed to take measures to protect against effects of activities that modify the ozone layer, but the measures are unspecified. There is no mention of any substances that might harm the ozone, but the main thrust of the convention was to encourage research, cooperation among countries and exchange of information. CONVENTION FOR THE COOPERATION IN THE PROTECTION AND DEVELOPMENT OF THE MARINE AND COASTAL ENVIRONMENT OF THE WEST AND CENTRAL AFRICAN REGION (ABIDJAN CONVENTION) The marine environment, as well as coastal zones and inland waters, of West and Central Africa, is covered by the Convention for the Co-operation in the Protection and Development of the Marine and Coastal Environment of the West and Central African Region, (the Abidjan Convention), signed in March 1981. Like a number of other regional conventions, the Abidjan Convention deals with pollution from ships, via incidental discharges and dumping, by simply referring the contracting parties to the applicable global convention. Thus whilst Nigeria is not specifically party to MARPOL 73/78, it is arguable that the rule of MARPOL, as customary international law, apply to vessels under Nigerian jurisdiction in the Abidjan Convention area. MARPOL 73/78 supersedes OILPOL, 1954 and is intended to deal with all forms of intentional pollution of the sea from ships, other than dumping. Detailed provisions are set out in five annexes to the Convention; Annex I deals with oil, Annex II with noxious liquid substances carried in bulk, the carriage of harmful substances at sea in packaged form is dealt with by Annex III, Annex IV applies to sewage and Annex V to garbage. States become parties to the Convention by ratifying Annexes I and II, whilst Annexes II, IV and V are optional. 19 In 1992, the Convention was amended and the discharge of oily wastes from vessels is forbidden if the oil in water content exceeds 15 ppm. Annex IV prohibits the discharge of sewage less than 4 nautical miles from land and between 4 and 12 miles from land, sewage must be comminuted and disinfected using an approved sewage treatment plant before discharge. Outside the 12 mile limit sewage can be discharged provided that it has been stored in holding tanks, is not discharged instantaneously and whilst the ship is proceeding at more than 4 knots. Alternatively sewage can be discharged if the vessel has an approved sewage treatment plant, or finally if the ship is under the jurisdiction of a State and is discharging sewage in accordance with any less stringent requirements imposed by that State. Party states are expected to provide suitable reception facilities at port for instances were a vessel cannot comply with the conditions and cannot therefore discharge at sea. Annex V sets minimum distances from land for the disposal of all principle kinds of garbage and prohibits the disposal of all plastics into the sea. PROTOCOL CONCERNING COOPERATION IN COMBATING POLLUTION IN CASES OF EMERGENCY IN THE WEST AND CENTRAL AFRICAN REGION, 1981 This protocol is designed to protect the marine environment of West and Central African region against pollution in cases of emergency. Under this agreement, member countries (Cameroon, Congo, Côte d'Ivoire, Gabon, Gambia, Ghana, Guinea, Nigeria, Senegal, and Togo) agree to cooperate to protect their respective coastline from pollution resulting from marine emergencies; to maintain and promote marine emergency contingency plans; and to take appropriate measures to prevent, reduce, combat and control the effects of pollution. CONVENTION ON THE CONSERVATION OF MIGRATORY SPECIES OF WILD ANIMALS, (Bonn, 1979) Objective: The Parties to this convention having acknowledged the importance of migratory species being conserved and of Range States agree to take action to this end whenever possible and appropriate, paying special attention to migratory species the conservation status of which is unfavourable, and taking individually or in cooperation appropriate and necessary steps to conserve such species and their habitat. The parties also acknowledge the need to take action to avoid any migratory species becoming endangered. HIGH LIGHTS OF ENVIRONMENTALLY RELATED PROVISIONS: Promote, cooperate in support research relating to migratory species: 20 Endeavour to provide immediate protection for migratory species included in Appendix I; and Endeavour to conclude Agreements covering the conservation and management of migratory species included in Appendix II INTERNATIONAL CONVENTION ON STANDARDS OF TRAINING CERTIFICATION AND WATCH-KEEPING FOR SEAFARERS (STCW), 1978 This convention first established basic requirements on training, certification and watch-keeping for seafarers on an international level. Previously the standards of training, certification and watch-keeping of officers and ratings were established by individual governments, so standards and procedures varied widely. STCW prescribes minimum standards relating to training, certification and watch- keeping for seafarers which countries are obliged to meet or exceed. PROTOCOL RELATING TO THE INTERNATIONAL CONVENTION FOR THE SAFETY OF LIFE AT SEA (SOLAS PROT), 1978, 1974 The main objective of the SOLAS Convention is to specify minimum standards for the construction, equipment and operation of ships. It sets flag states responsible for ensuring that ships under their flag comply with its requirements. Control provisions also allow inspection of ships of other States if there are clear grounds for believing that the ship and its equipment do not substantially comply with the requirements of the Convention. CONVENTION ON INTERNATIONAL REGULATIONS FOR PREVENTING COLLISIONS AT SEAS (COLREG), 1972 The 1972 Convention was designed to update and replace the Collision Regulations of 1960. One of the most important innovations in the 1972 COLREGs was the recognition given to traffic separation schemes. Rule 10 gives guidance in determining safe speed, the risk of collision and the conduct of vessels operating in or near traffic separation schemes. CONVENTION CONCERNING THE PROTECTION OF THE WORLD CULTURAL AND NATIONAL HERITAGE (WORLD HERITAGE CONVENTION), 1972 This convention defines the kind of natural or cultural sites, which can be considered for inscription on the World Heritage List, and sets out the duties of identifying potential sites and in protecting and preserving them. CONVENTION ON THE PREVENTION OF MARINE POLLUTION BY DUMPING OF WASTES AND OTHER MATTER, 1972 This convention prohibits dumping of certain hazardous materials, requires a prior special permit for the dumping of a number of other identified materials and a prior general permit for other wastes or matter in the international waters. 21 CONVENTION ON WETLAND OF INTERNATIONAL IMPORTANCE (RAMSAR, 1971) Objectives: To stem the progressive encroachment on and loss of wetlands now and in the future, recognizing the fundamental ecological functions of wetlands and their economic, cultural, scientific, and recreational value. HIGH LIGHTS OF ENVIRONMENTALLY RELATED PROVISIONS: Parties to designate at least one national wetland for inclusion in a list of Wetlands of International importance (Article 2); Parties to consider their international responsibilities for conservation, management and wise use of migratory stocks of wildfowl (Article 2); Parties to establish wetland nature reserves, cooperate in the exchange of information and train personnel for wetland management (Article 4); and Conference on the conservation of wetlands and water fowl to be convened as the need arises. Status in Nigeria: Entered into force on 2nd February 2001 INTERNATIONAL CONVENTION ON CIVIL LIABILITY FOR OIL POLLUTION DAMAGE (CLC), 1969 The Civil Liability Convention allows for compensation to persons who suffer oil pollution damage resulting from maritime casualties involving oil-carrying ships. It places the liability these damages on the owner of the ship from which the polluting oil escaped or was discharged and requires ships covered by it to maintain insurance or other financial security in sums equivalent to the owner's total liability for one incident. AFRICAN CONVENTION ON THE CONSERVATION OF NATURE AND NATURAL RESOURCES, 1968 This convention encourages action for the conservation, utilization and development of soil, water, flora and fauna for the present and future welfare of mankind, from an economic, nutritional, scientific, educational, cultural, and aesthetic point of view. CONVENTION ON FACILITATION OF INTERNATIONAL MARITIME TRAFFIC, 1965 This convention's main objectives are to prevent unnecessary delays in maritime traffic, to aid co-operation between Governments, and to secure the highest practicable degree of uniformity in formalities and other procedures. In particular, it establishes standards and reduces the number of declarations, which can be required by public authorities. 22 CONVENTION ON THE TERRITORIAL SEA AND CONTIGUOUS ZONE, 1958 This convention established a general regime for the territorial sea and contiguous zone, although it did not contain agreement on the extent of such zones. However, the UN Law of the Sea Convention (1982) now supercedes this convention. 23 Appendix 2A-1 Air Pollutant and Greenhouse Gas Emissions West African Gas Pipeline URS WAGP PROJECT MEMORANDUM Date: May 24, 2004 To: WAGP Project Team From: John Lague (URS Corporation) Subject: Air Pollutant and Greenhouse Gas Emissions and Emissions Savings Associated with the West Africa Gas Pipeline Project Introduction As requested by WAPCo and the West African Gas Pipeline (WAGP) Project Team, URS Corporation has conducted an evaluation of potential emissions of air pollutants and greenhouse gases (GHG) associated with future operations of the WAGP project and of the emissions that would occur in the absence of this project. This work represents an update of a 1999 URS study on the same subject, with the current version incorporating newer information that has become available since the original work was completed. The primary basis for the revised emissions estimates is a 2003 report on the likely demand for natural gas in Ghana, Togo and Benin (receiving countries for the WAGP gas) that was conducted by Purvin & Gertz (West African Gas Pipeline Project ­ Draft Market Report Update, August 2003). Specifically, the P&G report presents projections of WAGP gas throughputs that could be supported by the expected energy demand in the countries that would be served by the proposed pipeline during the first 20 years of its operation (assumed to be 2005 through 2025). Another important change from the 1999 report is the more accurate operational understanding regarding the fraction of the natural gas throughput of the pipeline that would be flared in the absence of the WAGP project. The previous assumption that the entire WAGP throughput would represent a savings in flared associated gas (AG) has been replaced with new data showing that only a portion of the gas sent through the pipeline would in fact be associated gas (AG). Based on the best information now available, the AG portion of P&G's projected Mid- Market demand throughput will grow from about 11 billion cubic feet (bcf) in 2005 to about 70 bcf in 2025. However, the volume of non-associated gas (NAG) shipped by the pipeline will increase at an even higher rate, with the result that the AG fraction of the total pipeline throughput will decline from approximately 65% to 43% over this same period as indicated in Figure 1 below. 1 Percent of AG into WAGP 80% 80% 70% 70% 60% 60% t cen 50% 50% erP 40% 40% Range Estimate AG into ELPS 30% 30% WAGP Emissions Reduction Assumption 20% 20% 2006 2011 2016 2021 2025 Forecast Year More detailed information regarding the likely AG/NAG blend supplied to WAGP via the Escravos Lagos Pipeline System (ELPS), and the effect on estimated GHG emissions, is provided later in this report and detailed further in the WAGP Environmental Impact Assessment. Emissions from the project and for the No-Project Scenario may be higher or lower than the levels presented in this report to the extent that the actual demand profiles in the receiving countries may evolve differently from the scenarios presented in the P&G report. The uncertainty that is inherent in forecasts of economic conditions over an extended time period has been dealt with by providing emissions estimates for a range of possible natural gas demand scenarios and for different assumptions regarding the extent to which the project itself may affect demand by providing a reliable source of natural gas fuel to the receiving countries. Estimating Emissions for WAGP Operations Development of emissions estimates for the WAGP project operations for different market/demand scenarios postulated by P&G (P90, P50, P10 cases) was straightforward and was accomplished by the following steps: (1) Per information provided by WAGP, compressor station natural gas consumption was assumed to amount to 1.25% of the total WAGP throughput, and a single compressor station in Nigeria was assumed to meet the project's requirements and to be equipped with gas turbine compressor drivers. This compressor station constitutes the only source in emissions in Nigeria for the Project Scenario. (2) Emissions associated with combustion of the natural gas delivered by the pipeline to users in Ghana, Togo and Benin were calculated for specific sectors as follows: - Power plants were assumed to combust the gas in gas turbines 2 - Commercial and industrial sources were assumed to combust the gas in boilers. (3) Emissions of air pollutants created by natural gas combustion (NOx, SOx, CO, VOC, PM10) were calculated using current emission factors from the US Environmental Protection Agency AP-42 compilation. (4) The WAGP gas throughput projected by P&G for each future year (average MMBtu/day) was apportioned between the electric power and industrial/commercial sectors in the three receiving countries according to the corresponding demand figures presented in the P&G report. The gas fuel energy amounts that would be delivered to each country and sector were then multiplied by appropriate emission factors to obtain greenhouse gas and air pollutant emissions estimates for these activities. (5) Emissions of greenhouse gas compounds, i.e., methane (CH4), carbon dioxide (CO2), and nitrous oxide (N2O), were calculated using emission factors appropriate to turbines or industrial boilers from the API Compendium of Greenhouse Gas Emissions Estimation Methodologies. An average chemical composition analysis of the gas that will be shipped by the WAGP was provided by WAGP, and has been used to calculate project-specific GHG emissions for the sources where the pipelined gas is combusted. Additional information is provided in Appendix A regarding technical assumptions incorporated in the emissions calculations presented throughout this report. Estimating Emissions for the No-Project Scenario In order to understand the net effect of the WAGP project on greenhouse gas and air pollutant emissions, potential emissions resulting from the project must be compared to a baseline or "No Project" scenario that represents the best estimate of conditions that would exist in the absence of this project. There are obvious uncertainties in estimating emissions for the No-Project Scenario (baseline) over an extended future period, because such projections require assumptions regarding outcomes that depend on many external factors. To allow for this uncertainty, a range of baseline scenarios has been considered and evaluated, and the corresponding emissions are compared with the project emissions estimates described in the previous section to estimate the net change in emissions that can be expected to occur due to WAGP. The P&G study was conducted to estimate the demand for natural gas in the receiving countries from 2005 though 2025, including foreseeable power generation and industrial/commercial projects in Ghana, Togo and Benin. The demand for gas (MMBtu/day) was estimated by P&G for each year, based on the best available evidence regarding the magnitude and timing of electric power generation and industrial sector growth over this period. Since the P&G study was not specifically designed to support an evaluation of emissions changes associated with the WAGP, it does not provide all of the information that would ideally be available for a detailed analysis of emissions without the project. The most important areas of uncertainty in this regard are: The report did not state explicitly whether and in what proportions new power plants and industrial projects in the future-year projections for the receiving countries would depend 3 upon the reliable supply of natural gas that would be provided by WAGP, or if these projects would have proceeded anyway without WAGP, using another fuel in response to the projected demand. Demand for natural gas in Benin and Togo was expressed in terms of totals for the two countries combined, rather than separately for each country. The methods and assumptions used by P&G to convert from estimated power generation requirements (MW) for specific developments in future years to incremental WAGP gas throughput changes were not clearly described, making it difficult to incorporate detailed information for specific projects in the emission calculations. Projections of natural gas demand in the power generation and industrial/commercial sectors of the receiving countries are provided by P&G only for a P50 ("Mid Market") scenario, whereas WAGP throughput projections are available for the P90, P50 and P10 demand levels1. Accordingly, it was assumed that the estimated fractions of the P50 throughput allocated to power plants and industrial facilities would be the same for the P10 and P90 cases as well. In recognition of the limitations of the available information on future natural gas demand, and to cover a range of possible future circumstances, emissions data for two possible No Project scenarios were developed: (see below). Assumptions for the Maximum Baseline Scenario This baseline scenario was developed on the following premises: - It is assumed that, in the absence of the proposed WAGP project, the AG portion of the projected natural gas throughput of the pipeline would be flared in Nigeria through 2025, with an assumed combustion efficiency of 98%. The projected fraction of the pipeline gas that would have been flared (i.e., AG) has been estimated to be 64.8% in 2006, decreasing gradually but steadily to a level of 42.8% by 2025. - The Nigerian government has stated that gas flaring in the country will cease by 2008, so it is likely that even the gas streams that are currently flared would have begun to be used for some other purpose after that year in the absence of the pipeline, e.g., combustion elsewhere in Nigeria or another country. The remainder of the pipeline throughput would be in the form of non-associated gas (NAG) that would not have been produced in the absence of the pipeline, and its combustion by users in the receiving countries is thus not considered to be part of the baseline condition. - The issues of identifying and justifying the most probable baseline condition, including the planned 2008 flares-out policy, would need to be addressed more fully if the WAGP 1 The P50 case represents a WAGP throughput level that is considered to have a 50% chance of being equaled or exceeded. The P10 throughput is higher than the P50 throughput and is at a level considered to have a 10% chance of being equaled or exceeded. The P90 throughput is lower and is at a level anticipated to have a 90% chance of being equaled or exceeded. 