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This document, and the opinions, analysis, evaluations, or recommendations contained herein are for the sole use of the contracting parties. There are no intended third party beneficiaries, and Jacobs Consultancy shall have no liability whatsoever to third parties for any defect, deficiency, error, omission in any statement contained in or in any way related to this document or the services provided.

Ghana 1000 Gas to Power Project ONE ENERGY, GHANA

ESIA Scoping Assessment 60K28901 Revision: 0 Date: 7 November 2014

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Jacobs Consultancy Petroleum, Chemicals & Energy Practice Tower Bridge Court 226 Tower Bridge Road London SE1 2UP

Ghana 1000 Gas to Power Project

ESIA Scoping Assessment

ONE ENERGY

JACOBS CONSULTANCY PROJECT NO: 60K28901

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Project No. : 60K28901

Document No. : 3

Revision : 0

Revision description : Draft for client review

Prepared by : Liz Turk / JP Wale

Checked by : Larraine Wilde

Approved by : Glyn Johnson and Endeavor – Steven Purvis / Richard Whyte

Issue date : 7 November 2014

Date Description Of Alteration Rev No

Proponent: One Energy Limited

Address for correspondence: 91 Osu Badu Street

West Airport

Accra

Ghana

Contact person Mr Kingsley Asare

Position Ghana 1000 Project Manager

Phone No. +233 (0) 55.451.3862

Fax No. N/A

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The report was prepared by Jacobs Consultancy Ltd. (“Jacobs’) for the sole benefit and use of Endeavor Energy. Jacobs and its affiliates shall have no liability whatsoever to third parties for any defect, deficiency, error, or omission in any statement contained in or in any way related to the study or report or any related documents. Neither Jacobs nor any person acting on Jacobs’ behalf makes any warranty, express or implied, or assumes any liability with respect to use or reliance on any information, technology or methods disclosed or discussed in the study or report. Any forecasts, estimates, projections, opinions or conclusions reached in the study or report are dependent upon numerous technical and economic conditions over which Jacobs has no control and which are or may not occur. Reliance upon such opinions or conclusions by any person or entity is at the sole risk of the person relying thereon.

The data, information and assumptions used to develop the report or study were obtained or derived from documents or information furnished by others. Jacobs did not independently verify or confirm such information and does not assume responsibility for its accuracy or completeness. Any forecasts, or costs or pricing estimates in the study or report are considered forward-looking statements and represent Jacobs’ current opinion and expectation of a likely outcome. They do not anticipate possible changes in governmental policies, governmental regulations, military action, embargoes, or production cutbacks, regional conflicts, or other events or factors that could cause the forecast or estimates to differ materially from what is contained in our forward-looking statements. The study or report is dated as of the date Jacobs completed its work. Jacobs has no obligation to update or revise the study or report or to revise any opinions, forecasts or assumptions because of events, circumstances or transactions occurring after the date of the study or report.”

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Contents EXECUTIVE SUMMARY .......................................................................................................................... i 1 Introduction .................................................................................................................................. 3

1.1 Overview ........................................................................................................................... 3 1.2 Project Location ................................................................................................................ 3 1.3 One Energy – The Proponent ........................................................................................... 7 1.4 Needs Case ...................................................................................................................... 7 1.5 Project Timescales ........................................................................................................... 8 1.6 Document Structure .......................................................................................................... 8

2 The ESIA Process ........................................................................................................................ 9

3 Project Description .................................................................................................................... 14

3.1 Onshore Components .................................................................................................... 14 3.2 Offshore Components .................................................................................................... 24 3.3 Project Alternatives ......................................................................................................... 45

4 Legislation and Standards ........................................................................................................ 49

4.1 National ........................................................................................................................... 49 4.2 International Conventions ............................................................................................... 49 4.3 International Standards .................................................................................................. 51 4.4 Emission Limit Values .................................................................................................... 52

5 Review of Stakeholder Activities to Date ................................................................................ 58

5.1 Overview ......................................................................................................................... 58 6 Environmental and Social Context ........................................................................................... 62

6.1 Overview ......................................................................................................................... 62 6.2 Project Area of Influence ................................................................................................ 62 6.3 Environmental Baseline .................................................................................................. 62

7 Environmental and Social Scoping Assessment.................................................................... 78

7.1 Overview ......................................................................................................................... 78 7.2 Onshore Power Plants and Pipeline ............................................................................... 78 7.3 Offshore Components .................................................................................................... 92 7.4 Summary of Key Findings from the Scoping Assessment ............................................. 96

8 EIA Terms of Reference ............................................................................................................. 98

8.1 Overview ......................................................................................................................... 98 8.2 EIA Table of Contents .................................................................................................... 98 8.3 Project Description.......................................................................................................... 98 8.4 Determining the need for the Project .............................................................................. 99 8.5 Policy, legal and administrative framework .................................................................... 99 8.6 Analysis of alternatives ................................................................................................... 99 8.7 Environmental and Social Baseline ................................................................................ 99 8.8 Impact assessment and evaluation of significance ...................................................... 100 8.9 Cumulative impacts ...................................................................................................... 101 8.10 Mitigation ...................................................................................................................... 101 8.11 Non-technical summary ................................................................................................ 101 8.12 Impact Assessment Methodologies .............................................................................. 101 8.13 Framework Environmental and Social Management Plan ........................................... 111

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Appendix A: EPA Screening Confirmation ...................................................................................... 114

Appendix B: International Labour Organisation — Conventions ................................................. 115

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Figures and Tables Figure 1-1: Project Location .................................................................................................................. 4 Figure 1-2: Onshore Project Components and Location ................................................................... 5

Figure 1-3: Offshore Project Components and Location ................................................................... 6

Table 1-1: Approximate Project Timescales ........................................................................................ 8

Table 2-1: Summary of Key ESIA Documentation required for National Permitting in Ghana and International Standards .................................................................................................................. 9

Figure 3-1: Open (Simple) Cycle ......................................................................................................... 17 Figure 3-2: Combined Cycle ................................................................................................................ 17

Table 3-1: Estimated Chemical Consumption ................................................................................... 24

Figure 3-3: Proposed Site Layout including Indicative Location of FSRU ..................................... 25

Figure 3-4: Typical FSRU ..................................................................................................................... 26

Figure 3-5: Ship to Ship Transfer ........................................................................................................ 27

Table 3-2: Ship to Ship Transfer Summary ........................................................................................ 28 Figure 3-6: Cargo Tank General Design ............................................................................................. 29

Table 3-3: LNG Carrier Water Use in Dock with FSRU ..................................................................... 33

Table 3-4: FSRU Classification ........................................................................................................... 36

Figure 3-7: Process Flow Diagram ..................................................................................................... 38

Figure 3-8: FSRU LNG Regasification Process ................................................................................. 41

Figure 3-9: High Pressure Gas Loading Arm .................................................................................... 43 Figure 3-10: Alternative Site Location and Sanzule .......................................................................... 46

Table 4-1: Treaties and Conventions.................................................................................................. 50

Table 4-2: Ambient Air Quality Standards ......................................................................................... 52

Table 4-3: EPA Energy Sector – Guidelines ...................................................................................... 53

Table 4-4: IFC Air Emission Guidelines for Natural Gas Thermal Power Plants Less than 50MWth (potentially applicable to the FSRU) .................................................................................... 54 Table 4-5: IFC Air Emission Guidelines for Thermal Power Plants Greater than 50MWth (applicable for onshore power plants) ............................................................................................... 54

Table 4-6: EPA Emissions from Sources ........................................................................................... 55

Table 4-7: IFC EHS Noise Limits ......................................................................................................... 55

Table 4-8: EPA Noise Limits ................................................................................................................ 56

Table 4-9: Ghanaian and IFC Water Quality Discharge Standards ................................................. 57 Table 5-1: ESIA Stakeholder Engagement Implementation Timescales and Responsibilities .... 58

Table 5-2: Pre-screening Site Visit Meetings Held July 2014 .......................................................... 60

Table 5-3: Site Visit Meetings Held Week 6 October 2014 .............................................................. 60

Table 6-1: Ambient Air Concentrations (T2 Expansion EIS, 2009) .................................................. 64

Table 6-2: Averaged Daytime Noise Levels from the Surveys at Aboadze Village ....................... 65

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Table 6-3: Averaged Night-time Noise Levels from the Surveys at Aboadze Village .................... 65

Table 6-4: Proposed Power Projects .................................................................................................. 75

Table 8-1: Key Characteristics to be Assessed during Turtle Nesting Beach Survey ................ 103

Table 8-2: Geographical Context and Policy Importance .............................................................. 110

Table 8-3: Magnitude Criteria ............................................................................................................ 110

Table 8-4 : Evaluation of Significance of Effect .............................................................................. 111

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Glossary BAT Best available technique BMPs Best Management Practices BOG Boil off Gas CCGT Combined Cycle Gas Turbine CEMs Continuous Emissions Monitoring CO Carbon monoxide CO2 Carbon dioxide DFO Diesel Fuel Oil DCS Distributed Control System DLN Dry Low NOx ECG Energy Commission of Ghana EIA Environmental Impact Assessment EHS Environmental Health and Safety EPA Environmental Protection Agency ESD Emergency Shutdown Valves ERC Emergency Release Couplings E&S Environmental and Social EIS Environmental Impact Statement EMS Environmental management system EPC Engineering, procurement and construction ESAP Environmental and social action plan ESMMP Environmental and social management and mitigation plan ESIA Environmental and social impact assessment FRA Flood risk assessment FSRU Floating Storage and Regasification Unit GE General Electric GH1k Ghana 1000MW Project GoG Government of Ghana HPMLA High pressure marine loading arm HP High Pressure HRSG Heat Recovery Steam Generator IAS Integrated Automation System IFI International Financial Institution ILO International Labour Organisation IFC International Finance Corporation IPP Independent Power Project JDA Joint Development Agreement JVA Joint Venture Agreement LCO Light Crude Oil LNG Liquefied Natural Gas LNGCs Liquefied Natural Gas Carriers LP Low Pressure MARPOL The International Convention for the Prevention of Pollution from Ships MMSCFD Million standard cubic feet per day MW Mega Watt MGD Million Gallons per Day NGO Non-Government Organisation

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NOx Nitrogen oxide NO2 Nitrogen dioxide O&M Operations and Maintenance PM Particular Matter PS Performance Standard QC/DC-ERS Quick connect/quick disconnect and emergency release system RAP Resettlement Action Plan RPT Rapid Phase Transition SAEMA Shama Ahanta East Metropolitan Assembly SCADA Supervisory Control and Data Acquisition SSL Ship shore link STS Ship to ship STV Shell and Tube Vaporisation SOx Sulphur oxide SO2 Sulphur dioxide SOLAS International Convention for the Safety of Life at Sea” (SOLAS) TTPP Takoradi Thermal Power Plant VOC Volatile Organic Compounds VRA Volta River Authority WAGP West African Gas Pipeline WHO World Health Organisation

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EXECUTIVE SUMMARY

Ghana 1000 (GH1K) is a greenfield, integrated gas-to-power Project that will produce 1300 megawatts (MW) of electricity from natural gas. The Project will include a combined cycle gas turbine power plant (CCGT), liquified natural gas import infrastructure in the form of a floating storage and regasification unit (“FSRU”) and gas pipeline from the FSRU to the power plant. The Project is located in Aboadze, Takoradi and is being developed by One Energy Limited.

One Energy has been formed under a Joint Development Agreement (JDA) between Endeavor Energy Power Holdings Limited (Endeavor Energy), General Electric (GE), SAGE Petroleum Limited (SAGE) and Eranove (Operations and Maintenance (O&M) Operator), together forming the “the Proponent”.

The Project comprises the following key aspects:

• Phase 1: 750MW net CCGT power plant;

• Phase 2: 550MW net CCGT power plant; and

• Off-shore FSRU: The FSRU component includes the FSRU, construction of an offshore breakwater and jetty to harbour the FSRU, and construction of a sub-sea pipeline from the FSRU to the existing gas receiving station via the existing VRA site, and then from receiving station on to the main site.

Project Location - The onshore components of the project are located on the south-west coast of Ghana approximately 15 km north west of the towns of Sekondi and Takoradi. The project site is situated roughly between five settlements of varying sizes, of which the nearest settlement (approximately 1 km to the west) is Aboadze. The VRA township for the plant is sited approximately 500m west of the site boundary. The surrounding area is relatively low lying, particularly the area immediately to the north of the site.

The location of the LNG FSRU is expected to be approximately 3km offshore of the Aboadze power plant area in order to avoid key fishing areas for artisanal fishermen (understood from consultations with the Ghana Fisheries Commission to be 4-6km off shore). A new gas pipeline connection will run to shore with a distance of approximately 4 km, most of which will be sub-sea.

Why is the project important - In the past 15 years, Ghana has added about 1,000 MW of thermal generation capacity to its existing load. Ghana’s current generation capacity of 2,125 MW is made up of about 50% hydro and 50% thermal plants. However, despite power development, unreliable power supply remains a major constraint to the future economic growth of the country.

The cut-off of West Africa Gas Pipeline (WAGP) gas and delays in production from the Jubilee gas fields has forced the existing local power producers in Takoradi to buy light crude oil (LCO) to operate their thermal power plants. LCO generation is nearly three times as expensive as gas-fired generation and atmospheric emissions from LCO are considered to contain more harmful pollutants than the emissions from natural gas.

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Ensuring a secure and adequate supply of natural gas is fundamental to improving the availability and cost of power in Ghana. The meeting of these increasing energy demands, both locally and within Ghana as a whole, is required to support continued growth, associated employment opportunities and necessary infrastructure developments.

What is this Document - This document presents the findings of the One Energy environmental and social impact assessment (ESIA) scoping assessment for the Project as part of the national environmental impact assessment (EIA) requirements. The scoping assessment includes the following components to meet the scoping requirements for the Ghana Environmental Protection Agency (EPA) and international finance community:

• Section 1 – Introduction.

• Section 2 – Overview of the Environmental and Social Impact Assessment (ESIA) Process.

• Section 3 – Project Description.

• Section 4 – Legislation and Standards.

• Section 5 – Review of Stakeholder Consultation Activities.

• Section 6 – Environmental and Social Context (baseline).

• Section 7 – Environmental and Social Scoping Assessment.

• Section 8 – ESIA Terms of Reference.

Have your say - As part of our commitment to consulting and sharing information about this project with the local community, One Energy will be hosting a community workshop as part of the first steps in the environmental and social impact assessment (ESIA) process for the project. This event will be held at Aboadze Community Centre on 20 November. Details are available on line at www.sagepetroleumgh.com and adverts placed locally and in media and press.

Comments relating to the project and this scoping assessment can be addressed to the following:

Name: Mr Kingsley Asare

Address: 91 Osu Badu Street West Airport Accra Ghana

Email: [email protected]

Telephone Number: +233 (0) 55.451.3862

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http://www.sagepetroleumgh.com/

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1 Introduction

1.1 Overview

Ghana 1000 (GH1K) is a greenfield, integrated gas-to-power project that will produce 1300 megawatts (MW) of electricity from natural gas. The project will include a combined cycle gas turbine (CCGT) power plant, liquified natural gas (LNG) import infrastructure in the form of a floating storage and regasification unit (“FSRU”) and gas pipeline from the FSRU to the power plant. The project is located in Aboadze, Takoradi and is being developed by One Energy Limited. The project comprises the following key aspects:

• Phase 1: 750MW net CCGT power plant;

• Phase 2: 550MW net CCGT power plant; and

• Off-shore FSRU: The FSRU component includes the FSRU, construction of an offshore breakwater and jetty to harbour the FSRU, and construction of a sub-sea pipeline from the FSRU to the existing gas receiving station via the existing VRA site, and then from receiving station on to the main site.

This document presents the findings of the One Energy environmental and social impact assessment (ESIA) scoping assessment for the project as part of the national environmental impact assessment (EIA) requirements. Further details on the national EIA requirements are presented in Section 4.

1.2 Project Location

The onshore components of the project are located on the south-west coast of Ghana approximately 15 km north west of the towns of Sekondi and Takoradi. The project site is situated roughly between five settlements of varying sizes, of which the nearest settlement (approximately 1 km to the west) is Aboadze. The VRA township for the plant is sited approximately 500m west of the site boundary. The surrounding area is relatively low lying, particularly the area immediately to the north of the site. The Anankwari River and associated tributaries flows east and south of the project site. Figure 1-1 and Figure 1-2 depicts the onshore project.

The location of the LNG FSRU is expected to be approximately 3km offshore of the Aboadze power plant area in order to avoid key fishing areas for artisanal fishermen (understood from consultations with the Ghana Fisheries Commission to be 4-6km off shore). A new gas pipeline connection will run to shore with a distance of approximately 4 km, most of which will be sub-sea. Figure 1-3 depicts the location of the offshore project components.

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Figure 1-1: Project Location

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Figure 1-2: Onshore Project Components and Location

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Figure 1-3: Offshore Project Components and Location

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1.3 One Energy – The Proponent

One Energy has been formed under a Joint Development Agreement (JDA) between Endeavor Energy Power Holdings Limited (Endeavor Energy), General Electric (GE), SAGE Petroleum Limited (SAGE) and Eranove (Operations and Maintenance (O&M) Operator), together forming the “the Proponent”.

Comments relating to the project and this scoping assessment can be addressed to the following:

Name: Mr Kingsley Asare Address: 91 Osu Badu Street

West Airport Accra Ghana

Email: [email protected] Telephone Number: +233 (0) 55.451.3862

1.4 Needs Case

In the past 15 years, Ghana has added about 1,000 MW of thermal generation capacity to its existing load. Ghana’s current generation capacity of 2,125 MW is made up of about 50% hydro and 50% thermal plants. However, despite power development, unreliable power supply remains a major constraint to the future economic growth of the country.

The cut-off of West Africa Gas Pipeline (WAGP) gas and delays in production from the Jubilee gas fields has forced the existing local power producers in Takoradi to buy light crude oil (LCO) to operate their thermal power plants. LCO generation is nearly three times as expensive as gas-fired generation and atmospheric emissions from LCO are considered to contain more harmful pollutants than the emissions from natural gas.

Ensuring a secure and adequate supply of natural gas is fundamental to improving the availability and cost of power in Ghana. The meeting of these increasing energy demands, both locally and within Ghana as a whole, is required to support continued growth, associated employment opportunities and necessary infrastructure developments.

The objective of the project is to:

• Provide continuous, reliable, high efficiency and low cost gas and subsequently energy for the region and country;

• Provide a source of gas, essential to current and future power supply from the Takoradi area;

• Contribute to national energy requirements for sustainable development;

• Contribute to regional energy requirements for sustainable development;

• Contribute to a diverse energy base to secure energy requirements for Ghana;

• Contribute to a diverse fuel mix by securing lower cost and lower emissions LNG supply;

• Provide economic and social benefits on both a national and regional level;

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• Provide employment opportunities to the community residing in the region and near-by;

• Contribute to the local economy, and social and technical infrastructure; and

• Increase the diversity of energy resources for Ghana.

1.5 Project Timescales

The estimated timing of the development for each of the project phases is summarised as follows:

Table 1-1: Approximate Project Timescales

Item Phase 1 Phase 2

EPC Contract Notice to Proceed October 2015 TBC

Early Phase Open Cycle Operation (Unit 1) June 2016 TBC

Early Phase Open Cycle Operation (Unit 2) August 2016 TBC

Combine Cycle Operation (Units 1 & 2) August 2017 TBC

Early Phase Open Cycle Operation (Unit 3) February 2017 TBC

Early Phase Open Cycle Operation (Unit 4) April 2017 TBC

Combined Cycle Operation (Total plant) April 2018 TBC

Plant operation life [25] years [25] years

1.6 Document Structure

The scoping assessment includes the following components to meet the scoping requirements for the Ghana Environmental Protection Agency (EPA) and international finance community:

• Section 1 – Introduction.

• Section 2 – Overview of the Environmental and Social Impact Assessment (ESIA) Process.

• Section 3 – Project Description.

• Section 4 – Legislation and Standards.

• Section 5 – Review of Stakeholder Consultation Activities.

• Section 6 – Environmental and Social Context (baseline).

• Section 7 – Environmental and Social Scoping Assessment.

• Section 8 – ESIA Terms of Reference.

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2 The ESIA Process

An ESIA is a systematic, scientific and participatory process to assess potential environmental and social impacts of a development, including consideration of project alternatives, cumulative impacts with other planned developments, the use of natural resources and potential implications of climate change. The process involves public consultation and disclosure of findings at every phase.

The key output of the ESIA process is the ESIA Study Report (sometimes referred to as an Environmental Impact Statement or EIS). The EIS is an independent document which sets out the predicted significant environmental and social impacts of the proposed development and proposes mitigation and associated action plans to avoid, reduce, remedy or compensate for identified potentially significant impacts. The ESIA is supplemented by the Environmental and Social Management Plan (ESMP). The ESMP summarises the mitigation action plan and shows how these will be implemented, managed, monitored and reported.

The ESIA Study Report enables the EPA, local community and other key stakeholders to determine whether or not the proposals (including recommended mitigation) are acceptable. The report also informs the permitting process as the recommended mitigation measures and other actions included in the ESMP form conditions of the EIA Permit issued by the EPA.

Table 2-1 below summarises the key ESIA documentation required for National Permitting and International Standards.

Table 2-1: Summary of Key ESIA Documentation required for National Permitting in Ghana and International Standards

Required for National /

International / Both

Phase / Project Status Documentation Required

Approximate National Approval

Timescale1

Both Screening - One Energy received approval for their screening application on the 28 October 2014. This is presented in Appendix A.

A proponent has to submit a registration form or environmental screening form to the EPA for all activities listed in Schedule I and II of the EPA Act 1994 (see Section 4 for further details). The screening documentation submitted by the proponent should contain information on:

• Details on the proposed activity (including a description of waste generation);

• The proposed location (location, zoning, site description, land cover and topography);

• Infrastructure and utilities; • Environmental impacts (air quality, biological

resources, cultural resources, water quality and hydrology, noise, other impacts);

• Health and safety impacts; • Management of impacts (air quality, biological

resources, cultural resources, water quality and hydrology, noise others);

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Timescale1

• Alternatives to the establishment of the activity; and

• List of stakeholders consulted (including evidence).

Lenders have their own internal risk screening process for categorization including Lenders that are signatories to the Equator Principles.

Both Scoping - this document.

Scoping is a required step, resulting in an approved Terms of Reference (ToR) for the ESIA. The proponent has to produce a scoping report, which includes a ToR for the ESIA. During scoping, the proponent should consult with affected parties (see Section 5 for details of consultation activities undertaken to date and proposed). The scoping report is made available for the general public. The EPA reviews the Scoping report with the help of a cross-sectoral technical committee and has to approve the report and the ToR before the full ESIA can be completed.

The scoping report contains a description of any issues raised during the consultation process, and how these will be addressed in the ESIA. The ToR for the ESIA is presented in Section 8 of this report.

A maximum of 25 days.

Both ESIA1 assessment and reporting

The ESIA study report, or EIS, has to contain information on direct and indirect impacts of the project on the environment at the pre-construction, construction, operation, decommissioning and post-decommissioning phases. The EIS2 draft report is reviewed by the EPA, assisted by a cross-sectoral technical committee at the regional and national levels. EPA uses an 'instructions for reviewing EIA reports' document. The review should result in a summary of strengths and weaknesses of the report, needs for further study (if any), any impact monitoring

The draft EIA report is reviewed in a maximum of 50 days.

11 ESIA – Environmental and Social Impact assessment. Note that national legislation only refers to EIA although there is an expectation that

social issues will also be addressed. Lenders use the term ESIA and the two should be considered to be interchangeable in the context of this project.

2 The Environmental Impact Statement (EIS) is the report/outcome of the ESIA/EIA process.

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Timescale1

required and any terms and conditions that should apply if approval is granted. The EPA and Committee make the decision whether a revision of the ESIA report is required or whether approval can be issued by the EPA. Then the ESIA report may be finalized.

National Environmental Permit

After finalization of the ESIA report the Environmental Permit should be issued within a maximum of 15 days. The EPA is bound by legislation to complete all its reviews/responses (e.g. for screening, scoping and draft ESIA/permit award) in not take more than 90 days – though this does not include time for any public hearings if these are required.

Environmental permit should be issued with 15 days on finalization of the ESIA.

Both Stakeholder Consultation / Public Participation See Section 5 for details of consultation events undertaken and proposed for the project.

Public concerns are key criteria for the screening decision. For a full ESIA, the affected and interested parties should be consulted at every stage of the ESIA process (see Section 5 for details of consultation activities undertaken to date and proposed for this project). The public may make comments on the scoping report, make a request to visit the project site, may comment on the draft ESIA report and, if a public hearing is deemed necessary, be involved in the public hearing. During scoping, the proponent is directed to advertise the project in at least one national newspaper and a local newspaper. The proponent should consult with affected parties. The public may also express their view to the managing director of the proposed activity and the executive director of EPA. A public consultation event has been booked and advertised for the 20 November. The draft EIS has to be published for 21 days so that the public can express their concerns. During the review process, EPA can decide to hold a public hearing in the following cases:

• The expected environmental impacts are considered extensive and far reaching;

• There is great adverse public reaction to a

Scoping – advertise / consult A 21 day period for public disclosure is required. In case a public hearing is held, the panel shall make recommendations in writing to the EPA within a period of not less than 15 days from the date it starts hearing representations. Draft EIS need to be publically disclosed for 21 days.

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Timescale1

proposal; and/or • There will be relocation or dislocation of

communities. The EPA will then appoint a panel of three to five persons to gather information on the public concerns and how these could be addressed. At least two-thirds of the panel members must be residents of the geographic area where the activity will be undertaken. The stakeholders to be involved are: the general public, relevant public agencies, organizations, NGOs, Metropolitan, Municipal and District Assemblies and local communities. See Section 5 for a full list of the stakeholders identified for this project. When a draft EIS has been prepared, the proponent publishes a notice for at least 21 days in at least a national and a local newspaper. No specific language requirements are made in the regulations for reporting, but consultation is conducted in the local language. The EPA decision on the environmental permit is published in the Gazette and through mass media.

Both Monitoring / compliance

Monitoring is required. The EPA has established Field Offices and head office departments that undertake compliance monitoring, evaluation and enforcement of conditions. The monitoring regimes and parameters are defined in permitting schedules on a case by case basis. Firstly self-compliance is expected from the proponent. In general, the proponent is required to submit a (provisional) Environmental Management Plan (EMP) to the EPA within 18 months of the commencement of the activities and thereafter every three years. The EMP shall set out steps that are intended to manage any significant impacts that may result from the operation of the undertaking. Moreover, an Annual Environmental

Provisional EMP – 18 months of commencement of activities and every 3 years subsequent. Within 24 months of commencement report documenting alignment with EPA conditions.

