Report

Transcription

Report

T.E.N. DEVELOPMENT PROJECT
TWENEBOA ENYENRA NTOMME (T.E.N.) –
SCOPING REPORT AND TERMS AND REFERENCE
PROJECT CODE: 00002
0
20/01/12
EPA submission
A. de Jong
M. Irvine
H. Camp
Rev
Date
Reason for Issue
Prepared
Checked
Approved
DOCUMENT NUMBER :
00002-E78-ES-RPT-0005
Contract Number
Area Code
TGHA-02078
System Code
Responsible Party
ERM
This document is the property of (TULLOW). It is furnished to establish requirements for a specific item or activity and solely for that
purpose. This document is not intended for general circulation and shall not be reproduced or distributed without written permission
from TULLOW or its representative.
Hardcopies of this document are considered uncontrolled. Refer to digital version for latest revision.
REVISION CONTROL
Revision:
Para /Sect
Change Description
This sheet must be completed in detail, at each revision once this document has been
approved. Details must include revision number, description and indication of which pages and
paragraphs have been revised, date of revision approval and approval indication.
Hardcopies of this document are considered uncontrolled. Refer to digital version for latest version
Tweneboa, Enyenra, Ntomme
(T.E.N.) Development, Ghana
Scoping Report and Terms of
Reference
Doc no: 00002-E78-ES-RPT-0005 – REV0
Tullow Ghana Limited
January 2012
Tweneboa, Enyenra, Ntomme
(T.E.N.) development, Ghana
Scoping Report and Terms of Reference
Doc no: 00002-E78-ES-RPT-0005 – REV0
January 2012
Submitted by:
71 George Bush Highway
(Tetteh Quarshie Int)
North Dzorwulu
Accra, Ghana
Prepared by:
Environmental Resources Management
For and on behalf of
Approved by:
Henry Camp
Signed:
Position:
Partner
Date:
20 January 2012
This report has been prepared by Environmental Resources
Management the trading name of Environmental Resources
Management Limited, with all reasonable skill, care and diligence
within the terms of the Contract with the client, incorporating our
General Terms and Conditions of Business and taking account of the
resources devoted to it by agreement with the client.
We disclaim any responsibility to the client and others in respect of
any matters outside the scope of the above.
CONTENTS
1
INTRODUCTION
1-1
1.1
1.2
1.3
1.4
1.5
OVERVIEW OF THE PROJECT
PURPOSE OF THIS REPORT
THE PROPONENT
THE EIA TEAM
STRUCTURE OF THIS REPORT
1-1
1-1
1-2
1-2
1-3
2
PROJECT DESCRIPTION
2-1
2.1
2.2
2.3
2.4
2.5
2.6
2.7
2.8
2.9
2.10
2.11
INTRODUCTION
PROJECT ALTERNATIVES
PROJECT LOCATION
PROJECT SCHEDULE
PRODUCTION FORECAST
FACILITIES AND EQUIPMENT
MAIN PROJECT ACTIVITIES
EMISSIONS, DISCHARGES AND WASTE
SEAFLOOR DISTURBANCE
PERSONAL REQUIREMENTS AND EMPLOYMENT
EHS PROGRAMMES, PLANS AND PROCEDURES
2-1
2-1
2-3
2-3
2-4
2-5
2-15
2-26
2-29
2-29
2-29
3
LEGAL AND POLICY FRAMEWORK
3-1
3.1
3.2
3.3
3.4
3.5
3.6
3.7
3.8
3.9
3.10
3.11
3.12
3.13
INTRODUCTION
THE GHANAIAN CONSTITUTION
ENVIRONMENTAL LEGISLATION
PETROLEUM LEGISLATION
MARITIME LEGISLATION
POLLUTION CONTROL
RADIATION PROTECTION INSTRUMENT
PROTECTION OF COASTAL AND MARINE AREAS
STATE, CONVENTIONS AND CLASSIFICATION REQUIREMENTS
RELEVANT INTERNATIONAL AGREEMENTS AND CONVENTIONS
GOOD PRACTICE STANDARDS AND GUIDELINES
PROJECT ENVIRONMENTAL STANDARDS
LEGISLATION UNDER PREPARATION
3-1
3-1
3-1
3-2
3-3
3-3
3-3
3-4
3-4
3-5
3-8
3-10
3-11
4
EIA PROCESS AND SCOPING
4-1
4.1
4.2
4.3
4.4
THE EIA PROCESS
PROJECT REGISTRATION
PROJECT SCREENING
SCOPING PHASE
4-1
4-1
4-1
4-1
5
SCOPING STAKEHOLDER ENGAGEMENT
5-1
5.1
5.2
5.3
INTRODUCTION
OBJECTIVES
STAKEHOLDER ENGAGEMENT ACTIVITIES
5-1
5-1
5-1
6
ENVIRONMENTAL AND SOCIAL BASELINE
6-1
6.1
6.2
6.3
6.4
6.5
INTRODUCTION
ENVIRONMENTAL BASELINE
BIOLOGICAL BASELINE
FISHERIES BASELINE
SOCIO-ECONOMIC BASELINE
6-1
6-1
6-6
6-15
6-20
7
IDENTIFICATION OF POTENTIAL IMPACTS
7-1
7.1
7.2
7.3
7.4
INTRODUCTION
ENVIRONMENTAL AND SOCIAL RESOURCES AND RECEPTORS
IDENTIFICATION OF POTENTIAL INTERACTIONS
IDENTIFICATION OF IMPACTS
7-1
7-1
7-1
7-2
8
TERMS OF REFERENCE FOR EIA
8-1
8.1
8.2
8.3
8.4
8.5
8.6
INTRODUCTION
NEXT STEPS TO COMPLETE THE EIA PROCESS
PROPOSED BASELINE STUDIES
STAKEHOLDER ENGAGEMENT
OUTLINE STRUCTURE OF THE EIS
PROVISIONAL SCHEDULE FOR THE EIA PROCESS
8-1
8-1
8-2
8-8
8-9
8-10
9
REFERENCES
ANNEX A
ANNEX B
ANNEX C
STAKEHOLDER ENGAGEMENT LIST
BACKGROUND INFORMATION DOCUMENT
CONSULTATION RECORDS
ANNEX C1 ATTENDANCE SHEETS
ANNEX C2 CONSULTATION NOTES
ANNEX C3 CONSULTATION PHOTOS
ISSUES TRAIL
IMPACT ASSESSMENT METHODOLOGY
PROPOSED EIS REPORT STRUCTURE
ANNEX D
ANNEX E
ANNEX F
ACRONYMS
ABS
ACDP
AHTS
AHV
bbl
BOP
bopd
bwpd
American Bureau of Standards
Acoustic Current Doppler Profile
Anchor Handling Tug Supply
Anchor Handling Vessel
barrels
Blow-out Preventor
barrels of oil per day
barrels of water per day
CALM
CO
CO 2
Catenary Anchor Leg Mooring [buoy]
Carbon Monoxide
Carbon Dioxide
COLREG
CSR
CTD
DCE
International Regulations for Preventing Collisions at Sea
Corporate Social Responsibility
Conductivity Temperature Depth [profile]
District Chief Executive
DP
Dynamically Positioned
ECC
EEZ
EHSMS
EIA
EIS
EMP
EPA
ERP
Equatorial Counter Current
Economic Exclusion Zone
Environmental Health and Safety Management System
Environmental Impact Assessment
Environmental Impact Statement
Environmental Management Plan
Environmental Protection Agency
Emergency Response Plan
FEED
Front End Engineering Design
FPSO
GDP
GMA
GNPC
IBA
IMO
ITCZ
IUCN
MARPOL
Floating Production Storage and Offloading Vessel
Gross Domestic Product
Ghana Maritime Authority
Ghana National Petroleum Corporation
Important Bird Area
International Maritime Organisation
Inter-topical Convergence Zone
International Union for Conservation of Nature
International Convention for the Prevention of Pollution From
Ships
Mbbl
million barrels
mmscfd
MODU
NADF
nm
million standard cubic feet per day
Modular Offshore Drilling Unit
Non-aqueous Drilling Fluid
nautical mile
NORM
NO x
Naturally Occurring Radioactive Material
Oxides of Nitrogen
NPA
OCNS
OGP
OPRC
National Petroleum Authority
Offshore Chemical Notification Scheme
International Oil and Gas Producers
International Convention on Oil Pollution Preparedness, Response
and Co-operation
OSRP
Oil Spill Reponses Plan
OOB
PER
QRA
Oil Offloading Buoy
Preliminary Environmental Report
Quantitative Risk Assessment
SAEMA
Shama Ahanta East Metropolitan Assembly
SCR
Steel Catenary Riser
SOPEP
Shipboard Oil Pollution Emergency Plan
SO x
Oxides of Sulphur
STCW
STMA
Standards of Training, Certification & Watchkeeping
Sekondi-Takoradi Metropolitan Assembly
T.E.N.
Tweneboa, Enyenra, Ntomme [development]
TGL
UNCLOS
WBF
WMP
United Nations Convention on the Law of the Sea
Water Based Fluid
Waste Management Plan
1
INTRODUCTION
1.1
OVERVIEW OF THE PROJECT
Tullow Ghana Limited (TGL) has interests in two oil and gas licence blocks
offshore Ghana, namely Deepwater Tano (DWT) and West Cape Three Points
(WCTP). In 2007, TGL and its Joint Venture Partners discovered the Jubilee
field, which straddles both blocks, and lies approximately 60 km off the coast
of Ghana. The Jubilee field was subsequently developed through a joint
venture partnership and first oil was achieved on 15 December 2010.
Further exploration and appraisal drilling in the DWT block during 2009 and
2010 resulted in the discovery of the Tweneboa, Enyenra (originally named
Owo) and Ntomme (T.E.N.) oil and gas fields. The fields are situated
approximately 30 km to the west of the Jubilee Field and lie in water depths
ranging between 1,000 m and 1,800 m (see Figure 1.1).
TGL and its Joint Venture Partners, Kosmos Energy LLC, Anadarko
Petroleum Corporation, Ghana National Petroleum Company and Sabre Oil
and Gas, known as the DWT Joint Venture, are proposing to develop the
T.E.N. fields. The project is referred to as the T.E.N. development. TGL is the
designated operator for the DWT block and will lead the project design,