4 sponsors were to apply for certified emission reduction credits under the Clean Development Mechanism program established by the Kyoto Protocol. However, for purposes of this analysis, continued flaring through 2025 was retained as the simplest baseline assumption, on the premise that the gas most likely would have been burned for some purpose whether or not flaring would actually have continued through 2025. - All existing power plants and industrial fuel consumers in the receiving countries are assumed to remain in liquid fuel service without WAGP through 2025, or to the end of their presumed operating lives, if sooner than 2025. - It is assumed that all new power plants and industrial fuel users in the receiving countries, except the "Strategic Projects" identified in the P&G report, would have materialized without the pipeline project according to the P&G demand projections, and would continue to use their current liquid fuels. The P&G report specifically identifies certain Strategic Projects in Ghana as developments that would materialize only if WAGP were implemented. Accordingly, the emissions due to natural gas usage associated with these facilities are included in the Project Scenario, but are omitted from the baseline, on the premise that they would not have occurred without the WAGP project. - In the absence of separate projections for Benin and Togo, we assumed that increased fuel demand for the power and commercial/industrial sectors would have been divided evenly between the two countries. No such assumption was required for Ghana, since the P&G report did provide a breakdown of the projected demand between the power generation and industrial fuel requirements in that country. Baseline emissions for these facilities were calculated assuming continued use of their current (liquid fuels) in gas turbine drivers for power plants and in boilers for commercial/industrial users. - Separate No-Project emissions projections were made based on P&G's P90, P50 and P10 natural gas demand scenarios. Less detailed information is provided in the P&G report on the allocation of demand for the power generation and industrial/commercial sectors for the P10 and P90 scenarios. For this reason, the fractions of the total fuel demand allocated to the power and industrial sectors for these scenarios were assumed to be the same as for the P50 scenario. A few additional words are warranted on the assumptions that have been made regarding the fractions of the WAGP throughput that would be supplied by AG and NAG. Appendix 2A-2 to the WAGP Environmental Impact Assessment provides detailed quantitative information regarding initial AG/NAG blends (Page 2A-5, ELPS Gas Supply & ELPS Gas Delivery Tables, Section 1.4). Over time, the AG/NAG blend ratios become more speculative, depending on macro-level market conditions for oil and gas sales, and the circumstances defining capital expenditure opportunities for both existing and new production wells (AG & NAG), processing facilities and export/transmission infrastructure. The yearly AG/NAG splits assumed in this analysis reflect the best information that is currently available on this subject. Note that greenhouse gas and air pollutant emissions and emissions changes due to fuel switching in the receiving countries of Benin, Ghana and Togo will be the same whether the gas shipped in the pipeline is from associated or non-associated production. 5 Assumptions for the Minimum Baseline Scenario (P50 only) This alternate baseline scenario has been constructed based on the following premises: - The same AG portion of the projected WAGP throughput that was flared in Nigeria through 2025 for the Maximum Baseline case would also be flared for the Minimum Baseline scenario. The reasons for assuming continued flaring in this baseline scenario are the same as those presented above for the Maximum Baseline. Again, the fraction of the throughput that will be non-associated gas is not included in the baseline, since it would not be produced in the absence of a pipeline. - It is assumed that all existing power plants and plants that will be on-line in the receiving countries before the WAGP comes on-line would continue to use their current or planned fuels in the absence of the pipeline, and would switch to natural gas fuel when WAGP commences operation. The power plants in this category that are included in the Minimum Baseline are: o Ghana: Tema (diesel, 32 MW) and Takoradi (fuel oil, combined cycle turbines, 550 MW) o Benin: CEB Cotoneau (fuel oil, turbine, 25 MW) o Togo: CEB Lome (jet kerosene, turbine, 25 MW) and Electro-Togo (jet kerosene, turbines, 87 MW) - All future new power plants and industrial fuel users that will be established in the receiving countries are assumed not to materialize in the absence of WAGP, and are thus not included in the baseline. During the first few years of the pipeline operation, the emissions of some greenhouse gases and air pollutants that were calculated for the existing power plants in Ghana, Togo and Benin were actually higher than those estimated from the P&G demand projections. These discrepancies reflect apparent differences in the methodologies used to derive the two sets of numbers. In keeping with the concept of a Minimum Baseline, the lower of the two emissions estimates was used in all such cases, while the higher value was used for the same years in the Maximum Baseline. The principal difference between the two baselines summarized above is that the Maximum Baseline scenario presumes that the entire energy demand forecasted by P&G would exist whether or not a reliable supply of natural gas were available in all three countries, and that, without WAGP, this demand would be met by continuing use of the liquid fuels that are currently utilized by power plants and industries in those countries. On the opposite extreme, the premise of the Minimum Baseline is that all future new development of power generation and industrial facilities would depend on the availability of natural gas and would not be implemented unless the WAGP project proceeds. In the latter case, the difference between the Project and No Project emissions scenarios results partially from the improvement in combustion efficiency that would typically be achieved by combusting gas in future turbines and boilers, rather than in flares. However, this reduction in emissions is at least partially offset by the fact 6 that only a portion of the gas throughput (the AG fraction) would be flared without the project, whereas the entire throughput would be combusted with the project. Table 1 is provided to help delineate which sources of greenhouse gases and air pollutants are included in the Project Scenario and in the two alternate Baseline scenarios examined in this report. Results of Emission Calculations Table 2 presents a summary of the estimated net emission changes that will occur as a result of the WAGP project during its first 20 years of operation. This table shows that overall emissions of greenhouse gases and air pollutants will be reduced as a result of the WAGP, regardless of the projected throughput and baseline scenario selected. Emissions of all pollutants will decrease in Nigeria as currently flared streams are instead sent out of the country by the proposed pipeline. Emissions of air pollutants will either increase or decrease in Ghana, Togo and Benin, depending on the assumptions that are made regarding the levels of future development that would occur without the WAGP project. More detail on the results for individual scenarios is provided below. Computed emissions of greenhouse gases and air pollutants with and without implementation of the WAGP project for the P50 demand scenario are shown in Tables 3 and 4 for the Maximum and Minimum Baseline cases, respectively. These and all subsequent tables for the other demand scenarios show the estimated annual emissions over a 20-year period for combined greenhouse gases in CO2 equivalents (i.e., CO2, methane and N2O weighted by their respective global warming potentials and added), as well as NOx, CO, SO2, PM10 and VOC. In the Maximum Baseline case presented in Table 3 we have assumed that all of the existing and new power generation and commercial/industrial development forecasted in the P&G report for Ghana, Togo and Benin by 2025 would have proceeded to meet the perceived demand, whether or not the natural gas supply to these countries materializes due to WAGP. Furthermore, this Maximum Baseline assumes that these power plants and industrial facilities would otherwise have been designed to use liquid fuels similar to those currently utilized by their respective economic sectors. For the Maximum Baseline case, the reduction of AG flaring in Nigeria and the replacement of liquid fuels by cleaner burning natural gas in Ghana, Togo and Benin is estimated to reduce greenhouse gas emissions by 2.5 to 3 million equivalent (MMTonnes CO2e per year) in the first several years of WAGP operation, with the avoided emissions reaching about 6.4 MMTonnes CO2e per year by 2025. The latter figure includes 4.3 MMTonnes/year due to elimination of flaring in Nigeria for part of the WAGP throughput volume and 2.1 MMTonnes/year from fuel switching at facilities in Ghana, Togo and Benin. The estimated cumulative reduction is nearly 86 MMTonnes CO2e over a 20-year period. Air pollutant emissions also are predicted to decrease significantly in all countries and all years as a result of WAGP, reflecting the generally lower equipment emission factors for combustion of gas versus liquid fuels and the improved fuel combustion efficiency of turbines and boilers versus flaring. By its assumption of maximum development powered by liquid fuels, this scenario effectively maximizes the emissions savings that could be realized by implementation of WAGP. 7 The opposite is true of the analysis presented in Table 4 for the Minimum Baseline scenario, which incorporates much more conservative assumptions regarding the level of development that would have occurred in future years without WAGP and the fuels that would have been used to support such development. For this scenario, it has been assumed that all of the specific and hypothetical future new developments incorporated in the P&G projections for all sectors (power generation, commercial/industrial and strategic projects) would not materialize at all without WAGP, or would use natural gas fuel anyway. This is then the baseline scenario that leads to the lowest estimate of the emissions savings attributable to WAGP. Emission reductions associated with these new developments would result from the improvement in the combustion efficiency that would be realized by burning the gas in modern boilers and turbines, as opposed to flaring it and the fuel switching that would occur for existing power plants. The results in Table 4 show that the emission reductions that could be achieved for greenhouse gases and most pollutants are well below those for the Maximum Baseline case, but are still significant. For example, the estimated cumulative greenhouse gas emissions decrease over 20 years for this very conservative set of assumptions is about 11.4 MMTonnes CO2e. Tables 5 and 6 present the detailed greenhouse gas and air pollutant emissions estimates with and without the WAGP for the P10 and P90 demand/throughput scenarios, respectively. Consistent with the definitions of these scenarios, the P10 case results in higher emissions than the P50 case for both the Project and No Project cases, and the P90 case emissions are lower than for P50. The P10 and P90 emissions calculations have been performed only for the Maximum Baseline scenario. The results summarized in Tables 2 through 6 show that total emissions of greenhouse gases and air pollutants in Nigeria and the receiving countries will decrease as a result of the WAGP over the full range of energy demand scenarios postulated by P&G, regardless of the baseline scenario assumed. The actual magnitude of the reductions that will be realized will likely be intermediate between the results obtained for the two extreme baseline scenarios addressed in this study. 8 TABLE 1: SUMMARY OF PROJECT AND BASELINE SCENARIOS Current Situation: Flaring of associated gas in Nigeria Some liquid fuel-fired power generation in Ghana, Togo & Benin Project Scenario Associated gas and non-associated gas are gathered and exported to Ghana, Togo & Benin and flaring is reduced to the extent of the AG supplied. Existing oil-fired power generation in Ghana, Togo and Benin is switched to gas. New power generation and industrial consumption in Ghana, Togo and Benin use gas up to the volume shipped by the pipeline (some of these projects are dependent on a supply of gas, others are not). Maximum Baseline Assumptions In the absence of WAGP, A volume of gas equal to the associated gas portion of the WAGP throughput would have been flared in Nigeria until 2025. Existing oil-fired power generation in Ghana, Togo and Benin would have continued to use liquid fuels. All new power generation and industrial consumption in Ghana, Togo and Benin would have used liquid fuels as the primary fuels. New power/industrial projects in Ghana. Togo and Benin that are contingent on an available gas supply (Strategic Projects) would have used gas from another source as their primary fuel. Minimum Baseline Assumptions In the absence of WAGP, It is assumed that flaring would have continued in Nigeria until 2025, but only the associated gas portion of the WAGP throughput is included in the baseline. Existing power generation plants in Ghana, Togo and Benin would have continued to operate with their current fuels and the resulting emissions are included in the baseline. All future new power and industrial projects in Ghana, Togo and Benin would not have been implemented without WAGP. 9 TABLE 2: SUMMARY OF ESTIMATED TOTAL GHG AND AIR POLLUTANT EMISSIONS CHANGES DUE TO WAGP OVER THE FIRST 20 YEARS OF THE PROJECT P-10 P-50 P-90 P-50 Market Market Market Minimum Forecast Forecast Forecast Baseline Greenhouse Gas Emissions, tonnes CO2 Eq/yr Nigeria -70,078,657-59,103,459-47,930,590-59,103,459 Ghana -15,914,496-15,934,514-10,903,553 31,428,566 Benin -4,961,934 -4,347,765 -3,418,603 12,371,033 Togo -5,280,332 -6,378,434 -3,637,941 3,914,246 Total -96,235,419-85,764,171-65,890,687-11,389,613 NOx Emissions, tonnes/yr Nigeria -32,369 -27,282 -22,111 -27,282 Ghana -333,152 -297,402 -230,267 -55,724 Benin -61,222 -62,671 -42,130 12,070 Togo -62,912 -66,862 -43,294 -32,276 Total -489,655 -454,218 -337,803 -103,213 CO Emissions, tonnes/yr Nigeria -197,844 -166,876 -135,344 -166,876 Ghana 56,313 47,770 39,023 49,759 Benin 10,317 8,732 7,114 10,166 Togo 11,253 9,512 7,759 11,410 Total -119,961 -100,862 -81,448 -95,542 SO2 Emissions, tonnes/yr Nigeria -501 -423 -343 -423 Ghana -654,987 -571,288 -453,110 -275,566 Benin -143,869 -122,781 -99,271 -18,448 Togo -159,853 -147,311 -110,282 -83,130 Total -959,211 -841,803 -663,006 -377,567 PM10 Emissions, tonnes/yr Nigeria -5,523 -3,832 -3,778 -4,658 Ghana -4,315 -1,871 -2,982 856 Benin -2,189 -2,488 -1,519 635 Togo -2,803 -12,849 -1,941 -56 Total -14,830 -21,040 -10,221 -3,223 VOC Emissions, tonnes/yr Nigeria -2,765 1,232 -1,891 -2,332 Ghana 1,455 176 1,011 1,510 Benin 208 185 143 387 Togo 223 -739 154 441 Total -878 854 -583 7 10 TABLE 3 West African Gas Pipeline OVERALL EMISSIONS SUMMARY P50 EMISSIONS - MAXIMUM BASELINE SCENARIO P50 Demand with Maximum Baseliine Scenario (NOTE: Flaring in Nigeria for Baseline Scenario Includes only the portion of the WAGP throughput that would be flared in the absence of WAGP) Greenhouse Gas Emissions, tonnes CO2 Eq./yr 2005 2006 2007 2008 2009 2010 2011 2012 2013 2014 2015 2016 2017 2018 2019 2020 2021 2022 2023 2024 2025 TOTAL No Project (Baseline) Nigeria 728,383 1,372,288 1,403,909 1,502,404 1,731,577 1,818,315 2,069,671 2,411,872 2,601,176 2,854,269 3,010,622 3,146,035 3,387,592 3,480,615 3,774,442 3,879,425 4,058,895 4,102,610 4,188,918 4,469,096 4,464,542 Ghana 2,224,793 2,224,793 2,224,793 2,224,793 2,224,793 2,296,817 2,495,188 2,955,968 3,154,339 3,512,909 3,818,080 4,072,145 4,564,214 4,762,585 5,604,045 5,991,610 6,566,072 6,846,837 7,263,396 8,189,545 8,365,805 Benin 148,661 432,322 432,322 441,758 521,812 539,163 657,711 743,876 832,078 940,416 999,303 1,069,406 1,125,999 1,187,181 1,230,263 1,266,462 1,322,797 1,365,621 1,408,446 1,478,291 1,548,136 Togo 725,879 725,879 725,879 725,879 725,879 725,879 731,139 856,313 999,586 1,117,103 1,169,106 1,234,619 1,279,739 1,329,448 1,365,646 1,397,256 1,453,590 1,498,710 1,541,535 1,613,674 1,683,519 TOTAL 3,827,716 4,755,281 4,786,903 4,894,833 5,204,061 5,380,174 5,953,710 6,968,029 7,587,180 8,424,697 8,997,111 9,522,205 10,357,543 10,759,828 11,974,397 12,534,752 13,401,354 13,813,779 14,402,295 15,750,606 16,062,003 195,358,457 With Project Nigeria 8,320 24,205 25,213 27,483 32,273 34,542 40,089 47,653 52,444 58,747 63,285 67,572 74,379 78,161 86,734 91,272 97,828 101,358 106,148 116,233 119,259 Ghana 665,632 1,290,922 1,391,775 1,510,580 1,738,000 1,874,756 2,096,354 2,535,740 2,733,217 3,051,718 3,331,888 3,587,798 4,037,304 4,240,811 4,896,253 5,190,703 5,626,347 5,840,114 6,156,745 6,858,628 6,993,722 Benin 0 322,730 322,730 332,746 401,124 425,071 523,670 592,153 660,670 743,328 789,665 844,077 888,404 936,751 970,992 999,203 1,041,554 1,073,820 1,106,087 1,158,523 1,210,960 Togo 0 322,730 322,730 346,817 429,266 451,202 587,993 690,648 807,407 898,106 938,412 988,804 1,023,080 1,061,377 1,089,588 1,113,778 1,156,130 1,190,406 1,222,672 1,277,119 1,329,556 TOTAL 673,952 1,960,588 2,062,449 2,217,625 2,600,662 2,785,571 3,248,107 3,866,194 4,253,739 4,751,899 5,123,251 5,488,251 6,023,167 6,317,100 7,043,566 7,394,956 7,921,859 8,205,698 8,591,651 9,410,503 9,653,497 109,594,286 CHANGE (Project-No Project) -3,153,764 -2,794,694 -2,724,453 -2,677,208 -2,603,399 -2,594,603 -2,705,603 -3,101,835 -3,333,441 -3,672,798 -3,873,860 -4,033,955 -4,334,377 -4,442,729 -4,930,831 -5,139,796 -5,479,496 -5,608,080 -5,810,644 -6,340,103 -6,408,506 -85,764,171 NOx Emissions, tonnes/yr 2005 2006 2007 2008 2009 2010 2011 2012 2013 2014 2015 2016 2017 2018 2019 2020 2021 2022 2023 2024 2025 TOTAL No Project (Baseline) Nigeria 372 700 716 766 883 927 1,056 1,230 1,327 1,456 1,536 1,605 1,728 1,775 1,925 1,979 2,070 2,093 2,137 2,280 2,277 Ghana 12,140 12,140 12,140 12,140 12,140 12,140 12,731 15,221 16,264 18,180 19,805 21,143 23,788 24,830 29,374 31,440 34,527 36,011 38,227 43,217 44,122 Benin 811 2,359 2,359 2,330 2,534 2,331 2,704 3,062 3,471 4,014 4,271 4,597 4,850 5,111 5,290 5,455 5,755 5,980 6,206 6,579 17,035 Togo 3,961 3,961 3,961 3,961 3,961 3,961 3,961 3,961 3,961 4,359 4,603 4,920 5,150 5,389 5,554 5,711 6,010 6,240 6,466 6,843 7,217 TOTAL 17,284 19,160 19,176 19,198 19,518 19,360 20,452 23,475 25,022 28,009 30,214 32,265 35,516 37,106 42,143 44,585 48,362 50,324 53,036 58,919 70,652 713,776 With Project Nigeria 22 64 66 72 85 91 105 125 138 154 166 177 195 205 228 240 257 266 279 305 313 Ghana 1,748 3,391 3,656 3,901 4,329 4,555 5,044 6,088 6,542 7,314 7,982 8,569 9,651 10,114 11,800 12,560 13,690 14,238 15,053 16,879 17,217 Benin 0 848 848 851 964 941 1,121 1,269 1,428 1,631 1,735 1,861 1,962 2,068 2,142 2,207 2,315 2,398 2,480 2,616 2,751 Togo 0 848 848 872 1,005 980 1,216 1,415 1,645 1,860 1,954 2,075 2,161 2,252 2,317 2,376 2,485 2,570 2,653 2,791 2,926 TOTAL 1,770 5,150 5,417 5,695 6,383 6,566 7,488 8,896 9,753 10,959 11,838 12,683 13,968 14,639 16,487 17,382 18,748 19,472 20,465 22,591 23,208 259,558 CHANGE (Project-No Project) -15,514 -14,010 -13,759 -13,502 -13,135 -12,794 -12,965 -14,578 -15,270 -17,049 -18,376 -19,582 -21,547 -22,467 -25,657 -27,203 -29,615 -30,852 -32,571 -36,328 -47,444 -454,218 CO Emissions, tonnes/yr 2005 2006 2007 2008 2009 2010 2011 2012 2013 2014 2015 2016 2017 2018 2019 2020 2021 2022 2023 2024 2025 TOTAL No Project (Baseline) Nigeria 2,022 3,809 3,896 4,170 4,806 5,046 5,744 6,694 7,219 7,922 8,355 8,731 9,402 9,660 10,475 10,767 11,265 11,386 11,626 12,403 12,391 Ghana 46 46 46 51 78 92 98 109 115 125 133 141 153 159 179 190 204 212 224 246 253 Benin 3 9 9 13 27 44 61 69 74 79 84 88 92 97 101 104 105 107 108 110 112 Togo 15 9 9 17 34 50 76 92 109 116 119 122 124 127 129 131 132 134 136 138 140 TOTAL 2,085 3,872 3,960 4,250 4,945 5,232 5,979 6,963 7,518 8,241 8,691 9,083 9,771 10,043 10,885 11,191 11,706 11,839 12,093 12,897 12,895 174,139 With Project Nigeria 6 16 17 18 22 23 27 32 35 40 43 45 50 53 58 61 66 68 71 78 80 Ghana 448 869 937 1,016 1,166 1,255 1,403 1,697 1,829 2,042 2,229 2,400 2,701 2,837 3,277 3,475 3,768 3,912 4,125 4,597 4,687 Benin 0 217 217 224 268 283 348 394 439 495 526 562 592 624 647 665 694 715 737 772 808 Togo 0 217 217 233 287 300 390 458 535 596 623 657 680 705 724 740 769 792 813 850 885 TOTAL 454 1,320 1,388 1,490 1,743 1,862 2,168 2,581 2,839 3,172 3,420 3,664 4,022 4,218 4,706 4,942 5,297 5,487 5,747 6,297 6,460 73,277 CHANGE (Project-No Project) -1,631 -2,552 -2,571 -2,760 -3,202 -3,370 -3,811 -4,383 -4,679 -5,069 -5,271 -5,418 -5,749 -5,825 -6,179 -6,249 -6,410 -6,352 -6,346 -6,600 -6,434 -100,862 SO2 Emissions, tonnes/yr 2005 2006 2007 2008 2009 2010 2011 2012 2013 2014 2015 2016 2017 2018 2019 2020 2021 2022 2023 2024 2025 TOTAL No Project (Baseline) Nigeria 5 10 10 11 12 13 15 17 19 20 22 23 24 25 27 28 29 29 30 32 32 Ghana 13,894 13,894 13,894 13,894 13,894 14,341 15,579 18,457 19,696 21,935 23,841 25,427 28,500 29,739 34,993 37,414 41,001 42,754 45,356 51,139 52,240 Benin 928 2,700 2,700 2,759 3,258 3,365 4,104 4,642 5,192 5,869 6,236 6,674 7,027 7,409 7,678 7,904 8,255 8,523 8,790 9,226 9,663 Togo 4,533 4,533 4,533 4,533 4,533 4,533 4,562 5,342 6,236 6,970 7,294 7,703 7,985 8,295 8,521 8,719 9,071 9,352 9,620 10,070 10,506 TOTAL 19,361 21,137 21,137 21,197 21,697 22,252 24,260 28,459 31,143 34,794 37,393 39,827 43,536 45,468 51,220 54,064 58,356 60,659 63,796 70,468 72,441 842,664 With Project Nigeria 0 0 0 0 0 0 0 0 0 0 0 1 1 1 1 1 1 1 1 1 1 Ghana 5 10 11 12 14 15 16 20 21 24 26 28 32 33 38 41 44 46 48 54 55 Benin 0 3 3 3 3 3 4 5 5 6 6 7 7 7 8 8 8 8 9 9 10 Togo 0 3 3 3 3 4 5 5 6 7 7 8 8 8 9 9 9 9 10 10 10 TOTAL 5 15 16 17 20 22 26 30 33 37 40 43 47 50 55 58 62 64 67 74 76 861 CHANGE (Project-No Project) -19,356 -21,122 -21,121 -21,179 -21,677 -22,230 -24,235 -28,428 -31,109 -34,757 -37,353 -39,784 -43,489 -45,418 -51,164 -54,006 -58,294 -60,594 -63,728 -70,394 -72,365 -841,803 2004 Emissions Summary-Final-5-20-04.xls 5/27/2004 TABLE 3 West African Gas Pipeline P50 EMISSIONS - MAXIMUM BASELINE SCENARIO PM10 Emissions, tonnes/yr 2005 2006 2007 2008 2009 2010 2011 2012 2013 2014 2015 2016 2017 2018 2019 2020 2021 2022 2023 2024 2025 TOTAL No Project (Baseline) Nigeria 57 107 110 118 136 142 162 189 204 223 236 246 265 272 295 304 318 321 328 350 349 Ghana 166 166 166 166 202 223 240 276 293 322 348 370 409 426 491 523 569 593 627 700 717 Benin 11 32 32 38 58 78 104 117 128 139 147 156 164 173 179 184 189 192 196 202 208 Togo 54 54 54 54 68 87 125 150 177 190 197 204 208 214 219 222 227 231 235 241 247 TOTAL 288 359 362 375 463 530 631 731 802 875 927 976 1,046 1,085 1,185 1,233 1,302 1,338 1,386 1,493 1,521 18,908 With Project Nigeria 0 1 1 1 2 2 2 3 3 3 3 4 4 4 5 5 5 5 6 6 6 Ghana 36 70 75 82 95 103 116 140 151 168 184 198 223 234 270 286 309 321 338 376 384 Benin 0 17 17 18 22 24 29 33 37 42 44 47 50 52 54 56 58 60 62 65 67 Togo 0 17 17 19 24 25 33 39 46 51 53 56 58 60 61 63 65 67 69 72 74 TOTAL 37 106 112 121 143 154 180 215 237 264 284 305 334 351 390 409 438 453 474 519 532 6,059 CHANGE (Project-No Project) -251 -253 -250 -254 -320 -376 -450 -517 -565 -611 -643 -671 -712 -735 -795 -824 -864 -884 -912 -974 -989 -12,849 VOC Emissions, tonnes/yr 2005 2006 2007 2008 2009 2010 2011 2012 2013 2014 2015 2016 2017 2018 2019 2020 2021 2022 2023 2024 2025 TOTAL No Project (Baseline) Nigeria 28 53 55 59 67 71 81 94 101 111 117 123 132 136 147 151 158 160 163 174 174 Ghana 6 6 6 7 11 13 14 15 16 17 18 19 21 22 24 26 27 29 30 33 34 Benin 0 1 1 2 4 6 9 10 11 12 12 13 14 14 15 15 15 16 16 16 16 Togo 2 2 2 2 5 7 11 14 16 17 18 18 18 19 19 19 20 20 20 20 21 TOTAL 36 62 63 69 87 97 115 133 144 157 166 173 185 190 205 211 221 224 229 244 245 3,257 With Project Nigeria 0 0 0 0 1 1 1 1 1 1 1 1 1 1 1 2 2 2 2 2 2 Ghana 11 22 24 28 35 41 46 56 61 68 75 81 91 96 108 113 121 125 131 143 146 Benin 0 6 6 6 9 11 15 17 18 20 21 22 24 25 26 27 27 28 29 29 30 Togo 0 6 6 7 10 12 17 21 24 27 28 29 29 30 31 31 32 33 33 35 35 TOTAL 12 34 36 41 55 65 79 95 105 116 124 133 145 152 166 173 182 188 195 209 214 2,518 CHANGE (Project-No Project) -25 -28 -28 -28 -32 -33 -35 -38 -40 -41 -41 -40 -40 -38 -39 -39 -38 -36 -34 -34 -31 -739 2004 Emissions Summary-Final-5-20-04.xls 5/27/2004 TABLE 4 West African Gas Pipeline P50 EMISSIONS - MINIMUM BASELINE SCENARIO OVERALL EMISSIONS SUMMARY P50 Demand with Minimum Baseline Scenario (NOTE: Flaring in Nigeria for Baseline Scenario Includes only the portion of the WAGP throughput that would be flared in the absence of WAGP) This analysis is based on the assumpation that no new power projects or commercial/industrial projects are developed in the absence of the pipeline. Therefore, the emissions baseline is based only on flaring. Greenhouse Gas Emissions, tonnes CO2 Eq./yr 2005 2006 2007 2008 2009 2010 2011 2012 2013 2014 2015 2016 2017 2018 2019 2020 2021 2022 2023 2024 2025 TOTAL No Project (Baseline) Nigeria 728,383 1,372,288 1,403,909 1,502,404 1,731,577 1,818,315 2,069,671 2,411,872 2,601,176 2,854,269 3,010,622 3,146,035 3,387,592 3,480,615 3,774,442 3,879,425 4,058,895 4,102,610 4,188,918 4,469,096 4,464,542 Ghana 891,664 1,708,784 1,842,283 1,977,453 2,203,573 2,224,793 2,224,793 2,224,793 2,224,793 2,224,793 2,224,793 2,224,793 2,224,793 2,224,793 2,224,793 2,224,793 2,224,793 2,224,793 2,224,793 2,224,793 2,224,793 Benin 0 148,661 148,661 148,661 148,661 148,661 148,661 148,661 148,661 148,661 148,661 148,661 148,661 148,661 148,661 148,661 148,661 148,661 148,661 148,661 148,661 Togo 0 432,322 432,322 457,821 553,937 568,994 725,879 725,879 725,879 725,879 725,879 725,879 725,879 725,879 725,879 725,879 725,879 725,879 725,879 725,879 725,879 TOTAL 1,620,047 3,662,055 3,827,175 4,086,339 4,637,749 4,760,763 5,169,004 5,511,205 5,700,509 5,953,602 6,109,954 6,245,367 6,486,925 6,579,947 6,873,775 6,978,758 7,158,228 7,201,943 7,288,251 7,568,429 7,563,875 120,983,899 With Project Nigeria 8,320 24,205 25,213 27,483 32,273 34,542 40,089 47,653 52,444 58,747 63,285 67,572 74,379 78,161 86,734 91,272 97,828 101,358 106,148 116,233 119,259 Ghana 665,632 1,290,922 1,391,775 1,510,580 1,738,000 1,874,756 2,096,354 2,535,740 2,733,217 3,051,718 3,331,888 3,587,798 4,037,304 4,240,811 4,896,253 5,190,703 5,626,347 5,840,114 6,156,745 6,858,628 6,993,722 Benin 0 322,730 322,730 332,746 401,124 425,071 523,670 592,153 660,670 743,328 789,665 844,077 888,404 936,751 970,992 999,203 1,041,554 1,073,820 1,106,087 1,158,523 1,210,960 Togo 0 322,730 322,730 346,817 429,266 451,202 587,993 690,648 807,407 898,106 938,412 988,804 1,023,080 1,061,377 1,089,588 1,113,778 1,156,130 1,190,406 1,222,672 1,277,119 1,329,556 TOTAL 673,952 1,960,588 2,062,449 2,217,625 2,600,662 2,785,571 3,248,107 3,866,194 4,253,739 4,751,899 5,123,251 5,488,251 6,023,167 6,317,100 7,043,566 7,394,956 7,921,859 8,205,698 8,591,651 9,410,503 9,653,497 109,594,286 CHANGE (Project-No Project) -946,095 -1,701,468 -1,764,726 -1,868,713 -2,037,086 -1,975,191 -1,920,897 -1,645,011 -1,446,770 -1,201,702 -986,703 -757,117 -463,758 -262,848 169,791 416,199 763,631 1,003,755 1,303,400 1,842,075 2,089,622 -11,389,613 NOx Emissions, tonnes/yr 2005 2006 2007 2008 2009 2010 2011 2012 2013 2014 2015 2016 2017 2018 2019 2020 2021 2022 2023 2024 2025 TOTAL No Project (Baseline) Nigeria 372 700 716 766 883 927 1,056 1,230 1,327 1,456 1,536 1,605 1,728 1,775 1,925 1,979 2,070 2,093 2,137 2,280 2,277 Ghana 4,866 9,324 10,053 10,598 11,413 11,689 12,140 12,140 12,140 12,140 12,140 12,140 12,140 12,140 12,140 12,140 12,140 12,140 12,140 12,140 12,140 Benin 0 811 811 811 811 811 811 811 811 811 811 811 811 811 811 811 811 811 811 811 6,952 Togo 0 2,359 2,359 2,362 2,597 2,389 2,848 3,282 3,798 3,961 3,961 3,961 3,961 3,961 3,961 3,961 3,961 3,961 3,961 3,961 3,961 TOTAL 5,237 13,195 13,939 14,537 15,704 15,817 16,855 17,463 18,076 18,368 18,448 18,517 18,640 18,688 18,838 18,891 18,983 19,005 19,049 19,192 25,331 362,771 With Project Nigeria 22 64 66 72 85 91 105 125 138 154 166 177 195 205 228 240 257 266 279 305 313 Ghana 1,748 3,391 3,656 3,901 4,329 4,555 5,044 6,088 6,542 7,314 7,982 8,569 9,651 10,114 11,800 12,560 13,690 14,238 15,053 16,879 17,217 Benin 0 848 848 851 964 941 1,121 1,269 1,428 1,631 1,735 1,861 1,962 2,068 2,142 2,207 2,315 2,398 2,480 2,616 2,751 Togo 0 848 848 872 1,005 980 1,216 1,415 1,645 1,860 1,954 2,075 2,161 2,252 2,317 2,376 2,485 2,570 2,653 2,791 2,926 TOTAL 1,770 5,150 5,417 5,695 6,383 6,566 7,488 8,896 9,753 10,959 11,838 12,683 13,968 14,639 16,487 17,382 18,748 19,472 20,465 22,591 23,208 259,558 CHANGE (Project-No Project) -3,467 -8,045 -8,522 -8,841 -9,321 -9,251 -9,367 -8,567 -8,324 -7,409 -6,610 -5,834 -4,672 -4,049 -2,351 -1,509 -235 467 1,416 3,399 -2,122 -103,213 CO Emissions, tonnes/yr 2005 2006 2007 2008 2009 2010 2011 2012 2013 2014 2015 2016 2017 2018 2019 2020 2021 2022 2023 2024 2025 TOTAL No Project (Baseline) Nigeria 2,022 3,809 3,896 4,170 4,806 5,046 5,744 6,694 7,219 7,922 8,355 8,731 9,402 9,660 10,475 10,767 11,265 11,386 11,626 12,403 12,391 Ghana 18 35 38 46 46 46 46 46 46 46 46 46 46 46 46 46 46 46 46 46 46 Benin 0 3 3 3 3 3 3 3 3 3 3 3 3 3 3 3 3 3 3 3 3 Togo 0 3 3 3 3 3 3 3 3 3 3 3 3 3 3 3 3 3 3 3 3 TOTAL 2,040 3,850 3,940 4,221 4,857 5,098 5,796 6,745 7,271 7,973 8,407 8,783 9,453 9,711 10,527 10,818 11,316 11,438 11,677 12,455 12,442 168,819 With Project Nigeria 6 16 17 18 22 23 27 32 35 40 43 45 50 53 58 61 66 68 71 78 80 Ghana 448 869 937 1,016 1,166 1,255 1,403 1,697 1,829 2,042 2,229 2,400 2,701 2,837 3,277 3,475 3,768 3,912 4,125 4,597 4,687 Benin 0 217 217 224 268 283 348 394 439 495 526 562 592 624 647 665 694 715 737 772 808 Togo 0 217 217 233 287 300 390 458 535 596 623 657 680 705 724 740 769 792 813 850 885 TOTAL 454 1,320 1,388 1,490 1,743 1,862 2,168 2,581 2,839 3,172 3,420 3,664 4,022 4,218 4,706 4,942 5,297 5,487 5,747 6,297 6,460 73,277 CHANGE (Project-No Project) -1,586 -2,530 -2,552 -2,731 -3,115 -3,236 -3,627 -4,165 -4,432 -4,801 -4,987 -5,119 -5,431 -5,493 -5,821 -5,876 -6,020 -5,951 -5,931 -6,158 -5,982 -95,542 SO2 Emissions, tonnes/yr 2005 2006 2007 2008 2009 2010 2011 2012 2013 2014 2015 2016 2017 2018 2019 2020 2021 2022 2023 2024 2025 TOTAL No Project (Baseline) Nigeria 5 10 10 11 12 13 15 17 19 20 22 23 24 25 27 28 29 29 30 32 32 Ghana 5,569 10,672 11,505 12,349 13,759 13,894 13,894 13,894 13,894 13,894 13,894 13,894 13,894 13,894 13,894 13,894 13,894 13,894 13,894 13,894 13,894 Benin 0 928 928 928 928 928 928 928 928 928 928 928 928 928 928 928 928 928 928 928 928 Togo 0 2,700 2,700 2,859 3,458 3,551 4,533 4,533 4,533 4,533 4,533 4,533 4,533 4,533 4,533 4,533 4,533 4,533 4,533 4,533 4,533 TOTAL 5,574 14,310 15,144 16,147 18,158 18,386 19,371 19,373 19,374 19,376 19,377 19,378 19,380 19,381 19,383 19,384 19,385 19,385 19,386 19,388 19,388 378,427 With Project Nigeria 0 0 0 0 0 0 0 0 0 0 0 1 1 1 1 1 1 1 1 1 1 Ghana 5 10 11 12 14 15 16 20 21 24 26 28 32 33 38 41 44 46 48 54 55 Benin 0 3 3 3 3 3 4 5 5 6 6 7 7 7 8 8 8 8 9 9 10 Togo 0 3 3 3 3 4 5 5 6 7 7 8 8 8 9 9 9 9 10 10 10 TOTAL 5 15 16 17 20 22 26 30 33 37 40 43 47 50 55 58 62 64 67 74 76 861 CHANGE (Project-No Project) -5,569 -14,294 -15,128 -16,129 -18,138 -18,364 -19,345 -19,343 -19,341 -19,339 -19,337 -19,335 -19,333 -19,331 -19,328 -19,326 -19,323 -19,321 -19,318 -19,314 -19,312 -377,567 2004 Emissions Summary-Final-5-20-04.xls 5/27/2004 TABLE 4 West African Gas Pipeline P50 EMISSIONS - MINIMUM BASELINE SCENARIO PM10 Emissions, tonnes/yr 2005 2006 2007 2008 2009 2010 2011 2012 2013 2014 2015 2016 2017 2018 2019 2020 2021 2022 2023 2024 2025 TOTAL No Project (Baseline) Nigeria 57 107 110 118 136 142 