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Timescale1

Report should be submitted to the EPA after 12 months and every 12 months thereafter. These deliverables have to be approved by the EPA. Within 24 months after commencing the activity, the proponent should send evidence to the EPA that the activity is in line with the conditions written in the ESIA. The proponent then obtains an Environmental Certificate, if the first Annual Environmental Report has been submitted. For international finance, lenders will expect to see EMPs produced as part of the ESIA and the EMP will underpin the lenders internal Environmental & Social Action Plan (ESAP) that will be used to monitor compliance with lenders requirements throughout the life of the project. Lenders construction monitoring will take place every 4-6 months, following commencement of the project and there will be periodic monitoring (generally annually) during the operational phase.

1) Timescales are provided within publically available information from the Ghana EPA. Timescales are likely to vary in practice.

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3 Project Description

3.1 Onshore Components3

3.1.1 Overview

The Ghana 1000 Project will be a combined cycle gas turbine (CCGT) generating station with a net electrical capacity of approximately 1310 MW. The Project is proposed for development in two phases; 750 MW developed in Phase 1 and 560 MW developed in Phase 2. Phase 1 will consist of two similar power blocks whilst Phase 2 will be developed as a single power block.

CCGT technology principally comprises a combination of gas turbines and steam turbines (together with associated generators). The gas turbines will be fired on regasified LNG or LCO whilst the steam will be provided by a heat recovery steam generator (HRSG) dedicated to each of the gas turbines.

For GH1K, the arrangement of turbines will be:

• Phase 1, two blocks (phase 1a and 1b) each consisting of:

o Two gas turbines;

o Two HRSGs; and

o One steam turbine.

• Phase 2 will consist of:

o Three gas turbines;

o Three HRSGs; and

o One steam turbine.

Cooling for the Project will be provided by air-cooled condensers (ACC), with one dedicated ACC serving the relevant cooling duty of each block.

As discussed later in this document, the Project will require demineralised water for make-up to the steam / water cycle of each power block and for the control of the emission of oxides of nitrogen (NOx) in the flue gases from each gas turbine. In order to provide such water, the Project will, for each Phase, include:

Raw water storage tank(s):

• Water treatment (demineralisation) plant; and

• Demineralised (demin) water storage tank(s).

It is anticipated that raw water will be supplied by the abstraction of sea water via new abstraction and intake pipe infrastructure.

3 Description for on shore components provided by One Energy technical advisor Parsons Brinkerhoff

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Waste water (e.g. from boiler blowdown or the water treatment plant effluent) will be treated by two dedicated waste water treatment plants (one for each Phase) to control the composition and properties of the effluent to within limits as defined by the EPA.

The Project will be designed for an operational life of at least 25 years. At the end of its life, the Project will be decommissioned and the site reinstated as agreed with the relevant authorities. Decommissioning would take account of the environmental legislation and the technology available at the time. Any necessary licences or permits would be acquired.

3.1.2 Site Layout

It is intended that Phase 1 of the Project will be located to the south of the overall site area proposed for GH1K. This arrangement has been selected in order to minimise the required high voltage (HV) cable route distance in the event that the first gas turbine unit is to evacuate power to the existing GRIDCo 330 kV or 161 kV switchyards.

The Phase 1 development includes three untreated LCO tanks and two treated LCO tanks to provide the backup fuel requirements for the Phase 1 project. An additional three treated LCO tanks are provided for the Phase 2 project.

The layout shows detail of the power block for each phase including additional ancillary plant and buildings (e.g. control buildings, workshop, water treatment plant, fuel treatment buildings, water storage tanks etc.). A more detailed specific site layout will be developed as the Project progresses.

The indicative LNG gas supply route and LCO forwarding pipe route has been proposed to avoid impacting upon the future development at the enclave and to minimise the co-location with the West African Gas Pipeline route. The LNG gas supply pipe route is based upon the assumption that the floating LNG storage regasification unit will be located adjacent to the existing Single Point Mooring (SPM) towards the south east of the site.

The above layout includes indicative routes for the following off-site plant:

• Site access road (370 m) from highway to the north;

• Seawater supply and effluent discharge pipes (1.6 km) to the south west (proposed location of seawater intake /outfall structure);

• LCO forwarding pipe (2.1 km) from the existing VRA LCO tanks;

• LNG Gas supply pipe (5.6 km, assuming 3 km offshore distance and 2.6km onshore route distance) following the same onshore route as for the LCO forwarding pipe; and

• Ghana Gas supply pipe (1.1 km) from Ghana Gas GRMS to the north.

For the above items, the final selection of the route is subject to detailed survey and identification of land ownership and arrangements for securing use of land for the Project.

To export the generated power from the Phase 1 and Phase 2 plant a new 330 kV switchyard configured with breaker and a half arrangement is proposed to the east of the site. This is selected to reduce the required overhead line tie-in distance to the 330 kV overhead line corridor route from

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the 330 kV Takoradi substation heading north. It is understood that GRIDCo is planning development of these 330 kV overhead lines in the near term.

As part of the temporary works the EPC Contractor would provide portable office site accommodation for his own and sub-Contractors staff, site office accommodation for the Engineer / Owner’s construction management personnel, toilet and kitchen facilities, graded parking areas and canteen facilities. All of these facilities will need to be located outside of the proposed site area.

Further to this a construction laydown area would be required. The additional area of land required is typically equivalent to the area of land that will be occupied by the finished power plant site. For the Phase 1 project it is expected that the future Phase 2 land area (to the north of the Project site) would be utilised for laydown. For Phase 2, additional land to the north east of the site, or to the west of the Anankwari River, may be required. The ESIA will assess the currently understood site boundary and appropriate buffer. Should any additional land be required, this will be subject of additional study and appropriate amendment to the ESIA and EPA permits.

3.1.3 Proposed Technology

The Project will be designed to provide a total generation capacity of approximately 1310 MW. Operation of the Project is intended to be developed as a CCGT plant however subject to instruction / dispatch requests from the GRIDCo (as the transmission system operator) or at times when the steam / water cycle is not available, the Project may also operate as an open cycle gas turbine (OCGT) plant.

Figure 3-1 presents a schematic representation of the OCGT principle and Figure 3-2 presents a schematic representation of the CCGT principle.

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Figure 3-1: Open (Simple) Cycle

Figure 3-2: Combined Cycle

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The Project will require the following elements:

• OCGT operation:

o Gas turbines;

o Electrical generator(s) and transformer(s);

o Raw / fire water storage tanks;

o On-site switchgear;

o Administration / workshop / warehouse and storage / etc. buildings;

o Ancillary plant and equipment; and

o Bypass Stacks.

• CCGT operation (in addition to the above):

o Steam turbines;

o HRSGs;

o ACCs and auxiliary cooling;

o Water treatment plant;

o Demineralised water storage tank(s); and

o Main Stacks4.

3.1.4 Fuel Supply

The Project will be capable of utilising regasified LNG or LCO as fuel for the combustion process. The Project may also be fired on natural gas.

The gas supply to the plant will be dependent upon the timing and / or the successful design and implementation of the partnering floating LNG regasification plant (LNG InfraCo). The floating storage regasification unit is expected to be moored at an offshore location at the Takoradi / Aboadze enclave area, as discussed in Section 3.2.

Following construction of the Project, should LNG not be available, natural gas may be taken from the gas supply pipeline from Ghana Gas GMRS, to the north of the site.

No natural gas or LNG will be stored on-site.

LCO will be delivered to site via an LCO forwarding pipe from the existing SPM unloading pipe valve station (to immediate south of existing VRA LCO tanks). The Project (both Phases) will incorporate storage tanks for both untreated LCO (three) and treated LCO (five).

Each tank will be capable of storing up to 26 000 m3 of LCO, with a total on-site storage of LCO of up to approximately 208 000 m3. These storage arrangements will be sufficient to allow for 36 days and 29 days operation for Phase 1 and Phase 2, respectively.

4 Bypass stacks will not be used during CCGT operation

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3.1.5 Equipment Description

3.1.5.1 Gas Turbines

Each power block will comprise industrial type gas turbines that will consist of an inlet air filter, an air compressor, combustion chambers (including water injection for control of NOx emissions), power turbine and exhaust silencer. Air will be compressed in the compressor of the gas turbine and gaseous fuel injected into the combustion chambers where the fuel will burn producing hot, high-pressure gases. These gases will expand across the rotor blades of the gas turbine, which will drive both the compressor and the electrical generator(s).

However, the low-pressure exhaust gases from the gas turbines will still contain useful and recoverable heat energy.

3.1.5.2 Heat Recovery Steam Generators

During CCGT operation, the exhaust gases will pass through a HRSG where this heat will be extracted from the exhaust gases to raise steam.

The HRSGs will consist of a series of tubes through which water will be passed. The hot exhaust gases from the gas turbines will flow across the tubes thus heating the cold HRSG inlet water to produce steam. The HRSGs will not be supplementary fired. The HRSGs will be specifically designed to match the operating characteristics of the gas turbines and provide optimum performance for the Project.

The HRSG is likely to comprise separate steam circuits operating at a variety of pressures.

3.1.5.3 Steam Turbines

The resultant steam from the HRSGs will be provided to the steam turbines at elevated pressure levels and will expand across the steam turbine blades. This expansion will, as within the gas turbines, rotate the turbine and drive the same or additional electrical generators to increase the electrical output of the Project.

The residual heat within the spent steam will be rejected via the ACC systems and the resultant condensate will be returned to the HRSGs for re-use.

3.1.5.4 Cooling

ACCs will be used to condense the steam exiting the steam turbines for re-use in the HRSGs. The ACCs will act in a similar manner to a car radiator. ACCs consist of an array of finned tubes (through which the spent steam will pass) and fans to provide sufficient air flow across the tubes to enable the air to act as the cooling medium thus removing the residual (non-useful) heat from the spent steam.

The use of air-cooling means that there is no need for cooling towers or a once-through cooling water system, thereby eliminating the environmental impacts associated with such systems, which include visible plumes from a cooling tower and abstraction from, or discharge to, a local water course (identified as sea water in Paragraph 2.1.6) and the associated impacts to marine flora and fauna.

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3.1.6 Stacks and Emissions

Natural gas / LNG is an inherently clean fuel, the combustion of which does not produce sulphur dioxide (SO2) or particulate matter emissions associated with the combustion of coal or oil in a conventional power station. The flue gases from the Bypass Stacks will therefore contain:

• Carbon dioxide (CO2);

• Water vapour;

• Oxygen;

• Nitrogen;

• Carbon monoxide (CO); and

• Oxides of nitrogen (NOx).

SO2 emissions are the result of combustion of fuel containing sulphur, such as LCO. The combustion of LCO will therefore result in emissions of SO2 (and particulate matter) in addition to those substances listed above.

3.1.6.1 Emissions Control

For the purposes of the protection of air quality in the vicinity of the Project, the key pollutants that will be emitted from the Stacks (either bypass or main) will be:

Natural Gas / LNG:

• NOx; and

• CO.

LCO (in addition to the above):

• Sulphur dioxide (SO2); and

• Particulate matter.

It is anticipated that the gas turbines will utilise water injection for the control of NOx from the gas turbines to levels at least in accordance with the World Bank / International Finance Corporation (IFC) Environmental, Health and Safety Guidelines (EHS Guidelines) for Thermal Power Plants:

• Gas - 51 mg/Nm3 (25 ppm)

• LCO - 152 mg/Nm3 (74 ppm)

The water / fuel injection ratio for gas operation is assumed at 0.918 meanwhile the water / fuel injection ratio for LCO operation is assumed to be 0.592.

There are no guideline emissions limit values for carbon monoxide within the IFC EHS Guidelines for Thermal Power Plants; however, 100 mg/Nm3 is considered to be readily achievable for gas turbine technology.

As discussed above, SO2 is a combustion product of the sulphur content of any particular fuel. As such, the primary measure for the control of SO2 emissions is to utilise fuel (i.e. LCO) with as low a

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sulphur content as is reasonably practicable. The IFC EHS Guidelines for Thermal Power Plants states that, for projects of greater than 300MWth, fuel oil containing <1 per cent sulphur should be used to limit the formation of SO2 (reducing to <0.5 per cent, should the Project be located within an area classed as a degraded air shed).

The use of LCO with a sulphur content of 1 per cent can be expected to result in emissions of circa 540 mg/Nm3.

The emissions of particulate matter can be controlled by maximising the combustion efficiency within the gas turbine, which will be an inherent part of the optimisation of the Project during commissioning / testing. It is, however, noted that the ash content of the LCO may also contribute to the emission of particulate matter.

The IFC EHS Guidelines for Thermal Power Plants state that, for a non-degraded air shed, the emissions of particulate matter should not exceed 50 mg/Nm3.

3.1.6.2 Bypass Stacks

During OCGT operation, these exhaust gases will be discharged to atmosphere via dedicated bypass stacks. Typical temperatures of the exhaust gases from gas turbines will be circa 540°C.

3.1.6.3 Main Stacks

During CCGT operation, after passing through the HRSGs, the exhaust gases will be discharged into the atmosphere through the Main Stacks. Typical temperatures of the flue gases from a HRSG (given that the HRSG removes the useful and recoverable heat energy) is circa 95°C.

3.1.7 Water Usage

3.1.7.1 Raw Water

The principal water uses for the Project will be:

• Gas turbine water injection for control of NOx emissions

• HRSG blowdown (1 per cent recirculation rate within the steam / water circuit)

• Other demin water consumption (dosing, sampling, laboratory: 2t/h CC, 1t/h OC)

• Service water consumption (1 t/h plant total)

• Potable water consumption (150 litres per person per day, 30 persons)

• The Raw water for the Project will be provided by abstracted seawater at a rate of up to circa 100 t/h (Phase 1 project) and an additional 70 t/h (Phase 2 project).

3.1.7.2 Water Treatment

The HRSG will generate steam from high purity water which is used to protect against internal corrosion and reductions in operational efficiency as a result of fouling / scaling of the equipment that will form the steam cycle for the Project.

Although of extremely high purity, this water will still contain some dissolved solids; water quality within the water / steam circuit will be controlled by purging small quantities from the system

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(blowdown) to prevent the excessive concentration of dissolved solids within the HRSGs. This water will be treated in the waste water treatment plant and either re-used within the Project or discharged either via site waste water discharge system.

Demineralised water will be required to replace the blowdown and will be supplied by an on-site water treatment (demineralisation) plant. The water treatment plant is expected to treat seawater using reverse osmosis. Demineralised water sufficient for up to one day of continuous operation (circa 1800 m3) may be stored on-site in a dedicated on-site storage tank.

3.1.7.3 Waste Water

The main aqueous emissions from the plant will consist of the following:

• Boiler blowdown;

• Water treatment plant effluent;

• Electro-chlorination effluent (options with seawater intake);

• Oily water from fuel oil storage and main building drainage;

• Oily water from transformer compounds

• Sanitary waste;

• Surface water drains;

• GT compressor wash effluent (intermittent); and

• Miscellaneous minor process effluents.

The Project will include a waste water treatment plant that will treat the waste water from the water treatment (demineralisation) plant effluent and the steam / water circuit blowdown, to control the concentrations of various compounds to within the limits prescribed by the Ghana EPA. The resulting effluent will then be discharged to the sewer connection / waste water outfall.

The Ghana EPA and the IFC EHS guidelines for effluent discharge limits have been provided below in Table 4-9:

3.1.8 Miscellaneous Equipment

3.1.8.1 Auxiliary Boiler / Generators

In addition to the main generating unit, one (or more) small auxiliary boilers may also be installed to provide steam for the start-up of the Project and will operate intermittently for a limited number of hours per year. This may be complemented with one or more emergency diesel-generators necessary to provide electricity to vital auxiliaries under black-out conditions.

3.1.8.2 Transformers

Transformers will be provided for plant electrical supplies. All transformers will be non-PCB oil-filled and each transformer will be provided with a containment bund that will retain all the transformer oil in the event of a spillage. Pumps will drain these sumps to an oil separator which in

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turn will discharge to the site drainage system. The sumps will be installed with high level alarms to avoid overflow.

3.1.8.3 Power Evacuation

It is currently anticipated that the electricity generated by the Project will be exported at 330 kV via overhead lines to the GRIDCo 330 kV network. Each unit generator will be connected to the west side of a breaker and a half 330 kV substation to be developed as part of the Project.

The implementation of this approach is however dependent upon timely development of the 330 kV grid export capacity from the enclave as part of GRIDCo transmission system development (e.g. proposed new 330 kV overhead circuits from the north). Previously, GRIDCo has advised that a total of four new 330kV lines, each rated 1000 MVA, will be made available in the future to increase power export capabilities from the enclave. Two single circuits to Cape Coast and Domunli and one double circuit to Dunkwa are envisaged.

It is considered that these proposals will provide sufficient export capacity for GH1K however this is subject to the respective development timelines of the new circuits, GH1K and the other identified projects in the Takoradi Enclave.

3.1.8.4 Fire Water

Fire water may be stored on-site; the storage tanks will be designed to comply with the relevant fire regulations and will be installed together with fire pumps, hose reels, fire hydrants and portable extinguishers. Current estimates suggest that storage of up to circa 7,000 m3 of fire water may be required.

3.1.8.5 Gas / LNG Supply

The operating range for the pressure of the natural gas at the gas turbine fuel intake will be specific to the gas turbine chosen for the Project. The minimum pressure of natural gas delivered to GH1K will be a negotiated condition of the fuel supply contract. Should the guaranteed minimum delivery pressure be lower than the minimum gas turbine requirement, compression equipment will be incorporated as part of the gas receiving facilities for the Project.

3.1.8.6 Control Systems

A compressed air system will be provided to compress and deliver air of a quantity and quality suitable for all general, instrument and control purposes at all appropriate points within the Project.

Process parameters will be continuously recorded to ensure correct and efficient operation of GH1K. Any significant deviations will be alarmed and corrections carried out on occurrence. Records will be maintained of performance and deviation. Full facilities for interfacing information, control and alarm systems will be installed so that the plant can be operated from a central control room via the distributed control system (DCS). In the event of a fault in the turbines or other major plant items the Project will be designed to shut down automatically in a controlled manner.

3.1.8.7 Chemicals / Storage

The Project will require a range of chemicals during operation. These substances and their anticipated annual usage is presented in Table 3-1.

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Table 3-1: Estimated Chemical Consumption

Category Chemical Consumption

(kg/year) Phase 1 Phase 2

Ammonia (as 25 per cent Solution) 7,300 5,500

Carbohydrazide 750 550

Trisodium phosphate 650 500

Antiscalant (Reverse Osmosis) 1,000 750

Sodium Bisulphite (Reverse Osmosis) 750 550

3.1.9 Maintenance of the Power Plant

The design of buildings, enclosures and plant will also minimise regular and long term maintenance. Sufficient spares will be held on-site to ensure reliable operation of the Project. Materials and finishes will be selected to meet this objective and to ensure that the appearance of GH1K does not deteriorate significantly over time.

Major plant maintenance shut downs will be planned on a long-term basis with such outages likely to be infrequent (of the order of every four years) and of short duration only (up to six weeks). There may occasionally be forced outages which will be infrequent in nature and typically of very short duration.

3.2 Offshore Components5

3.2.1 Overview

The proposed LNG terminal would be built to the specifications of an Excelerate GasPort®. A GasPort® incorporates a jetty-mounted, articulated, high-pressure gas-offloading arm and uses the moored FSRU to regasify LNG back into natural gas to send to market.

The gas throughput capacity of the GasPort® can also be increased to meet the larger regasification capacities of future generations of FSRUs. LNG supplies are delivered to the FSRU through periodic transfers from traditional LNG carriers in accordance with Excelerate ship to ship (STS) LNG transfer protocol. The regasification of LNG continues uninterrupted throughout the STS LNG transfer procedure, ensuring a continuous supply of gas to the local market.

The GasPort® will consist of a rubble and concrete breakwater and jetty constructed to moor the FSRU and LNG carriers constructed approximately 3 km offshore Aboadze. A subsea pipeline will take the gas from the GasPort® to the plant site.

5 Project Description for off-shore components provided by One Energy technical advisor Exclerate.

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Figure 3-3: Proposed Site Layout including Indicative Location of FSRU

The following sections describe the proposed FSRU, pipeline and associated facilities, and LNG carriers.

3.2.2 The FSRU

This section provides an overview of the key features of the FSRU and descriptions of the major equipment on the FSRU, including LNG storage tanks, berthing and unloading facilities, vaporization facilities, and major support facilities and systems.

The FSRU is a standard LNG tanker that has been purpose built to carry equipment capable of re-vaporisation of LNG for delivery of high-pressure natural gas. The FSRU will be capable of generating on-board power generation for operations and propulsion. The FSRU will be moored in place at an offshore berthing jetty (platform) and ‘breakwater’ to be constructed off shore of the main plant site for the duration of the project. The FSRU will be approximately 300m long and 45m wide, with a draft of approximately 12m.

The FSRU vaporisation of LNG will utilize six (6) shell and tube heat exchangers and six (6) high-pressure LNG pumps configured for operational flexibility. With this configuration, the FSRU will have a regasification capacity of up to 500 MMSCFD, operating in the open-loop regasification operation (seawater will be used in the regasification process).

The FSRU is equipped with three 3,700 kilowatt (kW) steam turbine generators, and work in conjunction with a 3,650 kW standby diesel generator to provide power for ship-wide operations.

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For maximum ship manoeuvring capability, in addition to a conventional variable pitch fixed-blade propeller powered by a 36,000 kW steam turbine combined with thrust vectoring by a high-lift rudder system, each FSRU is equipped with two bow thrusters, at 1,500 kW each, and one 2,000 kW stern thruster.

The FSRU will include the following structures/facilities:

• LNG storage tanks;

• Vaporised gas storage tanks;

• Ballast water systems

• Emergency flare;

• Closed-loop shell-and-tube vaporization (STV) system for vaporisation of LNG;

• Living quarters to accommodate 34 permanent crew; and,

• Unloading arms and other ancillary LNG unloading equipment and facilities.

Figure 3-4: Typical FSRU

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3.2.3 Berthing and Unloading Facilities

LNG carriers would berth alongside the FSRU; only one LNG carrier would be allowed to berth at a time. Each LNG carrier would be secured to the FSRU using mooring lines equipped with quick-release hooks that would be permanently attached to the FSRU. Floating pneumatic fenders would be used to separate and prevent contact between the hull of a moored vessel and the side of the FSRU while the vessel was berthed at the FSRU.

LNG transfer between the LNGC and FSRU would take place according to Excelerate STS procedure.

Figure 3-5: Ship to Ship Transfer

The berthing area would be equipped with protective and emergency safety systems, including emergency release mechanisms in the LNG loading hoses, protective steel cladding on the FSRU in the vicinity of the loading hoses, leak and fire detection and alarm systems, and personnel protection equipment.

Excelerate has conducted a total of 681 ship to ship transfers moving over 72 million cubic meters without incident. As shown in Table 3-2 below, the majority of transfers are conducted in the “double banked” configuration as proposed for the offshore GasPort® and with multiple suppliers of LNG.

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Table 3-2: Ship to Ship Transfer Summary

3.2.4 LNG Storage and Containment

The Cargo Containment System (see Figure 3-6) consists of four double insulated cargo tanks encased within the inner hull and situated in-line from forward to aft. The spaces between the inner hull and outer hull are used for the ballast and will also protect the tanks in the event of an emergency situation, such as collision or grounding.

The cargo tanks are separated from other compartments, and from each other by five transverse cofferdams which are all dry compartments. The ballast spaces around the cargo tanks are divided into two double bottom and two wing tanks port and starboard respectively. A ballast main runs through the pipe duct with water ballast valves mounted on the tank bulkheads. The double bottom tanks extend to the side of the cargo tanks and as far up as the trunk-ways.

The LNG to be transported is stored in the four cargo tanks numbered 1 to 4 from forward to aft. All cargo tanks have an octagonal transverse section matching the supporting inner hull. Each tank between the two transverse bulkheads is composed of a prism placed in a direction parallel to the keel plate.

The cargo tanks are of double membrane, Gaz Transport No.96-2 Evolution System design. The inner hull, i.e. the outer shell of each of the cargo tanks, is lined internally with the Gaz Transport integrated tank containment and insulation system. This consists of a thin flexible membrane called the primary membrane which is in contact with the cargo, a layer of plywood boxes filled with Perlite called the Primary Insulation, a second flexible membrane similar to the first one called the secondary membrane and a second layer of boxes also filled with Perlite in contact with the inner hull called the Secondary Insulation.

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The double membrane system meets the requirement of the relevant regulations on the Cargo Containment System to provide two separate barriers to prevent cargo leakage. Thus, the tank lining consists of two identical layers of membranes and insulation so that in the event of a leak in the primary barrier, the cargo will be contained indefinitely by the secondary barrier. This system ensures that the whole of the cargo hydrostatic loads are transmitted through the membranes and insulation to the inner hull plating of the ship.

The function of the membranes is to prevent leakage, whilst the insulation supports and transmits the loads and minimizes heat exchange between the cargo and the inner hull. The secondary membrane, sandwiched between the two layers of insulation, not only provides a safety barrier between the two layers of insulation but also reduces the convection currents within the insulation.

The primary and secondary insulation spaces are under a pressure controlled nitrogen atmosphere. The primary space’s pressure must never exceed the cargo tank pressure in order to prevent the primary membrane from collapsing inwards. In normal operation, the pressure in the primary and secondary insulation spaces shall be maintained between 0.2 kPag and 0.4 kPag.

Figure 3-6: Cargo Tank General Design

3.2.5 Vaporization Facilities

The FSRU vaporisation of LNG will utilize six (6) shell and tube heat exchangers and six (6) high-pressure LNG pumps configured for operational flexibility. With this configuration, the FSRU will have a regasification capacity of up to 500 MMSCFD, operating in the open-loop regasification operation (up to 76 million gallons per day (mgd) seawater will be used in the regasification process).

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3.2.6 Sea Water System

The FSRU requires seawater intake for the vaporizers, main condenser cooling and other cooling systems, ballast water, and to maintain emergency water deluge and fire main systems. The total intake of seawater during each 6-day regasification period would average 336 million gallons with an average withdrawal of about 56 mgd. The FSRU would discharge an average of about 54 mgd of seawater during this period. The water quantities that would be retained would be used for ballasting purposes (12 million gallons, or an average of approximately 2.0 mgd) to offset the discharge of the LNG, as well as for steam plant and hoteling water usage.

There would also be two firewater pump intakes on the FSRU, one on the forward end and the other on the aft end.

3.2.7 Power Generation

The FSRU is equipped with three 3,700 kilowatt (kW) steam turbine generators supplied by gas fired boilers and these will work in conjunction with a 3,650 kW standby diesel generator to provide power for ship-wide operations.