execution and operation of the proposed T.E.N. development.
The T.E.N. development will consist of oil and gas production wells, water
injection wells and gas injection wells. Production will be gathered through
subsea manifolds and conveyed by subsea flowlines to a Floating Production
Storage and Offloading vessel (FPSO) which will be moored in the area of the
T.E.N. fields. Subsea equipment installation is planned throughout 2014 and
the target for first production is quarter four (Q4) 2014.
1.2
PURPOSE OF THIS REPORT
Under the Ghanaian Environmental Assessment Regulations (1999), oil and
gas field development is an undertaking for which an Environmental Impact
Assessment (EIA) is mandatory. The undertaking also requires registration
and authorisation by the Ghana Environmental Protection Authority (EPA).
TGL has commissioned Environmental Resources Management (ERM) in
collaboration with ESL Consulting (ESL) and SRC Consulting (SRC) (jointly
referred to as the EIA team) to undertake the EIA for the T.E.N. development.
The EIA is currently at the Scoping study phase.
This Scoping Report, including the Terms of Reference for the EIA, has been
compiled by the EIA team on behalf of TGL as part of the EIA process.
The Scoping Report documents the scoping activities associated with the EIA
process and associated stakeholder consultation process. One of the main
TWENEBOA, ENYENRA NTOMME (T.E.N.) DEVELOPMENT
SCOPING REPORT AND TERMS OF REFERENCE
00002-E78-ES-RPT-0005 – REV0
20/1/2012
1-1
objectives of scoping is to identify the potentially significant environmental
issues that should be addressed in the EIA. The key issues raised by
stakeholders and identified by the EIA team to date are presented along with
Terms of Reference for the next stage in the EIA process.
This report has been compiled in accordance with the Ghanaian Environmental
Assessment Regulations (1999). The Scoping Report, including the Terms of
Reference, has been submitted to the EPA for review and acceptance. Copies
of the Scoping Report will be made available for public review and relevant
comments will be addressed in the EIA. An Environmental Impact Statement
(EIS), containing the findings of the EIA, will also be disclosed at a later stage
in the EIA process (see Chapter 8).
1.3
THE PROPONENT
Contact details for the project proponent, TGL, are also provided.
Proponent:
Ghana Projects EHS Manager:
Tel:
Email:
1.4
71 George Bush Highway
North Dzorwulu
Accra, Ghana
Dr Glenn Bestall
+233 30 274 2200
[email protected]
THE EIA TEAM
The core EIA team members that are involved in this EIA are listed in
Table 1.1.
Table 1.1
The EIA Team
Name
Mr Henry Camp
Role
Project Director
Qualifications, Experience
BA, 27 years
Mr Mark Irvine
Project Manager
BSc, MSc, 25 years
Mr Albert de Jong
Project Coordinator
BSc, 8 years
Mr AK Armah
Environmental and fisheries
specialist
BSc, MPhil, MSc, 31 years
Mr Adu–Nyarko Andorful
Socio-economic specialist
BA, M.Phil, 10 years
00002-E78-ES-RPT-0005 – REV0
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1-2
EIA team contact details are provided below.
Project manager:
Address:
Mark Irvine
Norloch House, 36 King’s Stables Road,
Edinburgh, EH1 2EU, United Kingdom
+44 131 478 6000
[email protected]
Tel:
Email:
1.5
STRUCTURE OF THIS REPORT
The structure of the remainder of this Scoping Report is as follows.
Chapter 2
Chapter 3
Chapter 4
Chapter 5
Chapter 6
Chapter 7
Chapter 8
Chapter 9
Project Description
Legislation and Standards
EIA Process and Scoping
Scoping Stakeholder Engagement
Environmental and Social Baseline
Identification of Potential Environmental and Social Impacts
Terms of Reference for EIA
References
The main report is supported by the following annexes.
Annex A
Annex B
Annex C
Annex D
Annex E
Annex F
Stakeholder List
Background Information Document
Consultation Records
Issues Trail
Impact Assessment Methodology
Proposed EIS Report Structure
00002-E78-ES-RPT-0005 – REV0
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1-3
3°30'0"W
3°0'0"W
2°30'0"W
KEY:
DWT Block
!
!
!
!
!
West Cape Three Points Block
T.E.N. Fields
Enyenra
Ntomme
Tweneboa
Jubilee Unit Area
Cote d'Ivoire
Other DWT Fields
Wawa and
Turonian-Cenomanian Deep
Ghana
(
!
International Boundary
Half Assini
60 k
m
5°0'0"N
(
!
Nkroful
Axim
appr
ox
(
!
0
.
20
Kilometres
Enyenra
Tweneboa
TITLE:
Ntomme
Figure 1.1
Locality Map
4°30'0"N
CLIENT:
DATE: 22/12/2011
CHECKED: ADJ
PROJECT: 0142816
DRAWN: KM
APPROVED: MI
SCALE: As scale bar
DRAWING:
Locality_PD.mxd
ERM
Norloch House
36 King's Stables Road
Edinburgh
EH1 2EU
United Kingdom
Telephone:+44 (0) 131 478 6000
Facsimile: +44 (0)131 656 5813
SOURCE:
PROJECTION: WGS_1984_UTM_Zone_30N
3°30'0"W
3°0'0"W
2°30'0"W
SIZE:
A4
REV:
0
2
PROJECT DESCRIPTION
2.1
INTRODUCTION
TGL and the DWT Joint Venture partners have discovered three fields in the
DWT block, namely Tweneboa, Enyenra and Ntomme, containing oil,
condensate and gas. TGL and the DWT Partners propose to develop and
produce these reservoirs. The base case development ( 1 ) will comprise
33 wells (15 oil production, 15 water injection, 1 gas production and 2 gas
injection) and subsea equipment connected to an FPSO vessel where well
fluids will be processed into crude oil product suitable for storage and export
to world markets. Gas will be reinjected into gas reservoirs, used for power
generation on the FPSO or exported to the Jubilee field for potential future
export to shore ( 2 ). Produced water will either be re-injected or discharged
overboard depending on the outcome of injection feasibility studies.
Information on the size and nature of the oil and gas reserves obtained
through further exploration and appraisal drilling will inform future
development. The high case ( 3 ) development would include up to 49 wells.
There is also the potential for future DWT block development with the
addition of the Wawa and Turonian-Cenomanian Deep fields. Details of these
potential future block developments are not available at this stage.
This chapter provides a description of the T.E.N. facilities and equipment,
main project activities and associated emissions and discharges. Information
on project personnel and an overview of the project contingency and safety
plans is also provided. Project engineering studies are underway and the
design details will be refined during the EIA. The EIS will present a more
detailed design concept which will be assessed in the EIA.
2.2
PROJECT ALTERNATIVES
This section describes the work undertaken for selecting the design concept
and process that will be followed for refining design details. The EIS will
provide a more detailed consideration of alternatives, including an outline of
design or selection criteria and/or reason for selecting preferred alternatives.
2.2.1
Development Concept Select Process
The development concept required to develop the various the T.E.N.
reservoirs, was proposed during TGL’s Concept Select studies. The
development concept will be revised and refined during subsequent pre-Front
(1) The base case refers to the medium production profile or P(50).. The probability of production being higher or lower
than this medium case is 50:50. This scoping report will refer to this base case unless otherwise stated.
(2) Potential future gas export to shore is outside the scope of this EIA.
(3) The high production profile or P(10)..
00002-E78-ES-RPT-0005 – REV0
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2-1
End Engineering Design (FEED) development studies. Given that the T.E.N.
reservoir appraisal programme is ongoing, the development concept will be
flexible to accommodate any changes in TGL’s understanding of subsea oil
and gas reservoirs.
For the T.E.N. development the main alternatives considered to date included:



2.2.2
project location alternatives;
development approach alternatives; and
engineering design alternatives.
Project Location Alternatives
The T.E.N. development location was defined based on the geophysical
seismic survey data and subsequent exploration and appraisal well drilling
results to date. Results of the Tweneboa and Owo (now Enyenra) discovery
wells, confirmed an accumulation of gas and oil reservoirs within the DWT
block. The proposed production drilling plan is based on the results of the
exploratory and appraisal drilling and is designed to optimise the extraction
of hydrocarbons in the most efficient and cost effective manner, therefore
options for drilling at alternative locations are limited.
2.2.3
Development Approach Alternatives
TGL evaluated the technical, operational and economic factors associated with
various development approaches. Oil industry experience elsewhere in
similar fields, including the nearby Jubilee field, was used to define the
approach. The evaluation process included a risk assessment of three
development concepts, including:



an FPSO with oil storage capacity of more than 14 days;
a tension-leg platform with oil export to the Jubilee field; and
a spar platform with oil storage capacity of two days and export to the
Jubilee FPSO.
Further information on the concept selection process will be provided in the
EIS. The risk assessment considered production operational risks, project cost,
Environment, Health and Safety (EHS) and schedule risks associated with
installation and risks arising from major accidental hazards. The FPSO was
rated to have the lowest risk for both project installation and operational
phases.
TGL, therefore, propose to use proven subsea production and control systems
that will be tied back to an FPSO. Several factors were considered to
determine the best subsea approach for the T.E.N. development including the
remote location, water depth, depth of the reservoir and aerial extent of the
T.E.N. fields. The proposed approach has been used successfully at the
00002-E78-ES-RPT-0005 – REV0
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2-2
Jubilee field and elsewhere in West Africa and other deep water locations
around the world.
2.2.4
Engineering Design Alternatives
TGL is evaluating a number of design alternatives, based on safety,
engineering, technical, financial and environmental considerations, in order to
determine the optimum field development concept. The development concept
includes a number of alternatives which will be further revised and refined
during subsequent engineering studies. These alternatives include:






mooring system;
FPSO hull design;
gas utilisation;
production chemical options;
offloading system; and
produced water disposal options.
Further design options can be addressed in the EIS and the reasons for
selection of the preferred option ( 1 ).
There have been a number of key lessons learnt regarding the installation,
hook-up, commissioning and start-up of the Jubilee Field from the Phase 1
development that will be considered in the T.E.N. subsea and FPSO design.
Further information will be provided in the EIS.
2.3
PROJECT LOCATION
The DWT block, at its closest point, is located approximately 50 kilometres
south of the Ghana coastline (see Figure 1.1). The T.E.N. facilities, including
the proposed FPSO vessel would lie approximately 140 km south-west of the
port at Takoradi, 60 km from shore, 10 km east of the Ghana and Cote d’Ivoire
border and 30 km west of the Jubilee field. Water depths at the fields range
from about 1,000 to 1,800 m.
The FPSO is planned to be located approximately in the centre of the DWT
block, at similar latitude to the Jubilee FPSO (E 484196 m, N 507446 m). At
this site, the FPSO will be located directly above a seabed channel (canyon).
The water depth at this location is approximately 1,410 m.
(1) It should be noted that certain options may be discounted during design due to TGL’s requirement for standardisation
of equipment to consolidate the number of suppliers, equipment and materials, thereby minimising investment in spare
parts, training and providing common maintenance procedures.
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2.4
PROJECT SCHEDULE
A provisional schedule, assuming a target date for first oil in Q4 2014, is
provided in Table 2.1. The programme may change subject to detailed
scheduling of fabrication times of various elements and the availability of
drilling vessels and specialist construction vessels. The schedule assumes that
permits will be in place by Q3 2012. The drilling and completion of the wells
is expected be undertaken from Q2 2013 to Q3 2014. Subsea facilities will be
fabricated from Q1 2013 and subsea installation will take place throughout
2014. The FPSO will be installed between Q3 2013 and Q4 2014.
Table 2.1
Provisional Schedule
Q2
Q3
Q4
Q1
2012
Q2 Q3
Q4
Q1
2013
Q2 Q3
Q4
Q1
2014
Q2 Q3
Q4
2015
Q1
Approvals and sanctions
EIA
PoD approval
Surface facilities
Design
Build and deliver
Well construction
Development drilling
Completion
Subsea facilities
Fabrication
Offshore installation
Production operations
Operations readiness
Commissioning
First oil
Note: This schedule is provisional and subject to change. A final schedule will be provided in the EIS.
2.5
PRODUCTION FORECAST
Production profiles for low, medium and high cases have been produced
using subsea modelling. A design basis has been developed considering
medium case production profiles (ie the P50 case). These production profiles
are likely to be further amended over the coming months in line with ongoing
sub-surface appraisal work and changes arising from new subsurface
modelling. Production profiles from the base case subsea model of September
2011 are shown in Figure 2.1.
00002-E78-ES-RPT-0005 – REV0
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2-4
Figure 2.1
Provisional Base Case Production Profiles (Sept 2011)
Source: TGL, 2011
Figure 2.1 shows a peak oil production rate of 99,998 barrels (bbl) per day by
2018. Oil production rates will then decrease to 3,434 bbl per day by 2040.
The oil production rate shown above includes stabilised and blended
condensate volumes. A total oil recovery of approximately 216 million barrels
(Mbbl) is expected by 2040. A gas production rate of 176 million standard
cubic feet per day (MMScfd) can be achieved by 2017, decreasing to 8 MMScfd
by 2040. The gas rate excludes all quantities of gas allocated to be used as fuel
gas for power generation (approximately 20 MMscfd). A peak water
production rate of 73,825 bbls is expected.
2.6
FACILITIES AND EQUIPMENT
2.6.1
FPSO
An FPSO is a vessel used for the processing and storage of hydrocarbons. An
FPSO is designed to receive hydrocarbons from production wells, process
them and store the crude oil until it can be offloaded onto an export tanker.
An FPSO can be a conversion of an oil tanker or a custom built vessel. For the
T.E.N. fields, TGL is proposing to commission a new, converted FPSO vessel
as the production facility with a nominal oil, gas and condensate processing
capacity of 105,000 barrels of oil per day (bopd). Further information on the
design of the FPSO will be provided in the EIS. The location of FPSO
construction and commissioning is yet to be finalised.
00002-E78-ES-RPT-0005 – REV0
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2-5
The following utility and support systems will likely be part of the FPSO.