162 189 204 223 236 246 265 272 295 304 318 321 328 350 349 Ghana 66 127 137 159 166 166 166 166 166 166 166 166 166 166 166 166 166 166 166 166 166 Benin 0 11 11 11 11 11 11 11 11 11 11 11 11 11 11 11 11 11 11 11 11 Togo 0 32 32 43 54 54 54 54 54 54 54 54 54 54 54 54 54 54 54 54 54 TOTAL 123 278 290 330 366 373 393 419 434 454 466 477 496 503 526 534 548 552 558 580 580 9,282 With Project Nigeria 0 1 1 1 2 2 2 3 3 3 3 4 4 4 5 5 5 5 6 6 6 Ghana 36 70 75 82 95 103 116 140 151 168 184 198 223 234 270 286 309 321 338 376 384 Benin 0 17 17 18 22 24 29 33 37 42 44 47 50 52 54 56 58 60 62 65 67 Togo 0 17 17 19 24 25 33 39 46 51 53 56 58 60 61 63 65 67 69 72 74 TOTAL 37 106 112 121 143 154 180 215 237 264 284 305 334 351 390 409 438 453 474 519 532 6,059 CHANGE (Project-No Project) -87 -172 -178 -210 -223 -219 -212 -205 -198 -190 -182 -172 -162 -152 -136 -125 -110 -98 -84 -61 -48 -3,223 VOC Emissions, tonnes/yr 2005 2006 2007 2008 2009 2010 2011 2012 2013 2014 2015 2016 2017 2018 2019 2020 2021 2022 2023 2024 2025 TOTAL No Project (Baseline) Nigeria 28 53 55 59 67 71 81 94 101 111 117 123 132 136 147 151 158 160 163 174 174 Ghana 2 4 5 6 6 6 6 6 6 6 6 6 6 6 6 6 6 6 6 6 6 Benin 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 Togo 0 1 1 2 2 2 2 2 2 2 2 2 2 2 2 2 2 2 2 2 2 TOTAL 31 59 61 66 75 79 89 102 109 119 125 130 140 143 155 159 166 168 171 182 182 2,511 With Project Nigeria 0 0 0 0 1 1 1 1 1 1 1 1 1 1 1 2 2 2 2 2 2 Ghana 11 22 24 28 35 41 46 56 61 68 75 81 91 96 108 113 121 125 131 143 146 Benin 0 6 6 6 9 11 15 17 18 20 21 22 24 25 26 27 27 28 29 29 30 Togo 0 6 6 7 10 12 17 21 24 27 28 29 29 30 31 31 32 33 33 35 35 TOTAL 12 34 36 41 55 65 79 95 105 116 124 133 145 152 166 173 182 188 195 209 214 2,518 CHANGE (Project-No Project) -19 -25 -25 -25 -21 -14 -9 -7 -4 -3 -1 3 5 9 11 14 16 20 24 28 32 7 2004 Emissions Summary-Final-5-20-04.xls 5/27/2004 TABLE 5 West African Gas Pipeline OVERALL EMISSIONS SUMMARY P10 EMISSIONS - MAXIMUM BASELINE SCENARIO P10 Demand Scenario (NOTE: Flaring in Nigeria for Baseline Scenario Includes only the portion of the WAGP throughput that would be flared in the absence of WAGP) Greenhouse Gas Emissions, tonnes CO2 Eq./yr 2005 2006 2007 2008 2009 2010 2011 2012 2013 2014 2015 2016 2017 2018 2019 2020 2021 2022 2023 2024 2025 TOTAL No Project (Baseline) Nigeria 1,081,539 1,829,717 1,825,082 1,874,559 2,069,776 2,243,031 2,499,226 2,998,889 3,201,448 3,540,274 3,610,347 3,873,849 4,030,660 3,997,093 4,399,859 4,447,407 4,623,793 4,633,296 4,696,364 5,138,006 5,059,185 Ghana 1,323,986 2,278,379 2,394,968 2,467,281 2,633,958 2,833,300 3,013,058 3,675,410 3,882,264 4,357,214 4,578,653 5,014,209 5,430,641 5,469,291 6,532,623 6,868,834 7,479,907 7,732,498 8,143,285 9,415,312 9,480,067 Benin 0 576,429 562,018 551,184 623,729 665,099 794,217 924,925 1,024,096 1,166,439 1,198,368 1,316,806 1,339,748 1,363,343 1,434,115 1,451,883 1,506,897 1,542,269 1,579,066 1,699,554 1,754,336 Togo 0 576,429 562,018 571,226 662,128 701,897 882,885 1,064,728 1,230,260 1,385,591 1,401,996 1,520,240 1,522,672 1,526,720 1,591,931 1,601,826 1,655,894 1,692,573 1,728,276 1,855,200 1,907,751 TOTAL 2,405,524 5,260,954 5,344,087 5,464,250 5,989,591 6,443,328 7,189,386 8,663,952 9,338,067 10,449,517 10,789,364 11,725,104 12,323,721 12,356,448 13,958,527 14,369,950 15,266,491 15,600,635 16,146,991 18,108,072 18,201,339 225,395,298 With Project Nigeria 12,355 32,273 32,777 34,290 38,576 42,611 48,410 59,251 64,546 72,866 75,892 83,204 88,499 89,759 101,105 104,635 111,443 114,468 119,007 133,631 135,143 Ghana 988,362 1,721,229 1,809,308 1,884,760 2,077,453 2,312,655 2,531,447 3,152,904 3,363,960 3,785,179 3,995,611 4,417,811 4,803,707 4,870,093 5,707,551 5,950,667 6,409,395 6,595,552 6,902,574 7,885,190 7,925,233 Benin 0 430,307 419,550 415,169 479,469 524,358 632,357 736,275 813,133 921,982 946,969 1,039,349 1,057,050 1,075,752 1,131,883 1,145,495 1,186,513 1,212,723 1,240,078 1,331,925 1,372,251 Togo 0 430,307 419,550 432,726 513,106 556,593 710,030 858,742 993,732 1,113,959 1,125,347 1,217,557 1,217,292 1,218,871 1,270,130 1,276,845 1,317,034 1,344,389 1,370,787 1,468,271 1,506,642 TOTAL 1,000,717 2,614,117 2,681,184 2,766,945 3,108,604 3,436,216 3,922,243 4,807,172 5,235,371 5,893,987 6,143,819 6,757,920 7,166,548 7,254,476 8,210,669 8,477,643 9,024,386 9,267,132 9,632,445 10,819,017 10,939,269 CHANGE (Project-No Project) -1,404,808 -2,646,837 -2,662,902 -2,697,304 -2,880,987 -3,007,112 -3,267,143 -3,856,779 -4,102,696 -4,555,530 -4,645,545 -4,967,183 -5,157,173 -5,101,972 -5,747,858 -5,892,307 -6,242,106 -6,333,504 -6,514,546 -7,289,055 -7,262,070 -225,395,298 NOx Emissions, tonnes/yr 2005 2006 2007 2008 2009 2010 2011 2012 2013 2014 2015 2016 2017 2018 2019 2020 2021 2022 2023 2024 2025 TOTAL No Project (Baseline) Nigeria 552 933 931 956 1,056 1,144 1,275 1,530 1,633 1,806 1,841 1,976 2,056 2,039 2,244 2,268 2,358 2,363 2,395 2,621 2,580 Ghana 7,225 12,433 13,069 13,223 13,642 14,419 15,373 18,926 20,017 22,550 23,750 26,035 28,304 28,515 34,241 36,044 39,332 40,669 42,858 49,685 49,999 Benin 0 3,145 3,067 2,907 3,029 2,875 3,266 3,807 4,272 4,979 5,122 5,661 5,770 5,870 6,167 6,254 6,556 6,754 6,958 7,564 7,878 Togo 0 3,145 3,067 2,946 3,104 2,947 3,439 4,080 4,675 5,407 5,519 6,058 6,128 6,189 6,475 6,547 6,847 7,047 7,249 7,868 8,178 TOTAL 7,776 19,657 20,133 20,033 20,831 21,386 23,353 28,343 30,596 34,741 36,233 39,729 42,258 42,612 49,126 51,113 55,093 56,834 59,461 67,738 68,636 795,681 With Project Nigeria 32 85 86 90 101 112 127 156 170 191 199 219 232 236 266 275 293 301 313 351 355 Ghana 2,596 4,521 4,752 4,867 5,175 5,619 6,091 7,569 8,051 9,071 9,573 10,552 11,483 11,614 13,756 14,399 15,596 16,080 16,877 19,405 19,510 Benin 0 1,130 1,102 1,062 1,152 1,161 1,354 1,578 1,758 2,024 2,080 2,292 2,334 2,375 2,497 2,530 2,638 2,708 2,781 3,007 3,118 Togo 0 1,130 1,102 1,088 1,201 1,208 1,469 1,759 2,025 2,307 2,344 2,555 2,571 2,586 2,701 2,724 2,831 2,903 2,974 3,209 3,316 TOTAL 2,628 6,866 7,042 7,106 7,629 8,100 9,042 11,062 12,003 13,593 14,196 15,618 16,620 16,811 19,219 19,927 21,357 21,991 22,944 25,972 26,299 306,025 CHANGE (Project-No Project) -5,148 -12,791 -13,091 -12,926 -13,201 -13,286 -14,311 -17,282 -18,593 -21,147 -22,037 -24,112 -25,638 -25,801 -29,908 -31,186 -33,736 -34,842 -36,516 -41,766 -42,336 -489,655 CO Emissions, tonnes/yr 2005 2006 2007 2008 2009 2010 2011 2012 2013 2014 2015 2016 2017 2018 2019 2020 2021 2022 2023 2024 2025 TOTAL No Project (Baseline) Nigeria 3,002 5,078 5,065 5,203 5,744 6,225 6,936 8,323 8,885 9,825 10,020 10,751 11,186 11,093 12,211 12,343 12,833 12,859 13,034 14,260 14,041 Ghana 27 47 49 63 93 114 119 136 142 155 160 174 182 183 209 217 232 240 251 283 287 Benin 0 12 12 17 33 54 73 85 91 98 100 108 110 112 118 119 120 120 121 126 126 Togo 0 12 12 21 41 62 92 114 134 143 143 151 148 146 151 150 151 152 152 159 158 TOTAL 3,029 5,148 5,137 5,303 5,911 6,454 7,220 8,658 9,252 10,222 10,422 11,184 11,626 11,534 12,689 12,829 13,336 13,371 13,558 14,827 14,612 206,322 With Project Nigeria 8 22 22 23 26 29 33 40 43 49 51 56 60 60 68 70 75 77 80 90 91 Ghana 665 1,158 1,218 1,267 1,393 1,549 1,694 2,110 2,251 2,533 2,673 2,955 3,214 3,258 3,820 3,984 4,293 4,418 4,624 5,285 5,312 Benin 0 290 282 279 321 349 420 489 541 614 630 692 704 716 754 763 790 808 826 888 915 Togo 0 290 282 290 343 370 471 569 659 739 747 808 809 810 844 849 876 894 912 977 1,003 TOTAL 674 1,759 1,805 1,860 2,083 2,297 2,618 3,209 3,494 3,935 4,102 4,512 4,786 4,844 5,486 5,666 6,034 6,197 6,443 7,240 7,321 86,362 CHANGE (Project-No Project) -2,355 -3,389 -3,333 -3,444 -3,828 -4,157 -4,602 -5,449 -5,759 -6,287 -6,321 -6,672 -6,840 -6,690 -7,203 -7,164 -7,302 -7,174 -7,115 -7,588 -7,291 -119,961 SO2 Emissions, tonnes/yr 2005 2006 2007 2008 2009 2010 2011 2012 2013 2014 2015 2016 2017 2018 2019 2020 2021 2022 2023 2024 2025 TOTAL No Project (Baseline) Nigeria 8 13 13 13 15 16 18 22 23 25 26 28 29 29 32 32 33 33 34 37 36 Ghana 8,268 14,229 14,957 15,408 16,447 17,690 18,813 22,949 24,241 27,207 28,590 31,309 33,910 34,151 40,792 42,891 46,707 48,285 50,850 58,794 59,198 Benin 0 3,600 3,510 3,442 3,894 4,151 4,956 5,772 6,391 7,279 7,479 8,218 8,361 8,508 8,950 9,061 9,404 9,625 9,855 10,607 10,950 Togo 0 3,600 3,510 3,567 4,133 4,380 5,508 6,643 7,675 8,645 8,748 9,486 9,501 9,526 9,933 9,995 10,333 10,562 10,785 11,577 11,906 TOTAL 8,276 21,442 21,990 22,430 24,488 26,237 29,295 35,385 38,330 43,156 44,842 49,041 51,801 52,215 59,707 61,979 66,478 68,505 71,524 81,015 82,089 960,225 With Project Nigeria 0 0 0 0 0 0 0 0 1 1 1 1 1 1 1 1 1 1 1 1 1 Ghana 8 14 14 15 16 18 20 25 26 30 31 35 38 38 45 47 50 52 54 62 62 Benin 0 3 3 3 4 4 5 6 6 7 7 8 8 8 9 9 9 10 10 10 11 Togo 0 3 3 3 4 4 6 7 8 9 9 10 10 10 10 10 10 11 11 12 12 TOTAL 8 21 21 22 24 27 31 38 41 46 48 53 56 57 64 67 71 73 76 85 86 1,014 CHANGE (Project-No Project) -8,268 -21,421 -21,969 -22,408 -24,464 -26,210 -29,264 -35,347 -38,289 -43,110 -44,793 -48,987 -51,745 -52,158 -59,642 -61,913 -66,407 -68,433 -71,448 -80,930 -82,003 -959,211 2004 Emissions Summary-Final-5-20-04.xls 5/27/2004 TABLE 5 West African Gas Pipeline P10 EMISSIONS - MAXIMUM BASELINE SCENARIO PM10 Emissions, tonnes/yr 2005 2006 2007 2008 2009 2010 2011 2012 2013 2014 2015 2016 2017 2018 2019 2020 2021 2022 2023 2024 2025 TOTAL No Project (Baseline) Nigeria 85 143 143 147 162 176 196 235 251 277 283 303 315 313 344 348 362 363 368 402 396 Ghana 99 170 178 198 241 275 290 343 361 400 417 455 486 489 573 600 648 670 703 805 812 Benin 0 43 42 47 70 96 125 145 157 172 177 192 195 198 209 211 215 217 220 232 235 Togo 0 43 42 53 81 107 151 186 217 236 236 251 248 246 255 255 258 261 263 277 280 TOTAL 183 399 405 445 553 653 762 909 986 1,086 1,112 1,202 1,245 1,246 1,382 1,414 1,484 1,511 1,554 1,717 1,723 21,970 With Project Nigeria 1 2 2 2 2 2 3 3 3 4 4 5 5 5 5 6 6 6 6 7 7 Ghana 54 93 98 102 114 127 140 174 186 209 220 244 265 269 315 328 353 363 379 433 435 Benin 0 23 23 23 26 29 36 41 46 52 53 58 59 60 63 64 66 68 69 74 76 Togo 0 23 23 24 28 31 40 49 56 63 64 69 69 69 72 72 74 76 77 82 84 TOTAL 54 142 145 151 171 190 218 267 291 327 341 375 398 403 455 469 499 512 532 597 603 7,140 CHANGE (Project-No Project) -129 -257 -259 -295 -383 -463 -544 -642 -695 -758 -771 -826 -847 -844 -927 -944 -985 -999 -1,022 -1,120 -1,120 -14,830 VOC Emissions, tonnes/yr 2005 2006 2007 2008 2009 2010 2011 2012 2013 2014 2015 2016 2017 2018 2019 2020 2021 2022 2023 2024 2025 TOTAL No Project (Baseline) Nigeria 42 71 71 73 81 87 97 117 125 138 141 151 157 156 171 173 180 180 183 200 197 Ghana 3 6 6 8 13 16 17 19 20 21 22 24 25 25 28 29 31 32 34 38 38 Benin 0 1 1 2 5 8 11 13 14 14 15 16 16 16 17 18 18 18 18 18 19 Togo 0 1 1 3 6 9 14 17 20 21 21 22 22 22 22 22 22 22 22 23 23 TOTAL 45 80 80 86 104 120 138 165 178 195 199 213 220 219 239 242 251 253 257 280 277 3,843 With Project Nigeria 0 1 1 1 1 1 1 1 1 1 1 1 2 2 2 2 2 2 2 2 2 Ghana 17 30 31 34 42 50 56 70 75 85 89 100 108 110 126 130 138 141 147 165 166 Benin 0 7 7 8 11 14 18 21 22 25 25 28 28 29 30 30 31 32 32 34 34 Togo 0 7 7 9 12 15 21 26 30 33 33 35 35 35 36 36 37 37 38 40 40 TOTAL 17 45 46 51 65 80 96 118 129 144 149 164 173 175 194 198 208 212 218 241 243 2,965 CHANGE (Project-No Project) -28 -35 -34 -35 -38 -40 -43 -48 -49 -51 -49 -49 -47 -44 -46 -44 -44 -41 -39 -39 -35 -878 2004 Emissions Summary-Final-5-20-04.xls 5/27/2004 TABLE 6 West African Gas Pipeline P90 EMISSIONS - MAXIMUM BASELINE SCENARIO OVERALL EMISSIONS SUMMARY P90 Demand Scenario (NOTE: Flaring in Nigeria for Baseline Scenario Includes only the portion of the WAGP throughput that would be flared in the absence of WAGP) Greenhouse Gas Emissions, tonnes CO2 Eq./yr 2005 2006 2007 2008 2009 2010 2011 2012 2013 2014 2015 2016 2017 2018 2019 2020 2021 2022 2023 2024 2025 TOTAL No Project (Baseline) Nigeria 419,372 1,029,216 1,038,893 1,171,599 1,339,267 1,393,599 1,666,151 1,914,184 2,038,422 2,254,015 2,398,902 2,406,482 2,756,007 2,896,770 3,105,137 3,257,860 3,410,309 3,398,431 3,641,672 3,722,631 3,775,511 Ghana 513,382 1,281,588 1,363,289 1,542,051 1,704,326 1,760,334 2,008,705 2,346,006 2,471,910 2,774,143 3,042,295 3,114,887 3,713,259 3,963,700 4,610,305 5,031,628 5,516,854 5,671,634 6,314,496 6,821,660 7,074,677 Benin 0 324,241 319,918 344,490 403,589 413,227 529,478 590,378 652,061 742,646 796,258 818,016 916,067 988,041 1,012,106 1,063,548 1,111,422 1,131,224 1,224,445 1,231,375 1,309,206 Togo 0 324,241 319,918 357,016 428,436 436,090 588,590 679,613 783,329 882,176 931,559 944,392 1,041,144 1,106,443 1,123,482 1,173,386 1,221,316 1,241,469 1,340,147 1,344,145 1,423,695 TOTAL 932,754 2,959,287 3,042,018 3,415,156 3,875,618 4,003,251 4,792,924 5,530,182 5,945,723 6,652,980 7,169,013 7,283,777 8,426,476 8,954,954 9,851,030 10,526,421 11,259,901 11,442,757 12,520,760 13,119,810 13,583,089 155,287,880 With Project Nigeria 4,791 18,154 18,658 21,431 24,961 26,474 32,273 37,820 41,098 46,393 50,427 51,687 60,512 65,050 71,354 76,648 82,195 83,960 92,281 96,819 100,853 Ghana 383,242 968,191 1,029,914 1,177,975 1,344,234 1,436,857 1,687,631 2,012,492 2,141,896 2,409,941 2,654,891 2,744,398 3,284,586 3,529,449 4,028,022 4,359,043 4,727,292 4,837,706 5,352,419 5,713,043 5,914,353 Benin 0 242,048 238,821 259,481 310,245 325,784 421,571 469,963 517,737 587,006 629,215 645,656 722,769 779,618 798,810 839,110 875,120 889,508 961,586 965,017 1,024,068 Togo 0 242,048 238,821 270,453 332,010 345,812 473,353 548,133 632,728 709,234 747,739 756,361 832,336 883,339 896,376 935,328 971,387 986,083 1,062,941 1,063,804 1,124,360 TOTAL 388,033 1,470,441 1,526,213 1,729,341 2,011,450 2,134,927 2,614,828 3,068,408 3,333,459 3,752,573 4,082,272 4,198,102 4,900,204 5,257,457 5,794,562 6,210,129 6,655,995 6,797,257 7,469,226 7,838,684 8,163,634 89,397,193 CHANGE (Project-No Project) -544,721 -1,488,846 -1,515,806 -1,685,815 -1,864,168 -1,868,324 -2,178,095 -2,461,774 -2,612,264 -2,900,407 -3,086,741 -3,085,675 -3,526,272 -3,697,497 -4,056,468 -4,316,292 -4,603,906 -4,645,499 -5,051,533 -5,281,127 -5,419,455 -65,890,687 NOx Emissions, tonnes/yr 2005 2006 2007 2008 2009 2010 2011 2012 2013 2014 2015 2016 2017 2018 2019 2020 2021 2022 2023 2024 2025 TOTAL No Project (Baseline) Nigeria 214 525 530 598 683 711 850 976 1,040 1,150 1,224 1,227 1,406 1,478 1,584 1,662 1,739 1,733 1,857 1,899 1,926 Ghana 2,801 6,993 7,439 8,264 8,827 8,959 10,249 12,080 12,745 14,357 15,781 16,173 19,353 20,665 24,165 26,403 29,010 29,830 33,233 35,998 37,313 Benin 0 1,769 1,746 1,817 1,960 1,787 2,177 2,430 2,720 3,170 3,403 3,517 3,946 4,254 4,352 4,581 4,835 4,954 5,395 5,480 5,879 Togo 0 1,769 1,746 1,842 2,008 1,831 2,293 2,604 2,976 3,442 3,667 3,763 4,190 4,485 4,569 4,796 5,050 5,169 5,621 5,700 6,103 TOTAL 3,015 11,057 11,460 12,520 13,479 13,287 15,569 18,092 19,481 22,119 24,075 24,680 28,894 30,882 34,670 37,442 40,634 41,686 46,107 49,078 51,221 549,448 With Project Nigeria 13 48 49 56 66 70 85 99 108 122 132 136 159 171 187 201 216 221 242 254 265 Ghana 1,007 2,543 2,705 3,042 3,349 3,491 4,061 4,831 5,126 5,776 6,361 6,555 7,851 8,417 9,708 10,548 11,503 11,794 13,087 14,059 14,560 Benin 0 636 627 664 745 721 903 1,007 1,119 1,288 1,382 1,424 1,596 1,721 1,762 1,853 1,945 1,986 2,156 2,179 2,327 Togo 0 636 627 680 777 751 979 1,123 1,289 1,469 1,557 1,587 1,758 1,874 1,906 1,995 2,088 2,129 2,306 2,325 2,475 TOTAL 1,019 3,862 4,009 4,441 4,937 5,032 6,028 7,061 7,643 8,655 9,433 9,702 11,364 12,183 13,563 14,597 15,752 16,130 17,792 18,817 19,626 211,645 CHANGE (Project-No Project) -1,996 -7,195 -7,452 -8,079 -8,542 -8,255 -9,541 -11,031 -11,839 -13,464 -14,643 -14,978 -17,530 -18,699 -21,107 -22,845 -24,882 -25,556 -28,316 -30,261 -31,594 -337,803 CO Emissions, tonnes/yr 2005 2006 2007 2008 2009 2010 2011 2012 2013 2014 2015 2016 2017 2018 2019 2020 2021 2022 2023 2024 2025 TOTAL No Project (Baseline) Nigeria 1,164 2,856 2,883 3,252 3,717 3,868 4,624 5,312 5,657 6,256 6,658 6,679 7,649 8,039 8,618 9,042 9,465 9,432 10,107 10,332 10,478 Ghana 11 26 28 40 60 71 79 87 90 99 106 108 125 133 147 159 171 176 195 205 214 Benin 0 7 7 10 21 33 49 54 58 62 67 67 75 81 83 87 88 88 94 91 94 Togo 0 7 7 13 26 38 61 73 85 91 95 94 101 106 106 110 111 111 118 115 118 TOTAL 1,174 2,896 2,924 3,315 3,825 4,010 4,813 5,526 5,891 6,508 6,925 6,948 7,949 8,359 8,955 9,398 9,836 9,807 10,513 10,743 10,905 141,220 With Project Nigeria 3 12 13 14 17 18 22 25 28 31 34 35 41 44 48 52 55 57 62 65 68 Ghana 258 652 693 792 902 962 1,129 1,347 1,433 1,613 1,776 1,836 2,197 2,361 2,696 2,918 3,166 3,240 3,586 3,829 3,964 Benin 0 163 161 174 208 217 280 312 344 391 419 430 481 519 532 559 583 593 641 643 683 Togo 0 163 161 182 222 230 314 363 419 471 496 502 553 587 596 622 646 656 707 708 749 TOTAL 261 990 1,027 1,162 1,348 1,427 1,746 2,048 2,225 2,505 2,725 2,803 3,272 3,511 3,872 4,150 4,450 4,545 4,996 5,245 5,463 59,772 CHANGE (Project-No Project) -913 -1,906 -1,897 -2,152 -2,477 -2,583 -3,068 -3,478 -3,667 -4,003 -4,200 -4,145 -4,677 -4,848 -5,083 -5,248 -5,386 -5,262 -5,517 -5,497 -5,441 -81,448 SO2 Emissions, tonnes/yr 2005 2006 2007 2008 2009 2010 2011 2012 2013 2014 2015 2016 2017 2018 2019 2020 2021 2022 2023 2024 2025 TOTAL No Project (Baseline) Nigeria 3 7 7 8 10 10 12 14 15 16 17 17 20 21 22 23 24 24 26 27 27 Ghana 3,206 8,004 