3.2.8 Utilities

3.2.8.1 Seawater System

In addition to use in the ballast system, seawater would be used for routine and emergency situations, including the following:

• Potable water – freshwater would be generated using a desalination plant (reverse osmosis unit); two pumps would be available, with only one pump in operation at any time;

• General Service pumps – to provide a water curtain for the LNG loading area;

• Inert gas scrubber cooling pump – for occasional use when storage tank inerting (purging with inert gas) or aerating would be required;

• Seawater cooling pump – for providing medium for vaporizer operations and general seawater cooling for equipment; and,

• Firewater system – to provide fire-fighting water in the event of a fire; this system would be used only in an emergency and during monthly system tests.

Seawater for routine uses of the seawater utility system would be taken in through the intake system described in Section 3.2.6. Seawater for the firewater system would be taken in through dedicated intake structures located in the fore and aft sections of the FSRU.

3.2.8.2 Sanitary Wastewater

Sanitary wastewater is collected and sent to a biological type sewage treatment plant, designed to process sewage for approximately 60 persons. The system meets the type approval of the International Maritime Organisation (IMO) authorities.

The plant is designed according to a three chamber system for fully biological operation, based on an aerobic process and discharged overboard.

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3.2.8.3 Storm water Handling and Pollution Prevention

Collection, treatment, and discharge of storm water would vary with location on the FSRU. Uncontaminated storm water runoff, as well as firewater system test water, would be directed overboard via scupper drains. Storm water that collects in the vicinity of equipment that could release oil or oil-like substances and other chemicals would be collected with curbs and gutters and routed to a holding tank.

The likelihood that storm water would be contaminated by hazardous materials on-board the FSRU would be minimized through the use of best management practices (BMPs). BMPs would include proper containment, storage, and handling of hazardous materials; regular inspections; and spill prevention practices.

3.2.9 Crew Quarters

Living quarters on the FSRU would accommodate a permanent crew of up to 34. Crew members would be transported to and from the FSRU on small boats or tugs. For safety reasons, all living, dining, and recreational areas would be contained within the crew quarters and separated from all processing areas.

3.2.10 Command and Control Facilities

Command and control facilities would be located in a central control room in the crew quarters area. These facilities would include control and monitoring systems for LNG and natural gas processing, ballasting, communication, radar equipment, electrical generation, emergency systems, and thruster controls.

3.2.11 Pipeline and Associated Facilities

The Project will include a subsea gas transmission pipeline from FSRU to the plant site. The indicative route currently under consideration is included in Figure 3-3. The design and construction of the pipeline will meet relevant international and local standards.

The pipeline will provide suitable means for the launching and retrieval of pipeline pigs to allow for inspection during the pipeline commissioning as well as periodic inspections as required. Pipeline construction is considered further below.

3.2.12 LNG Carriers Operation of the Project will require regular deliveries of LNG supplied from LNG carriers (LNGCs) loaded at various LNG liquefaction facilities worldwide.

Because the Offshore GasPort® will be located approximately 3 km offshore, no defined waterway will be used by LNGCs on-route to or departing from the Project. The Project will not require a defined approach channel delineated with a conventional navigation demarcation system. Furthermore, there are no shoreline areas adjacent to the approach. However, there will be a defined approach manoeuvre for vessels calling at the facility, which will include the use of escort vessels, licensed maritime pilots, and tug support vessels of adequate size.

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3.2.12.1 Hull System

LNGCs would be of double-hulled design (that is, each carrier would have a double bottom and double sides along the full length of the cargo area). The double-hulled design greatly decreases the likelihood of LNG release in the event of grounding and collisions. The vessels will meet all local and international regulations for LNGCs.

3.2.12.2 Containment System

The LNG containment system on LNGCs would consist principally of the cargo tank (sometimes called a primary barrier), the secondary barrier, and insulation. The containment system also would include monitoring and control and safety systems.

Three basic LNG tank designs are used by the current fleet of LNGCs: prismatic free standing, spherical, and membrane. Prismatic free-standing tanks are constructed of an aluminium alloy or 9 percent nickel steel, are supported and restrained by the hull structure, and are insulated on the bottom and sides by reinforced polyurethane foam and on the top by fiberglass. Spherical tanks are constructed of an unstiffened aluminium alloy and are supported by vertical cylindrical skirts, with the bottom of the skirt welded to the carrier’s structure. Spherical tanks are insulated with multi-layer close- cell polyurethane panels. Membrane tanks on LNG carriers would be similar to the LNG tanks proposed for the FSRU.

3.2.12.3 Pressure/Temperature Control

A basic goal of all LNG containment systems is to maintain the LNG cargo at or near atmospheric pressure (1 to 3 psi) and at the boiling temperature of the LNG (about -260° F). This is accomplished using “auto-refrigeration,” a phenomenon that results from constant heat flow into the tank and removal of the associated vapour. The vapour ranges from 0.15 to 0.25 to percent (by volume) per day and is used to supplement the bunker fuel in the carrier’s boilers. No mechanical means of refrigeration would be used to maintain the liquefied state of the gas; therefore, chlorofluorocarbons (CFCs) that typically present in coolants in mechanically powered refrigeration systems would not be used in this process.

3.2.12.4 Ballast and Cooling Water

While unloading LNG cargo at the Offshore GasPort®, LNGCs will take in seawater as ballast to maintain a constant draft. Ballast water is taken onto the vessel through its sea chests while offloading cargo which is estimated to take up to 72 hours to complete. Ballast water is typically only discharged during loading operations at an LNG export terminal or during mid-ocean ballast water exchanges during the transit. Therefore, no ballast water would be discharged from LNGCs while at the offshore berthing platform. It is expected that all LNGCs calling on the Project will comply with IMO standards for ballast water exchange.

LNGCs unloading at the Offshore GasPort® will also need cooling water for the engines that generate electrical power for the offloading pumps and other on-board systems. Ships’ engines will be powered up while at dock; therefore, there would be cooling water needs during the entire time each LNGC is at the offshore berthing platform (estimated to be up to approximately 88 hours).

Estimates for vessel water consumption are derived from three sources; the Jordan Cove FEIS (FERC 2009), the Broadwater LNG FEIS (FERC 2008), and information provided by Oregon LNG

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in its application to the FERC (CH2MHill 2008). The Jordan Cove FEIS estimated a range of cooling water intakes, with a low of 1,250 m3/hr based on diesel engine vessels using some shore power. Oregon LNG (CH2MHill 2008) estimated about 6,300 m3/hr for cooling water use, while the Broadwater EIS (FERC 2008) used the highest value of about 9,800 m3/hr. The range of potential cooling water and ballast water requirements are shown in Table 3-3. Based on the current vessel characteristics available in the fleet, the higher estimate of water use is most likely to be representative of this Project.

Table 3-3: LNG Carrier Water Use in Dock with FSRU

Estimates of LNG Carrier Water Use and Rate While at the Offshore Gas Port

Range

Time to Offload

(hr)

Total time at

GasPort® (hr)

Ballast Intake Rate

(M3/hr) 1, 2

Ballast Volume (million gallons)

Cooling Intake Rate

(M3/hr)

Cooling Volume (million gallons)

Total Intake

Volume (million gallons)

Low 25 41 2,600 17.2 1,250 13.5 30.7 High 72 88 3,900 74.2 9,800 227.8 302.0 1 All ballast intake occurs during offloading. 2 Low value from FERC 2009, high value from FERC 2008. 1 m3 = 264.17 gallons.

These LNGCs would take in about 17.2 to 74.2 million gallons of water for ballast while offloading at the Offshore GasPort®. Total cooling water volume would range from about 13.5 to 227.8 million gallons while stationed at the Offshore GasPort®. Therefore, the total water intake for each LNGC delivery (ballast and cooling water) could range from about 30.7 to 302.0 million gallons.

3.2.12.5 Carrier Safety Systems

The LNGC proposed for use in the Project would be required to comply with all federal and international standards regarding LNG shipping. As such, carriers that transport LNG to the Project would be fitted with an array of cargo monitoring and control systems that would automatically monitor and control cargo pressure, temperature of the cargo tanks and surrounding ballast tanks, emergency shutdown of cargo pumps and closing of critical valves, the level of cargo in the tanks, and gas and fire detection. These systems are active while the carrier is at sea and during the remote-control phase of cargo operations at the FSRU.

LNGCs would be fitted with many navigation and communication systems, such as the following:

• Two separate marine radar systems, including automatic radar plotting and radio direction finders;

• LORAN-C receivers;

• Echo depth finders; and,

• A satellite navigation system.

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All LNGCs also would have redundant, independent steering control systems that are operable from the bridge or steering gear room to maintain rudder movement in case of a steering system failure.

3.2.12.6 Fire Protection

All LNGCs arriving at the FSRU would be constructed according to structural fire protection standards contained in the “International Convention for the Safety of Life at Sea” (SOLAS). They also would be fitted with active fire protection systems that meet or exceed design parameters in Coast Guard regulations and international standards, such as the Gas Tanker Code and SOLAS, including:

• A water spray (deluge) system that covers the crew accommodation area and all main cargo control valves;

• A traditional firewater system that provides water to fire monitors on deck and to fire stations found throughout the carrier;

• A dry powder extinguishing system for LNG fires. The dry powder system would be used to extinguish LNG fires and prevent ignition of LNG leaks. Automatic dry powder extinguisher system would be integrated into the exposed deck of the cargo (LNG) area, loading arms and cargo tank domes, and in the LNG processing area; and,

• A CO2 system for protecting the machinery, ballast pumps, emergency generators, and cargo compressors.

3.2.13 Land-based Ancillary Infrastructure

The exact location of the Offshore GasPort® and subsea pipeline will be determined during final detailed design but the footprint and land take requirements should remain primarily similar.

3.2.14 Offshore GasPort® and Subsea Pipeline

Construction of the offshore GasPort® is assumed at this time to consist of a breakwater with integrated bulkhead suitable for mooring and support equipment for the FSRU. The final footprint of current proposed design incorporating the FSRU and LNGC moored is 240,000 m2. The subsea pipeline final footprint will be 18,000 m2 based on a sea floor length of 3 km pipeline (with additional on shore component) with a 6 m operational right of way.

Detailed design will determine the temporary land requirements for the installation of both the offshore GasPort® and subsea pipeline.

3.2.15 Onshore Support Facilities

Onshore support for the GasPort® will be minimal and primarily consist of suitable services for waste disposal (general trash, dirty oil, etc.), equipment/material supply and crew change to be facilitated by a sourced crew boat.

The onshore support facilities during the construction phase will be determined during the detailed engineering phase.

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3.2.16 Construction Procedures

The proposed LNG terminal and natural gas pipeline would be designed and constructed in accordance with national safety standards that are intended to ensure adequate protection for the public and to prevent LNG and natural gas pipeline accidents or failures.

3.2.16.1 LNG Terminal

The regulatory framework pertaining to the host country shall be applied to the design, permitting, construction and operation of the GasPort®. Where aspects of the design, permitting, construction and operation are not covered specifically by legislation, then widely accepted oil and gas industry codes and standards will be used to specify the design and in the selection of appropriate materials of construction.

Rubble mound breakwaters generally consist of three or more distinct layers of material. The innermost layer is the core and generally contains quarry run type material. The next layer is a transition layer or filter layer, and is located between the overlying armour layer and the underlying core layer. The outermost layer is the armour layer and is comprised of larger rocks or concrete armour units. The armour layer is designed to protect the structure from wave energy and the armour units or stones are sized accordingly.

During construction the breakwater material would be transported to site on a floating barge and either dumped or placed by floating cranes. The placement of material is managed to minimize the loss of material during the process. Measures are taken to minimize segregation of the core material during construction. Armour units are placed by floating crane and drop heights based on the size and type of armour unit are established to protect the armour units from breaking.

The breakwater construction will include the necessary structures to allow for the installation of quick release mooring hooks, the high pressure gas arm and additional facilities required for operation. This equipment will be delivered to the worksite prepared for installation and having completed acceptance testing thus reducing the onsite work scope.

Excelerate operates a fleet of specially designed, and purpose built FSRUs: These FSRUs have the following Classification that is further described in Table 3-4:

Bureau Veritas (BV nb: 03161N) I HULL MACH, liquefied gas carrier / LNG-RV (membrane tank 0.25 bar, -163C, 500 kg/m3), Unrestricted navigation, AUT-UMS, SYS-NEQ-1, MON-SHAFT, VeriSTAR-HULL 40 years, STL-SPM, IN WATER SURVEY.

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Table 3-4: FSRU Classification

Classification Notation Symbol Description

Class Symbol I The class symbol I is assigned to ships build in accordance with the requirements of the Rules or other rules recognized as equivalent, and maintained in a condition considered satisfactory by the society

Construction Mark

The mark is assigned to the relevant part of the ship, when it has been surveyed by the Society during its construction in compliance with the new building procedure detailed in Ch 2, Section 1

Construction Mark

HULL Meets the requirements for hull classification by Bureau Veritas

Construction Mark

MACH Meets the requirements for machinery classification by Bureau Veritas

Service Notation liquefied gas carrier

Ship specially intended to carry liquefied gases or other substances listed in Pt D, Ch 9 Sec 1 of the Rules

Additional Service Features

LNG-RV The ship is fitted with an installation for revaporization of the liquefied natural gas

Additional Service Features

(membrane tank 0.25 bar, -163C, 500kg/m3

The conditions of transportation (pressure, temperature, filling limits)

Navigational Notation

Unrestricted Navigation

Assigned to ships intended to operate in any area and any period of the year

Additional Class Notation

AUT-UMS Assigned to ships which are fitted with automated installations enabling machinery spaces to remain periodically unattended in all sailing conditions including manoeuvring


SYS-NEQ-1 Assigned to ships which are fitted with a centralized navigation control system so arranged that the navigation and manoeuvring of the ship can be operated under normal conditions by one person, for periodical one man watch


MON-SHAFT Assigned to ships fitted with oil or water lubricated systems for tailshaft bearings. The assignment of this notation allows the ship to be granted a reduced scope for complete tailshaft surveys.


VeriSTAR-HULL 40 years

Assigned to ships the structural condition of which is checked with 3D FEM calculation programme at design stage or after construction according the requirements of the Society Fatigue assessment has been carried out on selected structural details showing that their evaluated design fatigue life is not less than 40 years

Service Notation STL-SPM The ship is used as a re-gasification terminal and fitted forward with equipment for non-permanent mooring or single buoy


INWATERSURVEY

Assigned to ships provided with suitable arrangements to facilitate the in-water surveys as provided in Ch2, Sec2

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3.2.16.2 Pipeline and Associated Facilities

The proposed pipeline will be approximately 4 km in length and will be run in the most direct manner from the offshore GasPort® to the specified shorefall location. Pipeline will be designed according to international and local standards

Construction of the majority of the proposed pipeline would be accomplished using conventional underwater pipe lay techniques.

The proposed pipeline would be installed using the trenching method of pipelay in which the pipe will be installed by a pipelay barge into a trench that has been excavated prior to or during the procedure. The following methods may be employed to trench the pipeline:

• Ploughing;

• Jetting; and,

• Mechanical Cutters.

3.2.16.3 Pipeline Construction Support Vessels

Pipeline construction will involve various vessels with specialized construction capabilities, as well as vessels to support construction activities. Typical pipeline construction and support vessels are described below.

• Shallow Water Lay Barge: The lay barge constructs the pipeline through a series of functions that produce a welded, inspected pipeline on the seabed. This vessel utilizes a variety of winches, cranes, and specialized equipment to perform its function. The lay barge may be anchored to the bottom with temporary piles placed directly alongside the barge or by conventional anchor and chain. Any bottom impact from lay barges will be contained within the construction right-of-way. It is expected that a single lay barge will be used, repositioned along the pipeline route as needed.

• Dive Support Vessel: The dive vessel performs diving-related activities such as tie-ins, hydro testing, and other dive-related functions. This vessel utilizes winches, air compressors, pumps, lift devices, and hydraulic power units to perform its function. The dive support vessel would typically be a spud barge temporarily positioned within the construction right-of-way. It is expected that a single dive support vessel will be used, repositioned along the pipeline route as needed.

• Assist Tugs: Assist tugs will be used to spot the lay barge and other floating equipment. It is expected that one or two assist tugs will be used during pipeline construction depending on the level of activity and pipeline segment being installed.

• Crew/Supply Boat: This vessel is used to shuttle personnel and supplies from the landside dock to the lay barge and dive support vessel. It is expected that one crew/supply boat will be used during pipeline construction as needed to support the lay barge and dive support vessel.

• Pipe Transport Barge: This barge is loaded with pipeline segments at the pipe coater’s yard and transports the pipe to the lay barge. It is expected that a single pipe transport barge will be used during pipeline construction.

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• Pipehaul Barge Tug: This tug boat shuttles the pipe transport barges between the pipe yard and the lay barge. It is expected that a single pipehaul barge tug will be used during pipeline construction.

3.2.16.4 Hydrostatic Testing

The pipeline will be hydrostatically tested (hydro test) upon completion of the lay but prior to final tie in to the Offshore GasPort® and shoreside plant. Prior to hydro testing, the pipeline will be gauged to verify its geometric integrity by running a gauging plate inside the pipeline.

Detailed hydrostatic testing procedures will be developed during detailed pipeline design; however, general procedures will be as follows. The subsea pipeline will be pigged following construction. The hydrostatic test medium will be seawater, and the filter screen size for water intake will be 100 micron. The intake rate for the pig runs will be dependent upon the speed of the pig, which will be somewhere between 1.5 to 3 feet per second (fps).

The hydrostatic test water will not be treated when it is injected. Based on volume of the pipeline, about 155,000 gallons will be required to fill and test the pipeline, however the actual amount of water needed to complete the testing will depend on the number of hydrostatic tests required. Assuming one to three tests may be required to complete hydrostatic testing, testing will require between 155,000 and 465,000 gallons of water.

The pipeline will be dried upon completion of the hydrostatic test. All international and local rules, regulations, and permits related to the pipeline design, engineering, construction, installation, and commissioning will be taken into consideration during the continued design development of the project.

3.2.17 Operation and Maintenance of the FSRU and Ancillary Infrastructure

Operation of the proposed Project would involve importation and transfer of LNG to the FSRU from LNGCs, regasification of LNG on the FSRU, and transfer of regasified LNG (natural gas) into the 4 km subsea pipeline. Figure 3-7 presents a schematic diagram of the overall process. The key components of operation for each of these activities are described in the following sections.

Figure 3-7: Process Flow Diagram

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3.2.18 LNG Terminal Commissioning

3.2.18.1 Overview

Following completion of construction, but prior to the start of standard operation, the Offshore GasPort® must be commissioned. The commissioning process will focus on key activities pertinent to commissioning of the Offshore GasPort®. This process will provide necessary time to successfully complete all pre-commissioning activities, commissioning, and completion works to be performed at the Offshore GasPort® incorporating all requirements of vendors, regulatory agencies, and port operations.

All regasification equipment on board the FSRU has already been commissioned but will be run through full performance capability as defined by vendor specifications to ensure minimum and maximum rates are established for the Offshore GasPort®.

Equipment in the commissioning process will include:

• Offshore Berthing Platform and Associated Equipment:

o High pressure marine loading arm (HPMLA);

o Ship shore link (S SL) - fiber optic and electrical;

o Distributed control system (DCS);

o Quick Release Mooring Hooks with Tension Monitoring System;

o Berthing Assistance System;

o Emergency shutdown (ESD) valves and ESD system;

o Firefighting and gas detection equipment;

o Security and site monitoring equipment ;

o Gas meter(s) and gas chromatograph;

o Communications equipment; and,

o Berth monitoring system (BMS) and mooring system.

• FSRU Equipment:

o Regasification system and associated equipment;

o Emergency shutdown valves and ESD system;

o Gas meters and gas chromatographs; and,

o Communications equipment.

3.2.18.2 Pre-Commissioning Meeting

A pre-commissioning meeting will be conducted prior to the FSRU berthing and the start of commissioning activities. The meeting will be chaired by the Commissioning Manager. The FSRU’s Master, key FSRU officers, Person in Charge, pertinent technicians, and vendor representatives shall be in attendance. The meeting will include a discussion of the schedule of

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planned activities, safety considerations and requirements, communications, and responsibility and authority of persons involved.

3.2.18.3 Commissioning Activities

Commissioning will consist of the following activities:

• Onshore Receiving Facility - Commissioning procedures will be written in coordination with onshore plant operations team;

• Topsides - The bulk of activity for the topsides commissioning will be focused on verifying marine infrastructure, ship and shore side operation, and functionality of the mechanics and automation control, including:

o Ship to Shore Link (SSL);

o Mooring Systems;

o Firewater;

o High Pressure Loading Arm(s);

o Liquid transfer arm(s);

o Shore side high pressure gas system;

o Supervisory Control and Data Acquisition (SCADA) distributed control system;

o Emergency Shutdown Valves (ESD);

o Emergency Release Couplings (ERC); and,

o Utility support systems.

• Subsea Pipeline (High Pressure (HP) Gas Line N2 displacement, hydrocarbon fill and pressurization):

o All ESDVs, SDVs, SXNV's and FCVs shall have been opened prior;

o The low pressure nitrogen in the pipeline shall be vented to atmosphere using the vent points at the plant end;

o The pipeline shall be filled with hydrocarbon gas;

o Gas meters shall be used to verify that all nitrogen has been purged from the system; and,

o Gas flow shall be increased in pre-determined controlled stages until commissioning pressure and flow rate is achieved.

3.2.18.4 Post-Commissioning Meeting

A post-commissioning meeting will be conducted after completion of commissioning activities to discuss issues encountered, lessons learned, and required follow-up on same.

Following completion of Project commissioning, standard operation and maintenance procedures will begin as described below.

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3.2.19 LNG Regasification Process

The regasification system comprises a suction drum, high-pressure pumps, high pressure vaporizers, metering system, and low and high pressure pipe work and valves (see Figure 3-8). LNG is stored in the cargo tanks at a pressure slightly above atmospheric and is pumped by low pressure (LP) feed pumps to the suction drum which serves as an accumulator and surge vessel for the HP LNG pumps.

Figure 3-8: FSRU LNG Regasification Process

From the suction drum, the liquid pressure to the vaporizers is increased by the HP pumps. The regasification system includes two small HP pumps. The small HP pumps, each with a capacity of approximately 10 MMscf/d (11,800 sm3/h), are used for pressurization of the system during start up. These pumps increase the system pressure gradually during start up without excessive generation of boil off gas. Once a regasification flow rate of 10 MMscf/d (11,800sm3/h) has been achieved, the LNG vaporizer outlet control valves are set to control the vaporization process at a pressure of not less than 75 barg.

A single HP pump is utilized to increase the LNG flow rate to the minimum operating flow rate of 50 MMscf/d (59,000sm3/h). The flow rate can then be increased up to 100 MMscf/d (118,000 sm3/h) with a single pump. Flow rates up to the contractual flow rate can be met by progressively starting additional vaporizer and HP pump streams. The HP pump raises the pressure of the LNG to match the export pipeline pressure (75 to 100 barg) and sends the cold LNG to the LNG Vaporizer. There are six 100 MMscf/d (118,000 sm3/h) capacity HP pumps on an Excelerate Energy FSRU. Five pumps are utilized to deliver gas at a sustained rate of up to 500 MMscf/d (590,000sm3/h). Therefore, there will be sufficient spare capacity on the FSRU to ensure high availability and reliability of the terminal. The sixth pump is used for peak capacity operation.

The FSRUs incorporate six LNG vaporizers. The vaporizer is a shell-and-tube heat exchanger where the LNG is vaporized to natural gas and heated to approximately 4°C (39°F) minimum by seawater (open-loop mode). The normal natural gas flow rate through the vaporizer is between 50 and 100 MMscf/d (59,000 and 118,000 sm3/h), with a maximum peak flow rate of 115 MMscf/d (135,430 sm3/h). The temperature and pressure are measured at each vaporizer outlet line in order

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to calculate the re-gas flow rate using the recorded actual pressure drop at a flow measuring orifice. The signal is then sent to each vaporizer flow controller.

On leaving the LNG Vaporizer, natural gas flows through a metering station, and then through a Pressure Regulating Station that maintains a minimum pressure of approximately 75 barg in the regasification system, and then into the export pipeline. The natural gas then passes through the delivery flange on the high pressure manifold and into the high pressure natural gas loading arm on the offshore berthing platform.

3.2.20 Operation and Control of the Regasification System

The regasification and gas delivery operation is continuously manned and is controlled utilizing the FSRU’s Integrated Automation System (IAS). The high pressure gas system is protected by means of high pressure trips, low temperature trips, and relief valves. The FSRU ESD system will activate to shut down the regasification process in the event that a ship or shore side ESD condition is present. The FSRU’s IAS ensures the safe operation of the re-gasification plant within the system design parameters.

For each re-gasification nomination the FSRU operator will utilize a configuration screen to input three ordered parameters:

• Required discharge rate;

• Maximum discharge pressure; and

• Minimum discharge temperature.

The Offshore GasPort® design will provide for the following Operating Modes:

• Inerting;

• Warm Startup;

• Cold Startup;

• Startup from ambient temperature with air atmosphere within system;

• Steady-state Operation;

• Operation at minimum send out (turndown);

• Normal shutdown and Warm-up;

• Emergency Shutdown; and

• Depressurizing.

3.2.21 Receipt and Transfer of Regasified LNG

During operation the FSRU will convey the natural gas to the send out pipeline. Specific components to accomplish this include:

• High pressure gas loading arms and associated emergency disconnect equipment;

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• Class 900 low temperature carbon steel pipe work, incorporating non return valves, ESD valves, motorized isolation valves and pressure and temperature transmitters which interface the DCS and the SIS, and a pig launcher;

• FSRU SSL;

• Process support systems;

• Electrical systems; and,

• Safety systems.

3.2.21.1 High Pressure Gas Loading Arm

High Pressure Gas Loading Arms (Figure 3-9) are mounted on a steel tower located on the offshore berthing platform. The loading arm is used to convey high pressure regasified LNG from the delivery flange on the FSRU high pressure manifold to the platform. Incorporated in the arm are a quick connect/emergency disconnect system and an inlet ESD valve and an emergency disconnect ESD vent valve.

Figure 3-9: High Pressure Gas Loading Arm

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The NPS ANSI Class 900 loading arm has been designed by Emco Wheaton to the OCIMF Design and Construction Specification for Marine Loading Arms (Third Edition - 1999). The specification covers the minimum requirements for marine loading arms and their ancillary equipment for loading and/or unloading ships and barges at conventional marine terminals and Sea Islands. The design of the arms will accommodate the range of movements that are expected when the arms are connected to the FSRU under high and low water conditions and in the loaded cargo and ballasted states.

The High Pressure Gas Loading Arms will be in the stowed position on the platform without internal pressure when not in use. The motive power to enable the operator to move, connect or disconnect the loading arms is provided by a hydraulic power system.

Connection of the High Pressure Gas Loading Arms to the FSRU is made by a quick connect/quick disconnect and emergency release system (QC/DC-ERS). The QC/DC-ERS also provides a means of disconnecting the arm in an emergency in the event of the vessel/arm moving outside of the specified operating parameters. Additionally it allows a manually initiated emergency disconnection.