2.6.2




Blanket gas system.
Chemical injection.
Cooling/heating medium
system.
Diesel system.
Drain system.
Earthing system.
Emergency Shutdown Systems.
Emissions monitoring systems.
Fire and Gas Systems.
Flare/vent system.
Fuel gas system.
Helideck.
Instrument and plant air.
Laydown area.
Living quarters.









Lighting system.
Materials handling.
Nitrogen generation system.
Oily water treatment
(bilge/ballast).
Potable water system.
Power distribution.
Power generation.
Produced water treatment.
Safety systems.
Seawater system.
Steam system.
Telecommunications and
navigational aids.
Water injection.
Mooring System
Ocean wind and current data which has been gathered from the Jubilee Field
over the past few years indicate that a spread-moored FPSO (Figure 2.2), rather
than a turret moored weathervaning ( 1 ) FPSO as utilised at Jubilee, can be
deployed offshore Ghana. The use of a spread moored FPSO for T.E.N. is
ideal due to its flexibility and potential for later field expansion as it allows
additional risers to be added relatively simply compared to a turret moored
FPSO. A spread-mooring system would comprise of an array of mooring lines
between seabed anchors and fixed chain stoppers on the deck of the FPSO.
This array would keep the FPSO on location and effectively prevent it from
rotating.
Figure 2.2
Example of FPSO with a Spread Mooring
Spread moored FPSO Agbami offshore Nigeria
(1) The turret system has a universal joint which allows the vessel to freely turn 360 degrees around the mooring vertical
axis to align itself with prevailing wind, wave and current conditions. (ie the FPSO weathervanes).
00002-E78-ES-RPT-0005 – REV0
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2-6
2.6.3
Offloading System
With a spread moored FPSO at the T.E.N. fields it is proposed that export
tankers would load via a remote Oil Offloading Buoy (OOB), situated
approximately 1.8 km (one nautical mile) from the FPSO (Figure 2.3). This will
minimise the risk of potential collision between the tanker and the FPSO. The
buoy will be connected to the FPSO by a minimum of two mid-water flexible
or steel offloading flowlines. The buoy will have a multi-anchor leg mooring
system and will allow an export tanker to freely weathervane ( 1 ) during
offloading. At a processing capacity of 100,000 bopd, the FPSO will fill to
capacity in approximately 17 days. It is planned to offload oil in 1 million
barrel loads with each load taking approximately 20 hours to offload. Export
tanker visits will therefore be approximately every 10 days during the peak
production period.
Figure 2.3
Typical Oil Offloading Buoy
2.6.4
Development Plan
Nine wells, consisting of three oil producers, three water injectors, one gas
producer and two gas injectors, will be drilled and completed to be ready for
first oil. Once production has commenced additional wells will be drilled,
completed and subsea infrastructure connected. The base case development
will comprise a total of 33 wells. Sixteen additional wells may be required for
further high case development depending on actual production levels. A
summary of development wells is provided in Table 2.2 and an indicative base
case layout is provided in Figure 2.4. A full list of base case well data is
(1) The design of the OOB will allow the export tanker to swivel around the buoy in response to the prevailing
wind/current direction during offloading.
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provided in Table 2.3. It should be noted that final well locations have not
been confirmed and may deviate, typically within a 1 km radius of the
proposed well location.
Table 2.2
First Oil, Base Case and High Case Wells
Wells
Well status
Number of existing wells
Number of wells to be drilled
Well status (total)
Well type
Oil production wells
Gas production wells
Water injection wells
Gas injection wells
Well type (total)
Table 2.3
First Oil
Base Case
High Case
2
7
9
4
29
33
4
45
49
3
1
3
2
9
15
1
15
2
33
28
4
15
2
49
T.E.N Well Data
#
Name
Type
FO / BC
Status
1
2
3
4
5
6
7
8
9
10
11
12
13
14
15
16
17
18
19
20
21
22
23
24
25
26
27
28
29
30
31
32
33
Owo-1RA
Enyenra-02a
Enuenra-03a
Enyenra-04a
Enyenra-07
Enyenra-09
Enyenra-11
Enyenra-13
Enyenra-15
Enyenra-17
Enyenra-19
Enyenra-06
Enyenra-08
Enyenra-10
Enyenra-12
Enyenra-14
Enyenra-16
Enyenra-18
Enyenra-20
Enyenra-22
Enyenra-24
Enyenra-26
Enyenra-30
Enyenra-32
Enyenra-34
Enyenra-36
Enyenra-38
Enyenra-40
Tweneboa-06
Tweneboa-07
Tweneboa-3ST
Ntomme-01
Ntomme-02
Oil production
Water injection
Water injection
Water injection
Oil production
Water injection
Oil production
Oil production
Water injection
Oil production
Water injection
Water injection
Oil production
Water injection
Oil production
Oil production
Water injection
Oil production
Water injection
Oil production
Water injection
Oil production
Water injection
Oil production
Oil production
Water injection
Oil production
Water injection
Water injection
Oil production
Gas injection
Gas injection
Gas production
FO / BC
FO / BC
BC
BC
BC
BC
BC
BC
BC
BC
BC
FO / BC
FO / BC
FO / BC
FO / BC
BC
BC
BC
BC
BC
BC
BC
BC
BC
BC
BC
BC
BC
BC
BC
FO / BC
FO / BC
FO / BC
Existing
Existing
Existing
Existing
To be drilled
To be drilled
To be drilled
To be drilled
To be drilled
To be drilled
To be drilled
To be drilled
To be drilled
To be drilled
To be drilled
To be drilled
To be drilled
To be drilled
To be drilled
To be drilled
To be drilled
To be drilled
To be drilled
To be drilled
To be drilled
To be drilled
To be drilled
To be drilled
To be drilled
To be drilled
To be drilled
To be drilled
To be drilled
Water
Wellhead Location
Depth (m) (UTM)
East (m) North (m)
-1445
481038
508133
-1675
479259
501122
-1105
483092
514574
-1880
475632
495329
-995
485307
516945
-995
483774
516784
-1540
485259
501875
-1151
483527
513129
-1255
482076
511369
-1152
483526
513117
-1257
482068
511344
-1532
480694
505670
-1588
480192
503885
-1588
480225
503689
-1588
480200
503858
-1765
478734
498802
-1755
478589
498888
-1760
478693
498823
-1758
478553
498854
-1851
476934
496442
-1843
476921
496549
-1849
476893
496457
-1535
480686
505639
-1588
480190
503871
-1587
480237
503873
-1589
480217
503665
-1587
480237
503840
-1676
479262
501104
-1290
488040
508117
-1288
488032
508176
-1603
489047
501894
-1512
486536
503008
-1588
484141
500255
Source: TGL, 21.12.11; Datum: WGS84; TD = Total Depth; FO = First Oil; BC = Base Case
Note: wellhead locations and water depths have not been finalised.
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Figure 2.4
Base Case Field Layout
Source: TGL, 2011 (00002-INT-SU-LAY-1502-001_C)
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2.6.5
Subsea Infrastructure
Subsea infrastructure will likely comprise of the following elements: subsea
manifolds (approximately ten), production and injection trees (one per well),
riser bases (approximately three), jumpers, risers, flowlines, umbilicals and an
import/export pipeline. Definitions of subsea equipment terminology are
provided in Box 2.1.
Box 2.1
Subsea Equipment: Definition of Terms
Production manifolds
Production manifolds are subsea equipment installed on the seafloor, comprised of valves and
pipes, which is as a gathering point for the produced fluids/gas from individual production
wells.
Production trees
Production trees are comprised of a set of control valves that are installed on production
wellheads to control production fluids/gas.
Jumpers, flowlines and risers
Jumpers are generally rigid insulated pipes that correct wellheads to manifolds. Flowlines are
dual insulated pipes that carry production fluids from production manifolds to riser bases or
injection water/gas from riser bases to injection manifolds. Risers carry production fluids from
the riser base on the seabed to the FPSO or injection water/gas from the FPSO to riser bases.
Water injection manifolds
A water injection manifold is a piece of equipment comprised of valves and pipes that sit on the
seafloor through which water is distributed to individual water injection wells.
Water/Gas injection trees
Water/gas injection is controlled by subsea control values (within the injection trees) connected
to the wellhead.
Umbilicals
Umbilicals are used to convey chemicals, data (control system information, pressure and
temperature) electrical power and high/low pressure hydraulic fluid supply to allow
manipulation of infrastructure valves and tree safety valves and flow chokes.
2.6.6
Oil Production Systems
Oil Production Wells
The 15 oil production wells that are planned under the base case will be tied
back to subsea production manifolds via single flowlines (see Table 2.3).
Production will be carried from the production manifolds to riser bases via
single or dual pipelines. Finally production will be carried from the riser
bases through Steel Caternary Risers (SCR) to the FPSO. Flexible risers or
free-standing riser towers may also be considered rather than SCRs.
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Production Manifolds
Production manifolds will be installed on the seafloor as a gathering point for
oil, gas and water from individual production wells. Manifolds may be
mounted on suction piles. Manifold dimensions will be confirmed during
detailed design. Typically the dimensions of each manifold are 6 m by 9 m or
54 m2, with a weight of 100 tonnes. Approximately eight subsea production
manifolds are planned in the development base case.
Production Trees
Production from individual wells will be controlled by subsea control values