8,514 9,630 10,642 10,991 12,542 14,648 15,435 17,322 18,996 19,450 23,186 24,750 28,788 31,419 34,449 35,416 39,430 42,598 44,177 Benin 0 2,025 1,998 2,151 2,520 2,579 3,304 3,684 4,069 4,635 4,969 5,105 5,717 6,166 6,316 6,637 6,936 7,060 7,642 7,685 8,171 Togo 0 2,025 1,998 2,229 2,674 2,721 3,672 4,240 4,887 5,504 5,812 5,893 6,496 6,904 7,010 7,322 7,621 7,747 8,363 8,388 8,885 TOTAL 3,209 12,061 12,517 14,019 15,845 16,301 19,530 22,586 24,405 27,477 29,795 30,465 35,419 37,841 42,137 45,402 49,031 50,247 55,461 58,698 61,261 663,708 With Project Nigeria 0 0 0 0 0 0 0 0 0 0 0 0 0 1 1 1 1 1 1 1 1 Ghana 3 8 8 9 11 11 13 16 17 19 21 22 26 28 32 34 37 38 42 45 46 Benin 0 2 2 2 2 3 3 4 4 5 5 5 6 6 6 7 7 7 8 8 8 Togo 0 2 2 2 3 3 4 4 5 6 6 6 7 7 7 7 8 8 8 8 9 TOTAL 3 12 12 14 16 17 21 24 26 29 32 33 38 41 46 49 52 53 59 62 64 702 CHANGE (Project-No Project) -3,206 -12,049 -12,505 -14,005 -15,830 -16,285 -19,510 -22,562 -24,379 -27,447 -29,763 -30,432 -35,381 -37,800 -42,092 -45,353 -48,979 -50,194 -55,403 -58,636 -61,197 -663,006 2004 Emissions Summary-Final-5-20-04.xls 5/27/2004 TABLE 6 West African Gas Pipeline P90 EMISSIONS - MAXIMUM BASELINE SCENARIO PM10 Emissions, tonnes/yr 2005 2006 2007 2008 2009 2010 2011 2012 2013 2014 2015 2016 2017 2018 2019 2020 2021 2022 2023 2024 2025 TOTAL No Project (Baseline) Nigeria 33 81 81 92 105 109 130 150 160 176 188 188 216 227 243 255 267 266 285 291 295 Ghana 38 95 101 124 156 171 193 219 230 255 277 283 332 354 404 439 478 491 545 583 606 Benin 0 24 24 30 45 60 83 93 100 110 117 119 133 144 148 155 159 159 171 168 176 Togo 0 24 24 33 52 66 101 119 138 150 157 156 170 178 180 187 191 192 204 201 209 TOTAL 71 224 230 278 358 406 508 580 628 691 739 747 851 903 975 1,036 1,094 1,108 1,205 1,244 1,286 15,163 With Project Nigeria 0 1 1 1 1 1 2 2 2 3 3 3 3 4 4 4 4 5 5 5 5 Ghana 21 52 56 64 74 79 93 111 118 133 146 151 181 195 222 240 260 266 294 314 325 Benin 0 13 13 14 17 18 24 26 29 33 35 36 40 44 45 47 49 50 54 54 57 Togo 0 13 13 15 18 19 27 31 36 40 42 43 47 50 50 53 55 55 60 60 63 TOTAL 21 80 83 94 110 118 145 171 185 208 227 233 272 292 321 344 368 376 412 432 450 4,942 CHANGE (Project-No Project) -50 -145 -148 -184 -248 -288 -363 -410 -443 -483 -512 -513 -579 -611 -654 -692 -726 -732 -793 -811 -836 -10,221 VOC Emissions, tonnes/yr 2005 2006 2007 2008 2009 2010 2011 2012 2013 2014 2015 2016 2017 2018 2019 2020 2021 2022 2023 2024 2025 TOTAL No Project (Baseline) Nigeria 16 40 40 46 52 54 65 75 79 88 93 94 107 113 121 127 133 132 142 145 147 Ghana 1 3 3 5 8 10 11 12 12 14 15 15 17 18 20 22 23 24 26 27 29 Benin 0 1 1 1 3 5 7 8 9 9 10 10 11 12 12 13 13 13 14 13 14 Togo 0 1 1 2 4 6 9 11 13 14 14 14 15 16 16 16 16 16 17 17 17 TOTAL 18 45 46 54 67 75 92 105 113 124 132 132 150 159 169 178 185 186 199 203 207 2,639 With Project Nigeria 0 0 0 0 0 0 1 1 1 1 1 1 1 1 1 1 1 1 2 2 2 Ghana 7 17 18 21 27 31 37 45 48 54 59 62 74 80 89 95 102 104 114 120 124 Benin 0 4 4 5 7 9 12 13 14 16 17 17 19 21 21 22 23 23 25 25 26 Togo 0 4 4 5 8 9 14 16 19 21 22 22 24 25 25 26 27 27 29 29 30 TOTAL 7 25 26 32 42 50 64 75 82 91 99 102 118 127 137 145 153 155 169 175 181 2,056 CHANGE (Project-No Project) -11 -20 -19 -22 -25 -25 -29 -30 -31 -33 -33 -31 -32 -32 -32 -32 -32 -30 -30 -28 -26 -583 2004 Emissions Summary-Final-5-20-04.xls 5/27/2004 Appendix A Technical Assumptions Incorporated in Greenhouse Gas and Air Pollutant Emissions Calculations for Specific Source Categories - Emission calculations were made for the WAGP project and for the No-Project (baseline) cases based on a range of assumed market demand scenarios. Specific compounds for which emissions were estimated for each set of assumed circumstances included: Greenhouse gases: Carbon Dioxide (CO2), Methane (CH4), and Nitrous Oxide (N2O) Air pollutants: Nitrogen Oxides (NOx), Carbon Monoxide (CO), Non- Methane Volatile Organic Compounds (NMVOC), and Particulate Matter with aerodynamic diameter less than or equal to 10 microns (PM10) - The composition of the anticipated gas stream for the WAGP was provided by the Project Team (89.15% mole percent methane), and was used to calculate project-specific CO2 emissions for all gas-fired equipment. The heating value calculated from this gas composition (1,058.98 Btu/scf) was also used to compute gas combustion emissions of CH4, N2O and air pollutants. - Sulfur contents of 6 ppm by volume and 1% by weight were assumed for purposes of calculating SO2 emissions for natural gas and fuel oil combustion, respectively. Complete conversion of fuel-bound sulfur to SO2 during combustion was assumed. - No. 4 and No. 6 (distillate) oil heating values were assumed (143,095 and 140,000 Btu/gallon, respectively) based on heating values reported in the API Compendium for these fuels. - Boiler emission factors from the US EPA AP-42 compilation were used to estimate commercial /industrial sector emissions of air pollutants (oil or gas fuels). Complete conversion of fuel-bound carbon to CO2 was assumed. - Gas turbine emission factors from the US EPA AP-42 compilation were used to estimate electric power generation sector emissions of air pollutants (oil or gas fuels). Complete conversion of fuel-bound carbon to CO2 was assumed. - CO2 emissions calculations for flaring assume 98% conversion of fuel carbon to CO2 plus the CO2 contained in the unburned 2% of the gas, as indicated by the gas composition data. Methane emissions are assumed equal to the measured methane content of the unburned 2% of the gas (i.e., 2% of the CH4 in the flared gas is assumed to be emitted uncombusted). These assumptions are consistent with the emissions estimation approach provided in the API Compendium for upstream flares. - Total greenhouse gas emissions for the Project and Baseline scenarios are expressed as the sum of the contributions of CO2, CH4 and N20, each weighted by its respective global warming potential factor (1 for CO2, 21 for CH4, 310 for N2O). 13 Appendix 2A-2 Natural Gas Sources and Transmission Infrastructure ("Upstream of WAGP") West African Gas Pipeline APPENDIX 2A-2 Natural Gas Sources and Transmission Infrastructure ("Upstream of WAGP") 1.0 INTRODUCTION Initial West African Gas Pipeline capacity following construction and startup of WAGP is expected to be 190 MMscfd to service an initial demand of 140 MMscfd. The ultimate system 1 design flow rate (assuming no mid line compressor installation in Togo) is for 460 MMscfd with a maximum operating pressure of 153 barg for 20" mainline case. To support this initial demand and some of the expected future gas demand, gas volumes of up to 200 MMscfd have been identified from existing SPDC and CNL Joint Ventures oil and gas 2 3 operations in the western Niger Delta, Nigeria. Oil and gas facilities associated with the available gas volume identified above are already in place. From oil and gas operations in Nigeria, gas will then be transported via the ELPS, as depicted in Figure 2A-1. This available natural gas from existing SPDC and CNL Joint Ventures is made up of "Associated Gas" (AG), i.e., produced with crude oil from the same reservoir and released on oil stabilization at the flowstation, and "Non-Associated Gas" (NAG), i.e. gas not associated with oil production that is produced from reservoirs with low oil content. NAG wells are not typically operated unless the gas can be sold to meet customer demand, while AG wells are produced primarily to meet oil production quotas regardless of gas demand. AG gas that can not be used either as fuel for production operations or sold to downstream consumers is typically flared. WAGP is one of the key projects that the CNL and SPDC joint ventures are developing to eliminate their contribution to flaring in Nigeria, and it is unlikely that flaring can be eliminated without a portfolio of gas projects like WAGP, as shutting in oil production is the only viable alternative. Initially, the AG-NAG blended streams in ELPS for WAGP and Nigerian domestic gas markets is estimated to be approximately 60% AG / 40% NAG, declining to an estimated 40% / 60% ratio as the Nigerian domestic market grows and NAG gas supplies are added up to the existing capacity of the currently underutilized ELPS. These ratios, explained below, form the basis of the WAGP Greenhouse Gas Emissions Reduction benefit calculations detailed in WAGP EIA Appendix 1B (or 2A-2), incorporating: · Current and forecasted uncertainties regarding Nigerian domestic gas demand. · Some additional AG gas supply to ELPS from outside the CNL and SPDC joint venture As explained in Section 1.5 below, predicting AG-NAG ratios for future gas demand is very speculative, depending on macro-level market conditions for oil and gas sales and in terms of capital expenditure opportunities for both existing and new production wells (AG & NAG), processing facilities and export/transmission infrastructure. 1MMscfd means million standard cubic feet per day 2SPDC Joint Venture is the joint venture comprised of Nigerian National Petroleum Corporation (NNPC), The Shell Petroleum Development Company of Nigeria Limited (SPDC), Nigerian Agip Oil Company (NAOC), and Elf Nigeria, with SPDC as the operator of the Joint Venture. 3CNL Joint Venture is the joint venture comprised of NNPC and Chevron Nigeria Limited (CNL), with CNL as the operator of the Joint Venture Environmental Impact Assessment Page 2A-2-1 West African Gas Pipeline APPENDIX 2A-2 Natural Gas Sources and Transmission Infrastructure ("Upstream of WAGP") Also worth noting is that greenhouse gas emissions reduction for the downstream consumers in Benin, Ghana and Togo are the same whether gas is from associated or non-associated production. Escravos to Lagos Gas Pipeline System (ELPS) The ELPS, owned by NNPC and operated by its subsidiary Nigerian Gas Company (NGC), was constructed in segments during the period 1988-1992 and currently supplies gas to markets within Nigeria. Gas supply for the ELPS is currently from the SPDC and CNL producing Joint Ventures in the western Niger Delta, and enters the ELPS at 4-8 specific inlet points. The ELPS gas supply area (shown within circle on Figure 2A-1) represents less than 20% of the total geographic area of oil and gas production in Nigeria, and other producing areas further south and east in the Niger Delta are not connected to the ELPS. Gas supplied through ELPS, currently about 465 MMscfd, represents less than 70 % of total domestic gas demand within Nigeria. Figure 2A-2 is a schematic diagram of the ELPS System showing the Alagbado Tee where gas will be delivered to WAGP. Flow capacity of the ELPS from Warri to the Lagos area up to the interconnection with WAGP is about 900 MMscfd without any compression facilities. Based on current Nigerian domestic gas consumers on the ELPS, utilization is far below ELPS's capacity. Even with additional gas deliveries to WAGP when it starts up, sufficient capacity exists in ELPS to supply these deliveries without the need for any new facilities, including no need for installation of compression on ELPS. The gas coming into ELPS and therefore also into WAGP will be a blended stream of gas sourced from all of the fields which input gas into ELPS. Currently, all gas supply into ELPS comes from either the SPDC or the CNL Joint Venture. For the two Joint Ventures, gas management activities are done on a "macro" or plant basis, where associated and non-associated gas streams are processed together prior to further disposition whether it be internal fuel use or sale to consumers. In other words, there is no ability to track or to manage gas entering the ELPS, and therefore also the WAGP, all the way back to specific production wells nor to specific production fields. Gas Supply from SPDC Joint Venture Between startup (in the early 1990s) and until 1997, ELPS gas supply came only from SPDC JV fields, notably NAG sources at Oben and Utorogu. Initially demand came from the NEPA (National Electric Power Authority) for thermal power generation. NAG sources were preferred because they had low development cost and could be throttled to match the unsteady power plant demand without disruption to oil production, which would occur with AG. The largest of NEPA's power plants, Egbin which provides electricity to part of the Lagos area, initially had gas demand of about 220 MMscfd. Together, Utorogu and Oben have capacity of 360 MMscfd (current deliverability about 320 MMscfd) for gas into ELPS. SPDC also developed the Sapele NAG field, which is dedicated to NEPA's Sapele plant and does not flow into the ELPS because of its lower operating pressure regime. The other NEPA thermal power plant which is supplied from the ELPS System-B is the Delta IV power plant near Ughelli. SPDC JV also has AG collected at the Ughelli node that flows directly to NEPA's Environmental Impact Assessment Page 2A-2-2 West African Gas Pipeline APPENDIX 2A-2 Natural Gas Sources and Transmission Infrastructure ("Upstream of WAGP") Delta I-III plant units for electricity generation. This gas at the Ughelli node does not flow in to ELPS because gas pressure is below the pressure level needed to enter ELPS, but if required in the future, a booster compressor will be added so that this gas can flow into ELPS. Beside the NAG sources identified above, AG is compressed and put into the ELPS from a number of dedicated gas compressor stations located at Jones Creek, Odidi, and Escravos Beach. Each of these stations has a capacity of 18 MMscfd. Due to disrepair, these compressors stopped feeding gas into ELPS about 1994, but were refurbished by SPDC in 2002-2003 under agreement with NGC to resume flow into ELPS. In 2002, the SPDC Joint Venture also installed an AG gathering system and processing plant to collect AG in the Odidi area, with capacity of 80 MMscfd. This gas source, which is currently connected to the ELPS, will eventually go to Nigeria LNG at Bonny Island through SPDC's Offshore Gas Gathering System. Gas Supply from CNL Joint Venture In late 1997, the CNL Joint Venture started a gas gathering and central processing plant to utilize AG produced with oil from fields in the Escravos area. The number of fields where gas is gathered into Escravos, and the capacity of the gas processing plant, were both expanded in 2000-2001 which increased the total gas volume the Joint Venture can deliver into ELPS at Escravos to about 240 MMscfd. Gas Supply from other sources Beside the SPDC and CNL operated Joint Ventures, there are two additional sources of gas that could be connected into ELPS if market demands justify. These are operated by Nigerian Petroleum Development Company (NPDC), a subsidiary of NNPC, at Oredo with supply potential of 45 MMscfd, and by Pan Ocean in Ogharefe area with supply potential of 100 MMscfd. Environmental Impact Assessment Page 2A-2-3 West African Gas Pipeline APPENDIX 2A-2 Natural Gas Sources and Transmission Infrastructure ("Upstream of WAGP") Geographical Schematic of ELP System ELP SYSTEM Figure 2A-1 Gas Supply Area Figure 2A-2-1 _____________________________________________________________________ ELPS SYSTEM SCHEMATIC To the North Alagbado Tee Ore Node Oben Node SPDC Jones Creek SPDC Oben Lagos Beach CNL Escravos Compressor Station Warri GTP SPDC Ughelli SPDC Escravos Beach SPDC Odidi SPDC Utorogu Key ELPS System A ELPS System C ELPS System B WAGP Figure 2A-2-2 Environmental Impact Assessment Page 2A-2-4 West African Gas Pipeline APPENDIX 2A-2 Natural Gas Sources and Transmission Infrastructure ("Upstream of WAGP") The following table summarizes available gas supply into ELPS. Gas Supply Available into ELPS from SPDC & CNL Joint Ventures Operator Field or Inlet Point to ELPS AG or Installed Currently Available NAG Capacity Capacity SPDC Utorogu NAG 270 210 SPDC Oben NAG 90 60 SPDC Jones Creek Compressor Station AG 18 0 SPDC Odidi Compressor Station AG 18 18 SPDC Odidi AGG ** AG (80) ** 80 SPDC Escravos Beach Compressor AG 18 0 Station CNL Escravos Gas Plant Phase 1 AG 150 150 CNL Escravos Gas Plant Phase 2 AG 90 0 SPDC Ughelli node * AG 90 0 TOTAL 744-824 ** 518 Total AG Supply 384-464 248 Total NAG Supply 360 270 * Not currently connected to ELPS; if required in future could be with booster compressor ** In future, Odidi gas will go to Nigeria LNG at Bonny Island, and not be available to ELPS. Gas Demand Total gas demand in the Nigerian domestic market served by ELPS is currently about 465 MMscfd. Of this total, about 410 MMscfd is supplied to NEPA for power generation at the Delta IV and Egbin plants. Other large gas consumers supplied by ELPS include the two West African Portland Cement Company plants at Shagamu and Ewekoro, which together consume about 30 MMscfd of natural gas, as well as other smaller volume industrial customers in the greater Lagos area. The following table summarizes market gas deliveries made by ELPS. Gas Deliveries made by ELPS (including future WAGP) Customer Gas Usage Current Future Demand Demand (incl WAGP) NEPA Egbin and power barge Power generation 310 310 West African Portland Cement Cement Plants 30 30 Misc industrial Lagos & Ogun States Industrial & power 20 20 Demands at Oben node Power & industrial 5 5 NEPA Delta IV off ELPS System-B Power generation 100 100 Future WAGP Ghana, Togo, Benin Power & industrial 0 200 TOTAL 465 665 Projections of gas market growth within Nigeria and for WAGP involve great uncertainty. Past projections for domestic market growth in Nigeria have typically been optimistic (and have not Environmental Impact Assessment Page 2A-2-5 West African Gas Pipeline APPENDIX 2A-2 Natural Gas Sources and Transmission Infrastructure ("Upstream of WAGP") been realized). Industrial demand for gas involves fewer uncertainties once a pipeline is built for supply, but most of the total market demand for gas is for power generation. In developing gas reserves and related supply facilities it is assumed that buyers will be able to pay a gas price sufficient to justify the capital investments needed to produce, gather, process, compress, and transport the gas (on ELPS and distribution pipelines) to the consumer. Gas Reserves Within the western Niger Delta area in proximity to ELPS, natural gas reserves are estimated to exceed 20 Trillion Cubic Feet (TCF), which far exceeds the current market demands projected for an economic time frame of 20 years or more. For example based on the WAGP market forecast, cumulative gas required for WAGP markets in Ghana, Togo, and Benin over the first 20 years only totals about 1.5 TCF. This large reserve base in Nigeria has led production Joint Ventures to propose and develop gas utilization projects beyond those needed to supply gas markets by pipeline within Nigeria and West Africa. For example, in 1999 the Nigeria LNG plant at Bonny Island began operations for export of LNG (liquefied natural gas) to world markets in Europe and the United States, and has been expanded since its original startup. Additional projects are being developed to monetize Nigeria's gas resources for sale of products in world markets. Where these projects impact the ELPS supply area, they will be mentioned briefly to convey a complete picture of production operations in the area where gas is supplied for WAGP. Additional details regarding the SPDC Joint Venture, the CNL Joint Venture, and ELPS operations are provided in following sections of this Appendix. 