When connected to the FSRU the operating envelope of the arm is monitored by potentiometers and the arm position can be viewed and tracked via a monitoring system located in the control room on the ship. The arm position can also be monitored from the FSRU via a communications link. Independent proximity switches are used to monitor the position of the arm against predefined operating limits and these will initiate sequential safety actions in the event that the position of the arm exceeds the operating limits.

3.2.22 Additional Considerations

3.2.22.1 Environmental Compliance Inspection and Mitigation Monitoring

In preparing construction drawings and specifications for the Project, Excelerate would incorporate all mitigation measures identified in its application as well as requirements of international standards, conventions and requirements of the EPA. Contractors would be provided copies of applicable environmental permits and would be fully apprised of mitigation requirements and other applicable environmental commitments.

All construction personnel would be trained by Excelerate to ensure that they understand and are able to properly implement all mitigation measures stipulated by other environmental regulatory agencies. Such training would be conducted before commencement of construction and during construction, as needed.

Excelerate would select a Chief Inspector, who would be responsible for quality assurance and compliance with mitigation measures, other applicable regulatory requirements, and other monitoring and reporting specifications. The Chief Inspector would be assisted by one or more full-time Environmental Inspectors, who would report directly to the Chief Inspector and would have the authority to stop work. The Environmental Inspector’s duties would include ensuring compliance with environmental conditions attached to permits or authorizations and Excelerate’s environmental designs and specifications.

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In addition, local regulatory agency personnel, and representatives of the ship classification society would conduct inspections to monitor the Project for compliance with the applicable environmental conditions.

3.2.22.2 Future Plans and Abandonment

Excelerate presently has no plans for expansion of the Offshore GasPort®. The Project is designed to meet the requested volume of its single customer. To the extent that expansion or modification of the Offshore GasPort® becomes warranted in response to additional requests from the customer, any expansion, modification or additional use of the Offshore GasPort® will be designed to be compatible with the proposed facilities.

Excelerate has no current plans for abandonment of the Offshore GasPort®. In the event the decision is made to abandon the Offshore GasPort®, Excelerate will work with the appropriate agencies to properly abandon the facility either in place or by removal.

3.3 Project Alternatives

3.3.1 Overview

Throughout the course of the Project development, many decisions are made concerning, for example, the type of technologies, the location and the processes involved in the proposed development. Many of the identified potential alternatives will be unable to be considered for reasons of technical, regulatory or economic grounds.

This section summarises the key elements of the alternatives that have been considered to date. The full assessment of alternatives will be found within the full ESIA. The role of analysis of alternatives within the ESIA is to ensure that environmental criteria are considered in these early design decisions and allow transparent consideration within design choices.

3.3.2 On-Shore Components

3.3.2.1 Sites

The proposed site location for the power plants is depicted Figure 1-1. The site is located adjacent to the existing Takoradi Thermal Power Plant (TTPP) installations and the VRA residential compound. The town of Aboadze is located approximately 1km from the existing plant. The benefits of locating the power plants in this site is the proximity of existing industrial and power plants, which have resulted in the industrialisation of the area, existing infrastructure and a well-developed road network.

A proposed secondary site at Sanzule approximately 100km from Takoradi was considered by the project, due to the proximity to the gas tie in from the offshore gas fields. The location of the site is depicted in Figure 3-10 below. The potential site forms part of a large area of approximately 800 acres, located ~2km east of the town of Sanzule (8 km northwest from Essiama), adjacent to the Gulf of Guinea, approximately 100 m inland from the sea. The area was indicated to be owned by families from a local community, located approximately 2 km to the east of Sanzule, down a thin (~100 m wide) coastal bar strip which borders the 800 acres. A site walkover undertaken of the secondary site in Sanzule identified that from an environmental and social perspective this site

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would be more challenging to develop than the currently proposed site. Key reasons for this included the likely need for resettlement, proximity to a possible indigenous community, site being located at or very close to sea level and the lack of existing infrastructure in the area which would be needed to support the development, such as transmission infrastructure and good quality road network to enable efficient construction.

Figure 3-10: Alternative Site Location and Sanzule

3.3.2.2 Fuel

The combustion of fossil fuels (coal, oil, natural gas) results in the creation of gaseous emissions such as NOx, SO2, particulate matter, carbon monoxide (CO) and CO2. The use of natural gas however results in lower emissions of NOx, CO and CO2 and negligible emissions of particulate matter, volatile organic compounds (VOCs) and SO2 when compared with other hydrocarbon fuels and as such is the preferred fuel for the onshore power plants. Whilst the project is currently proposing the use of imported LNG due to the slow implementation of gas extraction offshore, it is envisaged subject to confirmation of adequate local resource that in the future the power plants may be fed by natural gas from Ghana’s own gas fields.

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3.3.2.3 Alternative Generating Technologies

The main thermal generating configurations applicable to this project are conventional gas-fired boilers, CCGT and OCGTs. CCGT is currently considered the best available technique (BAT) and is the most efficient and environmental friendly technology available for the combustion of natural gas.

3.3.2.4 Cooling Water Options

The Project has compared seven cooling system cases: once-through seawater cooling, mechanical draft cooling towers (seawater), mechanical draft cooling towers (fresh water supply required), hybrid wet-dry cooling tower (seawater), hybrid wet-dry cooling tower (fresh water supply required), ACC’s (seawater), and ACC’s (fresh water).

There is already significant seawater abstraction locally to provide for the existing and soon to be operational once-through cooling water systems for T1, T2 and T3. Once through cooling is therefore unlikely to be feasible for the project without impacting the existing system. Based upon the operational experience at the existing T1 site there has been extensive corrosion damage throughout the plant due to operation of seawater cooling towers. Therefore the preferred cooling option currently considered is the air cooled condensers option for the project in order to avoid this issue. The use of ACC also confers environmental benefits as impacts associated with large volumes for cooling water abstraction are avoided.

A relatively small seawater intake will supply process water for the closed loop within the ACC’s.

3.3.2.5 Water Source

The potential for sourcing water from the river Anankwari is not expected to be feasible due to the seasonal flow characteristic understood to be experienced in the catchment. In addition, based upon previous borehole testing performed for an adjacent project, it is expected that there may not be sufficient ground water available for the requirements of the plant, particularly for the higher water requirements typically required for wet (standard) combustion NOx control.

As such, it is expected that the only feasible option for water supply to the plant would be seawater extraction through a dedicated new build seawater intake structure. This will require also require a reverse osmosis desalination plant for treatment of seawater to be developed as part of Project.

It is also understood that a potential water supply facility is under consideration by VRA and/or the local municipality which may be able to provide a local fresh water source for the requirements of the Project. However this is dependent upon development of such facilities and agreements between the many potential end users in the timescale for the GH1K project development. One Energy will monitor the development of this project.

3.3.3 Offshore Components

A third party assessment of potential sites for the FSRU was undertaken in 2014. A total of seven for the FSRU where identified:

• Domunli – off-shore mooring ;

• Atuabo – off-shore mooring;

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• Essiama – offshore mooring;

• Takoradi – fixed berth;

• Sekondi – fixed berth;

• Aboadze – offshore mooring; and

• Tema – offshore mooring.

Consideration was given to the following technology options for the FSRU:

• Fixed berth with breakwater – the FSRU would be moored at a conventional berth comprising a platform and mooring and breasting dolphins, protected by a breakwater. The LNG tanker would berth alongside the FSRU for cargo offload.

• Offshore Mooring – Offshore moorings are divided into two distinct classes:

o Fixed mooring: The ship is a moored at multiple points to maintain a fixed heading; and

o SPM: The ship is moored only at the bow such that it can rotate about a fixed point. The SPM permits the ship to weathervane and thereby assume a heading that minimizes the mooring forces. SPMs can take a number of forms.

The fixed berth technology is considered to have potentially more environmental impacts than the offshore mooring option due to the location near to the shoreline and sensitive habitats. The sites utilising the fixed berth technology are expected to have somewhat greater impacts associated with their discharge of chilled water into shallower waters near shore.

An off-shore site at Aboadze was identified as the preferred location. This is primarily because of its proximity to current demand, to the sites of future power generation capacity adjacent to the existing power plants, and its ease of connection to the Western Corridor pipeline to allow distribution of gas within the Western Region as other plants come online. This location also provides potential for use of WAGP to transport gas to Tema via reverse flow.

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4 Legislation and Standards

The Project is required to comply with the relevant Ghanaian law and regulations, with international Conventions to which Ghana is a signatory and with the relevant international standards including the IFC) Performance Standards for Environmental and Social Sustainability and the IFC EHS Guidelines. Each set of requirements is discussed in turn.

4.1 National

Environmental regulation within Ghana falls under the requirements of the EPA Act 1994, Act 490. Act 490 also sets out the governing requirements for industrial developments and the ESIA requirements. Under Act 490, the EPA is mandated with responsibility for environmental and compliance for development activities.

Supporting legislation includes the Ghana EIA Procedures in 1995 and the Environmental Assessment Regulations 1999 (LI 1652) which were enacted in February 1999, consistent with Section 28 of the EPA Act 490.

Other application legislation to the project includes:

• Electricity Company of Ghana (ECG), Act 461 of 1997;

• Labour Act No (2003) Act 651;

• Land Act 586 (2000) and Act 125 (1962);

• Electricity Transmission (Technical, Operational And Standards Of Performance) Rules, 2008 L.I. 1934;

• L.I. 1937: Electricity Regulations, 2008;

• Ghana National Fire Service Act of 1997 (Act 537);

• Fire Precaution (Premises) Regulations, 2003, LI 1724;

• Ghana Investment Code, PNDC Law 116 (1985);

• Public Utilities Regulatory Commission (PURC), Act 538 (1997);

• General Environmental Quality Standards (Ghana) Regulations 2002; and

• Takoradi-Sekondi Metropolitan Assembly by-laws.

• National Energy Policy; and

• National HIV/AIDS STI Policy (2004) which provides for “Workplace HIV Policy”.

4.2 International Conventions

Ghana has ratified or acceded to a large number of environmental and social international treaties and conventions. Those which may be relevant to the project are listed in Table 4-1.

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Table 4-1: Treaties and Conventions

Treaties and Conventions Year Ratified

African Convention on the Conservation of Nature and Natural Resources 1968

African Charter on Human and Peoples’ Rights 1989

Convention on Biological Diversity 1992

The Convention on Wetlands of International Importance Especially Waterfowl Habitat (RAMSAR Convention)

1971

The Convention Concerning the Protection of World Cultural and Natural Heritage 1972

The Convention on the Prevention of Marine Pollution by Dumping of Wastes and other Matters, London

1972

The Convention on International Trade in Endangered Species of Wild Fauna and Flora (CITES), Washington

1973

International Convention on Civil Liability for Oil Pollution Damage 1969

International Convention for the Conservation of Atlantic Tunas 1966

The United National Convention on Law of the Sea, Montego Bay 1982

The Convention on the Prevention of Marine Pollution from Ships (MARPOL) 1973

International Convention Relating to Intervention on the High Seas in Cases of Oil Pollution Casualties (Intervention Convention)

1969

Convention on the International Regulations for Preventing Collisions at Sea (COLREGs) 1972

International Convention for the Safety of Life at Sea (SOLAS) 1974

Convention on Limitation of Liability for Maritime Claims (LLMC) 1976

International Convention on Standards of Training, Certification, and Watch keeping for Seafarers (STCW)

1978

International Convention of Oil Preparedness, Response and Co-operation (ORPC) 1990

International Convention on Civil Liability for Oil Pollution Damage 1969

International Convention on the Establishment of an International Fund for Compensation of Oil Pollution Damage

1971

International Covenant on Civil and Political Rights 2000

Montreal Protocol on Substances that Deplete the Ozone Layer 1993

International Covenant on Economic, Social and Cultural Rights 2000

Bamako Convention on the Ban of the Import into Africa and the Control of Transboundary Movements of Hazardous Wastes within Africa

1990

The Vienna Convention on the Protection of Ozone Layer 1993

The Basel Convention on the Control of Transboundary Movements of Hazardous Wastes and their Disposal

2003

International 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

1981

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Treaties and Conventions Year Ratified

United Nations Framework Convention on Climate Change 1996

United Nations Convention on Biological Diversity 1996

Unit Nations Convention to Combat Desertification 1997

Rotterdam Convention of Prior Informed Consent Chemicals 1998

In addition to the environmental conventions, Ghana is a signatory to 51 of the International Labour Organisations Conventions. The full list is presented in Appendix B.

4.3 International Standards

To secure international finance the project will also need to meet international standards as required by international financing institutions (IFI). Whilst there are some variations in the requirements of different IFI, in the main this means compliance with the IFC performance standards and EHS guidelines.

A full list of applicable standards will be included in the ESIA but as a minimum this will include:

• International Finance Corporation (IFC) Performance Standards for Social and Environmental Sustainability (2013) (“IFC Standards”); including:

o Performance Standard 1: Assessment and Management of Environmental and Social Risks and Impacts (PS1);

o Performance Standard 2: Labour and Working Conditions (PS2);

o Performance Standard 3: Resource Efficiency and Pollution Prevention (PS3);

o Performance Standard 4: Community Health, Safety, and Security (PS4);

o Performance Standard 5: Land Acquisition and Involuntary Resettlement (PS5);

o Performance Standard 6: Biodiversity Conservation and Sustainable Management of Living Natural Resources (PS6);

o Performance Standard 7: Indigenous Peoples (PS7); and,

o Performance Standard 8: Cultural Heritage.

• Relevant IFC Environmental, Health and Safety (EHS) Guidelines including:

o General EHS Guidelines (2007);

o EHS Guidelines for LNG facilities (2007);

o EHS Guideline for Electric Power Transmission & distribution (2007); and,

o EHS Guidelines for Thermal Power (2008).

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4.4 Emission Limit Values

The following national and international emission limit values are applicable to the Project.

4.4.1 Ambient Air Quality

The Ghanaian Ambient Air Quality Standards are provided in Table 4-2 below, together with associated World Health Organisation (WHO) (2005) standards. It should be noted that the Ghanaian Standards are applicable at defined locations, classified as ‘industrial’ or ‘residential’. The WHO Guidelines are understood to be applicable to the protection of public health.

The EPA has produced a ‘Guidelines Development’ report (undated, but circa 2004), which includes draft guideline limits for the Energy sector. The EPA Environmental Quality Guidelines for Ambient Air has been modified to be relevant to stationary plant situations. Although these guidelines have not passed into legislation, they have been included within this assessment for completeness, and can be found in Table 4-3 below. It is understood that ‘nitrogen oxide’ levels in the document is intended to represent nitrogen dioxide. A 24 hour average not to be exceeded 7 days/year is equivalent to the 98.08th percentile of 365 ranked measurements. An hourly average not to be exceeded 240 hours/year is equivalent to the 97.26th percentile of 8760 ranked measurements.

Table 4-2: Ambient Air Quality Standards

Pollutant

Standards & Guidelines EPA WHO

Averaging Time Location Time Weighted Average (TWA) Guideline

Sulphur Dioxide (SO2)

10 minute - - 500ug/m3

1hr Industrial 900

- Residential 700

24hrs Industrial 150

20ug/m3 Residential 100

Annual Industrial 80

- Residential 50

Nitrogen dioxide

1hr Industrial 400

200ug/m3 Residential -


- Residential 60

Annual - - 40ug/m3

Total Suspended Particulate (TSP)


- Residential 150

Annual Industrial 75

Residential 60 Ozone 8 hr mean - 100ug/m3

Particulate Matter (PM10)

24hrs - 70 50ug/m3 Annual - - 20ug/m3

Particulate Matter (PM2.5)

24hrs - 70 25ug/m3 Annual - - 10ug/m3

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Table 4-3: EPA Energy Sector – Guidelines

Substance Sensitive Areas (µg/m3)

Residential & Rural (µg/m3)

Industrial / Commercial

(µg/m3) Sulphur Dioxide

Annual arithmetic mean

20 (for protection of ecosystem;

mining areas, forest/vegetation).

50 50

Max 24hr average 100

(not to exceed 7 days per year)

100 (not to exceed 7 days/yr)

125 (not to exceed 7

days/yr)

Max one 1hr average 200

(not to exceed 240 hrs/yr) 350

(not to exceed 240 hrs/yr)


hrs/yr

Nitrogen Dioxide

Annual arithmetic mean

30 (for protection of ecosystem;

mining areas, forest/vegetation)

80 100

Max 24 hour average 60

(not to exceed 7 days/yr) 60

(not to exceed 7 days/yr)


days/yr)

Max one 1hr average 90

(not to exceed 240 hrs/yr) 90

(not to exceed 240 hrs/yr)


hrs/yr)

Particulates Annual arithmetic Annual 70 100 200

Monthly Average during harmattan 6 100 200

500 (particularly in mining

areas) Max 24hr average 110 150 260

Facilities or projects located within poor or degraded quality airsheds, and within or next to areas established as ecologically sensitive (e.g. national parks), should ensure that any increase in pollution levels is as small as feasible, and amounts to a fraction of the applicable short-term and annual average air quality guidelines or standards as established in the project-specific environmental assessment.

Suitable mitigation measures may also include the relocation of significant sources of emissions outside the airshed in question, use of cleaner fuels or technologies, application of comprehensive pollution control measures, offset activities at installations controlled by the project sponsor or other facilities within the same airshed, and buy-down of emissions within the same airshed.

6 Data adopted from the World Bank and the India Standards

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Specific provisions for minimising emissions and their impacts in poor air quality or ecologically sensitive airsheds should be established on a project-by-project or industry-specific basis.

Offset provisions outside the immediate control of the project sponsor should be monitored and enforced by the local agency responsible for granting and monitoring emission permits. Such provisions should be in place prior to final commissioning of the facility / project.

4.4.2 Air Emission Sources

The following are EPA and IFC EHS Guideline values for process emissions from the source.

Table 4-4: IFC Air Emission Guidelines for Natural Gas Thermal Power Plants Less than 50MWth7 (potentially applicable to the FSRU)

MWth - turbine Particulate Matter SO2 Nitrogen Oxides (NOx)

Dry Gas, Excess O2

Content (%)

=3MWth to <15 MWth N/A N/A 42 ppm (electrical generation)

15

100 ppm (mechanical drive) 15

=15 WMth to <50 MWth N/A N/A 25 ppm 15

Table 4-5: IFC Air Emission Guidelines for Thermal Power Plants Greater than 50MWth

(applicable for onshore power plants)

Fuel Type

Particulate Matter SO2 NOx Dry Gas,

Excess O2 Content

(%)

Non degraded airshed (NDA)

Degraded airshed

(DA) NDA DA NDA / DA

Natural gas N/A N/A N/A N/A 51 mg/Nm3

(25 ppm) 15

Fuels other than natural gas

50 mg/Nm3 30 mg/Nm3 Use of 1% of less S fuel

Use of 0.5% of less S fuel

152 mg/Nm3

(74 ppm) 15

7 Combustion source emissions guidelines associated with steam and power generation activities from sources with a capacity equal to or lower than 50 MWth are addressed in the General EHS Guidelines with larger power source emissions addressed in the EHS Guidelines for Thermal Power.

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Table 4-6: EPA Emissions from Sources

Pollutant Applicable to Standard

Smoke All stationary fuel burning source Ringlemann No. 2 of equivalent opacity (not to exceed more than 5 minutes in any period of one hour

Smoke All stationary sources other than fuel burning equipment

Ringlemann No. 2

Solid particles Any trade, industry, process, industrial plant or fuel-burning equipment

200 mg/m3

Sulphuric acid mist or sulphur trioxide

a) Any trade, industry or process (other than combustion processes and plants for the manufacture of sulphuric acid)

120 mg/m3 as sulphur trioxide

b) Any trade, industry or process in which sulphuric acid is manufactured.

30,000mg/m3 as sulphur trioxide

Hydrogen sulphide

Any trade, industry or process 5 ppm as hydrogen sulphide gas

Nitric acid or oxides or nitrogen

Any trade, industry or process in which the manufacture of nitric acid is carried out

2000 mg/m3 as nitrogen dioxide

Nitric acid or oxides of Nitrogen

Any trade, industry or process other than nitric acid plant

1000 mg/m3 as nitrogen dioxide

Carbon monoxide Any trade, industry or process 1000 mg/m3 as carbon monoxide

4.4.3 Noise

International guidelines for ambient noise levels are set out by the IFC in their Environmental, Health, and Safety Guidelines (2007) and presented in Table 4-7. In addition, the EPA provides national guidance on maximum permissible noise levels for prescribed areas (Table 4-8). The IFC requires that noise impacts should achieve either the levels given below in Table 4-7 or a maximum increase of 3 dB at the nearest receptor location offsite.

Table 4-7: IFC EHS Noise Limits

Receptor

Maximum allowable log equivalent (hourly measurements), in dB(A)

Day (0700 – 2200)

Night (2200 – 0700)

Residential Institutional Educational

55

45

Industrial Commercial

70 70

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Table 4-8: EPA Noise Limits

Zone Description of Area of Noise Reception Permissible Noise Level dB(A)

Day (0600 – 2200)

Night (2200 – 0600)

A Residential areas with negligible or infrequent transportation

55 48

B1 Educational (School), and health (Hospital, clinic) facilities.

55 50

B2 Areas with some commercial or light industry. 60 55

C1 Areas with some light industry, places of entertainment or public assembly, and places of worship such as churches and mosques.

65 60

C2 Predominantly commercial areas. 75 65

D Light industrial areas. 70 60

E Predominantly heavy industrial areas. 70 70

The WHO has published guidelines on which indicate the onset of sleep disturbance, and the likelihood of disturbance in open spaces during the daytime.

The WHO states:

“To avoid sleep disturbance, indoor guideline values are 30 dBLAeq for continuous noise and 45 dBLAmax for single sound events. At night, sound pressure at the outside facades of the living spaces should not exceed 45 dBLAeq and 60 dBLAmax, so that people may sleep with bedroom windows open. These values have been obtained by assuming that the noise reduction from outside to inside with the window partly open is 15 dB.”

WHO further states:

“To protect the majority of people from being seriously annoyed during the daytime, the sound pressure level on balconies, terraces and outdoor living areas should not exceed 55 dBLAeq for a steady continuous noise. To protect the majority of people from being moderately annoyed during the daytime, the outdoor sound pressure level should not exceed 50 dBLAeq.” DRAFT

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4.4.4 Water Quality

The EPA and IFC water quality discharge standards are presented below.

Table 4-9: Ghanaian and IFC Water Quality Discharge Standards8

Parameter Ghanaian limits for Thermal Power Plant IFC guidelines

pH 6 – 9 6-9

BOD5 (mg/l) 50

Oil & Grease (mg/l) 5 10

Total Suspended Solids (mg/l) 50 50

Total Phosphorus (mg/l) 2.0

Temperature increase < 3oC above ambient < 3oC (b)

Colour (TCU) 200

COD (mg/l) 250

Chromium (total) mg/l 0.5

Sulphide (mg/l) 1.5

E. Coli (MPN/100 ml)

Turbidity (N.T.U.) 75

Lead (mg/l) 0.1

Nitrate (mg/l) 50

Copper 0.5

Iron 1

Zinc 1

Total residual chlorine 0.2 (a) a) So called chlorine shocking may be preferable in certain circumstances. This involves using high chlorine levels for a few seconds rather than a continuous low level release. The maximum value is 2 mg/l for up to 2 hours not to be repeated more frequently than once in 24 hours, with a 24 hour average of 0.2 mg/l (the same limits would apply to bromine and fluorine). b) The effluent should result in a temperature increase of no more than 3 degrees Celsius at the edge of the zone where initial mixing and dilution takes place. Where the zone is not defined, use 100 m from the point of discharge when there are no sensitive aquatic ecosystems within this distance.

8 Note that for oil and grease the more stringent Ghanaian limit will apply. Where there are no Ghanaian limits those of the IFC will

apply.

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5 Review of Stakeholder Activities to Date

5.1 Overview

A Stakeholder Engagement Plan (SEP) has been developed for the project which sets out the approach to stakeholder and community consultation and disclosure for the lifecycle of the Ghana 1000 Power Plant and LNG development. The SEP has been developed in order to enhance the stakeholder engagement approach and procedures for the project.

The objectives of the SEP are to:

• Identify the Ghana legal framework for consultation activities and disclosure requirements, particularly in respect of those public consultation activities that are directly required under the local permitting process;

• Identify potential stakeholders in the area of influence, as well as relevant interested parties such as government agencies and other key stakeholders;

• Record all consultation activities, including those prior to the commencement of the ESIA process;

• Describe how concerns or grievances will be handled;

• Provide an action plan for further consultation during preparation, construction and operational phases of the project, including details on appropriate formats and language for effective and culturally meaningful interaction with the community and identified relevant stakeholders; and

• Provide a disclosure plan, including the identification of any locations where relevant project documentation will be available locally and elsewhere, as well as languages to be used.

The Project SEP can be viewed at www.sagepetroleumgh.com

The following summarises the stakeholder engagement activities undertaken to date and proposed throughout the ESIA process.

Table 5-1: ESIA Stakeholder Engagement Implementation Timescales and Responsibilities

Activity Timing Responsibility

ESIA Phase Engagement ESIA Scoping Public Consultation and Disclosure Event

November 20 Aboadze Community Hall

Material in English -Jacobs Consultancy Adverts and translation of adverts to local language (where appropriate) - Jacobs Consultancy / One energy Event arrangement and advertisement by One Energy

ESIA – Draft ESIA Public Consultation Event

TBC – approximately February / March 2015

Draft ESIA in English – Jacobs Consultancy; Adverts and translation of adverts - Jacobs Consultancy Event arranged and advertised by One

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Activity Timing Responsibility

Energy Draft ESIA Disclosure on Project/World Bank website and One Energy website

TBC – approximately February / March 2015

One Energy / World Bank

Steering committee Currently taking place every 2 weeks to discuss development aspects of the project

One Energy

Private meetings and workshops

As necessary over the duration of the ESIA process to collect data and register /concerns opinions with other power developers in the area. The first of these meetings is proposed for week commencing 17 November.

Jacobs Consultancy One Energy

Focus groups discussions with vulnerable groups

At least one meeting with: • Village elders or community

representatives • Fishing communities

One Energy Community Liaison Officer and Jacobs Consultancy

Media communications

• Newspaper adverts/ radio communication at least 2-3 weeks before ESIA scoping and draft ESIA public consultation event

• Newspaper (with nationwide coverage) notice s after ESIA approval

• Radio (with nationwide coverage) announcement after ESIA approval in relevant languages

• As requested or when press releases deemed relevant

One Energy

A number of stakeholder consultation meetings have taken place to inform this scoping assessment and the terms of reference for the full ESIA. Details of the findings of these meetings is within the project SEP. Table 5-2 summarises informal meetings held during the pre-scoping visit undertaken in June 2014.

Table 5-3 summarises the formal meetings held during the ESIA screening phase site visit in October 2014.