(known as Christmas trees) connected to the wellhead. A horizontal subsea
tree system is currently the preferred option, however, production tree
specifications will be confirmed during detailed design. Typically, the
seafloor footprint dimensions for each production tree are approximately 5 m
by 5 m, or approximately 25 m2.
2.6.7
Water Injection System
Water Injection Wells
Water injection is planned for the Enyenra and Tweneboa fields. There will be
15 water injections wells as part of the base case development, 14 into the
Enyenra field and one in the Tweneboa field.
Water Injection Manifolds
Water will be distributed to the individual injection wells via water injection
manifolds that will be installed on the seafloor. Suction piles will be installed
to ensure manifold support and stability. SCRs will be installed ( 1 ) from the
FPSO balconies to the riser bases / central water injection distribution
manifold. From the distribution manifold, flowlines will carry water to
regional manifolds and via jumpers to individual wells. The water
distribution manifold and flowline specifications will be confirmed during
detailed design. Typically each manifold will measure approximately 6 m by
6 m or 36 m2, with a weight of 80 tonnes. Approximately two water injection
manifolds are planned in the development base case.
2.6.8
Water Injection Trees
All injection well trees will likely be enhanced horizontal subsea trees,
mounted on top of subsea wellheads in a similar manner to that employed for
the production trees. Water injection tree specifications will be confirmed
during detailed design. Typically, they have a seafloor footprint dimension of
approximately 5 by 5 m, or approximately 25 m2.
(1) Flexible risers or free-standing riser towers may also be considered rather than SCRs.
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2.6.9
Gas Production / Injection System
Gas Production / Injection Wells
Gas production and injection will occur at the Ntomme field, which is located
in the east of the development area. There will be one gas production
(Ntomme-2) and two gas injection wells (Ntomme-01 and Twneboa-3ST) as
part of the base case development.
Gas Injection Manifolds
One gas injection manifold will be installed on the seafloor as a distribution
point for injected gas to the individual injection wells. The gas injection
manifold will be supported by suction piles to provide additional support.
The gas injection manifold will be similar to the water injection manifold.
Manifold specifications will be confirmed during detailed design. Typically
each manifold will measure approximately 6 by 6 m or 36 m2, with a weight of
80 tonnes.
Gas Injection Trees
Gas production and injection trees will be similar to the water injection trees
and equipped with a modified choke design. Typically the injection trees will
weigh approximately 40 tonnes and with a seafloor footprint dimension of
approximately 5 by 5 m, or approximately 25 m2 each.
2.6.10
Injection Flowlines, Risers and Umbilicals
Water injection will be through SCRs ( 1 ) from the FPSO to an intermediate
water distribution manifold and then to the outlying manifolds via steel
flowlines. Gas injection will leave the FPSO through an SCR to a riser base.
Injection gas will then be transferred to the eastern manifold via a flowline.
Gas production will be transferred from the Ntomme-2 gas production well
via a flowline to the riser base and then via a separate SCR to the FPSO.
Umbilicals will be used to convey chemical, pressure and temperature data
and allow hydraulic manipulation of chokes and tree valves. Specifications
and dimensions of the flowlines, risers and umbilical will be confirmed during
detailed design.
2.6.11
Import/Export Pipeline
The development plan will require installation of a bi-directional 12-inch
(30 cm) gas import/export pipeline that will connect T.E.N. FPSO to Jubilee
field. The length of the pipeline will be approximately 30 km, depending on
the final route and FPSO location. The pipeline will import gas from Jubilee
for the commissioning of gas compression or handling systems at the T.E.N.
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FPSO prior to first oil. It may also be used to import fuel gas for the T.E.N.
FPSO from Jubilee. Engineering and geotechnical studies are undertaken to
determine the optimal pipeline design and route. Further details will be
provided in the EIS.
2.6.12
Oil Production Flowlines and Risers
Flowlines will carry multi-phase and commingled well streams from
individual wells and manifolds. Steel production flowlines will extend to all
production manifolds in series and convey the well streams to riser bases
located in proximity to the FPSO. SCRs ( 1 ) will connect the individual lines at
the riser bases to the FPSO at the riser balconies. Risers will be installed in the
field after FPSO installation.
2.6.13
Subsea Control Systems
All subsea hydraulically operated valves will be actuated using an electrohydraulic subsea control system. Hydraulic power, electrical power,
communication signals and production chemicals will be supplied and
distributed from the FPSO Subsea Control System through intermediate
Subsea Distribution Units (SDUs). The SDUs will be mounted on mud mats
placed on the seabed in proximity to the manifolds to distribute the weight of
infrastructure to prevent it prevent it from sinking into the seabed. Each SDU
will provide a central distribution point for the distribution of electrical,
optical and fluid services to the subsea equipment. Electric and hydraulic
leads will connect the SDUs to the subsea trees and manifolds. Dimensions of
these components will be confirmed during detailed design. Dynamic
umbilical sections will connect at the FPSO balconies and riser bases, and
static umbilical sections will connect the riser bases to the SDUs.
2.6.14
Safety Exclusion Zone
A temporary 500 m radius exclusion zone will be applied at each subsea
drilling location when the drilling vessels are present.
Permanent restricted access areas, such as advisory and exclusion zones, will
be established around offshore facilities (ie FPSO and OOB) in the T.E.N.
development area. A dedicated field vessel will be located on site to enforce
the safety exclusion zone. Seabed activity in the area will also be precluded
due to the presence of subsea infrastructure. The area that will be restricted
for all seabed activity will be determined during the final design and further
information will be provided in the EIS.
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2.7
MAIN PROJECT ACTIVITIES
2.7.1
Drilling and Completions
Four existing, and currently suspended, wells will be completed and 29 new
wells drilled and completed. A mobile offshore drilling unit (MODU), such as
the Sedco Energy (see Figure 2.5), will be used for the drilling programme.
Other drilling vessels may also be used depending on schedule and
availability.
Figure 2.5
Sedco Energy MODU
Source: Transocean, 2011
Drilling Process Description
Drilling for oil and gas uses a rotating drill bit attached to the end of a drill
pipe (the ‘drill string’) to bore into the earth to reach oil and gas deposits. For
each well to be drilled the drilling vessel will be positioned at the well
location. The first stage in drilling (known as ‘spudding’) is to place the 36
inch (90 cm) diameter casing (marine riser) between the drilling vessel and
approximately 70 m below the seabed. Once this is place drilling continues
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using a series of two to three (or more) progressively smaller diameter drill
casings eg from 16 inches (41 cm) to 12 ¼ inches (31 cm) diameter as the well
is drilled deeper. These casings will be cemented in place. Well designs will
be provided in the EIS. The rotating drill bit breaks off small pieces of rock
(called drill cuttings) as it penetrates rock strata (Figure 2.6). The cuttings
typically range in size from clay to coarse gravel and their composition will
vary depending on the types of sedimentary rock penetrated by the drill bit.
Drilling fluids (also called muds) are pumped down the drill string during
drilling to maintain a positive pressure in the well, cool and lubricate the drill
bit, protect and support the exposed formations in the well and lift the
cuttings from the bottom of the hole to the surface. Drilling fluids are slurries
of various solids and additives (used to control the fluids functional properties
such as density). For the 36 inch conductor the drilling fluids (mainly
seawater) and cuttings are discharged onto the seabed but once the surface
casing is in place the drilling fluids can be re-circulated between the drilling
vessel and the well. Returned drill cuttings and drilling fluid will be
separated and cleaned on the drilling vessel using solid control equipment
(Figure 2.7).
Figure 2.6
Circulation of Drilling Fluid during Drilling
Drill String
Drilling fluid
flows down the
drill string and
then carries up
the annulus
Borehole wall
Drill Bit
Formation being drilled
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Figure 2.7
Advanced Solid Control System including a Secondary Treatment System
Source: OGP, 2003
Types of Drilling Fluid
There are two broad categories of drilling fluid; water based fluids (WBFs)
and non-aqueous drilling fluids (NADFs). There are a wide range of types of