1.1 SPDC Joint Venture Operations The SPDC JV plans to initially supply WAGP gas contracts from an existing mix of AG and NAG sources currently connected to the ELPS. Consequently no new field developments are envisaged for initial supply into WAGP. From the existing developed resources, some 54 MMscfd of AG will flow into ELPS in equal proportion from the compressors leased from NGC. These compressors are located at Escravos Beach, Jones Creek and Odidi fields in the northern swamp area (NSA) of western Niger Delta. The NAG contribution required to make up SPDC JV's supply to WAGP markets is planned to come from any of the existing NAG plants built to contractually supply some 260 MMscfd predominantly to NEPA for thermal power generation and some local manufacturing industries. These plants at Utorogu (270 MMscfd capacity) and Oben (90 MMscfd) together have a spare capacity of 100 MMscfd above peak contractual demand. The supply planning philosophy is to give priority to AG, keeping sufficient spare capacity of NAG to top up and ensure reliability and security of supply. Gas supply to meet WAGP demand growth is being addressed as part of overall activities to satisfy gas supply-demand balance for the totality of SPDC JV's gas market opportunities through the ELPS, including both Nigerian and WAGP markets. Largely to meet projected growth in Nigerian market demand, the SPDC JV is planning to increase overall supply availability as discussed below. Environmental Impact Assessment Page 2A-2-6 West African Gas Pipeline APPENDIX 2A-2 Natural Gas Sources and Transmission Infrastructure ("Upstream of WAGP") Utorogu To bring gas deliverability back up to plant design capacity of 270 MMscfd, the Joint Venture plans to repair one well by re-perforating the well's gas producing zone. Also, it expects to drill 2 new gas wells within the next 10 years. New wells will be drilled in existing well slots in a pre-defined well template set up when the Utorogu facility was designed. Therefore, the new wells do not create new physical space requirements and those associated environmental impacts (the space has already been set aside), but they do create impacts with disposal of drilling fluids. Oben The Oben field is the prime candidate for expansion of gas supply into the ELPS. In the near term, plans are to debottleneck the existing plant to increase capacity from 90 to 120 MMscfd. In the medium term, the plant could be expanded by 50% to 180 MMscfd, which would also require drilling of 3 new gas wells to complete the expansion of gas supply. These are capacity additions of a facility that is already in operation. Ughelli East Current well production capacity is higher than plant capacity, and a project to increase plant capacity has been undertaken by refurbishing NAG processing units now at Sapele and moving them to Ughelli East. The refurbishment of the affected units is nearly completed. Ughelli East also has significant remaining reserves and the opportunity exists to drill two additional wells to increase overall supply capacity. Currently, available gas pressure at Ughelli (both AG and NAG sources) is not high enough to get into the ELPS at Ughelli Node. If necessary to boost gas supply capacity into ELPS, the installation of booster compressors at Ughelli Node and tie in of the Ughelli East supply could increase total supply into ELPS. Egwa/Odidi An Odidi NAG project is being considered to supply an additional 40-100 MMscfd into the ELPS in the medium term. Feasibility studies are ongoing, but actualization depends upon growth in demand in domestic (Nigerian) and regional (WAGP) markets, and availability of funds from JV partners. Environmental Impact Assessment Page 2A-2-7 West African Gas Pipeline APPENDIX 2A-2 Natural Gas Sources and Transmission Infrastructure ("Upstream of WAGP") 1.2 CNL Joint Venture Operations About 90% of ChevronTexaco's current production in Nigeria comes from onshore and offshore fields in the Escravos area, under the NNPC-CNL (Chevron Nigeria Limited) Joint Venture. The remaining 10% of total production occurs in offshore fields in the TOPCON area, and onshore fields in the Eastern area in the vicinity of Port Harcourt. Only gas produced in the Escravos area can flow into ELPS for supply to WAGP. Escravos is located in the western Niger Delta and is the location of a major oil and gas processing and shipment terminal for the Joint Venture. Both oil and associated gas from a number of fields located onshore and offshore are gathered by pipelines and transported to Escravos prior to processing and shipment to markets. Gas to be supplied to the WAGP markets from the CNL Joint Venture will come from the Escravos Gas Plant. Figure 2A-3 shows a schematic diagram of producing facilities both offshore and onshore, and how crude oil flows in to the Escravos terminal. Where gas is gathered from the same fields, it flows by separate parallel pipelines and is routed to the Escravos Gas Plant. In 1997, Phase 1 of the Escravos Gas Plant (EGP-1) was completed with a capacity to process 165 MMscfd of gas that had previously been flared in Okan and Meren fields offshore of Escravos. The processed gas is sold to NGC for resale to end-users in Nigeria, via the ELPS. In 2001, Phase 2 of the Escravos Gas Plant (EGP-2) was completed with a capacity to process an additional 120 MMscfd of gas. As part of the EGP-2 project, gas that was previously flared was gathered from the Olero Creek, Abiteye, and Dibi fields in the onshore/swamp area near Escravos. The total EGP plant inlet capacity is currently 285 MMscfd, however due to volume shrinkage associated with removal of LPG and use of fuel gas in operations, the residue gas volume available for market sales is about 240 MMscfd. As described, Phases 1 and 2 of the Escravos gathering gas and processing plant were completed in 1997 and 2001 respectively, and can supply enough processed gas for contracts to both the Nigerian domestic market and initial WAGP markets for end-users in Ghana, Togo, and Benin. The gas deliverability from the combined EGP-1 and EGP-2 is sufficient to supply the CNL JV share of gas for the WAGP forecasted market for the first 5-10 years after WAGP starts operations (as well as the CNL JV's existing domestic market contract). The CNL Joint Venture gas initiatives in Nigeria have these two broad objectives: · Eliminate routine gas flaring by 2008 · Monetize the Joint Venture's significant gas resources Strategies to achieve these objectives are as follows: · Identify, evaluate, and develop gas markets. · Develop infrastructure and gather gas production in phases. · Sell gas in the Nigerian, regional (West African), and international markets. · Convert gas to liquids via GTL or LNG and sell products in global markets. Environmental Impact Assessment Page 2A-2-8 West African Gas Pipeline APPENDIX 2A-2 Natural Gas Sources and Transmission Infrastructure ("Upstream of WAGP") NNPC-CNL Escravos Operational Area BeninRiver NNPC Tank Farm Gas Plant Dehyd Escravos River ration · Partly treated crude is pumped from the fields to the tank farm via the pipeline network · Crude oil gathering capacity is 500,000 Barrels Per Day. · Tank Farm has 3.4 million barrels storage capacity Figure 2A-2-3 Figure 2A-2-4 Environmental Impact Assessment Page 2A-2-9 West African Gas Pipeline APPENDIX 2A-2 Natural Gas Sources and Transmission Infrastructure ("Upstream of WAGP") As part of these objectives to stop routine gas flaring and develop additional commercial uses for gas reserves, CNL has plans to further expand gas gathering from Escravos Area fields as shown in Figure 2A-4. Plans are currently in progress for Phase 3A & 3B of the gas gathering project and the addition of more processing capacity at the onshore gas plant. Phase 3 will gather most remaining associated gas that is now being flared, and can be used for growth in the domestic market and a planned Gas-to-Liquids (GTL) conversion plant at Escravos. This plant will take natural gas as a feedstock, and convert it to a liquid hydrocarbon that can be used as a component of transportation fuels such as diesel fuel. It is expected that the GTL product will be exported from Nigeria for sale to world markets. Total volumes of additional gas being gathered in Phases 3A and 3B are 300 MMscfd, which includes both AG and NAG. Figure 2A-5 shows the scope of additional gas gathering lines being planned for EGP Phases 3A and 3B. All of this additional facility installation is independent of gas supply to WAGP, since existing supply that has been developed already is available to meet WAGP market demand. Note that new developments are to gather gas from offshore fields. Onshore, the expansion of the processing plant, and construction of the new Escravos GTL plant, are all on land the Joint Venture has already acquired within the Escravos Terminal and Plant area. In the longer term, the Joint Venture expects that additional development of gas reserves will be primarily from offshore fields. Figure 2A-6 shows a forecast of Escravos Area associated gas (AG) production from existing fields over the 20-year period 2000-2020. Since current market demands have not justified capital expenditures for gas gathering and processing facilities for this entire volume, some AG is now flared. However, with completion of EGP Phases 3A and 3B as currently planned, the vast majority of the flared volumes in the Escravos area will have been gathered and processed for market use. With growth in the domestic market and the completion of the GTL conversion plant, all the AG will be used to supply revenue generating markets. However, since AG is generally not produced at steady rates for a variety of reasons and AG production will decline over time with decline in oil production, it will be necessary to develop other gas resources (NAG) to maintain gas supply in excess of 600 MMscfd. Phase 3 of the gas gathering program includes plans to develop NAG resources to maintain total Escravos gas supply in excess of 600 MMscfd for supply to Nigerian, WAGP, and GTL feedstock markets. The CNL Joint Venture has gas reserves in the Escravos area exceeding 10 trillion cubic feet (Tcf). The total demand for all currently planned gas uses in the Escravos area is estimated at less than 7 Tcf over a 20-year time period. This includes volume shrinkage due to gas processing, plant fuel gas, sales into the Nigerian domestic market, supply to WAGP for sales in Ghana, Togo, and Benin, and feedstock supply to the proposed Escravos GTL plant. Assuming that the CNL Joint Venture supplied half of the total gas market demand to WAGP over this time, the WAGP supply would be only about ¾ of 1 Tcf. One other field with the ability to deliver gas into ELPS, the Makaraba Field onshore near Escravos, should be discussed. The gas was initially delivered into the ELPS in 1992 with compression from an NGC station into an 8 inch ELPS pipeline that flowed over to Jones Creek, and then onward into the ELPS System A at Central Node. However, the field gas pressure declined such that the gas pressure has not been high enough to run the reciprocating Environmental Impact Assessment Page 2A-2-10 West African Gas Pipeline APPENDIX 2A-2 Natural Gas Sources and Transmission Infrastructure ("Upstream of WAGP") compressors, and gas has not gone into ELPS from Makaraba since the mid-1990s. Current plans are to bring Makaraba gas to Abiteye, and then onward to Escravos for utilization. ____________________________ EGP 3 Offshore - Phased Development Proposal EGP Offshore Phased Development Proposal NORTH W. ISAN OPUEKEBA MINA 12"Bulk ISAN DIBI GAS PARABE OLEROCREEK 12" COMPRESSION GGCP 12" GASCOMPRESSION 10" BARGE BARGE EWAN NEW PARABE BOOSTER MAKARABA PP COMPRESSOR BENIN RIVER ABITEYE 10" COMPRESSION MEREN2 MEJO MEREN PP 18" MALU 24" KITO MEREN Jones Creek TAPA 16" 8" GasLift CP DELTA 18" 18" UTONANA OPOLO 12"20" 12" 12" 18" MEREN 24" EGTL1 NAG DELTA Train1 GGCP 8" 104 Gas Plant 20" 102 103 Quarters 101 12 TO 24" 10 16" 11 NGC@ 9 8 Train2 20" WARRI 7 6 4 ESCRAVOS 5 2 3 TANKFARM 1 RIVER Produced 20" Water 20" Outfall ESCRAVOS Produced Water Outfall Discharge 8" LPG 24" Sub-SeaTie-In ESCRAVOS DELTASOUTH BEACH LEGEND 18"EGT18LPRODUCTEXPORT "CONDENSATEEXPORT 12" DELTAS. GASINJECTION WP19 SAT I OKAN GGCP 24" EGP3 "A" OKAN Existing PP SAT II EGP3 "B" MEJI LPG NEW BOOSTER FSO SPM5 OKAN 12" COMPRESSOR TANKER NAG OKAN33 Figure 2A-2-5 7 00 Forecast of Escravos Area AG Production from Existing Fields 6 00 5 00 FCS 4 00 M M e m luoV 3 00 2 00 1 00 - 2 0 0 0 2 0 0 1 2 0 0 2 2 0 0 3 2 00 4 2 0 0 5 2 0 0 6 2 0 0 7 20 0 8 2 0 0 9 2 0 1 0 2 0 1 1 2 0 1 2 2 0 1 3 2 01 4 2 0 1 5 2 0 1 6 2 0 1 7 20 1 8 2 0 1 9 2 0 2 0 Y e a r E s cra vo s A G - L e ss O ffs ho re F u e l Figure 2A-2-6 Environmental Impact Assessment Page 2A-2-11 West African Gas Pipeline APPENDIX 2A-2 Natural Gas Sources and Transmission Infrastructure ("Upstream of WAGP") 1.3 Escravos-to-Lagos Pipeline System (ELPS) As shown in Figures 2A-1 and 2A-2, the Escravos ­ Lagos Pipeline System originates in the western Niger Delta with gas supply legs west and south of Warri. The pipeline is owned by NNPC, and operated by its subsidiary Nigerian Gas Company Limited (NGC). The western supply leg (ELPS System-A) comprises 58 km of 20 and 24 inch pipeline from inlet points at Escravos (CNL), Escravos Beach (SPDC), Jones Creek and Odidi (SPDC) and Central Node, and flows to Warri. The southern supply leg (ELPS System-B) is a 30 inch line that flows 32 km from the SPDC plant at Utorogu to Warri. Where the two supply lines join at Warri is the NGC company headquarters and operational center. From Warri, the pipeline continues north and west toward Lagos as a 36 inch line to the Egbin node. From the Egbin node, a 30 inch spur line flows south to meet the demand of NEPA at its electric power plant at Egbin. The main 36 inch line reduces in diameter after the Egbin node to a 24 inch pipeline which flows further west to its terminus at Alagbado tee near Itoki in Ogun State where the West African Gas Pipeline project (WAGP) will tie into the ELPS. The total length of the Warri to Alagbado tee line (ELPS System C) is 380 km. The ELPS pipeline which is designed to the limit of ANSI Class 600 at a pressure of 100 bar is capable of delivering 900 MMscfd of gas out of Warri without compression. The demand on the main Lagos trunkline (System C) at the moment is of the order of 365 MMscfd which represents about 40 % capacity utilization. The pipeline system will not need to be upgraded or modified with additional installation of equipment or facilities to meet the WAGP gas demand of up to 200 MMscfd forecasted within the next 5-10 years. Even with the addition of the full WAGP demand of 200 MMscf, capacity utilization on the main Lagos trunkline would increase to about 63%, which still provides a significant capacity margin for additional domestic growth before the addition of compression facilities is needed. The WAGP is therefore not expected to generate any additional burden or impact on the ELPS since no capacity upgrade or major intervention is required to meet both WAGP and growing Nigerian market demands. Because it has been in operation