The format of meetings was generally introductions, followed by a project description (including phasing and timelines) and then a question and answer session regarding the ESIA approach with feedback from the stakeholder regarding the project and potential environmental and social issues.

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Table 5-2: Pre-screening Site Visit Meetings Held July 2014

Date Organisation

17/06/14 Ghana Environmental Protection Agency (EPA) Head Quarters, in Accra. Meeting with Deputy-Director Agbenor-Efunam; and Larry Cotoe (Environmental Officer)

18/06/14 Sanzule community representatives (for alternative site walk over)

19/06/14 EPA Takoradi Regional Office (Yaw Sarfo-Afriyie, Environmental Protection Agency (EPA) Takoradi Regional Director)

19/06/14 VRA plant manager at TTPP (for site walkover);

19/06/14 Lt Simon Asiedu and his Flag Officer Command (FOC) of the Ghanaian Navy administration at Sekondi Naval Base

20/06/14 Meeting with Maritime Authority

20/06/14 Telephone meeting with Hen Mpoano (Our Coast) Non-Government Organisation (NGO)

Table 5-3: Site Visit Meetings Held Week 6 October 2014

Date Organisation

07/10/14 EPA – Mr Kwabena Badu-Yeboah (Head of Environmental Assessment and Audit)

07/10/14 West African Gas Pipeline Company (WAGP)

08/10/14 Ghana Forestry Commission (GFC) (Wildlife Division), Sekondi-Takoradi office

08/10/14 VRA representatives (multiple persons) and EPA Takoradi Regional Office - Yaw Sarfo-Afriyie, Regional Director (at VRA compound)

08/10/14 Meeting with District Chief Executive (DCE) of Shama District Assembly (at VRA compound)

09/10/14 Energy Commission of Ghana (ECG) (Accra office)

09/10/14 Ghana Maritime Authority (GMA)

09/10/14 Town and Country Planning (T&CP) (Ministry of Environment, Science and Technology - MEST)

10/10/14 Fisheries Commission (Tema office), Kofi Amador. Fisheries Scientific Survey Division (FSSD)

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The following photos show some of the consultation meetings which took place during the pre-scoping and screening/scoping phase site visits.

08/10/14 VRA representatives (multiple persons) and EPA Takoradi Regional Director (at VRA compound)

07/10/14 WAGP, Accra

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6 Environmental and Social Context

6.1 Overview

The following sections present an overview of the environmental and social context (baseline) relating to the area in which the development will take place (the “area of influence”). The overview has been collated by undertaking a desk review of identified publically available information, site walkovers of the project area and feedback during consultation events. The full list of third party data and reports used to inform this section is included within the reference list at the end of this document.

6.2 Project Area of Influence

The scale of the project is such that, whilst some elements (e.g. air emissions, materials supply) may have national or international influence, the key positive and negative project impacts will affect the environment and communities local to the site. In addition to mainly secondary information presented in this report, collected at the national/provincial level, baseline data will therefore be collected from sources at the local and district level.

The main study area for the ESIA will focus on the on-shore site and the pipeline route. Where appropriate for specific technical disciplines (e.g. for the air quality assessment), wider areas will be considered.

For the offshore facilities, impacts are considered from the FSRU vessel, jetty, breakwater and sub-sea pipeline to connect to the shore.

6.3 Environmental Baseline

6.3.1 Physical Baseline

6.3.1.1 Overview

Takoradi is located on the southwest coast of Ghana in the Western Region in the District of Shama Ahanta East. The proposed site for the plant is approximately 15 km northeast of the city of Sekondi-Takoradi, immediately to the west of the village of Aboadze.

6.3.1.2 Climate

The meteorological conditions at Takoradi are characterized by stable temperatures. Overall, there is very little temperature variation throughout the year, with mean daily maxima averaging 27°C from July through September and reaching 30°C to 31°C, between November and April. Mean daily minimum temperatures vary only between 21°C to 23°C. Average relative humidity shows a consistent daily variation, reaching 95% overnight and decreasing to 70% to 80% during the day.

Ghana has a bimodal rainfall distribution (June/July and September/October) with distinct differences in the amount and seasonal distribution of precipitation. Average annual precipitation at Takoradi is approximately 1200 mm, with May and June being the wettest months, when over 250 mm of rain falls each month.

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There are two main seasons during the course of the year, i.e., wet and dry, with a short break in the wet season in August. During the dry season, the coastal areas of Ghana are dominated by the northeast trade wind system, which is relatively free of clouds and rain, and is cool, dry, and dust-laden; it is known as the “Harmattan.” During the wet season, the south east trade winds are associated with more periods of increased clouds and precipitation.

The prevailing south west wind is relatively light but steady throughout the year, with distinct diurnal variation relative to the land/sea breeze effect.

6.3.1.3 Ambient Air Quality

Ambient air quality in the vicinity of the project site is reportedly impacted by salt spray from the surf zone, wood smoke from fish smoking operations and the existing power stations operations in the area.

There are a number of operational power plants in the vicinity of the project which are currently operating on LCO. These are:

• T1 — 330MW – VRA

• T2 — 330 MW – VRA / TAQA

• T3 — 132 MW - VRA

The main pollutants from the combustion of LCO are CO2 and water vapour and some NOx and SOx.

Air quality in the Takoradi area is already believed to be impacted by operation of the existing TTPP plants.

Existing ambient air quality monitoring data has been requested from the EPA / VRA for the purposes of this assessment including data from the following operational ambient air quality monitoring stations:

• Aboadze Monitoring Station, which monitors NOx, SOx and PM10. This station provides details of the air quality at the nearest residential area to the project; and

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Table 6-1 presents ambient air quality data for the area from the EIS for T2 (2009).

Table 6-1: Ambient Air Concentrations (T2 Expansion EIS, 2009)

Station Aboadze Monitoring Station VRA Township

Parameter NOx 24 hr µg/m3 SOx 24 hr µg/m3 PM10 24 hr µg/m3 PM10 24 hr µg/m3

January 10.02 13.4 50 26

February 80.19 13.17 49 23

March 79.15 15.19 51 31

April - - 0 28

May - - 43 38

June 80.79 7.41 35 32

July - - 60 -

August - - 52 36

September - - 44 23

October - - 0 45

November - - 0 45

December - - 0 48

The ambient air quality results below demonstrate that are there some exceedances of NOx levels at Aboadze when compared against the EPA ambient air quality standards (60 µg/m3) for residential areas. The ambient air quality data presented below is from before the expansion of T2 and the operation of T3 and potentially the ambient air quality conditions at Aboadze and the VRA township could have worsened.

6.3.1.4 Noise

The noise levels in the vicinity of the site are considered in this section. These have been obtained from publically available environmental assessments previously undertaken in the area.

Table 6-2 provides the averaged daytime noise levels obtained at sites around Aboadze Village for surveys undertaken in 1993, 1999, 2006, 2007, 2008, 2009 and 2010.

Table 6-3 details the averaged night time noise levels for surveys undertaken in 1993, 1996 and 2006. The noise levels for 2007, 2008, 2009 and 2010 are daytime averages derived from the routine monitoring undertaken, no night-time data was reported to be available.

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Table 6-2: Averaged Daytime Noise Levels from the Surveys at Aboadze Village

Location (Period, Date)

Averaged Noise Levels dB LAeq LA1 LA10 LA90

Near Aboadze Primary School 1993 47 -- -- -- Near Methodist Church Cemetery 1993 51 -- -- -- Aboadze - Adjacent lorry station/market 1999 52 60 54 46

(43.4 - 48.5)

Aboadze - Environmental Monitoring Station

1999 53 62 55 46 (43.0 - 49.6)

2006 (May 11/12) 68 70 63 54

(44.3 - 73.8) 2006

(May 14/15) 69 70 69

63 (45.4 - 69.9)

2007 51 - - -

2008 51 - - -

2009 51 - - -

2010 52 - - -

Table 6-3: Averaged Night-time Noise Levels from the Surveys at Aboadze Village

Location (Period, Date)

Averaged Noise Levels dB

LAeq LA1 LA10 LA90 Near Aboadze Primary School 1993 46 -- -- -- Near Methodist Church Cemetery 1993 48 -- -- --

Aboadze - Environmental Monitoring Station

1999 46 52 48 42 (38.8 - 43.5)

2006 (May 11/12)

56 57 50 43

(40.9 - 45.6)

2006 (May 14/15)

52 57 51 46

(42.4 - 47.9)

The ordinal T2 expansion study had required noise mitigation measures (ultimately provided via contract conditions limiting noise increase to 3dBA in line with IFC standards). The 2010 study found that, even before the expansion of T2 and operation of T3, there were already discrete exceedances of EPA night time limits from local noise sources.

6.3.1.5 Hydrology, Flooding and Surface Waters

The main regional watercourse is the Pra River, which discharges into the sea through a coastal lagoon just east of Shama, 15km east of the site. Given the distance from the site, the Pra River is not considered as a potential receptor for the project.

The Anankwari River flows along the western boundary of the site. Its tributaries flow through a very low-lying, perennial wetland floodplain which includes some areas of the site. The lower reaches of river and its floodplain are generally isolated from the ocean by a sand bar that builds up across its mouth during the dry season.

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The river regime is controlled by a dam at Inchaban. The dam is believed to be consumptive and is known to supply water to the existing TTPP. At present, no detailed information has been obtained regarding the operation of the reservoir. However, it is assumed that the reservoir is drawn down in the dry season by the abstraction of water for public water supply. In the wet season the reservoir is then allowed to refill and once full excess flows are then allowed to overtop and proceed downstream. In addition when no overtopping is occurring a small environmental baseflow is released from the reservoir to prevent the river downstream from drying up. The net result of this is that dry season flows are low but constant while wet season flows are significantly lower than would naturally be the case until the point where the reservoir is full.

Otherwise the flow in the lower reaches of the river in the vicinity of the site results from a few small tributaries downstream of the dam. In particular, one large tributary drains a small catchment to the east of the TTPP and flows through that facility via a storm drainage system into the wetland on the western side of the TTPP site compound, which is understood to be the original discharge location for that catchment. Anecdotal information from site visits indicates that this drainage system design is not functioning well and that backing up of waters is common in low lying parts of the catchment to the east of TTPP.

The seasonal freshwater wetland in the vicinity of the site occupies a depression between the coastal strand vegetation and raised areas of scrub and thicket vegetation. Groundwater is also found at the surface in low lying areas and at shallow depths (between 0m and 2m). Seasonal flooding is reported in the area. The onshore power plants will be partly constructed on the wetland areas, which form part of the floodplain for the area.

Climate change impacts associated with potential increases in sea level and/or rainfall may exacerbate flood risk or other issues associated with the development’s impact on the wetland and local hydrological regime. Implications of climate change risks will need to be considered as part of the hydrology and flood risk assessments.

6.3.1.6 Geology

The regional geological formations of the Ghana coastal areas are heavily influenced by the processes of continental drift during the Cretaceous period (about 135 million years ago), when Africa broke away from South America. The underlying basement formations consist of hard granites, granodiorites, and metamorphosed lava and pyroclastics. Some coastal areas are covered by Ordovician, Silurian, and Devonian sandstone and shale.

The geology of the local area is described as Precambrian to Carboniferous age basement rocks (primarily gneiss, granites and schist) overlain by Sekondi Series sandstones and shale with occasional conglomerate strata, which are believed to be of Devonian or Carboniferous age.

The project site geology comprises Ajua Shale and Elmina Sandstone units of the Sekondi Series. The Ajua Shale’s are present in an east-west depression across the north end or the site, but there are no surface outcrops. Outcrops of Elmina sandstone occur east of the site in Aboadze, along the shoreline to the south of the site, and along the elevated areas to the north and west of the site. Surface outcrops along the tidal zone of the shoreline consist of fresh to slightly weathered sandstone, whereas outcrops exposed further inland usually have a weathered mantle of 0.5m to 1m. The rock weathers to a brown, hard sand, and clay to clayey sand.

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From a marine aspect, the continental shelf is at its widest, up to 90km from the coast. The substrate is believed to comprise predominantly sandy-mud, with patches of harder sand and shallow depth to underlying bedrock.

6.3.1.7 Soils

The major soils of the area are forest and coastal savanna ochrosols. Forest ochrosols are developed in forest and savanna environment under rainfall between 900mm and 1,650mm. The organic matter content of such soils is low, with pH generally less than 5.5. Coastal savanna ochrosols are mainly red and brown, moderately well drained medium to light-texture soils developed over Voltaian sandstone, granite, phyllites and schists. They are also generally low in organic matter due to insufficient accumulation of biomass.

6.3.1.8 Seismicity

Seismic studies have indicated that Ghana's seismicity is associated with active faulting, particularly near the intersection of the east-west trending Coastal Boundary Fault and the northeast to southeast Akwapim Fault Zone.

Southern Ghana is not a highly active seismic area; however, it is a region capable of producing significant earthquakes and previous studies have identified an earthquake risk due to a periodically active seismic area approximately 100-200km east-southeast of the Aboadze area. Risk of earthquakes and associated tsunami will need to be considered in the design.

6.3.1.9 Oceanography

The oceanography of the West African region is influenced by the meteorological and oceanographic processes of the South and North Atlantic Oceans. The coastline in the region is a series of beaches intersected by rocky promontories and some cliffs. This is apparent in the vicinity of Aboadze, where the shoreline consists primarily of sandy beaches with rocky outcrops. The coastal surface currents are predominantly wind-driven and are confined to a layer of 10 to 40m in thickness.

Littoral drift, which is the main driving force in coastal circulation in this area, is generated by breaking waves. The littoral drifts generally flow in an eastward direction and are responsible for transporting large volumes of littoral sediments. The direction of tidal current around the coast of Ghana is mostly North or North-East.

The tide on Ghana's coast is regular and semi-diurnal. The tidal wave has virtually the same phase across the coast of the country. The average range of Neap and Spring tides increases from west to east. Tidal currents are low and have an insignificant influence on coastal processes except within tidal inlets.

6.3.1.10 Marine Water Quality

Generally, the Tropical Surface Water is characterized by warm, well-mixed water that extends from the surface to the depth of the thermocline (depths from about 30m to 40m). Sea surface temperatures and salinities along the coast of Ghana can vary widely, with the oceanographic regime characterized by a seasonal major upwelling and a minor upwelling. The major upwelling occurs for approximately three months each year, beginning late June or early July and ending in

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late September or early October. This event is defined as that period when sea surface temperature falls below 25º C. The upwelling is stronger and lasts longer along the western section of the coast.

Salinity on average is highest in August and lowest in late October and November. Salinity is influenced by rains and high volume river discharges which dilute near-shore waters and upwelling that brings deeper, more saline waters to the surface.

Previous works done on physicochemical properties of the water column in the Gulf of Guinea Ocean indicate a healthy marine environment. Turbidity is generally low in the offshore, oceanic waters; however, a coastal zone of turbid, greenish water meets the clearer oceanic water approximately 6-8km from the coast. The high population density in the coastal zone is associated with increasing amounts of untreated domestic waste being discharged into the marine environment. There has been increasing faecal and nutrient-pollution of the marine environment in the Takoradi area.

6.3.1.11 Seabed Topography

The continental shelf varies in width from a minimum of about 20km off Cape St. Paul to about 90km at the widest portion between Takoradi and Cape Coast. Submarine canyons exist off the Volta Delta (Edwards et al., 1997). The entire shelf is traversed by a belt of ancient, fossilized madreporarian coral (stony, reefbuilding corals of tropical seas) beginning at a depth of 75m. Beyond this coral belt, the bottom falls sharply, marking the transition from the continental shelf to the slope which reaches depths of some 2000m over 10km. Soft sediments predominate along the coastline up to the coral belt (WAPC, 2004).

6.3.2 Biological Baseline

6.3.2.1 Overview

In Ghana, immediate coastal zone vegetation is broadly mapped as strand and mangrove. On a broad scale, the regional vegetation pattern of the area inland of Sekondi-Takoradi is semi-deciduous. Mangrove communities develop, especially within the coastal lagoons. Aboadze is an area of occasionally exposed rocky shores intermixed with larger expanses of sandy beaches. The distribution of coastal marine flora and fauna is dependent on tidal levels, coastal geomorphology and seasonal variations.

6.3.2.2 Terrestrial Flora and Fauna

An ecological desk study and a walkover survey were carried out in October 2014 to inform a preliminary definition of the ecological baseline of the site. Ghana has a 550km coastline with about 90 lagoons and associated wetlands. Major rivers and their associated estuaries are also located in the coastal area. Ten wetlands types based on the classification of the Ramsar Convention on Wetlands (Ramsar, Iran, 1971) occur in the coastal zone of Ghana (Gordon et. al., 1998) although none are located near to the project site.

The Aboadze area lies in the wet evergreen forest region of Ghana which is rich in flora and has more characteristic species than any forest type in Ghana (Hall and Swaine, 1981). The Region has various types of coastal habitats including swamps, sandy beaches, lagoons, estuaries and

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mangroves. Permanently flooded areas of the coastal habitats are occupied by well-developed freshwater swamp forest dominated by wine palm (Raphia hookeri) and swamp arum (Cyrtosperma senegalense). Areas behind the coast, which are subjected to seasonal freshwater flooding, have heavily leached podzolic soils which support only short grassland with many herbaceous species.

The wetland area itself has a relatively low range of plant and animal species. The northern section is more diverse (in terms of both flora and fauna) than the middle and southern sections. Several wetland categories are present within or adjacent to the project area, including swamp and mangrove forests, flood plains, and sandy beach with streams and lagoons and the sea. Most of the area has been modified by different anthropogenic activities such as settlement and farming, but small areas may still have their original vegetation type intact.

The most common trees in the wetland areas are the raffia palm (Raphia vinifera), swamp couch (Paspalum vaginatum) and bulrush (Typha spp.) which grow in stands at waterlogged portions of the site. The drier portions of the wetland areas comprise mainly sedges and grasses. The wetland is subject to seasonal flooding during the wet season.

Major habitat types found in the project area include coastal strand and coconut vegetation, grassland and thicket, freshwater swamp forest and mangrove forest. Others are farms with palm plantations, cassava and plantain and also cassia woodlots.

The coastal stretch from in the project area has poorly developed strand vegetation confined to the foreshore, above high-water mark. The vegetation comprises umbrella sedge (Cyperus maritimus), beach morning glory (Ipomoea pes-caprae), swamp couch, dropseed grass (Sporobolus pyramidalis) and American aloe (Agave sp.). Coconut plantations (Cocos nucifera) occur along the entire stretch of the elevated sandy beach bar.

The site proposed for the construction of the power facilities is seasonally flooded grassland and thicket vegetation. The grasses found here include spear grass (Heteropogon contortus), a Panicum species, Panicum congoense, and golden brittle grass (Setaria anceps). The thicket clumps are composed of species such as African oil palm (Elaeis guineensis), and African fan palm (Borassus aethiopum) scattered widely in the area. Swamp couch and bullrush may also be present in such areas.

Freshwater swamp forest occurs in isolated patches in mainly the central and southern sections of the project site although a small area also occurs in the north-western corner of the site. This habitat, which is seasonally inundated, contains fewer large trees than surrounding high forest areas and is also poorer in species. Although not very extensive in scale, it provides fishing grounds for the nearby communities. Raffia palm, Swamp couch (Paspalum vaginatum) and bullrush are the dominant species of this area.

Mangrove forest is located along the north-western boundary of the project site, along the Anankware river which empties into the Anankware lagoon and finally into the sea at the Anakware estuary. White mangrove (Avicennia germinans), red mangroves (Rhizophora racemosa) and black mangroves (Laguncularia racmosa) are the dominant species . Typically Rhizophora and Laguncularia species are found on the seaward side of lagoons whilst Avecinnia is found on the landward side of the swamps (FAO/UNEP, 1981). Mangroves are typically accompanied in the marshes by the mangrove fern Acrostichum aureum and the grass Paspalum vaginatum.

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Associated with the mangroves are swamp grass and buttonwood (Cornocarpus erectus). Faunal composition includes the lagoon crab (Cardiosoma amartum), mudskipper (Periophthalmus papilio), Tilapia species, weaver birds, pied king fisher and western reef egret. The presence of mangrove fern in places is indicative of degradation.

The northern section of the site has Cassia woodlot established by community members for charcoal production. Food crops are also cultivated within and around the site by the nearby communities. Relative to the southern section of the site, there is high diversity of both flora and fauna in this area. Notable vegetation in this area includes cassias (Cassia spp.), plantain (Musa paradisiacal), cassava (Manihot esculenta), Africa oil palm (Elaeis guineensis) and sweet potato (Ipomoea batatas). The fauna include several species of birds and rodents; common species include the birds common bulbul (Pycnonotus barbatus), village weaver (Ploceus cucullatus), Senegal coucal (Centropus senegalensis), pied crow (Corvus albus), pied kingfisher (Ceryle rudis) and black kite (Milvus migrans), as well as the mammals grass cutter (Thryonomys swinderianus) and ground squirrel (Otospermophilus beecheyi). The higher abundance and diversity of fauna in this section of the proposed project site is likely a result of the greater range of opportunities for such species provided by the more varied vegetation in this area.

6.3.2.3 Terrestrial Protected Areas and Species

There are no designated sites of ecological or nature conservational value in the vicinity of the site, and the region is not considered to be of ecological significance for congregational or migratory species.

6.3.2.4 Marine Flora and Fauna

Benthic Environment

Benthic fauna forms an important part of the marine ecosystem, providing a food source for other invertebrates and fish as well as cycling nutrients and materials between the water column and underlying sediments. Previous studies have identified that benthic flora and fauna in the area is limited due to the sandy wave swept coast being a relatively hostile marine environment. During a biotope survey conducted in August 2010 (by Jacobs as part of an environmental impact assessment for a project in Takoradi) only the ghost crab (Ocypoda cursa) and several species of polychaete were observed. Two areas of intertidal rock are present within the vicinity of the proposed site. This intertidal area is likely to extend subtidally by several hundred metres and may form the edge of the Sherbro Bank which the WAGP crosses. A number of mid and low shore transects were surveyed during August 2010. The results show a diverse community of green (e.g. Ulva fasciata, Enteromopha flexuosa), brown (Basispora afrlcana), the encrusting Ralfsia expansa) and red seaweeds (Centroceras clavulatum); snails (Littorina spp); anenomes; urchins (Diadema spp); and, limpets (Siphonaria spp). In the rockpools crabs, fish and a sea cucumber were recorded.

Plankton

The diversity and abundance of the planktonic community changes seasonally. The main driving influence is the oceanographic regime. Offshore the phytoplankton community maintains a high diversity and low abundance during stratification, during periods of upwelling the diversity declines but numbers increase rapidly (Wiafe, 2002). The main seasonal upwelling mixes cold, nutrient rich

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lower layers with surface layers, enhancing productivity. It is this process that results in populations of phytoplankton and zooplankton increasing (Minta, 2003). The timing of fish spawning means that fish larv/ae and eggs can contribute significantly to this peak (Acres, 1995).

During the WAGP surveys (2004) as many as 63 species of zooplankton were recorded. The phytoplankton community was dominated by the dinoflagellate genus, Chaetoceros spp and also included Dinophysis acuta, known to cause diarrhetic shellfish poisoning during blooms. The most common species of zooplankton was the cladoceran, Penilia avirostris (WAGP, 2004).

Dinoflagellates are the main components of the coastal water community during the upwelling, dominating in temperatures below 25 °C. Diatoms proliferate at other times (Anang, 1978).

There appears to be an underlying trend of declining zooplankton abundances along parts of the Ghanaian coast. There is little evidence to support rising temperatures although the large copepod, Calanoides carinatus, an important species in the planktonic community, is sensitive to temperature above 23 °C (Wiafe et al, 2008).

It has been observed that Chaetognaths are sparse most of the year, but become prolific September to November. Thaliaceans, mainly Thalia democratica, become prolific only in December and July, and Appendicularians are often abundant in June and October (Thiriot, 1977 cited in WAGP, 2004)).

Sea Turtles

In general, five species of sea turtles have been identified as commonly nesting in the Gulf of Guinea (Marquez, 1990; FAO, 1981). These are the leatherback turtle (Dermochelys coriacea), green turtle (Chelonia mydas), hawksbill turtle (Eretmochelys imbricata), loggerhead turtle (Caretta caretta) and olive ridley (Lepidochelys olivacea). Leatherback and hawksbill turtles are classified globally as Critically Endangered, green turtles as Endangered and olive ridley turtles as Vulnerable by the IUCN Red List of Threatened Species (2012).

All five of the above named species of sea turtle are thought to nest on beaches in Ghana. Sea turtles are afforded protection in Ghana under the Wildlife Conservation Regulations, 1971 (LI 685), which prohibits hunting, capture and destruction of animals. The penalty for contravening this law can lead to imprisonment for a period up to 6 months.

There would appear to be some potential for nesting to occur within the Project area due to the evidence of nesting having occurred in western Ghana and the fact that the beach that fronts the Project site may provide suitable habitat.

Marine Mammals

There are a few records of dolphins and whales spotted along the coastline of Ghana (WAGP, 2004) with the majority of sightings are offshore (>3 km for the coast). A survey by Waerbeek and Ofori-Danson (1999) recorded six cetacean species: humpback whale (Megatera novaeangliae), sperm whale (Physeter macrocephalus), dwarf sperm whale (Kogia simus), bottlenose dolphin (Tursiops truncatus), clymene dolphin (Stenella clymene) and rough-toothed dolphin (Steno bredanensis). However, a thorough study of by-catch data confirmed there were at least 18 species along the coast of Ghana (Van Waerebeek et al, 2009).

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Of the cetacean species noted in the area two are specifically coastal; humpback whales and bottlenose dolphins. However, Van Waerebeek et al. (2009) state that bottlenose dolphin is the third most frequently (15.5%) landed small cetacean in Ghana (Ofori-Danson et al., 2003). The location of the usual drift gillnetting grounds suggests an offshore stock, although this has not been morphologically or genetically confirmed.

Some other species may also occur in shallow coastal water from time to time, including Bryde’s whale, fin whale, killer whale and common dolphins. The rest are largely deepwater, offshore species.

Fish

The marine fish and shellfish species found in Ghanaian waters can be grouped as pelagic fish (small and large), demersal fish, molluscs, and crustaceans. Some of the deep water species may also be relevant but their importance to the fisheries is less well understood.

The small pelagic fish species found at depths between 50m and 400m are the most abundant marine resources exploited by fishing fleets. Historically, seasonal increases in the abundance of small pelagic fish species are influenced by upwelling regimes which occurs between July and September. Four main small pelagic species of high economic value found in the Ghanaian waters (mainly in shallow water) are round Sardinella (Sardinella aurita), Madeira/flat Sardinella (S.maderensis), European anchovy (Engraulis encrasicolus) and chub mackerel (Scomber japonicus).