each drilling fluid used by the oil and gas industry around the world. For
both types of drilling fluid a variety of chemicals are added to the water or
non-aqueous liquid to modify the properties of the fluids. Additives include
clays and barite to control density and viscosity and polymers such as starch
and cellulose to control filtration. The type of drilling fluid used for a
particular well or drilling program will depend largely on the technical
requirements of the well, local availability of the products and the contracted
drilling fluid supplier. Often, both WBFs and NADFs are used in drilling the
same well. WBFs will be used to drill some sections (particularly the top
sections) of the well and then NADFs will be substituted for the deeper
sections to the bottom of the well.
NADFs are often required for particular sections of the well as they offer
better well stability (particularly when drilling through water-sensitive
formations such as primarily shales). They also offer better lubricity and high
temperature stability and reduce the formation of gas hydrates (which is a
particular issue for deep water wells). In addition, NADF use results in more
efficient drilling, and give rise to fewer drilling problems (and therefore the
requirement for remedial work thereby improving health and safety risks).
For the T.E.N. drilling programme, seawater and some WBFs will be used to
drill in the upper sections of the wellbore (including spudding) of each well
and a low toxicity NADF will be used for the mid and lower sections of each
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well. NADFs will not be discharged to sea but recycled for further use and
ultimately returned to the suppliers; however, a portion of the fluids will be
adhered to the drilling cuttings that are discharged to sea. Further
information on the composition and treatment of drilling fluid will be
Well Completions
After wells have been drilled a process known as ‘well completion’ is
undertaken to prepare the well for its operational function (ie producing well
or injector well) and to install a number of safety and operational controls,
such as produced sand filters. Completions will be undertaken from the
drilling vessel and for each well this process will take approximately 25 days.
For each well, subsurface safety valves will be installed to provide pressure
isolation and prevent pollution in the event of damage to the wellhead,
surface (mudline) isolation valves and flow control valve (subsea tree). For
producing wells downhole pressure and temperature gauges will be installed
to provide continuous data during the life of the wells. In addition, pressure
and temperature will be recorded at the subsea tree and throughout the
subsea facilities.
To prevent sand from the well face from entering the well completion, sand
control will be installed by hydraulically fracturing the reservoir rock and
placing a known size of synthetic gravel (sand) in the fractures. The gravel
prevents migration of sand into the well bore and a screen within the well
casing prevents the gravel from being transported back into the well with the
flow of hydrocarbons.
Flaring
Completion fluids such as weighted brines or acids, methanol and glycols will
be injected into the wells to clean the wellbore, stimulate the flow of
hydrocarbons, and/or to maintain downhole pressure. Upper completion and
well flowback fluids will be flared off after use. Disposal of the fluids by
burning will result in emissions to the atmosphere. In addition, inefficient
burning of reservoir fluid may result in some incomplete combustion of the
flowed hydrocarbons and potential fallout of unburned droplets to the sea
surface. Completion fluid will be flared using an efficient test burner. The
test burner will be mounted on a standard burner boom which can be
directionally swivelled according to the prevailing wind conditions.
2.7.2
Installation
FPSO and OOB
The first step will be to install four mooring clusters positioned 1,000 m from
the final FPSO location and three mooring clusters from the final OOB
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location. Each of the mooring clusters will likely consist of suction piles, chain
or polyester, spiral wire strand and a temporary support buoy.
Final setting of each anchor is expected to disturb a volume of sediment which
will be confirmed in the EIA based on the refined mooring system design.
The chain and wire segment of each mooring line is expected to disturb a
narrow zone of sediments from the anchor toward the centre of the array for a
distance of 300 to 600 m. At completion of the pre-installation, a support buoy
will support each segment prior to the FPSO hook-up. The work will be
undertaken using a pair of large (20,000 hp) anchor handling vessels (AHVs)
or Anchor Handling Tug Supply (AHTS) vessels and will last approximately
two to four weeks.
The FPSO will sail to site using its main engine which will then be
decommissioned once it is on site. Alternatively, the FPSO will be towed from
the construction yard and pre-commissioning site to the installation site by
three to five tugs. The portion of the FPSO sailing within Ghanaian waters
will last one to two days. Hook-up of the FPSO to the mooring spread will be
performed by a Dynamically Positioned (DP) construction vessel (see
Figure 2.8). The vessel will pick up the upper end of the preinstalled mooring
segments, move toward the FPSO and connect the mooring wire to the FPSO.
Figure 2.8
Typical Subsea Installation Vessel (top) and Pipelay Vessel (bottom)
Subsea Manifolds
Each of the eight subsea manifolds and thee riser bases will be installed on the
seafloor at various locations in the T.E.N. development area. The equipment
will be installed using a DP construction vessel, an AHV/AHTS outfitted with
an A-frame or a drilling vessel. Manifolds and riser bases will be mounted on
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suction piles and may be equipped with short steel extensions that will
penetrate the sediments and provide horizontal resistance to movement and
stability. The seafloor extensions of the manifolds will penetrate
approximately 3 m below the seafloor depending on the strength of the
sediments.
Flowlines and Umbilicals
Installation of the flowlines will be performed by a DP lay vessel and will
likely begin by lowering flowlines from individual production wells to the
production manifolds, then in the direction of the FPSO. The FPSO end of
each flowline will be temporarily abandoned on the seafloor in the vicinity of
the planned location of the lower end of the production riser, which will be
connected to the flowline and installed after the FPSO is moored in place.
Disturbance of seafloor sediments by flowlines will be limited to narrow
corridors. The lay vessel will be resupplied (with pipe, material and fuel)
either by supply vessel or cargo barges towed by tugs.
Installation of the control umbilicals, one to each subsea manifold, will
proceed in a manner similar to installation of flowlines and may be performed
by a special DP cable/umbilical vessel or by the same lay vessel that installs
the flowlines (Figure 2.9). Installation will likely begin by lowering the
umbilical on the seafloor within 15 to 30 m of the subsea manifold and laying
in the direction of the FPSO location. As in the case of the subsea flowlines,
disturbance of seafloor sediments by the deepwater portion of the control
umbilicals will be limited to narrow corridors.
Figure 2.9
Typical Pipeline Installation Vessel
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Risers
Installation of umbilical risers, production risers, and the gas and water
injection risers are required to complete the FPSO installation. All risers will
be suspended underneath the FPSO from two riser balconies; a DP
construction vessel will locate the temporarily abandoned terminus of each
flowline on the seafloor and raise it to the surface. The bottom end of the riser
will be connected to the terminus of the injection line. The vessel will move
toward the FPSO and will pass the top termination of the riser to the FPSO.
The FPSO will be fitted with either fixed boom or movable winches to pull
and connect the risers to the FPSO.
2.7.3
Commissioning and Start-up
Commissioning of all FPSO systems will occur to ensure compliance with
engineering completions, testing, and commissioning of fire and gas, safety
and process control systems. Commissioning and start-up will take
approximately five months. It is intended that a maximum amount of precommissioning will be undertaken at the FPSO ship yard to minimise the
amount of pre-commissioning required once the FPSO arrives on site.
2.7.4
Processing and Production
Oil Processing and Production
The well stream fluid will be stabilised and separated on board the FPSO. The
produced crude oil and condensate will be blended and stored on board for
subsequent export via export tankers. Associated gas will be processed and
used for fuel, with surplus sent into the gas injection flowline or
import/export line to Jubilee. It is envisaged that the treated produced water
will be discharged to sea, however, there is an on-going study to assess the
feasibility of produced water reinjection.
Gas Processing
Gas will be separated from production fluids, and together with produced
gas, routed to a gas treatment module. The gas treatment module design has
not been finalised but could comprise the following:



gas compression for reinjection;
gas compression for export to pipeline; or
gas for downhole gas lift (1) to improve the well stream.
Some of the gas will also be routed to the fuel gas module to be used for
power generation. In the fuel gas module the received gas will be cleaned and
compressed as required for the gas turbines to be used for power generation.
(1) Gas lift is one of a number of processes used to artificially lift oil or water from wells where there is insufficient reservoir
pressure to produce the well.
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Water Injection
The water injection system will use treated seawater injection (and produced
water reinjection subject to feasibility study – see above) to maintain reservoir
pressure. The sulphate content in the seawater may also be reduced to
eliminate the possibility of barium sulphate formation in the wells. The
injection water will be pumped at high pressure to the water injection wells in
the field.
Gas Injection, Compression and Riser Gas-lift
Primary gas injection equipment (compression, filtration, and dehydration
equipment) will be located on the FPSO in support of gas injection and riser
gas-lift. The T.E.N. development will utilise high-pressure gas from the FPSO
as injection gas to enhance ultimate recovery. Gas for riser gas-lift will be
accommodated either by using a separate, low pressure gas-lift riser that feeds
lift gas into the riser base, or by taking a side-stream off of the high pressure
gas injection riser in the riser base.
Export Tanker Operations
During the period of peak production, crude oil stored on the FPSO will be
transferred to an export tanker via the OOB approximately every 10 days,
with offloading volumes typically being approximately one million barrels of
oil. Offloading will typically require 20 hours. All crude oil transfers and
vessel movements in the T.E.N. development will be controlled via marine
terminal rules and regulations being developed by the project. Upon arrival at
the T.E.N. fields, the export tanker will be boarded by a Mooring Master
before proceeding to the loading position with the FPSO. The export tanker
will be moored to the buoy by a hawser, with fluid transfer through a floating
hose.
The FPSO will not be equipped to receive dirty ballast water from incoming
tankers. Export tankers in the T.E.N. fields for cargo transfers may only
discharge clean ballast water meeting international guidelines. The FPSO will
have permanent, separate ballast tanks and there will be routine discharge of
clean ballast water from the FPSO to maintain the proper draft during
production and cargo loading cycles.
The FPSO will have a blanket gas system, comprising of either an inert gas or
fuel gas based system. The system is intended to maintain the vapour spaces
in the FPSO cargo tanks in a stable state to avoid the potential for a fire or
explosion. The system will include equipment for the safe venting of excess
gas.
Electrical Power Generation
The electrical power generation system aboard the FPSO will consist of dual
fuel turbine generator sets that can provide sufficient electrical power to serve
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the entire facility. Precise specifications will be determined later during
detailed engineering design phase. In addition, shipside diesel engine power
generators will be installed as an essential alternative power source for
shutdown and start-up of all the processing and subsea systems. Emergency
power generation capacity will also be provided.
2.7.5
Support Operations
Marine vessel and Helicopter Support
Support vessels, including crew and supply boats, will be required to support
the T.E.N. drilling, completion, installation and production operations.
Helicopter support will also be necessary during installation and production
operations. Typical vessel and helicopter requirements are detailed in
Table 2.4.
Table 2.4
Summary of Vessel and Helicopter Support Requirements for T.E.N.
Phase
Number
Required
Drilling and Completions
AHV/AHTS
1
Support vessels
2
helicopter
1 or 2
Candidate Vessel or Aircraft
Characteristics
Frequency (round
trip per day)
60 to 75 m length, 10,000 hp
Two 60 m workboats per drilling vessels
Sikorsky S76, S-61 or S-92; Eurocopter
AS332, EC 155, AS365; Bell 212, 412
FPSO and infrastructure installation
AHV/AHTS
1
60 to 75 m length, 10,000 hp
Tow-in vessel
3 to 5
Length variable; 4,200 to 7,000 hp
Support vessel
2
85 m workboat; 8,500 hp
Pipelay vessel
1
20,000 hp
Umbilical vessel
1
16,000 hp
Helicopter
1
AS332, EC 155, AS365; Bell 212, 412
Production
FPSO
1
Specs TBA
Support vessel
1
85 m workboat; 8,500 hp
Shuttle tanker
1
1 Mbbl
Tug assist
2
4,200 hp; used as needed during mooring
Helicopter
1
AS332, EC 155, AS365; Bell 212, 412
N/A
2
4
N/A
N/A
1
N/A
N/A
1
N/A; moored
1
N/A
N/A
2
Onshore Support Locations
The onshore support location will be Takoradi, approximately 140 km inshore
of the T.E.N. fields. Takoradi has existing port operations (Figure 2.10) and
already serves as a support base for Ghana’s offshore oil industry. Additional
port facilities at the naval base at Sekondi may be required during drilling,
installation and commissioning operations.
Crew transfers will take place from the Takoradi air force base. Once the
FPSO has been installed and begins operations, a single work boat will visit
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the FPSO on a daily basis. In addition, two helicopter trips to the FPSO will be
required daily.
The locations of onshore facilities are shown in Figure 2.11.
Figure 2.10
Aerial View of Takoradi Port and Oil and Gas Support Facilities at Berth 3/4
The project may require the development of additional onshore facilities. The
EIA will provide details of any further onshore developments that are
planned as part of the T.E.N. project.
Figure 2.11
Locations of Onshore Facilities
Fabrication Yard
TGL intends to invest in Tema port (Figure 2.12) to develop the infrastructure
to provide suitable facilities for the construction of equipment for the T.E.N.
project and the oil and gas industry in Ghana in general. Currently, minimal
domestic manufacturing, fabrication capabilities exist in Ghana, therefore the
Tema yard development would represent an opportunity to generate
capability in Ghana to support the long-term development of the oil and gas
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sector in Ghana. It would also allow the use of Ghanaian goods and services
to be maximised on the T.E.N. project.
The financial viability of establishing the fabrication yard at Tema is currently
being evaluated, however, TGL has identified a potential site within the
existing port area (see Figure 2.12).
Figure 2.12
Potential Site for Fabrication Yard at Tema
TGL plans to make an initial investment at Tema port to upgrade and
refurbish the existing facilities and develop new facilities. TGL is seeking
investment from its potential subsea and FPSO contractors to further develop
the port facilities for the construction of equipment associated with the T.E.N.
development. This may include the manufacturing of the T.E.N. OOB and
subsea manifolds.
Upgrading and refurbishment work will likely involve the following.