more than 10 years, an ELPS Integrity Study was carried out by the independent engineering firm Penspen Limited to determine the pipeline's integrity for future use as a supply pipeline to the WAGP. NNPC has made a commitment to ensure the availability of the ELPS pipeline system by committing to rectifying all defects identified during the integrity study. Phase 1 of that study was completed in 2001, and examined the system design, operational history, and future expected usage for both Nigerian domestic and WAGP markets over a forecast 20-year period. The Phase 1 report did make some recommendations for repair of certain facilities and identified operating practices to be changed by NGC. Since 2001, NGC has largely completed the recommended repairs, which included repair of leaky valves, reinstatement of an active Right-of-Way maintenance program, refurbishment of cathodic protection systems for external corrosion protection, as well as modifications necessary for intelligent pigging (IP) of the pipeline. In the ELPS Integrity Study Phase 1 report, Penspen states "On the question of overall integrity assessment, there were no major problems observed that would render the ELP buried pipeline system non viable in the short term." The risks that were discussed are largely the potential for time dependent deterioration over the next 20 years, and therefore most recommendations were focused on long term operational and maintenance practices to prevent such deterioration. Environmental Impact Assessment Page 2A-2-12 West African Gas Pipeline APPENDIX 2A-2 Natural Gas Sources and Transmission Infrastructure ("Upstream of WAGP") Phase 1 also analyzed the system capacity for both WAGP and increasing Nigerian market demand relative to the existing pipeline system. The system was found to have adequate pipeline capacity without the need for any compression until after 2020, some 15 years after startup of the WAGP. As stated already, the flow capacity of the Warri-to-Lagos trunkline (ELPS System C) without any compression is 900 MMscfd. Capacity of System C can be increased to 1200 MMscfd with the future installation of two compressor stations at Ore and Oben nodes, although based on forecasts these will not be needed until 15+ years in the future. This forecast is dependent on anticipated growth in the Nigerian domestic market especially for power generation, which has been very difficult to forecast in the past. Penspen also reported that "there have been no reports of major loss of gas incidents in the ELP system", although there have been incidents of vandalism, several minor valve leaks, and one reported gas leak due to hardware failure. Pipeline vandalism is a common concern in Nigeria, although usually it is targeted toward petroleum refined product pipelines where thieves are hoping to obtain gasoline or kerosene. ELPS has been subject to a small number of damage incidents, with local hand drilling into the pipeline that led to pinhole leaks when gas began to escape. These leaks have been repaired by plugging and sleeving the hole with full encirclement clamps, which is a good engineering practice for a permanent repair of pipeline damage. An upgrade of overall pipeline security surveillance of Rights-of-Way, as recommended by Penspen, should also deter future incidents of such vandalism. Also taken from Penspen's Phase 1 Integrity Study report, "There are no reports of pipeline failures due to third party damage or corrosion in the ELPS. The absence of corrosion failures is predictable due to the relatively short service life of ELPS to date, but future failures are predicted to occur. This corrosion is likely to cause a leak rather than a rupture, which will allow easy and rapid repairs. Therefore, the most likely failure in the next five years (other than vandalism) is a leak from corrosion. However, good maintenance and inspection procedures should keep these failures to a low level, easily below one every three years." Phase 2 of the Integrity Study was to run intelligent pigging tools inside the length of the majority of ELPS segments important for gas delivery to WAGP. The IP tools identify locations where pipe wall deterioration may have occurred due to internal or external corrosion. Inspection of almost all the line segments was completed in 2003. NGC is now preparing a work program to excavate selected locations identified by the IP, and examine these areas further for evidence of damage that could reduce the ultimate pipeline life below a 20-year target life desired for WAGP. Based on the IP inspection results alone, it appears that the ELPS pipeline is overall in good condition for continued future deliveries, and also appears that no major line section repairs will be needed in the next 10 years if it is maintained, operated and inspected in line with Integrity Study recommendations. 1.4 Associated and Non-Associated Gas The gas coming into WAGP will be a blended stream of gas sourced from all of the fields which input gas into ELPS, including the SPDC and CNL Joint Ventures previously described. The gas that is to be nominated for supply to WAGP customers will actually commingle with current Environmental Impact Assessment Page 2A-2-13 West African Gas Pipeline APPENDIX 2A-2 Natural Gas Sources and Transmission Infrastructure ("Upstream of WAGP") volumes of gas being supplied under existing domestic (Nigerian market) contracts for power generation and industrial use. For CNL and SPDC, most gas management activities are done on a "macro" or plant basis, where associated and non-associated gas streams are processed together prior to further disposition whether it be sales to consumers, flaring, or internal fuel use. In other words, current operations do not allow for tracking or management of gas entering the ELPS, let alone WAGP, all the way back to the wellhead. The CNL JV has advised that the current plan is to supply WAGP contracts from their associated gas stream in the western Niger Delta. As part of the contract obligation, there are some NAG sources connected to the system to ensure security of supply, but NAG is not initially intended to be produced for WAGP contracts under normal operating conditions. This situation is expected to last 5-10 years at which time the supply of AG may become insufficient for this Joint Venture to satisfy the growth in the gas market. AG will then need to be supplemented by NAG or other, currently unidentified sources (see Section 1.5 below). The SPDC JV plans to supply WAGP gas contracts from an existing mix of AG and NAG currently connected to the ELPS. The available capacity of connected AG is expected to remain constant over the years (subject to OPEC oil production quota levels). The supply planning philosophy is to give priority to AG, keeping sufficient spare capacity of NAG to top up and ensure reliability and security of supply. Over time, it is expected that the quantity of NAG will have to increase to supply regional market growth, and the proportion of overall AG in the blended stream will decrease. On the basis of all expected gas supply in to ELPS, we estimate that upon the start of WAGP operations, the gas stream will be about 60% associated gas, and as the Nigerian domestic market grows and additional NAG gas supplies are added, the gas stream may decrease to about 40% associated gas. Since a part of the total ELPS commingled stream is fed into WAGP, the percentages of associated gas in ELPS also apply to WAGP. It is clear that WAGP, as one of the projects being developed that supports utilization of gas by these two producing Joint Ventures, will make a contribution to the reduction of associated gas flaring in Nigeria. It is unlikely that flaring can be eliminated without a portfolio of gas projects like WAGP, as shutting in oil production is the only alternative. The information described above, therefore forms the basis of the WAGP Greenhouse Gas Emissions Reduction benefit calculations detailed in WAGP EIA Appendix 1B (or 2A-2) , incorporating: · Current and forecasted uncertainties regarding Nigerian domestic gas demand. · Some additional AG gas supply to ELPS from outside the CNL and SPDC joint venture. 1.5 Future Gas Supply The table below attempts to summarize specific actions to bring current gas supply in line with plant capacity, in part to supply the WAGP, but also to supply Nigerian market demand. Environmental Impact Assessment Page 2A-2-14 West African Gas Pipeline APPENDIX 2A-2 Natural Gas Sources and Transmission Infrastructure ("Upstream of WAGP") Timeframe After Near Term Medium Term WAGP Startup (0 ­ 5 Years) (5-10 Years) Utorogu NAG Drill 2 new wells & SPDC JV repair (re-perforate) 1 well. Oben NAG Debottleneck gas plant Expansion of gas plant SPDC JV from 90 to 120 MMscfd. capacity to 180 MMscfd and drill 3 new wells. Ughelli East NAG Additional gas processing Possible addition of SPDC JV units (being moved from booster compression Sapele), drill 2 new wells. into ELPS. Gas sources for WAGP volume above 200 MMscfd from the SPDC and CNL Joint Ventures are not fully defined at this time. Over the long term, as gas demand increases and the WAGP system is expanded via additional compressors at Lagos Beach, existing associated gas reserves may become depleted or may not be able to completely provide for the increased demand. Delivery requirements are likely to be supplemented in a number of ways including the following options: · Existing NAG sources as described above. · Recompletion of existing wells, producing AG and/or NAG from shallower hydrocarbon reservoirs. Surface facilities to collect, process and transport this production to the ELPS would likely be from existing infrastructure (platforms, flowlines and pipelines), but could also be from upgraded or new infrastructure depending on the characteristics of the gas and other fluids produced from the new reservoirs. · New wells drilled in existing fields producing AG and/or NAG. Some new infrastructure, particularly flowlines from the new wells are likely, although it's also likely that existing, centralized collection points in existing fields would continue to be used. · New wells drilled in new fields, with new surface facilities and infrastructure. Decisions on which options to pursue will depend on a number of factors including overall commercial gas commitments, including WAGP. Associated gas decision making will factor in oil sales and related economic decision criteria. Large gas volume delivery and the related "economies of scale" in terms of capital cost efficiency are also critical inputs to the decision making, as are operating cost economics. In other words, upstream producers may decide to sell, shut in and/or abandon certain wells and fields rather than making further capital investment in wells or surface facility infrastructure for small volume sources. Also worth noting is that under the WAGP International Project Agreement (IPA), there is a provision for "open access", i.e., that access to WAGP is available to other producers and consumers after year 10 or contracted demand exceeds 200 MMscfd, which ever occurs first. For total sales volume requirements below 200 MMscfd, gas supply is reserved for the Nigerian Joint Venture upstream sources described above. For total incremental sales volumes above 200 MMscfd, gas supply may come from any source (along the pipeline route) if the appropriate contractual relationships are in place between gas sellers, shippers, and users and WAPCo, Environmental Impact Assessment Page 2A-2-15 West African Gas Pipeline APPENDIX 2A-2 Natural Gas Sources and Transmission Infrastructure ("Upstream of WAGP") including facility interconnection agreements, gas composition/specification, and as appropriate, Environmental Impact Assessment (EIA) requirements. 2.0 ASSOCIATED UPSTREAM IMPACTS & BENEFITS 2.1 Existing Operations Any discussion regarding upstream impacts associated with WAGP from existing gas sources should consider the fact that a majority of the potential impacts would be operational in nature, and many would occur regardless of WAGP. As mentioned previously, gas operations upstream of WAGP are managed on a "macro" or plant basis where capital and operational decisions are based on aggregate commercial commitments with gas sales delivery typically occurring from centralized infrastructure (like the CNL Escravos plant). Furthermore, associated gas decisions are driven in large part by the economics related to oil production. Both the SPDC and the CNL JVs have comprehensive programs in place already to mitigate potential operating risks associated with production of oil and gas in the Niger Delta including: · Community and Worker safety incidents (injuries, etc.) · Transportation Incidents · Spills and/or unplanned releases of liquid contaminants including produced oil/water and hazardous materials leading to acute and chronic pollution · Air emissions · Fires or explosions · Negative community or other stakeholder reactions to real or perceived environmental or social performance gaps of the oil industry or government Continued benefits associated with upstream gas supply to WAGP include: · Joint Venture gas sales revenue · Government tax revenue · Nigerian / indigenous employment · Technology transfer and local capacity building (local content/local business development) · Community development projects Quantifying these benefits and impacts is beyond the scope of this EIA, and as mentioned would occur regardless of WAGP demand. Highlighting these and other issues qualitatively, however, provides stakeholders reviewing this EIA with information and background to engage the upstream producers and Nigerian regulators regarding their concerns and issues such as how HES Management Systems and existing regulatory and other oversight is being managed and how these can be improved to eliminate the potential negative impacts and enhance the benefits of upstream operations. 2.2 Future Gas Supply Impacts and Benefits Environmental Impact Assessment Page 2A-2-16 West African Gas Pipeline APPENDIX 2A-2 Natural Gas Sources and Transmission Infrastructure ("Upstream of WAGP") As described in Section 1.5 above, future WAGP gas supply could come from many sources, both existing and new. As these sources are brought on line, operational impacts and benefits would be similar to those listed above. The table below summarizes known actions for increase in gas supply, and briefly describes associated impacts. Timeframe After Near Term Medium Term Long Term WAGP Startup (0 ­ 5 Years) (5-10 Years) (10+ Years) Existing fields Debottleneck gas plant Expansion of Oben plant Utorogu NAG capacity within existing capacity by 50% and Oben NAG plant boundaries. Drill up drill 3 more new wells. Ughelli East NAG to 3 new wells to increase SPDC JV supply to gas plants. Ughelli Node Possible addition of SPDC JV booster compression into ELPS. Egwa / Odidi NAG Not applicable Possible addition of 300 SPDC JV MMscfd new capacity Both SPDC and Not applicable Not applicable Unidentified CNL JVs new capacity ELPS Pipeline None None Potential addition Mainline Warri to of compression Lagos (System C) New green fields developments would likely result in benefits and impacts similar to those identified in this EIA including but not limited to: POTENTIAL BENEFITS POTENTIAL IMPACTS Employment Environmental Joint Venture Product Revenues · Land Use Government Tax Revenues · Habitats and Biological Resources Providing Cleaner Burning Fuel to the Region · Topography, Geology, and Soils Further reductions in flaring if associated gas is supplied · Water Resources and Hydrology · Air Quality Socioeconomic · Transportation and Infrastructure · Cultural and Social Traditions · Goods and Services · Livelihood Health and Safety · Public Health and Safety · Worker Health and Safety Environmental Impact Assessment Page 2A-2-17 West African Gas Pipeline APPENDIX 2A-2 Natural Gas Sources and Transmission Infrastructure ("Upstream of WAGP") Similar to operational impacts from existing gas sources, quantification of these benefits and impacts is beyond the scope of this EIA and would be difficult to assess at this point in time because of the overall uncertainties of timing, WAGP gas demand and other macro-economic issues, let alone site specific issues associated with any future gas source. Nigeria's EIA procedures, along with other regulatory safeguards would require an EIA to identify and address the benefits and potential negative impacts for future new development associated with upstream gas supply for the CNL and SPDC Joint Ventures including future supply to WAGP. EIA's were conducted prior to the development of a number of the existing projects and facilities listed above and the upstream JV operating companies will continue to conduct impact assessments as appropriate on future projects. Environmental Impact Assessment Page 2A-2-18 West African Gas Pipeline Appendix 2-B WAGP Waste Estimates West African Gas Pipeline WAGP ENVIRONMENTAL IMPACT ASSESSMENT APPENDIX 2B-WASTE ESTIMATES WAGP LINE AND BIOCIDE TREATMENT VOLUMES BIOCIDE - LINE WATER (bbl) THPS 100% ACTIVE Parts Per Million (bbl) 20" OFFSHORE MAINLINE - ATLANTIC WATER(1) 663,646 84.5 127.3 20" OFFSHORE