The large class of pelagic fish species include tuna, billfishes and some sharks. The main tuna species found in Ghanaian waters are skipjack tuna (Katsuwonus pelamis), yellowfin tuna (Thunnus albacares) and bigeye tuna (Thunnus obesus). Billfish species are found in shelf waters and open ocean and include the Atlantic blue marlin (Makaira nigricans), Atlantic sailfish (Istiophorus albicans) and swordfish (Xiphias gladius). The main species of sharks in Ghanaian waters include blue shark (Prionace glauca) and hammerhead shark (Sphyrna spp.)

Demersal fish are common on the continental shelf along the entire length of the Ghanaian coastline and include a variety of tropical species including, Triggerfish (e.g., grey triggerfish - Balistes capriscus), Grunts (Haemulidae), Croakers or Drums (Sciaenidae), Seabreams (Sparidae), Goatfishes (Mullidae), Snappers (Lutjanidae), Groupers (Serranidae), Threadfins (Polynemidae), Emperors (Lethrinidae)

Molluscs and crustaceans are demersal species that can be found on the continental shelf and upper slope at depths ranging from 5 to 500 meters. The main species include the common cuttlefish, pink cuttlefish (Sepia orbignyana), common squid (Loligo vulgaris), common octopus (Octopus vulgaris), the royal spiny lobster (Panulirus regius), deep-sea rose shrimp (Parapenaeus longirostris) and other shrimps (mainly southern pink shrimp Penaeus notialis, caramote prawn Penaeus kerathurus and Guinea shrimp Parapenaeopsis atlantica).

Fisheries

Over 100 fish species are known to frequent the Ghanaian waters the most abundant species The local fishery is extremely important to the local economy. Estimates in Acres (1995) state it contributes ‘50% of the district’s artisanal catch, which itself contributes up to 5 % of the national catch’. Agyepong et al. (1990) estimated that there were 5,350 fishermen in the villages of Aboesi,

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Aboadze and Shama. In Aboadze, fishermen are attracted from throughout the country with the majority of people (up to 75%) in the village engaged in fishing, with men catching the fish and women smoking, processing and trading fish (WAGP, 2004).

Interviews with the Shama Canoe Fishing Council undertaken for the T2 Cooling water EIS indicates that the majority of fishing occurs offshore (greater than 3 km from the shore). This view was supported by consultation with the Ghana Fisheries Commission in October 2014. The methods and locations of fishing vary seasonally. Between May and September many local fisherman travel westwards from Shama, transiting offshore past TTPP. The key species fished are Sardinella spp. which are caught using fine meshed drift nets.

When Sardinella spp are not as prevalent, fishermen target a large range of other species (e.g. tuna) and travel west, east and south from Shama in search of offshore fishing grounds.

No significant fishery resource is known to exist nearshore (within 3 km of the coast) around TTPP. The WAGP which comes ashore several hundred metres to the west of the plant has a fishing exclusion zone extending 1 nautical mile (1.8 km) east and west of the pipe which runs offshore some 15 km. Some seasonally dependant fishing does occur around Shama Bay; cassava fish, shrimp, ribbonfish and lobster are all caught. Acres (1995) identified shrimp fishing grounds in waters 20 to 50 m deep (approximately 8 km offshore) south east of Shama Bay. It is likely that shrimp will use the sheltered bay at Shama as a nursery area.

West of Shama Bay is a length of rocky shoreline where lobsters are common, which are then sold on to market at Sekondi and Takoradi, or exported. There is no lobster fishing either bordering the proposed site, or close by in the Anankwari Estuary. Crab, shrimp and shellfish are known to be harvested in coastal lagoons and river mouths, but in the area this is confined to around the Pra River, 7 km from TTPP.

The Sherbro Bank, located about 1.5 - 2 km south of the high water mark near the TTPP (within the nearshore area) is an area of rocks approximately 2 km long which potentially provides a valuable fish and benthic community. The Roani Bank is of a similar sized rocky outcrop located 4 km south of TTPP and within the offshore area. The currently anticipated location of the FSRU is within 3km from the shore. It will be important to ensure that the FSRU does not impact on the Sherbro bank.

These areas are likely to contain a rich diversity of organisms including damsel fish (Abudefdut saxatilis), surgeonfish (Ophioblennius atlanticus), and large parrot fish (Pseudoscarus hoefien) (Acres, 1995).

Worthy of note because of the commercial value is the sardinella fishery. The major part of this fishery is located offshore (circa 15 km) although sardinella lar\/ae and juvenile may come inshore to feed (Acres 1995). From July to September the major upwelling provides the most productive fishing season with the round sardinella (S.aurita) and flat sardinella (S.maderensis) the dominant species.

Marine Birds

None of the 50 marine bird species known to occur in the Aboadze area are of international conservation significance, but fourteen species including the black kite (Milvus migrans), hooded

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vulture (Neophron monachus), bronze manikin (Lonchura cucullata) and village weaver (Ploceus cucullatus) are of national conservation significance.

Marine Protected Areas and Species

There are no marine protected areas in Ghana.

A small number of marine fish are considered to be endangered, especially deep sea species (as listed on the International Union for the Conservation of Nature and Natural Resources (IUCN) Red List. A number of these species are believed to be commercially important and are subjected to heavy exploitation, particularly tuna. Critically endangered listed species include Goliath Grouper, Wide Sawfish and the Largetooth Sawfish.

Species of both international and national conservation concern such as green sea turtle, leatherback sea turtle, hawksbill sea turtle, dwarf sperm whale, short-snouted seahorse, and West African manatee, among others are reported to be present in the area. Other marine species of international conservation concern including false killer whale, pan-tropical spotted dolphin, rough-toothed dolphin, and the northern star coral have also been found in the area.

6.3.3 Social Baseline

6.3.3.1 Governance Structure

In Ghana there are two parallel government systems operating at the local level, the district assembly administrative structure and the traditional administrative system. The district administration consists of elected representatives and central government appointed personnel, whereas the traditional administration is derived from the chieftaincy institutions. At the community level, an elected assembly person serves as the main link between the district assembly and the community.

Chiefs and elders comprise the traditional administrative institution and they have both judicial and executive functions within the communities.

In the Aboadze area the land is termed “Stool Lands” and comes under the control of the Paramount Chief but the right of use lies with the families who are direct beneficiaries of any returns from the land. The Dwomo Stool (the Stool with custody of land in the vicinity of Aboadze) resides in Dwomo, 3km from the Takoradi-Accra highway to the north of Inchaban. The inhabitants of Aboadze are thought to be predominantly migrant fishermen who have no legal ownership rights to the land. The Stool is the custodian of the land and as such can release land for projects of community or national interest. They can also reassign land, for example making land available to compensate displaced farmers.

6.3.3.2 Land Use

The regional area exhibits a range of land uses from intense urbanization / industrialisation in the Sekondi-Takoradi area to well established plantations of coconut and oil palm, to areas of native forests and savannahs further to the north. The Aboadze town is typified by closely spaced houses that extend down to the shoreline. Planted along the beach ridge and on the high knolls on either side of the Aboadze-lnchaban road are Coconut palms. Farm plots are also found among heavily wooded area around the town site.

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However, the area identified for the onshore components of the project has already been developed as a power enclave. The following power plants are currently operating within the vicinity of the proposed project site:

• T1 — 330MW – VRA

• T2 — 330 MW – VRA / TAQA

• T3 — 132 MW - VRA

Additionally, there are a number of proposed new power projects. Those known or thought to be in the planning process as of October 2014 are described in Table 6-4 below.

Table 6-4: Proposed Power Projects

Potential Project

Known Design Details Current Status / Additional Info

Amandi 239MW combined cycle LCO. Potentially with seawater cooling.

Permit issued 23 July 2014

Jacobsen 360MW gas turbines (possibly 3 x 9E) Permit issued 23 April 2014

ASG 200MW (possibly 191MW). A second possible ASG site is mentioned in the ECG document.

Scoping phase

Astropower 200MW - Greek plant to be rebuilt in Ghana. Scoping phase

Rotan Power IPP

660MW floating power barge (off shore in Aboadze, adjacent)

Provisional licence issued 01/04/14, expires 31/03/16 Unsure of EIA status

ERL systems Limited

370MW combined cycle plant in Takoradi – unsure of location

Provisional licence issued 03/04/13, expires 02/04/15 Unsure of EIA status

T4 186MW combined cycle (likely LCO) Provisional licence issued 16/12/13, expires 17/12/15 Unsure of EIA status

T5 Globeleq - No further information No further details

Patina Energy Limited

200MW combined cycle Provisional licence issued 05/04/13, expires 04/04/15 Unsure of EIA status

KAR Powership Ghana

225MW at Sekondi Harbour. Part of a two barge project with alternative licence

No further details

Source: Energy Commission of Ghana (ECG) website October 2014, and letter from EPA (October 2014)

There are a small number (2 or 3) of houses and small scale farming in the wetland area in the vicinity of the proposed onshore power plants and as highlighted in Section 6.3.2.2, part of the project area is used by the community for charcoal production, various farming activities and fishing.

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6.3.3.3 Local Demographics

The population of the Sekondi Takoradi Metropolitan Area, within the western region, had a population of 559,548 in 2010. The western region of Ghana has seen a growth rate from 2000 to 2010 of 2 million. In the Sekondi Takoradi Metropolitan Area, the male population is slightly lower than the female population, a 49 percent and 51 percent breakdown respectively. The population of Abodze is believed to be approximately 10,000.

6.3.3.4 Religion

Christianity is the predominant religion practiced in the Coastal regions of Ghana, including Aboadze, followed to a far lesser extent by traditional beliefs, Islam, and atheism. In Aboadze, Catholicism and Protestantism are the main forms of Christianity practiced. The village also has one of the highest proportions of Muslims in Southern Ghana.

6.3.3.5 Ethnicity

The traditional community of Aboadze are predominantly of the Akan extraction (mainly Fante). The ethnic groups include Fantes, Elmina, Ekumfi, Komenda and Sekondi. The population of Aboadze is predominantly Fantes who have migrated from the surrounding areas. The common local dialects of the people in this area are Ahanta and Fante.

6.3.3.6 Employment

Agriculture (including fishing, animal husbandry and hunting), production and transport works, sales work and professional and technical works are the four broad categories of employment avenues or occupations in the district where Aboadze is located. The majority of the people in the district are involved in agriculture. Aboadze is a very active fishing town. The economy of the coastal dwellers is tied to fishing, salt production and subsistence farming.

6.3.3.7 Quality of Life

The quality of life in Aboadze is relatively higher than other rural communities in the western region. This is because of the presence of a lot of social infrastructure and employment by the local power plants. A hospital, schools, health centre, pharmacy, electricity, telephone, rural bank, police station, market and small industries are all present in the community.

6.3.3.8 Roads

The local road network in the Aboadze area was noted to be in good condition, with sealed surfaces on main roads. Access to the site will be via the existing main site access to TTPP or potentially one of the existing accesses to the north of the VRA compound. The two main routes into the area are a 4 km sealed asphalt road from the Accra-Takoradi highway at Inchaban to the north and a 9.6km road off Accra-Takoradi highway from Shama Junction to the east which passes through Shama, Abuesi and Aboadze. This road however is only sealed for 3km from Shama Junction to Shama with the remaining portion dirt/unsealed road. Previous studies indicate that the Inchaban-Aboadze road was resurfaced before 2009 to accommodate the increased traffic flows and it passes through a number of villages.

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6.3.3.9 Cultural Profile

The indigenous people of Aboadze are a typical fishing community. The presence of the power stations in the area has resulted in the introduction of “foreign” culture into the community and has resulted in the rural community having a relatively high level of economic and industrial activity. Apart from the power stations, other energy development projects that influence the socioeconomic conditions of the local community are the West African Gas Pipeline Company.

Like all fishing communities scattered along the shores of Ghana, people of Aboadze observe certain traditional rituals, celebrations and practices. The Nye-yi Pra festival is an annual festival celebrated by the people in the area from September to November.

6.3.3.10 Historical Resources

The area of the proposed development was initially settled by the Akan speaking people with the study area falling under the jurisdiction of the Ahanta tribe. Sekondi-Takoradi, also known as Shama Ahanta East Metropolitan Assembly (SAEMA), like most coastal towns of Ghana, has had a long association with European trade. From the 15th century onwards, the Ahanta area, which covers the Shama and the entire southeastern part of the Western region, was a scene of intense trade with Europeans. The main trade commodity was gold. At the beginning of the 20th century, a wharf was built at Sekondi to mark a significant industrial and commercial leap in the area. The area became known as European Town. A new and modern harbor was built at Takoradi in 1928 and it became the most important port in the country until the development of Tema.

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7 Environmental and Social Scoping Assessment

7.1 Overview

The following presents the key findings of potential environmental and social effects identified during the scoping assessment undertaken for the project between June and October 2014. This information has been provided to meet the Ghana EIA “scoping” requirements. Key environmental and social effects identified are described alongside proposed further assessment and mitigation measures.

A public and statutory consultation for the scoping phase will take place on the 20 November 2014. Following this consultation period the following assessment will be updated to accommodate relevant findings of the consultation activities.

7.2 Onshore Power Plants and Pipeline

7.2.1 Air

7.2.1.1 Construction

The most significant issues that could potentially impact on ambient air quality (and climate) during construction are combustion gas emissions and nuisance dust.

The principal sources of combustion gases are the exhausts of vehicles and construction equipment, power generation at the work camps and storage yards and waste incineration (if used).

A small amount of combustion gases could be released as a result of power requirements during testing units.

There may be some venting of small amounts of VOCs, during testing and commissioning of the pipelines and facilities.

Dust will be generated as a result of vehicle movements and typical construction activities (e.g. stripping, compacting and trenching). Dust suppression measures should be implemented during construction to minimize dust production.

Due to the nature of the construction process, emissions will not be constant and will fluctuate according to the operating periods for each item of plant and the combination of machinery being used at any one time. The location of emission sources will also change as the construction progresses.

7.2.1.2 Operation

Natural gas is the cleanest of all the fossil fuels and is composed primarily of methane, from which the main products of the combustion are CO2 and water vapour and some NOx. In comparison emissions from coal and oil contain higher nitrogen and sulphur oxides contents.

Based on combustion of gas the key pollutants considered within the assessment of the operational phase are likely to be NOx and CO. Some additional emissions will occur from the use of LCO in Phases 1 and 2 for one month a year, as currently proposed.

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Air quality in the Takoradi area is already believed to be impacted by operation of the existing TTPP plants. There is a risk that operational emissions from the existing power plants and other proposed power developments will result in an exceedance of national and international ambient air quality limits due to cumulative impacts.

7.2.1.3 Assessment, Management and Mitigation

Atmospheric emissions of pollutants have the potential to cause detrimental effects to human and ecological receptors. For a Project of this nature a robust assessment of air quality emissions and subsequent effects on ambient air quality will form an essential part of the ESIA process.

The projected impacts on local air quality will be modelled using internationally recognised dispersion modelling techniques to demonstrate all relevant air quality objectives and limit values will be met. Stack height determination will be undertaken taking into account the findings of the dispersion model.

If modelling predicts that limits will be exceeded, mitigation measures will be identified, for example increased stack height and/or by controlling the emission at the source, e.g. ensuring the installation of dry low NOx (DLN) burners.

Continuous Emissions Monitoring Systems (CEMS) monitors will be installed to monitor emissions of NOx, CO, and CO2, flow rate and temperature of the operational power plants.

Monitoring and emissions data will be used to predict GHG emissions from the facility and operational reporting of GHG emissions (in line with IFC Performance Standard 2 requirements) will form an action in the ESMP.

See Section 8.12.4 for a detailed methodology for the air quality assessment proposed for the ESIA.

7.2.2 Noise


Due to the nature of the construction process, noise levels will fluctuate in line with operating periods for each item of plant and with the combination of machinery being used at any one time. Noise levels will also vary depending on time, and distance as the construction progresses, particularly along linear infrastructure i.e. the pipeline. Construction works may generate high noise levels i.e. above 70 dB LAeq. Construction traffic on the heavy haul road is also likely to generate impacts to residential receptors. Potential noise impacts to humans include sleep disturbance, an increased incidence of social and behavioural problems (including annoyance and increased aggressive behaviour) and in extreme cases, hearing impairment. Construction works at water edge and sub-sea may result in disturbance to marine ecology in this area.

7.2.2.2 Operation

During operation the main sources of noise will be: boilers, steam and gas turbines, large pumps and fans (including inlets, outlets and stacks), cooling system and transformers.

The key issue for environmental noise from the power plants is the potential for cumulative effects from multiple projects at residential receptors. There is a risk that cumulative impacts with T1-3

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and other proposed projects identified by the EPA will result in noise levels above EPA and IFC limits.


The ESIA will include a robust noise modelling assessment which should consider cumulative sources from both existing plants and planned projects identified by EPA as requiring cumulative assessment in order to determine the true likelihood of potential impacts.

The power plants will be designed to meet a maximum of 80dBA one metre from the source in line with international requirements. Acoustic cladding incorporated into the CCGT housing building (including ducting) should guarantee that the noise generated is within international design parameters. Mitigation measures for operation noise may also be considered in design depending upon modelling results. The following are examples of possible noise mitigation measures:

• Physical barriers (e.g., machine housing, enclosures and walls), except for relieving devices;

• Relief silencers designed to lower the noise of safety valve vents;

• Buildings or enclosures, including sound-insulating materials, installed on large compressor packages; and

• Anti-surge valves and control valves (with special trim inside the valves), discharge silencers, flow straighteners, and specially designed valve casing.

See Section 8.12.4 for a detailed methodology for the noise modelling and assessment proposed for the ESIA.

7.2.3 Water


Typical impacts to surface and groundwater during construction activities include the generation of sediment laden runoff, alteration of the hydrological flows of watercourses and the mobilisation or release of contaminants to watercourses and / or groundwater.

Spills during construction (and operation) could impact on groundwater and potentially pollute wells used for potable water supply. Additionally, construction activities can result in saline intrusion during groundwater dewatering / abstraction for construction uses. Similarly spills into, or in the direct vicinity of, surface water features will result in the pollution of these receptors as could storm water runoff from area of land where contamination has occurred.

Blasting (if required) could cause increased turbidity in groundwater near the blast area (however, these impacts should be short-term and localised).

There could be increases in suspended solids in the water column in the vicinity of pilling activities, dredging and construction vessels. This could also impact on the marine environment. Section 7.2.5 discusses impacts to marine environments.

Hydrostatic testing of storage tanks and pipelines could require the use of sizeable quantities of water and discharge of the effluent. Chemical additives may be added to the water to prevent

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internal corrosion and which may be present as potential contaminants in the effluent released to the environment.

7.2.3.2 Operation

Operation of the plant and FSRU will water use for process (e.g. refrigerant within air-cooling and combustion NOx control) requiring both an abstraction from the environment and the generation and discharge of effluent from the facilities.

Abstraction from surface waters and groundwater are not considered to be viable and therefore it is proposed to abstract water from the marine environment. Given its relatively small volume, the impact of this abstraction on the marine environment is likely to be minimal although impacts on aquatic ecology from entrapment of the screen will need to be considered (see Section 7.2.5).

An alternative water supply option is the use of the municipal network. There is however a risk that the water requirements for the proposed development may impact local water resources, users of the resource and/or users of the municipal network if this is ultimately capable of supplying the Project.

The discharge of process effluent will occur into either the marine environment or the wetland or river system and could cause water quality problems. The nature of potential problems varies widely depending on the type of fuel used, the abatement technique applied, cooling technique and associated water use and the chemical and biological treatment reagent added for cleaning and maintenance purposes. All effluent discharges will however be treated to international standards prior to release and as such no significant adverse water quality impacts from pollutants are anticipated.

The discharged water will however be ‘fresh’ as the abstracted water will be desalinised prior to use. If this freshwater effluent is discharged to the sea it could have an impact on coastal and marine communities and hence also on fisheries and sensitive habitats, especially mangroves that can be affected by changes in saline/freshwater flows. Dilution of this will however be significant and as such impacts are unlikely to be significant.

Storm water runoff from the site is likely to be directed into the storm water network for the power enclave and ultimately either into the wetland or to sea, dependent upon plans by VRA. Accidental releases / spills on or adjacent to the development could therefore enter watercourses and would pose community health and safety risks and threats to sensitive ecosystems, in particular for those facilities that will be operating on or next to the river (and sea).


Construction phase impacts on the local water environment will largely be controlled through the application of good construction methodology including consideration of drainage on the construction site and appropriate control and storage or potential pollutants such as fuels or cementitous material used in the construction process.

There are a number of potential options for water supply which have already been considered by the project engineers. As already highlighted, it is considered unlikely that groundwater will not be used, due to limited availability within the aquifer.

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The confirmed outcome from the water supply options assessment will be highlighted in the ESIA. If there is the potential for significant impacts, these impacts would be assessed as part of the appropriate chapter within the ESIA.

The power plant will be air cooled and so will not require significant quantities of water in comparison with hybrid or once through cooling systems. It will also not require significant water take and discharge infrastructure, minimising potential impacts compared with substantial water take structures such as those currently under construction for the T1/2 once-through cooling system.

Plume modelling will be undertaken to determine impacts of process water discharges from the power plant once operational and confirm compliance with the EPA and IFC effluent discharge limits.

See Section 8.12.4 for a detailed methodology for the wastewater modelling and assessment proposed for the ESIA.

7.2.4 Terrestrial Ecology

7.2.4.1 Construction and Operation

The main project site has been identified as likely “modified9” wetland site forming part of the Anankwari river lagoon estuarine wetland system. An initial ecological walkover of the project site undertaken in October 2014, concluded that the proposed Project site is generally poor in flora and fauna diversity. It has mainly grassland and thicket vegetation that is seasonally flooded, but also includes an area of degraded mangroves adjoining the Anankwari river. The project area has diverse types of habitat that may provide safe haven for wildlife species possibly including species of conservation interest. No endangered species of flora or fauna were encountered in the project area during the walkover. Accordingly, it is considered unlikely that the wetland would meet the IFC definition of ‘natural10 or critical habitat11’.

The proposed Project will not have any significant adverse impact on the sandy beach since the vegetation along the beach is already poorly developed and only a small width of beach will be impacted by the infrastructure associated with the gas and water supply pipelines. The coconut plantations and strand vegetation occupying the dunes have no conservation concern.

Previous environmental impact assessments reviewed as part of the desk study have reported sightings and records of a number of mammals in the area, including some small antelope (e.g., duikers). The sewage lagoons in particular were observed to contain/support a variety of wildlife including frogs, fish, pied kingfishers, species of cormorant, geese and coots, as well as aquatic

9 Modified habitats are areas that may contain a large proportion of plant and/or animal species of non-native origin, and/or where human activity

has substantially modified an area’s primary ecological functions and species composition. Modified habitats may include areas managed for agriculture, forest plantations, reclaimed coastal zones, and reclaimed wetlands.

10 Natural habitats are areas composed of viable assemblages of plant and/or animal species of largely native origin, and/or where human activity has not essentially modified an area’s primary ecological functions and species composition

11 Critical habitats are areas with high biodiversity value, including (i) habitat of significant importance to Critically Endangered and/or

Endangered11 species; (ii) habitat of significant importance to endemic and/or restricted-range species; (iii) habitat supporting globally significant concentrations of migratory species and/or congregatory species; (iv) highly threatened and/or unique ecosystems; and/or (v) areas associated with key evolutionary processes.

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insects. It is also considered that the area is a suitable habitat for snakes, including puff adders, cobra, and green mambas.

Although no endangered species of flora or fauna was encountered during the walkover, reports from some members of nearby communities indicated the presence of some species that are listed on the IUCN list of endangered species as “Vulnerable” and “Endangered”.

Previous EIAs for the area indicate the lagoon is a semi-closed lagoon with estuarine wetlands fed by perennial streams and rivers. This habitat and its associated flora and fauna will be directly and irreversibly impacted by the construction of the power plants and associated infrastructure.

The site is been used for agricultural purposes with some evidence of residential settlements and as such has been altered from its natural state by human activity. Additionally, the existing power plants are constructed on part of the original wetland site. The cumulative impact of construction of several new large infrastructure projects is likely to significantly alter the wetlands hydrological system.

Habitat not directly affected by the development may be indirectly affected by contamination from construction or risk of accidental spills / runoff during operation.


One wet season and (if required) one dry season terrestrial surveys will be carried out for the ESIA in order to determine the baseline sensitivity and importance of the wetland.

Depending upon the sensitivity and scale/significance of the impacts, mitigation measures will be considered by the project and discussed with statutory stakeholders and the lenders.

Standard design mitigation will address drainage / contamination risks to wetland/river system.

The ecology assessment undertaken will also address the requirements of IFC performance standard 6 in relation to ecosystem services.

See Section 8.12.4 for a detailed methodology for the terrestrial ecological surveys and assessment proposed for the ESIA.

7.2.5 Marine Ecology


Marine ecology would be impacted primarily from the construction of the breakwater, dredging of the turning circle and pipeline route, and construction of the section of pipeline crossing the beach (and impacts on sea turtles).

Fish and fish spawning and breeding areas could be impacted during construction (and operation). Construction activity has the potential to cause physical disturbance to fish principally as a result of dredging in general and possibly underwater noise / vibration associated with piling. The displacement of fish due to dredging is likely to be a temporary impact. However, because dredging will permanently alter the character of the area and turning basin (FSRU), it is possible that the species composition of any fish that return to the area will change. Installation of marine pipelines may also have disturbance effects, but as described above, these should be relatively localized and temporary. Dredging vessel operations will generate underwater noise that may temporarily

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displace fish. Experience from dredging activities worldwide suggests that temporary dredging noise is not a significant impact.

Initial findings indicate that the benthic environment and ecology in this area is unlikely to be sensitive to dredging and significant impacts are not anticipated. However, dredging techniques will still aim to minimise potential seafloor impacts. Disposal of potential contamination within dredged sediments is discussed under the waste management assessment.

Marine mammal populations (whales, dolphins) are known to be present along the Ghana coast, although no sightings were observed within the Takoradi area in previous EIA studies. Previous studies also indicated no sea turtle nesting sites in the Takoradi area. Sherbro bank (1.5km) and Roani Bank (4km) are important sites for fish and benthic communities but the pipeline route should avoid these areas.

Sardinella fisheries (c. 15km off shore) is one of the major commercial fisheries in Ghana, running along the coast for >100km. Whilst the potential offshore FSRU infrastructure will not be located that far out, the pipeline to shore is likely to require fisheries exclusion zone (WAGP has ~ 3km exclusion corridor) which may impact upon fisheries. Given regulatory tightening in recent years, local fisheries may be sensitive to further fishing exclusion zones and early consultation will be required to understand and address the needs of fishermen. It is also noted, however, that exclusion zones can in some areas result in the recovery of fish stocks.

7.2.5.2 Operation

Similar impacts are anticipated as for construction associated with ongoing dredging of turning circle.

Entrapment and impingement of fish and other organisms could occur during intake of water for hydrostatic testing and process water.

Operational elements of the FSRU aside from the fisheries exclusion may also impact fisheries as poorly designed lighting can attract fish leading either to lesser fish resources outside of the exclusion zones and/or the potential for artisanal fishermen to encroach within the exclusion zone, creating a security risk.


The ESIA will include assessment of impacts to the marine environment and fisheries from the project. This assessment will include:

• Potential for impacts on subsistence fishing;

• Consultation with fishing communities;

• Assessment of sensitivity of the marine environment;

• Plume modelling for discharges to the marine environment (see 7.2.3 above);

• A survey for nesting turtles, impact assessment and mitigation measures, such as intake design to prevent turtle entrainment (if required);

• Standard mitigation design regarding run off measures;

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• Treatment of effluent to meet the more stringent of EPA and IFC effluent emission limits (see Water above); and,

The ecology assessment undertaken will also address the requirements of IFC performance standard 6 in relation to ecosystem services.

See Section 8.12.4 for a detailed methodology for the marine ecological surveys and assessment proposed for the ESIA.

7.2.6 Flood Risk


Construction of the new plants for this and other proposed power projects will remove large areas of wetland and impact the local flood catchment area.

Construction of the new plants for this and other proposed power projects will remove large areas of wetland which are believed to currently act as floodplain and this will change how flood water can be conveyed or stored in these areas.

Parts of the site are clearly vulnerable to flooding and as such if the proposed facility is built at current levels it is likely that it will be susceptible to inundation. If ground levels at the site are raised to protect it from flooding this could however exacerbate flood risk in other low lying areas potentially resulting in farmland or properties locally being flooded more frequently and or more severely than currently occurs, e.g. existing problems associated with the drainage design of T1/2 could be exacerbated.

In addition climate change related changes in sea level and or rainfall/run-off could alter the flood regime locally further.


A flood risk assessment (FRA) will be undertaken as part of the ESIA. This assessment will need to consider the likely mechanisms for flooding locally (i.e. is it tidal or fluvial dominated) and in particular determine how the presence and operation of the reservoir upstream has impacted this as areas of apparent floodplain may no longer be active given the change in river hydrology.

Depending upon results of the FRA, residential areas upstream may need to be surveyed for elevation to determine their risk of flooding and ascertain whether the changes likely to arise as a result of the development proposals will alter this significantly

Outputs from the FRA will include recommended finished floor levels for key site infrastructure. In the event that the assessment indicates that significant adverse flood impacts to local residential areas are likely flood response / mitigation measures may need to be considered by the project.

The FRA will consider the potential for cumulative effects for other planned plants, and any relevant outputs from the climate change impact assessment.

See Section 8.12.4 for a detailed methodology FRA proposed for the ESIA.

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7.2.7 Social

7.2.7.1 Resettlement

Construction and Operation

Physical displacement of residential communities (with or without legal entitlement) or economic displacement from key activities such as fishing or farming, as a result of the development and associated infrastructure can plunge households into poverty and / or dislocate communities severing extended support networks such as childcare. If not mitigated appropriately and early, resettlement impacts can cause great controversy and result in significant public objections, time delays and considerable cost overruns for the project.

During the ESIA process it will be determined whether these settlements will need to be resettled as part of the proposed project. If located on land impacted by the project, the people and houses will need to be relocated to make way for the project and new land or alternative means of subsidence or livelihood generating activities may be required.

Assessment, Management and Mitigation

Baseline socio-economic surveys will be undertaken as part of the ESIA to confirm potential for residence and farming or other economic activity sites on the One Energy land and provide a cut-off date against opportunistic settlers moving into the area.

VRA has indicated it will relocate / compensate any residents living on or working the land and provide a cleared site. However, if resettlement is required and undertaken by VRA, One Energy will engage with VRA as early as possible in this process to influence the scope of the resettlement action plan (RAP) in line with the IFC requirements.

The RAP (if required) will be developed in consultation with affected communities and as well as providing alternative housing and / or cash compensation, livelihood restoration measures must be provided for those considered to be severely affected and or vulnerable. The ESIA team will review the RAP proposed by VRA against Ghana and international standards, confirm if any gaps are present and, if so, provide recommendations for steps to address these gaps.

See Section 8.12.4 for a detailed for social impact assessment.

7.2.7.2 Labour and Working Conditions

Construction and Operation

It will be necessary for the EPC Contractor and project parties to ensure appropriate labour and working conditions and facilities are in place for their workforce. These conditions will need to meet national and international requirements.


The ESIA will provide recommendations for compliance with international requirements under IFC Performance Standard 2. This will include for example recommendations for the project on implementation of appropriate grievance mechanisms and standards for workers accommodation.

See Section 8.12.4 for a detailed for social impact assessment methodology on Labour and Working Conditions.

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7.2.7.3 Community, Health, Safety and Security

Construction

The impact of employment created during construction is considered a positive effect from the project. However, the majority of employment during construction is likely to be relatively short-term and significant employment opportunities for local communities may be limited due to the low levels of education, skills and limited experience and training opportunities that the local people have. This can result in a large percentage of skilled and semi-skilled workforce being sourced on a temporary or permanent basis from outside of the local community. At this stage in the project development, the origin of these workers is unknown.

There will be the potential for increased road traffic accidents from increased construction traffic.

During construction, non-local employees are typically employed on a ‘single’ basis, they will not come with their families. Often they can be housed close to the construction sites in purpose built accommodation.

Coinciding with the influx of migrant workers is typically a raise in demand for goods and services during the construction period which can result in a rapid expansion in supply chain businesses operating in the area. This will result in increases in formal employment and informal labour. This expansion may result in migration into the area.

The impacts that may arise from the presence of migrant and/or expatriate employees are largely comprised of:

• Inappropriate behaviour and lack of respect for local leadership and cultural norms on the part of expatriate workers;

• Conflict resulting in part from resentment by skilled nationals and local residents if they perceive that expatriates have been hired into jobs for which they are suitably qualified;

• Spread of transmissible diseases including HIV/AIDS both within the workforce and between the workforce and the local community;

• Resentment of non-local nationals by local residents if they are perceived to have taken jobs that could be successfully filled by local people, or due to non-integration with the local community; and

• Increased local demand for consumer goods and housing with resulting encouragement for improved supply resulting in financial hardship and benefits for local people; and,

• Increased pressure on infrastructure, services (such as healthcare) and roads, particularly with the establishment of informal settlements.

• The ESMP will include a requirement for an management plan to address the above issues.

Operation

During operation the impacts are considered largely positive. The project will provide a good source of long term primary and secondary employment and economic growth for the area.

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The socio-economic assessment will consider potential impacts to the community, health, safety and security from the project.

Initiatives to encourage local recruitment and training will be considered within the ESIA.

Community, health, safety and security will be considered in environmental and social management plans developed for the project.

Consultation will take place with community members.

Information about the project will be disclosed and grievance mechanisms developed and implemented for the benefit of the local community.

Section 8.12.4 presents a detailed methodology for social impact assessment.

7.2.8 Solid Wastes


Wastes will be generated during construction (and operation) of both the on and offshore infrastructure. The majority of these wastes will be inert. However, some hazardous materials will be generated and these will need to be disposed of with appropriately licensed facilities if these are identified locally.

Dredged or excavated materials may contain contaminated materials and appropriate dredge disposal sites will need to be located.

If wastes are disposed of illegally, pollution from waste has the potential to cause human health impacts through contamination of surface waters and ground waters (drinking water) with implications for fisheries and human consumption.

It is understood that there are operational engineered landfills in Ghana that are licenced to receive inert waste. However, it is not clear if there are licenced hazardous waste facilities and, even if so, what level of confidence could be placed in the design and management of such facilities.

7.2.8.2 Operation

As for construction; however, less waste will be generated throughout the operation of the facility. Some of this waste will be hazardous and will require careful disposal. The Waste Management Plan (WMP) that will be prepared as an ESMP action will define ultimate disposal routes for hazardous wastes.


All disposal of waste will require adequate temporary storage on site and disposal to approved authorised waste contractors.

Wastes can be suitably managed with the implementation of a waste management plan and standard mitigation options (such as hierarchy of reuse, recycling, and disposal) for waste management will be provided by the ESIA waste assessment.

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The ESIA will determine the nature of available waste management facilities, in particular hazardous waste facilities.

Dredged materials may contain contaminated materials. Potential contamination of material will need to be established prior to dredging. If contamination is present, this should be neutralised. Disposal sites need to be identified and used according to best practice.

If there are no appropriate management facilities in Ghana, either a project specific solution will need to be designed/approved locally, or any hazardous waste will require export from the site to the nearest appropriate facility which may potentially be as far as South Africa or Europe.

7.2.9 Traffic and Transport


Observations from the Jacobs Consultancy’s site visits indicate that the roads from Takoradi-Sekondi to the site are in good condition. Road works are underway between Takoradi and Inchuaban, which will improve the road conditions. Given that several plants have been constructed in the area, it is anticipated that significant road improvements will not be required. However, the construction phase will require a temporary increase in traffic travelling to and from the site due to the delivery of construction materials and the movement of construction workers. Heavy goods vehicles, large construction equipment (e.g. earth movers and cranes) and some abnormal loads will also be mobilised to the site.

7.2.9.2 Operation

There may be some alterations in the existing road traffic movements associated with the operational project. However, these impacts will be considerable less than during construction.


The ESIA will include desk based assessment of the existing capacity of the roads, ability to accommodate wide / heavy loads and give preferences for routing. A traffic management plan may need to be developed. Depending on the sensitivity of the area surrounding chosen transport routes, movements of construction vehicles may be restricted to daylight hours.

The socio-economic assessment will discuss potential impacts to local communities from the increased traffic movements.

7.2.10 Land Quality


Contamination of ground and groundwater at the development site may be present as a consequence of past releases and neighbouring power plants. However, as the site is a greenfield development, these risks are considered low.

Possible sources of contamination associated with construction work may include spills, leaks, failure of tanks or pipelines or deliberate discharges. Substances may include raw materials, fluids, intermediate produces, wastes and effluents.

Dredged material may contain contaminants– see Solid Wastes above.

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7.2.10.2 Operation

There are potential impacts to land quality from the operation of the facility as a consequence of the presence of contaminative substances and the possibility of minor or major uncontrolled releases.


The design of the facility to good practice standards will aim to prevent such releases and minimise the potential consequences such that any effects should be insignificant. However, consideration within the ESIA is likely to be required to demonstrate that adequate control and mitigation measures are included in the development scheme.

Relevant management, remediation (if required) and mitigation for identified contamination will be included within the ESIA.

Dredged material – see Solid Wastes above on Onshore.

7.2.11 Climate Change


The site will be constructed on land that is at or within 5m of sea level. There is a risk that effects of climate change may include sea level rise and/or increase in wet season rainfall which could impact on the development.

A rise in average ambient air temperature would adversely affect the efficiency of the turbines, albeit not significantly.


A climate change impact assessment will be undertaken as part of the ESIA to ensure that adaptation measures are include in the design as necessary.

Mitigation may take the form of an increase in the finished floor levels of the plant and access roads, or recommendations for increased storm water drainage design capacity.

7.2.12 Cultural Heritage


Construction activities and land take has the potential to impact on areas of cultural heritage. However, previous studies for the area have not identified any areas of cultural interest within the project area.

7.2.12.2 Operation

The general impacts are the same as for construction. Once built, it is unlikely that operation of the facility would impact on any areas of cultural interest.


No further assessment is proposed as no heritage features have been identified during the development of T1 and T2 or during site walk overs for this scoping assessment. However, if

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during the course of the ESIA evidence of cultural heritage impacts are identified appropriate assessment, management and mitigation measures will be developed.

7.2.13 Cumulative Impacts


Cumulative impacts may result from both onshore and offshore facilities. Cumulative impacts with existing and planned facilities may occur during construction and operation.

An indicative list of potential projects in the vicinity of the proposed site is presented in Section 6. EPA has confirmed12 that four of these projects are already progressing in their applications and environmental assessments and should therefore be considered for cumulative impacts by the One Energy ESIA. These are listed in the following table, taken from the EPA letter:

Potential Project Known Design Details Current Status / Additional Info

Amandi 239MW combined cycle LCO. Potentially with seawater cooling.

Permit issued 23 July 2014

Jacobsen 360MW gas turbines (possibly 3 x 9E) Permit issued 23 April 2014

ASG 200MW (possibly 191MW). A second possible ASG site is mentioned in the ECG document.

Scoping phase

Astropower 200MW - Greek plant to be rebuilt in Ghana.

Scoping phase

Cumulative impacts from operation of project will need to be considered in relation to the existing and the above proposed developments.


The ESIA will consider cumulative impact assessment of the project against current and future planned projects confirmed as within the permitting process. If cumulative impacts are identified, appropriate management and mitigation measures will be identified during the ESIA process. Further discussion on cumulative impacts is given in individual topics above.

7.2.14 Trans-boundary


It is considered unlikely that trans-boundary issues will result during construction of the onshore facilities given the distance to neighbouring countries.

12 EPA letter “Follow up to meeting held between EPA and Ghana 1000 Project Team”, 28/10/14.

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No trans-boundary impacts have been identified to date for the onshore project components as such no further assessment is proposed.

7.3 Offshore Components

7.3.1 Air


The general impacts are the same as for Section 7.2.1. However, the FSRU will be constructed in the shipyard of a third party outside of Ghana as such local impacts to the air quality of this part of the Project will be negligible.

7.3.1.2 Operation

The most significant sources of air pollutants from the offshore operations include combustion emissions from ships’ propulsion and auxiliary engines and boilers, mainly consisting of SO2, NOX, greenhouse gases (e.g. CO2 and CO, fine particulate matter and VOC, followed by combustion source emissions from vehicles and land-based engines and boilers contributing similar pollutants.

LNG facilities include combustion sources for power and heat generation (e.g. for dehydration and liquefaction activities, and re-gasification), in addition to the use of compressors, pumps, and reciprocating engines (e.g. boilers, turbines, and other engines).

Emissions resulting from flaring and other fugitive emission sources may result from both LNG liquefaction and re-gasification.

Venting (flaring) is an important safety measure used at LNG facilities to ensure gas is safely disposed of in the event of an emergency, power or equipment failure, or other plant upset condition.

Stored LNG emits methane gas vapour, known as ‘boil off gas’ (BOG), due to heat from ambient conditions and tank pumps, in addition to barometric pressure changes.

LNG spilled directly onto a warm surface (such as water13) could result in a sudden phase change known as a Rapid Phase Transition (RPT)14.


As for Section 7.2.1 above, air quality assessment will determine the potential impacts associated with the FSRU operation. Maintaining emissions of NOx and SO2 within the limits established by international regulations15.

13 LNG vaporizes rapidly when exposed to ambient heat sources such as water, producing approximately 600 standard cubic meters of natural

gas for each cubic meter of liquid. 14 A potentially significant environmental and safety hazard from LNG shipping is related to Rapid Phase Transition (RPT) that can occur when

LNG is accidentally spilled onto water at a very fast rate. The heat transfer from water to spilled LNG causes LNG to instantly convert from its liquid phase to its gaseous phase. The large amount of energy released during a RPT can cause a physical explosion with no combustion or chemical reaction. The hazard potential of rapid phase transitions can be severe, but is generally localized within the spill area.

15 NOx and SOx emissions from ships are regulated under Annex VI, Chapter III, Regulation 13 and 14 of the International Convention for the Prevention of Pollution from Ships (MARPOL 73/78).

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VOC emissions from fuel storage and transfer activities should be minimized by means of equipment selection, such as the use of floating top storage tanks or vapour recovery systems for fuel storage, loading / offloading, and fuelling activities (depending on the type of material to be stored), and adoption of management practices such as limiting or eliminating loading / unloading during poor air quality episodes or implementing tank and piping leak detection and repair programs.

Flaring should be used only in emergency or plant upset conditions.

Continuous venting of BOG should not occur. Methods for management BOG will be identified by the project. For re-gasification facilities the collected vapours are typically returned to the process system to be used as a fuel on-site or compressed and placed into the sales stream / pipeline.

Spills / leaks from the FSRU are considered unlikely and the latest technology and safety systems will be utilised during operation to prevent such incidents. Emergency response and preparedness plans will also be developed by the project to management impacts.

7.3.2 Water


As for Section 7.2.3.

7.3.2.2 Operation

As for Section 7.2.3. There is potential for surface water contamination from leaks or spills from other substances used during construction and operation of the terminal e.g. oils and chemicals.

Accidental or intentional releases of fuel, or waste water from vessels to the marine environment resulting in degraded water quality in the surrounding environment. Although accidental pollution unlikely pollution from operational vessel activities is a major threat. Discharges from vessels also include other forms of pollution such as air pollution, chemicals, harmful substances carried in packaged form, sewage and waste products.

Temperature discharges of water for process cooling at facilities and for example in re-vaporisation heating of LNG may result in water use and discharge streams and the intake of cooling water. Discharge of the cooling water would alter the ambient water temperature at the discharge location. Temperature changes can impact on sensitive marine environments.


As for Section 7.2.3. Strict pollution control measures in line with MARPOL requirements will be set up for the project, including management of effluent, liquid and solid waste from the FSRU.

7.3.3 Solid Wastes


Impacts are considered to reflect those indicated in Section 7.2.8.

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7.3.3.2 Operation

Non-hazardous and hazardous wastes routinely generated at LNG facilities include general office and packaging wastes, waste oils, oil contaminated rags, hydraulic fluids, used batteries, empty paint cans, waste chemicals and used chemical containers, used filters, spent sweetening and dehydration media (e.g. molecular sieves) and oily sludge from oil water separators, spent amine from acid gas removal units, scrap metals, and medical waste, among others.


The provision of waste reception facilities for the FSRU should be developed in coordination with the national governments according to their commitments to the MARPOL.

All disposal of waste will require adequate temporary storage on site and disposal to approved authorised waste contractors.

Wastes can be suitably managed with the implementation of a waste management plan and standard mitigation options (such as hierarchy of reuse, recycling, and disposal) for waste management will be provided by the ESIA waste assessment.

The ESIA will determine the nature of available waste management facilities, in particular hazardous waste facilities.

7.3.4 Traffic and Transport


There will be an increase in marine vessels within the construction area. During operation there will be a number of LNG vessels coming to the area of the FSRU. These vessel movements could impact on existing vessel movements and fishing fleets.



7.3.5 Land Quality


Dredged materials may contain contaminated materials. See wastes above in 7.2.8


Potential contamination of material will need to be established prior to dredging. If contamination is present, this should be neutralised. Disposal sites need to be identified and used according to best practice. See wastes above in 7.2.8.

7.3.6 Social - Community, Health, Safety and Security


As for Section 7.2.7. However, there may be disturbance during construction periods to marine vessels and fishing activities.

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7.3.6.2 Operation

As for Section 7.2.7. However, exclusions zones will be put in place around offshore project facilities. These could impact fishing activities and existing vessel movements.



7.3.7 Cumulative


The FSRU will be constructed in a third party ship yard and sailed to the mooring location, minimizing cumulative impacts from its construction. There may be some cumulative impacts from the construction of the sub-sea pipeline, breakwater and jetty, if other sub-sea infrastructure is being constructed within similar timescales, though it is anticipated that the current construction will have completed by then.

7.3.7.2 Operation

There are a number of industrial emissions associated with the operation of an LNG FSRU. These impacts include, noise, air pollution, water discharges etc.


The ESIA will consider the cumulative impact of the FSRU and offshore infrastructure with existing or other proposed industrial developments in the area. Additionally, the socio-economic assessment will give consideration will be given to the potential LNG source opening up a pathway for further industrial / power development within the area and what the impacts of this may be on for example, local communities. Management and mitigation measures will be identified within the ESIA if impacts are identified.

7.3.8 Trans-boundary


Trans-boundary impacts from construction activities are considered unlikely.

7.3.8.2 Operation

Trans-boundary impacts could occur from the operation of the FSRU and the third party vessels required for the FSRU operation.


The ESIA will consider the potential for trans-boundary impacts from the operation of the FSRU. However, the potential trans-boundary impacts associated with the operation of the FSRU will be managed through compliance of the operation with international conventions such as MARPOL.

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7.3.9 Other Potential Offshore Effects

The following assessments will be as described for the onshore components:

• Noise;

• Marine Ecology / Fisheries;

• Climate change; and

• Social – labour and working conditions.

The following aspects are not considered applicable to the offshore components of the project:

• Terrestrial ecology;

• Flood risk;

• Social – resettlement; and

• Archaeology and cultural heritage.

7.4 Summary of Key Findings from the Scoping Assessment

Following the scoping assessment and consultation activities undertaken to date, it is considered that the following detailed assessments will be required for the ESIA:

• Air quality;

• Carbon / Greenhouse Gas Emissions;

• Noise;

• Wastewater;

• Marine ecology;

• Terrestrial ecology;

• Flood risk; and

• Social impact assessment

Detailed impact assessment methodologies for the above are presented in Section 8 below. Cumulative impact assessment will be incorporated into the topics above as relevant.

The following assessments will also be considered within the ESIA but in qualitative terms as the impacts are considered less significant:

• Solid waste management;

• Traffic and transport;

• Land quality, soils and groundwater;

• Landscape and visual impact;

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• Climate change; and

• Trans-boundary impacts.

Further discussion on the assessments proposed for the above points is given in Section 8.

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8 EIA Terms of Reference

8.1 Overview

In line with the Environmental Assessment Regulation 1999, the following provides the terms of reference (ToR) for the ESIA. The ToR lays out the approach to the EIA and specific methodologies for those areas where we have identified a need for further assessment within the scoping exercise.

8.2 EIA Table of Contents

The layout of the EIS report will typically include separately bound volumes, these being as follows:

• Volume I: Non-technical summary;

• Volume II: ESIA main body including EMPs; and

• Volume III: Technical appendices.

The EIS report, as contained in Volume II, would, as a minimum, contain the following sections:

• Executive summary – brief summary.

• Project description.

• Determining the need for the Project.

• Policy, legal and administrative framework.

• Analysis of alternatives, including site selection discussion.

• Consultation and disclosure.

• Description of the baseline environment

• Impact Assessment and Evaluation of Significance

• Mitigation measures.

• EMP.

• Conclusions.

• Appendices.

8.3 Project Description

The project description includes relevant information about the project such as location, planned development schedule, construction activities and methods, process description, operational use of raw materials, ancillary facilities, dedicated infrastructure and operational releases. The project description describes the existing environment of the project and its surroundings. It includes statements of significance in terms of the environmental noise, air, water quality, marine environments as well as describing any influencing factors such as planned or proposed new developments which could affect this project during the construction or operational phases. The

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project description also includes detail on the construction programme, timing and sequencing. It elaborates on the phasing of developments and the implications of the phasing of the works and describes relevant facilities to be provided such as internal infrastructure of local roads, drains, sewers etc. to give background information.

8.4 Determining the need for the Project

The ESIA will include a discussion of project needs and justification taking into consideration, environmental, social, economic aspects from a regional, national and local level.

8.5 Policy, legal and administrative framework

The ESIA report contains a detailed description of the policy, legal and administrative framework in which the project is to be developed, both in terms of national environmental assessment requirements and international guidelines. National and local land use and development planning aspects are also described, as well as applicable environmental limits and standards. Relevant emissions, discharge limits, and environmental standards will be included, comparing Project design/guarantee levels against regulatory and guideline standards.

8.6 Analysis of alternatives

Good practice within ESIA necessitates, as part of the early concept and feasibility development stages, a comprehensive analysis of alternative options, geared to the prevention and minimisation of adverse environmental and socio-economic effects and the enhancement of beneficial effects, within an overall context of economic and technical project viability. The technical, economic and environmental analysis will consider different options to show that the project design represents an overall optimum. This section will include a “without project” scenario in terms of the environmental impacts.

8.7 Environmental and Social Baseline

The ESIA will include a baseline environmental and social report that will provide a complete characterisation of the environmental and social baseline conditions within the study areas, to the extent necessary to adequately evaluate all potential impacts associated with ‘project’. This will form the basis for setting guidelines in the assessment framework. The topics within the baseline environmental report will be identified and discussed as follows:

• Physical Environment – geography, geology, hydrogeology, topography, soils, meteorology, potential natural hazards;

• Marine and Terrestrial Biodiversity, fauna and flora – vegetation cover, existing wildlife, rare or endangered species, sensitive habitats, species of commercial importance, nuisance species, pests and vectors;

• Population – noise, urban centres, rural areas, land use;

• Water – hydrology, flood zones, main rivers, groundwater;

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• Air Quality and Greenhouse Gases – qualitative description of existing air quality in the area including energy efficiency and management of greenhouse gases; and

• Social - demographics, community facilities and services, economic environment; employment labour and livelihood issues; resource use land use and natural resources; governance structures, health, education, culture, lifestyle and recreation.

Baseline data will be used to assess the potential impacts of normal operation on the physical, biological and human environment, within the area of influence. The tasks will involve the collection and review of available environmental information via consultation and the use of existing databases, aerial photographs, satellite imagery, documents held by relevant authorities, universities, non-governmental organisations existing reports and the internet.

8.8 Impact assessment and evaluation of significance

It is proposed to employ where possible a quantified approach to defining the ‘project’ impacts. To clearly relate the magnitude of the impact to the sensitivity of the receiving environment for the assessment of significance thus enabling a clear set of definitions to be applied and to ensure the cumulative, trans-boundary impacts arising from non-normal operations and construction, operational and decommissioning impacts are assessed as an integral part of the impact assessment activity. The environmental significance of a range of construction and operational conditions is evaluated based on impacts identified.

Determining the significance of impacts (assessment of effects) identified is one of the main purposes of an ESIA and enables the identification of necessary mitigation and a determination of environmental costs associated with the Project. An environmental or social impact can be either beneficial or adverse and is assessed by comparing the quality of the existing environment with the predicted quality of the environment once the project is in place. The two main factors in determining significance are receptor sensitivity and impact magnitude. A number of criteria can be used to determine whether or not the potential impacts of the project are ‘significant’. In order to assess significance, consideration should be given to the following criteria:

• International and national standards;

• Relationship with planning policy;

• Sensitivity of receiving environment;

• Duration of the impact;

• Spatial extent of the impact;

• Reversibility of effects;

• Likelihood;

• Inter-relationship between effects; and

• The results of consultation.

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Effects considered to be significant would be identified in the ESIA. The significance of impacts reflects judgements as to the importance or sensitivity of the affected receptor(s) and the nature and magnitude of the predicted changes, for example, a large adverse impact on a feature or site of low importance will be of lesser significance than the same impact on a feature or site of high importance.

8.9 Cumulative impacts

A qualitative analysis of cumulative impacts resulting from the construction and operation of the proposed project using the data obtained from the baseline assessment will be undertaken. The cumulative assessment will only consider existing neighbouring developments or those formally within the planning process.