MAINLINE - LAGOON WATER (1) 663,646 192.0 289.3 30" ONSHORE LINE - ATLANTIC WATER 152,730 26.0 170.2 30" ONSHORE LINE - LAGOON WATER 152,730 39.0 255.4 18" TEMA LATERAL - ATLANTIC WATER 15,116 2.0 132.3 10" LOME LATERAL - ATLANTIC WATER 5,176 0.7 125.6 8" COTONOU LATERAL - ATLANTIC WATER 3,584 0.5 139.5 NOTES (1) Decrease line and biocide volume by 18% for the 18" mainline option. WASTE STREAM VOLUME ESTIMATES From WAPCo's Waste Inventory and Characterization estimates of potential waste volumes are developed. The volumes estimated are separated into onshore and offshore construction and operational activities. The largest single one time amounts of waste is created during construction. During the operational period over the 20 year life of the pipeline, small continuous amounts of wastes are created. Waste Stream and Volume Estimates for Construction The pipeline will be constructed over a 15 month period. The construction will be done in each country and offshore. The offshore section of the pipeline extends about 620km along the Nigeria, Benin, Togo, and Ghana coasts from Lagos Beach to Takoradi and about 30km offshore into the inner continental shelf of the Atlantic Ocean within the Gulf of Guinea. The offshore construction will be done on boats and the pipeline laid on the surface of the inner continental shelf. All, or some portion, wastes, except grey and black water, will be either transported to shore at central location in Ghana or Nigeria for collection and storage prior to disposal or transported back to the home base of the offshore EPC contractor/subcontractor. WAGP ENVIRONMENTAL IMPACT ASSESSMENT APPENDIX 2B-WASTE ESTIMATES The onshore construction will occur in each country. The R & M stations located in Ghana, Togo, and Benin will each take approximately four months to construct. The Nigerian onshore construction will take one year to construct and will occur over 57 kilometers from the Algabado T'ee (an existing R & M Station) to the Bagadry Compressor Station located at the coast. All, or some portion, wastes, except grey and black water, will be transported to the Compressor Station Construction Site or other temporary central location for collection and storage prior to disposal. Estimates of construction waste volumes are presented in the tables below (note procedures for handling and disposal are presented in Appendix 1): WAGP ENVIRONMENTAL IMPACT ASSESSMENT APPENDIX 2B-WASTE ESTIMATES TABLE 1 WAGP ALGABADO TEE SOLID AND HAZARDOUS WASTES CONSTRUCTION SUMMARY Equipment Waste Name Waste Types Quantity Frequency Classification Equipment Lube Oil 0.5 BBLs annually Hazardous AutoVehicles Filter 20 annually Hazardous Minor Spill Clean ups; Maintenance activities Oily Rags 0.25m3 monthly Hazardous Medical treatment materials such bandages, Mobile Clinic swipes etc 0.25m3 monthly Hazardous Pipeline X- Once at ray Radioactive completion of inspection Materials 3 construction Hazardous Sanitary Collection System­ toilets Black water 43,800 gallons annually Non-Hazardous Generators, Pipeline Tie ins, etc Steel 0.25m3 monthly Non-Hazardous Concrete slab construction Once at start and any 5 kg from slab of RoW removed construction Clearance and concrete /.25 tonne for then monthly blocks from the RoW during site Concrete removal construction Non-Hazardous Site Vegetation, Once at start Clearance1 Woody Debri 10,000 m3 of construction Non-Hazardous Pipeline joint Coating raps; FBE; 50 kg per Materials Adhesive month Once a month Non-Hazardous Welding Rod (welding Pipeline stubs) Construction 3 Once a month Non-Hazardous WAGP ENVIRONMENTAL IMPACT ASSESSMENT APPENDIX 2B-WASTE ESTIMATES TABLE 1 WAGP ALGABADO TEE SOLID AND HAZARDOUS WASTES CONSTRUCTION SUMMARY Equipment Waste Name Waste Types Quantity Frequency Classification Computer Computer Toners/Ink 2 Once a month Non-Hazardous Paper, Plastics, Office Rubbish 3 Once a week Non-Hazardous Kitchen / Cafeteria Food 3 Once a week Non-Hazardous Waste Volumes are either specifically calculated or predicted qualitatively with: 1 = None; 2 = Minimal amounts infrequently; 3 = Minimal amounts frequently or moderate amounts infrequently; (0.25 m3 Solid or 0.5 BBL liquid) 4 = Regular production of moderate amounts and occasional production of large amounts; (1 m3 solid or 2 BBL Liquid) 5 = regular production of large amounts (> 10 m3 Solid or > 20 BBLs liquid) Note 1 - Assumes entire site has 1 m band of vegetation WAGP ENVIRONMENTAL IMPACT ASSESSMENT APPENDIX 2B-WASTE ESTIMATES TABLE 2 WAGP Lagos Beach Compressor Station SOLID AND HAZARDOUS WASTES CONSTRUCTION SUMMARY Equipment Estimated Waste Name Waste Types Quantity Frequency Classification Equipment Lube Oil 2 BBLs Annually Hazardous AutoVehicles Filter 40 Annually Hazardous Minor Spill Clean ups; Maintenance activities Oily Rags 0.25 m3 Monthly Hazardous Medical treatment materials such bandages, Mobile Clinic swipes etc 0.25 m3 Once a week Hazardous Once at Pipeline X-ray Radioactive completion of inspection Materials 3 construction Hazardous Hydrotest during Pipeline Once at commissioning Biocide Treated completion of activities Water 152,730 BBLs construction Hazardous Sanitary Collection System­ 2,000,000 toilets Black water gallons Annually Non-Hazardous Waste Volumes are either specifically calculated or predicted qualitatively with: 1 = None; 2 = Minimal amounts infrequently; 3 = Minimal amounts frequently or moderate amounts infrequently; (0.25 m3 Solid or 0.5 BBL liquid) 4 = Regular production of moderate amounts and occasional production of large amounts; (1 m3 solid or 2 BBL Liquid) 5 = regular production of large amounts (> 10 m3 Solid or > 20 BBLs liquid) WAGP ENVIRONMENTAL IMPACT ASSESSMENT APPENDIX 2B-WASTE ESTIMATES TABLE 3 WAGP Pipeline ROW SOLID AND HAZARDOUS WASTES CONSTRUCTION SUMMARY (To Be Collected and Managed at the Lagos Beach Compressor Station or other centralized collection point) Equipment Waste Name Waste Types Quantity Frequency Classification RoW Vegetation, Once at start of Non- Clearance1 Woody Debri 1,500,000 m3 construction Hazardous Once after Steel Pipe Line delivery of Non- Line Pipe End Caps 3 pipeline Hazardous Non- Line Pipe Pipeline Offcuts 2 Once a week Hazardous Non- Line Pipe Wood / Dunnage 3 once at delivery Hazardous Concrete coating 500 kg per plant, month of Once at start of construction sites concrete plant RoW Clearance at R&MS*/ operations/.25 and then monthly removed concrete tonne for the during Non- Concrete blocks from RoW RoW removal construction Hazardous Pipeline joint Coating raps; FBE; 500 kg per Non- Materials Adhesive month Once a month Hazardous Welding Rod (welding Pipeline Non- stubs) Construction 3 Hazardous Computer Non- Computer Toners/Ink 2 Once a month Hazardous Paper, Plastics, Non- Office Rubbish 3 Once a week Hazardous Kitchen / Non- Cafeteria Food 3 Once a week Hazardous Waste Volumes are either specifically calculated or predicted qualitatively with: 1 = None; 2 = Minimal amounts infrequently; 3 = Minimal amounts frequently or moderate amounts infrequently; (0.25 m3 Solid or 0.5 BBL liquid) 4 = Regular production of moderate amounts and occasional production of large amounts; (1 m3 solid or 2 BBL Liquid) WAGP ENVIRONMENTAL IMPACT ASSESSMENT APPENDIX 2B-WASTE ESTIMATES TABLE 3 WAGP Pipeline ROW SOLID AND HAZARDOUS WASTES CONSTRUCTION SUMMARY (To Be Collected and Managed at the Lagos Beach Compressor Station or other centralized collection point) Equipment Waste Name Waste Types Quantity Frequency Classification 5 = regular production of large amounts (> 10 m3 Solid or > 20 BBLs liquid) Notes 1 - Assumes entire RoW has 1 m by 25 m band of vegetation * Assumes concrete coating operations occur at Compressor Station-no-concrete COATING occurs offsite (3rd Party)...you might be thinking concrete foundation works... WAGP ENVIRONMENTAL IMPACT ASSESSMENT APPENDIX 2B-WASTE ESTIMATES TABLE 4 WAGP R & M Station Togo, Benin, and Ghana CONSTRUCTION SOLID AND HAZARDOUS WASTES SUMMARY Activity / Equipment / Material Waste Name Waste Types Quantity Frequency Classification Equipment Lube Oil 1 BBLs Annually Hazardous AutoVehicles Filter 20 Annually Hazardous Minor Spill Clean ups; Maintenance activities Oily Rags 0.25 m3 Monthly Hazardous Medical treatment materials such bandages, swipes Mobile Clinic etc 0.25 m3 Monthly Hazardous Once at Pipeline X-ray Radioactive completion of inspection Materials 3 construction Hazardous Hydrotest during Pipeline Once at commissioning Biocide Treated completion of activities Water 23,876 BBLs construction Hazardous Sanitary Collection System­ 43,800 Non- toilets Black water gallons Annually Hazardous RoW Vegetation, Once at start of Non- Clearance1 Woody Debri 75,000 m3 construction Hazardous Steel Pipe Line Once after Non- Line Pipe End Caps 9,400 delivery of pipeline Hazardous Non- Line Pipe Pipeline Offcuts 9,400 Total Hazardous Non- Line Pipe Wood / Dunnage 4 once at delivery Hazardous WAGP ENVIRONMENTAL IMPACT ASSESSMENT APPENDIX 2B-WASTE ESTIMATES TABLE 4 WAGP R & M Station Togo, Benin, and Ghana CONSTRUCTION SOLID AND HAZARDOUS WASTES SUMMARY Activity / Equipment / Material Waste Name Waste Types Quantity Frequency Classification 500 kg per month of Once at start of Concrete coating concrete plant RoW Clearance plant, and operations/.25 and then monthly removed concrete tonne for the during Non- Concrete blocks from RoW RoW removal construction Hazardous Pipeline joint Coating raps; FBE; 500 kg per Non- Materials Adhesive month Once a month Hazardous HDD HDD Drilling Once during Non- Operations Muds 500m3 operation of HDD Hazardous Welding Rod (welding Pipeline Non- stubs) Construction 3 Once a month Hazardous Computer Non- Computer Toners/Ink 2 Once a month Hazardous Paper, Plastics, Non- Office Rubbish 0.25 m3 Once a week Hazardous Kitchen / Non- Cafeteria Food 0.25 m4 Once a week Hazardous Waste Volumes are either specifically calculated or predicted qualitatively with: 1 = None; 2 = Minimal amounts infrequently; 3 = Minimal amounts frequently or moderate amounts infrequently; (0.25 m3 Solid or 0.5 BBL liquid) 4 = Regular production of moderate amounts and occasional production of large amounts; (1 m3 solid or 2 BBL Liquid) 5 = regular production of large amounts (> 10 m3 Solid or > 20 BBLs liquid) Notes 1 - Assumes entire RoW has 1 m by 25 m band of vegetation * Assumes concrete coating operations occur at R&M Station-no-concrete COATING occurs offsite (3rd Party)...you might be thinking concrete foundation works... WAGP ENVIRONMENTAL IMPACT ASSESSMENT APPENDIX 2B-WASTE ESTIMATES Waste Stream and Volume Estimates for Operations From WAPCo's Waste Inventory and Characterization estimates of potential small continuous amounts of wastes are created due to operations (e.g. pigging, maintenance, etc.) of the pipeline. Operational activities will occur in each country. Specifically each R & M Station in Ghana, Togo, Benin, and at the Algabado T'ee in Nigeria. Operational activates will also be centered at the Compressor Station located in Nigeria Estimates of operation waste volumes are presented in the tables below (note procedures for handling and disposal are presented in Appendix 1): TABLE 5 WAGP ALGABADO Station SOLID AND HAZARDOUS WASTES OPERATIONS SUMMARY Waste Waste Equipment Name Types Quantity Frequency Classification Gas generators ­ 40 kW (2) Lube oil 2 barrels 1 Hazardous Gas generators ­ 40 kW (2) Filters 16 filters 1 Hazardous Sump Tank liquids 50 barrels 1 Hazardous Maintenance Free - Sealed Lead Batteries Acid 25 4 Hazardous AutoVehicles Filter 2 Annually Hazardous Minor Spill Clean ups; Maintenance activities Oily Rags 0.25 m3 Annually Hazardous Minor Spill Clean ups; Maintenance activities Oily Rags 0.25 m3 Annually Hazardous Sanitary Collection System­ 15,000 toilets Black water gallons Annually Non-Hazardous Paper, Plastics, Office Rubbish 0.25 m3 Monthly Non-Hazardous Woody/Plant Debris Vegetation 1 skip 0 Non-Hazardous WAGP ENVIRONMENTAL IMPACT ASSESSMENT APPENDIX 2B-WASTE ESTIMATES TABLE 5 WAGP ALGABADO Station SOLID AND HAZARDOUS WASTES OPERATIONS SUMMARY Waste Waste Equipment Name Types Quantity Frequency Classification Waste Volumes are either specifically calculated or predicted qualitatively with: 1 = None; 2 = Minimal amounts infrequently; 3 = Minimal amounts frequently or moderate amounts infrequently; (0.25 m3 Solid or 0.5 BBL liquid) 4 = Regular production of moderate amounts and occasional production of large amounts; (1 m3 solid or 2 BBL Liquid) 5 = regular production of large amounts (> 10 m3 Solid or > 20 BBLs liquid) WAGP ENVIRONMENTAL IMPACT ASSESSMENT APPENDIX 2B-WASTE ESTIMATES TABLE 6 WAGP Compressor Station SOLID AND HAZARDOUS WASTES OPERATIONS SUMMARY Waste Waste Equipment Name Types Quantity Frequency Classification Gas generators ­ 2 mW (2) Lube oil 20 barrels 4 Hazardous Gas generators ­ 2 mW (2) Filters 24 filters 1 Hazardous Compressors ­ (2) Lube oil 40 barrels 4 Hazardous Compressors ­ (2) Filters 24 filters 1 Hazardous Black start diesel generator (1) Lube Oil 2 Barrels 1 Hazardous Black start diesel generator (1) Filters 4 filters 1 Hazardous Fire pump ­ diesel (1) Lube Oil 1 barrel 1 Hazardous Fire pump ­ diesel (1) Filters 4 filters 1 Hazardous Ten Vehicles Lube Oil 2 Barrels 1 Hazardous Waste Volumes are either specifically calculated or predicted qualitatively with: 1 = None; 2 = Minimal amounts infrequently; 3 = Minimal amounts frequently or moderate amounts infrequently; (0.25 m3 Solid or 0.5 BBL liquid) 4 = Regular production of moderate amounts and occasional production of large amounts; (1 m3 solid or 2 BBL Liquid) 5 = regular production of large amounts (> 10 m3 Solid or > 20 BBLs liquid) WAGP ENVIRONMENTAL IMPACT ASSESSMENT APPENDIX 2B-WASTE ESTIMATES TABLE 6 WAGP Compressor Station SOLID AND HAZARDOUS WASTES OPERATIONS SUMMARY Waste Waste Equipment Name Types Quantity Frequency Classification Ten Vehicles Filters 20 1 Hazardous pigging Vessel Process liquids operation 50 barrels 1 Hazardous Air compressors (2) Lube oil 1 1 Hazardous Air compressors (2) Filters 4 1 Hazardous Maintenance Free - Sealed Lead Batteries Acid 75 4 Hazardous Minor Spill Clean ups; Maintenance activities Oily Rags 0.25 m3 Annually Hazardous Sanitary Collection 15,000 Non- System­ toilets Black water gallons Annually Hazardous Paper, Plastics, Non- Office Rubbish 0.25 m3 Monthly Hazardous Non- Woody/plant Debri Vegetation 1 skip 0 Hazardous Non- Ten Vehicles Used Tires 60 1 Hazardous Non- Air compressors (2) Desiccant 25 kg 5 Hazardous Waste Volumes are either specifically calculated or predicted qualitatively with: 1 = None; 2 = Minimal amounts infrequently; 3 = Minimal amounts frequently or moderate amounts infrequently; (0.25 m3 Solid or 0.5 BBL liquid) 4 = Regular production of moderate amounts and occasional production of large amounts; (1 m3 solid or 2 BBL Liquid) 5 = regular production of large amounts (> 10 m3 Solid or > 20 BBLs liquid) WAGP ENVIRONMENTAL IMPACT ASSESSMENT APPENDIX 2B-WASTE ESTIMATES TABLE 7 WAPCo R & M Stations Operations Solid and Hazardous Waste Summary Waste Waste Equipment Name Types Quantity Frequency Classification Gas generators ­ 40 kW (2) Lube oil 2 barrels 1 Hazardous Gas generators ­ 40 kW (2) Filters 16 filters 1 Hazardous Sump Tank liquids 10 barrels 1 Hazardous Maintenance Free - Sealed Lead Batteries Acid 25 4 Hazardous AutoVehicles Filter 2 Annually Hazardous Minor Spill Clean ups; Maintenance activities Oily Rags 0.25 m3 Annually Hazardous Sanitary Collection Non- System­ toilets Black water 45,000 gallons Annually Hazardous Paper, Plastics, Non- Office Rubbish 0.25 m3 Monthly Hazardous Non- Woody/plant Debris Vegetation 1 skip 0 Hazardous Appendix 2-C Onshore and Offshore Commissioning Procedures and Specifications List West African Gas Pipeline PIPELINE CLEANING, FLOODING AND GAUGING PARAGON ENGINEERING SERVICES Specification No.: WAGP-P-Y-SA-0086-0 Paragon Project Number A2089 Revision: A 0 1 2 Description: Issued for Client Review Issued for Tender Prepared By: RST RST Check By: JHG JHG Dept. Check By: - TFC Approved By: DH DH Date of Issue: 26 March 2003 28 March 2003 WEST AFRICA GAS PIPELINE PROJECT SPECIFICATION NUMBER: WAGP-P-Y-SA-0086-0 TABLE OF CONTENTS 1. INTRODUCTION .................................................................................................................3 2. REFERENCE CODES, STANDARDS AND SPECIFICATIONS.........................................3 3. GENERAL REQUIREMENTS..............................................................................................3 4. EQUIPMENT AND INSTRUMENTATION ...........................................................................7 5. SAFETY AND PERMITS .....................................................................................................8 6. PROCEDURE MANUAL......................................................................................................8 Page 2 of 9 1. INTRODUCTION 1.1. Scope This Specification defines the minimum requirements for cleaning, flooding and gauging of pipelines for the onshore pipelines associated with the West African Gas Pipeline Project prior to hydrostatic testing. Within the body of this specification, the following definitions will apply: COMPANY is the West African Gas Pipeline Company (WAPCo).