8.10 Mitigation

Where both negative and positive impacts are identified, the ESIA will recommend possible mitigation measures to reduce or eliminate the negative impacts and enhancement measures to increase positive impacts. Each recommended mitigation measure will be described in detail and the possible degree of attenuation identified. The ESIA will also assess whether residual impacts, either beneficial or adverse, remain after mitigation. It will be important to clearly link mitigation measures to significant environmental and social impacts and to ensure they are developed in close consultation with technical contractors to ensure that measures are practical, cost effective and achieve their objectives.

8.11 Non-technical summary

The non-technical summary acts as an easily understandable executive summary of the ESIA report for general use.

8.12 Impact Assessment Methodologies

8.12.1 Overview

The following describes specific impact assessment methodologies for the key impacts identified during the scoping assessment.

8.12.2 Marine Ecological Assessment

Scoping assessment undertaken for the project has identified a number of effects will need to be addressed as part of the marine ecological study as follows:

• Potential impacts on marine mammals, including endangered and vulnerable species that are thought to be present in the local area and known to be present in the wider area;

• Potential impacts on sea turtle species that may nest in the area of works and migrate across the area;

• Potential impacts on fish nursery and spawning grounds; and

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• Loss and disturbance to subtidal benthos (including water quality impacts).

The spatial extent of the marine ecology assessment will relate to the marine subtidal and eulittoral zone.

The baseline review will aim to determine the importance/value and potential sensitivity of marine ecological receptors to impacts in line with IFC guidance. An important factor will be the consideration of the criticality of habitats that may be affected. This will require an understanding of the nature of habitats, the context of these within a local, regional, national and international sense; and the importance of habitats for species present.

The main impacts that will be considered as part of the study for construction and operation, includes:

• Habitat loss and disturbance;

• Underwater noise generation;

• Water quality related impacts; and

• Vessel collision.

Additionally, it has been identified that the project will require a survey with respect to key species to inform the assessment of critical habitat status. It is known that important sea turtle species nest in the wider area, but there is a lack of information of the importance of the local site area about the project site area. The following survey will be undertaken as part of the scope for the marine ecological impact assessment:

• Rapid Sea Turtle Field Verification Survey: coastal nesting beach surveys (where access allows). Time frame: To be completed October - December. Duration 4 days. The preferred timing for the survey is the peak nesting season, which is expected to be November/December. Surveys later in the peak season allow nesting activities from previous months to be recorded where they are visible.

Beaches in the Study Area will be assessed for their potential for nesting and for any signs of actual nesting by turtles. It is expected that access will be achieved by a 4x4 vehicle, but the survey will be carried out on foot. The survey will be carried in the day time only and will focus on the elements identified in the table below. The results of surveys will be primarily used to assess numbers and density of nesting attempts by turtles (if any), and to classify beaches according to their potential for nesting by different species at other times of year.

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Table 8-1: Key Characteristics to be Assessed during Turtle Nesting Beach Survey

Features Key Characteristics

Beach morphology and characteristics • Beach slope • Exposure index • Strandline • Dune height • Grain size and type • Intertidal width

Beach dynamics • Erosion/accretion • Flooding

Beach vegetation and litter • Beach litter • Beach and dune vegetation • Inland landscape and habitat

Nesting habitat/potential • Available beach area for nesting • Human activity • Existing impacts/threats

Evidence of nesting • Tracks • Track width • Nest characteristics • Egg shell • Hatchlings • Evidence of nest predation

Stranded/dead turtles • Species • Stranding state • Carapace measurements • Any other stranded or beach wildlife

The survey will be conducted over an area of 4 km across the immediate site frontage (where sand beach habitat is present). It must be noted that the sand beach frontage of the local town is highly impacted by fishing activities. Therefore this area will only be visited once during the survey to determine its potential value, but detailed walk-over surveys will be avoided in this area – mainly as this beach is likely to be of lower importance and the ability to track emergences will be very complicated due to beach disturbance.

The site frontage will be surveyed on four separate occasions during the survey period. By repeating the survey effort we will get more certainty on the nature of nesting events. Visits to sandy beaches in adjacent areas will be completed wherever time allows. This will provide some context to the site.

A marine mammal survey is not proposed as the nature of the project also means that impacts will likely be addressed through the adoption of robust mitigation and monitoring strategies – following international best practice. The impact assessment will consider wider behavioural effects, but at this stage, identified information indicates the area is not considered to be critical for marine

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mammals and therefore a survey would not add significantly to the understanding of effects. This would be revisited should information to the contrary be identified. Any such survey would also need to be wide-scale as behavioural impacts can occur over large distances. On balance it is considered that the focus should be on short term injurious effects and the approach to be taken by the impact assessment should negate the need for upfront survey. There will be a presumption of presence of species if identified as being potentially located in the study area during the desk-top review, which will promote a precautionary assessment. It is likely that monitoring and survey will be proposed as part of the recommendations for the marine ecological impact assessment. The key issue for the survey will be to understand the importance of the site and wider study area for marine mammals. A short snapshot survey would not provide any robust certainty in this regard. Therefore the impact assessment will consider the presence of marine mammals known to be in the wider area as a factor when considering impacts; and use desk-top data, as far as possible, to inform the determination of the potential value of the Study Area.

A benthic survey is not proposed due to the difficulty of survey using grabbing (especially in rocky areas), diving or drop-down camera in this region. It is also anticipated that the benthos of the area will not be significantly affected by the scheme and that best practice approaches will ensure that impacts are acceptable to the species and habitats of the study area.

Given the scale of local fisheries industries, it is expected that sufficient information can be obtained through consultations with fisheries’ representatives and organisations to negate the need for fisheries assessment. Jacobs will undertake this fisheries consultation as part of wider consultation effort. Results of the fisheries consultation will be used to inform the impact assessment.

8.12.3 Terrestrial Ecology

The preliminary habitat survey will be updated with more detailed survey during the wet season (early November 2014) and (if required) the dry season, if it is concluded during the earlier surveys that migratory species of nature conservation interest may enter the site in the dry season. The surveys will mainly focus on fauna, although habitat descriptions from the October 2014 survey will be updated as appropriate. Species will be recorded together with a note on their abundance within the site.

Mammal surveys will be carried out using line transects spaced at regular intervals across the site. Experienced ecologists will walk each transect and record evidence of protected or otherwise notable species and note any features of potential ecological importance. Data to be recorded will include opportunistic sightings of animals as well as field evidence, such as burrows, faecal pellets, footprints, etc. Examination of potential refuge habitat, such as fallen logs, tree stumps, underside of rocks, leaf litter, rodent burrows and old termite mounds, may also be carried out in order to investigate the potential presence of species which habitually conceal themselves in such features, e.g. hinged back tortoises (Kinixyx spp.). Relevant ecological information will also be sourced from local stakeholders, including hunters and farmers.

Avian species will also be recorded along the transects. This will be done through a combination of identifying bird calls and by observing birds through binoculars.

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The baseline information will be detailed in a stand-alone ecology report, which will be appended to the ESIA and summarised within the ESIA itself. Ecological receptors will be evaluated with respect to a local, regional, national or international framework, as appropriate, and an Ecological Impact Assessment will be carried out for receptors with a regional or higher importance. This is anticipated to follow guidelines produced by the Institute of Ecology and Environmental Management (IEEM) (2006). Although these guidelines were produced for the United Kingdom, they set out a general process which is also relevant to Ghana, i.e. the process of first identifying the value of ecological receptors, then characterising the impacts that are predicted, e.g. loss or modification of wetland habitat, discussing the effects on the integrity or conservation status of valuable receptors, before describing proposed mitigation and compensation, if required, and finally assessing the residual impacts. Reference will be made to relevant national or international guidance, such as IFC PS 6, as appropriate.

8.12.4 Air Quality

Distinct potential air quality effects are associated with the construction and operation phases of the project. In recognition of this, the assessment methodology, identification of effects and proposals for mitigation measures will be presented appropriate to each phase within the ESIA report.

The primary construction activities associated with the project include on site preparations and clearance, drilling, earthworks associated with laying of pipelines, infrastructure and above ground construction. Such activities will give rise to particulate emissions, including PM10 (which can be detrimental to health) and dust (which can cause nuisance, loss of amenity and, in extreme circumstances, effects on ecological receptors). In addition, air quality could be impacted during construction phase through emissions from construction machinery, transport of equipment, materials and staff.

During operations, key impacts would come from three types of sources: continuous releases such as boiler stacks, fugitive emissions (such as vents) and occasional releases under normal and exceptional conditions (flares). Key pollutants will be NOx, SOx, particulates and CO, as well as other acid gases including CO2. Qualitative consideration will be given to hydrogen sulphide and hydrocarbons, based on available information. Impacts from accidental releases will also be discussed.

Although numerical criteria do exist for such effects, a semi quantitative or qualitative risk assessment approach is considered to be suitably robust for the construction phase. The assessment should identify receptors at risk from particulate emissions as a result of specific construction activities and identify practical mitigation measures.

For the operational phase, characteristics of emissions will be provided the project. The releases to atmosphere will be compared to national legislation and IFC Standards.

Emission sources identified will be screened; insignificant sources will be discussed qualitatively while significant sources will be incorporated and modelled in a dispersion model.

A dispersion model (e.g. USEPA approved AERMOD, or ADMS-4) will be used to predict the contribution of the facilities to ground level concentrations of key pollutants. These models incorporate the latest theories in describing atmospheric dispersion and turbulence, taking account

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of local topography, meteorology and building wake effects. Baseline ambient air quality data will be collated from existing third party sources and supplemented with 20 working days of dry season ambient air quality monitoring.

The dispersion modelling will focus on continuous combustion emissions (including continuous flares if any), although significant vents may be included if relevant, which may also include odour). Dispersion modelling will be undertaken for regular combustion pollutants include NO2, SO2, PM10 and CO. Assessment scenarios will be agreed with the client prior to running the model, but will be limited to three scenarios.

The results will be presented with a combination of summary tables for key receptors and contour plots to illustrate the distribution in air quality. The results will be compared directly with relevant short and long term air quality criteria. Pollution control techniques will be evaluated as part of the modelling assessment.

Combustion sources would release significant amounts of CO2 while vents and other fugitive emissions would lead to the release of other greenhouse gases. This would add-up to one-off emissions arising during construction phase from construction plant, vehicles, materials manufacture and waste disposal.

We will undertake an assessment of carbon emissions following recognised methodologies. The carbon study will consider, where possible:

• Emissions arising from construction activities;

• Emissions associated with transport of equipment, materials, personnel and waste;

• Emissions released during manufacture of key components of the project;

• Emissions from combustion sources; and

• Emissions from vents, leaks and other fugitive emissions.

The assessment will provide:

• An overall Greenhouse Gases emissions balance (tonnes of carbon equivalent per year);

• A source apportionment; and

• Recommendations for areas of improvements in the most cost-effective ways.

8.12.5 Noise

Noise modelling is required to verify the results of the existing results which indicate elevated noise levels from current operations and restrictions on further project development. A key aim of the assessment would be to identify any appropriate mitigation in order to ensure compliance with relevant noise limits at the boundaries of the facilities.

Noise from the construction and subsequent operation of the development is likely to vary in nature and duration.

The noise assessment will involve a description of the acoustic environment in the study area (based on existing information or noise surveys conducted during our site visit) and any anticipated

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changes in environmental noise conditions. Current and future Project major noise emission sources will be identified.

The noise modelling report would include an explanation of the modelling techniques adopted, methods used, assumptions made and outline any associated limitations. The project would be modelled under worst case conditions.

It is proposed to use existing baseline noise information will be used. This existing information will be supplemented with 10 working days of baseline noise monitoring at 10 locations with spot monitoring in accordance with the requirements of ISO:1996-2 using hand held device during discrete times of the day, evening and night.

The noise impact assessment will identify, describe and discuss noise issues associated with both construction and decommissioning and operational phases of the project.

Specifically, the noise impact assessment will consider:

• The sound power level of all major items / activities used during construction and decommissioning of the Project, the percentage of the time for which they are in use, and the distance between noise source and sensitive receptor;

• Construction noise predictions of ‘free field’ equivalent continuous noise levels are to be made using the methodology outlined in BS 5228: 1997 'Noise and vibration control on construction and open sites' or another internationally accepted method;

• Construction vibration where there is scope for potential impact on sensitive receptors; and

• Any environmental noise monitoring that will be conducted during construction of the project.

The noise impact assessment will also consider as applicable:

• Comparison of predicted noise levels with current baseline data and appropriate national and international guidelines. These are to include relevant IFC sector guidelines and the General Environmental, Health and Safety Guidelines;

• The potential for increased noise levels (including tonal and intermittent noise) resulting from the Project and any implications of the predicted noise levels for environmental protection and public health;

• The cumulative effects at noise sensitive receptors from the Project in combination with existing operations;

• Aspects of the Project that retain the potential to affect pre-existing noise levels and the implications and measures used to mitigate. This is to be performed with respect to magnitude, duration, frequency and time of day of noise events and the expected performance of mitigation measures;

• Ambient noise monitoring that will be conducted during operation of the Project (including both daytime and night-time periods); and

• The sound power level of all major plant items used in the Project.

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8.12.6 Social Impact Assessment (SIA)

The SIA will involve the processes of analysing, monitoring and managing the intended and unintended social consequences, both positive and negative, of the proposed project interventions and any social change processes invoked by those interventions. The SIA will be undertaken according to the International Association for Impact Assessment’s (IAIA) definition of social impacts as changes to people’s way of life, their community, culture, environment, health and well-being and personal and community property rights.

Social baseline data will be collected relating to: demographics, community facilities and services, economic environment; employment labour and livelihood issues; land use and natural resources; governance structures, health, education, culture, lifestyle and recreation.

The baseline will illustrate the spatial distribution of key local resources and receptors in a community constraints map. Generic social receptors will be considered as individuals, households, social groups, businesses, socio-cultural and economic networks and communities. The most sensitive social receptors will be identified and they are expected to be any persons impacted by resettlment or economic displacement, the workforce employed by the project and the wider local communities. In the context of the project locality critical social resources are expected to include essential services in short supply such as potable water and sanitation, and; employment and livelihood opportunities and revenue streams.

Social impacts will be identified and assessed by determining the extent to which the project results in social receptors gaining or losing access to and control over social resources respectively. The focus will be on direct impacts to local communities and workers and indirect issues relating to public-perceptions and wider regional socio-economic development will also be considered. Impacts will be considered according to the IFC performance Standards on Social and Environmental Sustainability that relate to social issues. Significance will be attributed to impacts taking into consideration clearly defined impact magnitude and receptor sensitivity criteria relating to people’s well-being and vulnerability to impoverishment and social exclusion.

Negative impact avoidance and mitigation measures will be proposed along with benefit enhancement activities and likely residual impacts following mitigation will be evaluated.

8.12.7 Wastewater

Water effluents associated with the onshore and offshore activities will include process water, stormwater and sewage from operations, as well as sewage, ballast water, bilge water, and vessel cleaning wastewater from ships. All potential water effluents and their impacts will be assessed as part of the ESIA with comparisons against internationally recognised discharge standards.

Stormwater and sewage from the project will be assessed against the recommendations provided in relevant IFC Guidelines. Ships wastewater management and discharges will be assessed against the requirements of MARPOL.

Thermal plume behaviour for thermal discharges of process water from the onshore facilities and FSRU will be predicted using the latest version of the CORMIX 8 mixing zone software model, which is the most widely-utilised thermal plume discharge model. This version of the program produces 2D and 3D predictions of plume behaviour.

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The assessment of thermal plume behaviour will include desk based gathering the data required for the model, running models at about 6 variations of environmental conditions (normally max min water temperature and different current velocities), a report of findings and answering some queries.

8.12.8 Flood Risk

Key issues that will need to be considered within the flood risk assessment include:

• Fluvial flooding from the Anankwari River;

• Tidal flooding;

• Joint fluvial / tidal flood events;

• Fluvial flooding from small tributaries of the Anankwari River;

• Backwater effects on tributaries from high water levels along Anankwari River;

• Upstream reservoir failure;

• Groundwater flooding / localised overland flow; and.

• Impacts on flood mechanisms above from the building up of site levels.

A preliminary qualitative review of the site’s hydrological context and of existing studies will initially be undertaken to determine flood mechanisms and pathways that are likely to be significant in the context of the development proposals. This will include a review of topography at and around the development site (ideally based on a detailed digital terrain model) to ascertain which areas are likely to be hydrologically connected under severe flood conditions.

The full scope of the subsequent assessment will only be determined following completion of this initial stage, but based on our current understanding is likely to involve:

• Detailed catchment mapping;

• Analysis of any historic data relating to

o Flows released from / overtopping the upstream reservoir

o Water levels at and around the site; and

o Tidal levels regionally.

• Community liaison to determine areas of regular flooding and maximum extent of recent historic flood events along with any changes in flooding associated with the construction of the reservoir;

• Modelling of extreme fluvial flows and the interaction of fluvial and tidal flood events;

• Consideration of the likely impact of climate change of flood risk;

• Modelling assessment of the impact of the loss of flood storage on flood dynamics locally; and

• Review of changes in flood dynamics on key local receptors.

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8.12.9 Assessing Significance of Impacts The methodology developed and adopted for this assessment provides a tool for assessing and evaluating the significance of effects and is based on the following criteria:

• The type of effect (i.e. whether it is positive/acceptable, negative/unacceptable, neutral or uncertain);

• Duration and/or frequency of occurrence (short term/frequent, long term/long return period, intermittent);

• The policy importance or sensitivity of the resource under consideration in a geographical context (whether it is international, national, regional or local, as defined in Table 8-2); and

The magnitude of the effect in relation to the resource that has been evaluated, quantified if possible, or rated qualitatively as high, medium or low, as defined in Table 8-3.

Both professional judgement and the results of modelling analysis are used to assess the findings in relation to each of these criteria to give an assessment of significance for each effect. Effects are considered to be major, minor or negligible and can be negative or positive. Where positive impacts are identified mitigation is not required.

Table 8-2: Geographical Context and Policy Importance

Geographical Context Topic Definition

International Important at global, African or trans-boundary levels National Important in the context of Ghana Regional Important in the context of Shama District Important in the context of the Sekondi – Takoradi Local Important within the site and up to 1 km from the site

Table 8-3: Magnitude Criteria

Magnitude of effect Negative effects Positive effects

High • Widespread community concern. • Failure to meet legal compliance

requirements. • Fatality or serious health disability. • Severe or possibly irreversible damage

to an important ecosystem or resource.

• Widespread community benefit.

• High contribution to safety or prevention of fatalities.

• High level of technology transfer.

• Prevents serious damage to an important ecosystem or resource.

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Magnitude of effect Negative effects Positive effects

Medium • Local community opposition and levels of complaint.

• Regulatory concerns. • Lost time injury or short term health

effects. • Medium term damage to an ecosystem

or resource.

• Contributes to local development and economy.

• Provides confidence to regulators.

• Prevents medium term damage to an ecosystem or resource.

Low • Minor community opposition or complaints.

• Able to comply with legal requirements. • Local/minor health effects requiring

short-term treatment. • Short-term, minor damage to an

ecosystem or resource.

• Low level of community support.

• Economic benefits not distributed locally.

As a guide Table 8-4 presents a significance evaluation tool which calculates the significance of the effect by a combination of importance/ sensitivity and magnitude.

Table 8-4 : Evaluation of Significance of Effect

Sensitivity of Impact Magnitude of Impact

Low Medium High

International Minor / Major Major Major National Minor / Major Major Major Regional Minor / Major Minor / Major Major District Negligible / Minor Minor / Major Minor / Major Local Negligible Minor Minor / Major

8.13 Framework Environmental and Social Management Plan

An EMP will be produced at the end of the EIA. The EMP will be sufficiently robust to support International Lending requirements as stipulated in IFC Performance Standard 1 – Environmental and Social Assessment and meet the requirements of the EPA EIA requirements.

The EMP will rank and prioritise recommended environmental and social actions, describing time period for implementation. In addition, the EMP will indicate the roles and responsibilities of project personnel and third parties such as local and regional administrations and sub-contractors.

The EMP will follow the following format:

• Project description;

• Applicable regulatory standards and guidelines;

• Environmental and social management plan– This section would provide the environmental and social aspects and impacts along with the proposed outline mitigation measures for the construction and operational phases for key issues. This will include: summarising all anticipated significant adverse impacts, identification of measures to prevent, minimise,

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mitigate, compensate, offset and otherwise manage and control such impacts and identification of monitoring requirements to demonstrate compliance with applicable standards and guidelines and measure the effectiveness of impact mitigation measures. The environmental management plan would provide technical details in respect of the mitigation measures to be implemented and define the responsibility for such measures;

• Environmental and social monitoring plan – This section would outline the physical and biological environmental monitoring and measurement for the construction and operational phase; and

• Reporting and review requirements.

The EMP will address both the construction and operational phases of the project. For implementation of the construction phase, the EMP will primarily be the responsibility of the construction contractor(s). The document will contain generic (and where identified project-specific) good practice environmental and social management measures commensurate with any construction project and site specific mitigation, and control measures geared to address specific impacts identified as part of the ESIA. We would expect the construction contractor(s) and site operator to further develop the EMP with detailed management and/or action plans as pertinent to their scope of work.

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Appendices

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Appendix A: EPA Screening Confirmation

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Appendix B: International Labour Organisation — Conventions

Convention Date Status

C029 - Forced Labour Convention, 1930 (No. 29) 20 May 1957 In Force

C087 - Freedom of Association and Protection of the Right to Organise Convention,

1948 (No. 87) 02 Jun 1965 In Force

C098 - Right to Organise and Collective Bargaining Convention, 1949 (No. 98) 02 Jul 1959 In Force

C100 - Equal Remuneration Convention, 1951 (No. 100) 14 Mar 1968 In Force

C105 - Abolition of Forced Labour Convention, 1957 (No. 105) 15 Dec 1958 In Force

C111 - Discrimination (Employment and Occupation) Convention, 1958 (No. 111) 04 Apr 1961 In Force

C138 - Minimum Age Convention, 1973 (No. 138)Minimum age specified: 15 years

06 Jun 2011 In Force

C182 - Worst Forms of Child Labour Convention, 1999 (No. 182) 13 Jun 2000 In Force


C081 - Labour Inspection Convention, 1947 (No. 81) 02 Jul 1959 In Force

C144 - Tripartite Consultation (International Labour Standards) Convention, 1976

(No. 144) 06 Jun 2011 In Force


C001 - Hours of Work (Industry) Convention, 1919 (No. 1) 19 Jun 1973 In Force

C008 - Unemployment Indemnity (Shipwreck) Convention, 1920 (No. 8) 18 Mar 1965 In Force

C011 - Right of Association (Agriculture) Convention, 1921 (No. 11) 14 Mar 1968 In Force

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C014 - Weekly Rest (Industry) Convention, 1921 (No. 14) 19 Jun 1973 In Force

C015 - Minimum Age (Trimmers and Stokers) Convention, 1921 (No. 15) 20 May 1957 Not in force

C016 - Medical Examination of Young Persons (Sea) Convention, 1921 (No. 16) 20 May 1957 In Force

C019 - Equality of Treatment (Accident Compensation) Convention, 1925 (No. 19) 20 May 1957 In Force

C022 - Seamen's Articles of Agreement Convention, 1926 (No. 22) 18 Mar 1965 In Force

C023 - Repatriation of Seamen Convention, 1926 (No. 23) 18 Mar 1965 In Force

C026 - Minimum Wage-Fixing Machinery Convention, 1928 (No. 26) 02 Jul 1959 In Force

C030 - Hours of Work (Commerce and Offices) Convention, 1930 (No. 30) 19 Jun 1973 In Force

C045 - Underground Work (Women) Convention, 1935 (No. 45) 20 May 1957 In Force

C050 - Recruiting of Indigenous Workers Convention, 1936 (No. 50) 20 May 1957 In Force

C058 - Minimum Age (Sea) Convention (Revised), 1936 (No. 58) 20 May 1957 In Force

C059 - Minimum Age (Industry) Convention (Revised), 1937 (No. 59) 20 May 1957 Not in force

C064 - Contracts of Employment (Indigenous Workers) Convention, 1939 (No. 64) 20 May 1957 In Force

C065 - Penal Sanctions (Indigenous Workers) Convention, 1939 (No. 65) 20 May 1957 In Force

C069 - Certification of Ships' Cooks Convention, 1946 (No. 69) 18 Mar 1965 In Force

C074 - Certification of Able Seamen Convention, 1946 (No. 74) 18 Mar 1965 In Force

C088 - Employment Service Convention, 1948 (No. 88) 04 Apr 1961 In Force

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C089 - Night Work (Women) Convention (Revised), 1948 (No. 89) 02 Jul 1959 In Force

C090 - Night Work of Young Persons (Industry) Convention (Revised), 1948 (No. 90) 04 Apr 1961 In Force

C092 - Accommodation of Crews Convention (Revised), 1949 (No. 92) 18 Mar 1965 In Force

C094 - Labour Clauses (Public Contracts) Convention, 1949 (No. 94) 04 Apr 1961 In Force

C096 - Fee-Charging Employment Agencies Convention (Revised), 1949

(No. 96)Has accepted the provisions of Part II 21 Aug 1973 In Force

C103 - Maternity Protection Convention (Revised), 1952 (No. 103) 27 May 1986 In Force

C106 - Weekly Rest (Commerce and Offices) Convention, 1957 (No. 106) 15 Dec 1958 In Force

C107 - Indigenous and Tribal Populations Convention, 1957 (No. 107) 15 Dec 1958 In Force

C108 - Seafarers' Identity Documents Convention, 1958 (No. 108) 19 Feb 1960 In Force

C115 - Radiation Protection Convention, 1960 (No. 115) 07 Nov 1961 In Force

C116 - Final Articles Revision Convention, 1961 (No. 116) 27 Aug 1963 In Force

C117 - Social Policy (Basic Aims and Standards) Convention, 1962 (No. 117) 18 Jun 1964 In Force

C119 - Guarding of Machinery Convention, 1963 (No. 119) 18 Mar 1965 In Force

C120 - Hygiene (Commerce and Offices) Convention, 1964 (No. 120) 21 Nov 1966 In Force

C147 - Merchant Shipping (Minimum Standards) Convention, 1976 (No. 147) 10 May 2005 In Force

C148 - Working Environment (Air Pollution, Noise and Vibration) Convention, 1977

(No. 148) 27 May 1986 In Force

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C149 - Nursing Personnel Convention, 1977 (No. 149) 27 May 1986 In Force

C150 - Labour Administration Convention, 1978 (No. 150) 27 May 1986 In Force

C151 - Labour Relations (Public Service) Convention, 1978 (No. 151) 27 May 1986 In Force

C184 - Safety and Health in Agriculture Convention, 2001 (No. 184) 06 Jun 2011 In Force

MLC - Maritime Labour Convention, 2006 (MLC, 2006)In accordance with Standard A4.5 (2) and (10), the Government has specified the following branches of social security: medical care; sickness benefit; old-age benefit; employment injury benefit; maternity benefit; invalidity benefit and survivors’ benefit.

16 Aug 2013 In Force

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