Stabilisation of open areas within the yard to facilitate fabrication of subassemblies.

Major equipment overhauls, including re-wiring and load-testing of
gantry cranes and, where required, major equipment replacement.

Storage areas for scaffolding, new rigging and lifting equipment, and paint
and chemicals.

Open blasting facilities and equipment.

New hand tools and consumables as required.
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2.7.6

Remedial work to fabrication workshop, refurbishment of offices and
provision of new offices to suit likely workload and requirements.
Construction of a canteen facilities, changing-rooms and showers for
workers.

Replacement of electrical supply and distribution, lighting and small
power equipment.

Upgrading of communications and provision of new computer
infrastructure (hardware and software).
Decommissioning
The T.E.N. development will be decommissioned at the end of its economic
life. Field life is likely 25 years from first oil. This will involve dismantling
production and transportation facilities and restoration of the area in
accordance with license requirements and/or regulations. The wells will be
individually decommissioned using a drilling rig or well service vessel
depending on the requirements and casings will be severed 3 to 5 m below the
seabed. In each well, cement and mechanical plugs will be installed to ensure
that no hydrocarbons will be released into the environment. All subsea flow
lines and manifolds will be flushed of hydrocarbons and left in place. Where
required, equipment that could possibly interfere with marine or fishing
activities will be removed. TGL will comply with any decommissioning
conditions in the T.E.N. production permit and submit a decommissioning
plan as part of the Field Development Plan. Further information on
decommissioning will be provided in the EIS.
2.8
EMISSIONS, DISCHARGES AND WASTE
2.8.1
Emissions
T.E.N. activities, including well drilling and completion, construction of
facilities and equipment, the FPSO facility installation and operation, export
tanker operation, flowline and umbilical installation and support vessel and
helicopter operations will emit greenhouse gases and varying amounts of
other pollutants such as carbon monoxide (CO), oxides of nitrogen (NOx) and
sulphur (SOx), volatile organic compounds (VOCs) and particulate matter.
Estimated volumes will be provided in the EIS.
2.8.2
Discharges
The drilling vessel, FPSO facility and associated support vessels and export
tankers will produce a series of discharges. FPSO discharges will continue for
the life of the development. Discharges from the T.E.N. development will
result from the following activities.
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
Drilling. Drilling and support vessel operations will result in routine
discharges to sea (ie sewage, grey water, food waste, bilge water, ballast
water and deck drainage). In addition, non-routine discharges will
include drill cuttings and fluid. WBM will be used for the two top sections
and drilling fluid and cuttings will be discharged to the seabed. The
middle and bottom sections will be drilled with NADF and the drilling
vessel will use drill cuttings dryers and centrifuges to treat cuttings prior
to disposal.

Completions. Drilling and support vessels operations during well
completions will result in routine discharges (ie sewage, grey water, food
waste, bilge water, ballast water and deck drainage). In addition, nonroutine discharges will include returned completion fluids. Completion
fluids can typically include weighted brines, or acids, methanol and
glycols and other chemical systems. Completion fluids will include
completion brine, earth filter aid, surfactant and surfactant boosters.

Installation and Commissioning. Installation and pipelay vessels will result
in routine discharges during installation and commissioning (ie sewage,
grey water, food waste, bilge water, ballast water and deck drainage). In
addition, non-routine discharges will include pre-commissioning fluids
including dye, oxygen scavenger, corrosion inhibitor and biocide. When
flowlines and risers are dewatered (ie water is pumped out) after pressure
testing and treatment, Monethylene Glycol (MEG) will be pumped
through the pipelines to remove any remaining water. Anticipated
discharge volumes are reported in Table 2.5.

Operations. Routine discharges from the T.E.N. development will include
the following: produced water, black water (sewage), grey water, food
waste, deck drainage, bilge water, ballast water, brine, desulphation
system reject stream, cooling water. Non-routine discharges from the
Phase 1 development include the following: hydraulic fluid, workover
fluid, Naturally Occurring Radio-active Material (NORM) (potentially)
and hydrate inhibitor.
Anticipated discharge volumes and treatment methods will be discussed in
the EIS. TGL will develop an Environmental Mitigation and Monitoring Plan
which will be applied to all discharges in accordance with licence conditions
and EPA Guidelines for Environmental Assessment and Management in the
Offshore Oil and Gas Development (2010).
2.8.3
Noise
The FPSO, installation vessels, export tankers and support vessels will
introduce sound into the marine environment during their operation. Vessel
noise is primarily attributed to propeller cavitation and propulsion engines (ie,
noise transmitted through the vessel hull). Noise will also be produced from
equipment such as flowlines and valves. Once the specification of the vessels
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and equipment to be used is known in detail an assessment of the noise
sources can be made as part of the EIA.
2.8.4
Solid Waste
Operations will generate solid waste including paper, plastic, wood, glass and
metal. Most wastes are associated with galley and food service operations and
with operational supplies such as shipping pallets, containers. The solid
waste generated on board the drilling vessels, FPSO or support vessels will be
shipped back to the port of Takoradi where it will be reused or recycled where
possible or disposed of using EPA approved contractors. Anticipated annual
non-hazardous waste arisings produced from TGL’s operations are outlined in
Table 2.5.
Table 2.5
Anticipated Quantities of Waste Streams Generated from TGL Activities
Waste Type
State
Description
Batteries (lead acid and
small
portable/household
type)
Solid
All types of battery including lead
acid, alkali and lithium ion.
Chemicals
Liquid
Small amounts of various solvents,
paints, cleaners left over in
containers or no longer required.
1.5 – 2.0
Flammable liquids
Liquid
Solvents, thinners, paints and other
flammable liquids.
Small quantities
Fluorescent tubes and
bulbs
Solid
Lighting tubes and bulbs
0.2 – 0.3
Oily sediments / tank
bottom sludge
Sludge
/Liquid
Packing gravel, produced sand,
drill cuttings.
Un-pumpable hydrocarbon sludge.
5.0 – 10.0
Oily solids
Solid
Oily rags, used spill absorbent,
hydraulic hoses, minor quantities
of grease.
20.0 – 40.0
Plastics (non-hazardous) Solid
Radioactive waste
Tank slops
Waste Electrical and
Electronic Equipment
Solid
/Liquid
Liquids
Solid
Anticipated
Quantity
(tonnes/year)
0.25 – 0.5
Bottles and mixed plastics such as
12.0 – 30.0
pipe end caps and packing
materials. All plastics (ie types 1 to
7) are included.
NORM waste – scale build up on
None expected
FPSO and gathering network pipe. (potentially 10 to 25)
Wash water used for tank cleaning.
10.0 – 20.0
Old computers, screens, televisions,
1.0 – 1.2
fridges, air conditioning units,
instrumentation and other electrical
goods.
Source: adapted from TGL Waste Management Plan.
Document No. TGL-EHS-PLN-04-0008. June 30th 2010.
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2.9
SEAFLOOR DISTURBANCE
T.E.N. project activities will cause disturbance to the seafloor, mainly during
the drilling and installation phase. Disturbances will be caused as a result of
discharges of cuttings, and the installation of the anchoring system and the
subsea infrastructure (trees, riser bases, manifolds and flowlines). There will
also be a long-term impact as a result of the physical presence of subsea
infrastructure on the seabed. The spatial extent of seafloor disturbance will be
quantified in the EIS based on drilling discharge modelling and equipment
specifications.
2.10
PERSONNEL REQUIREMENTS AND EMPLOYMENT
Trained personnel normally accompany support vessels under contract.
Similarly, the FPSO will be manned by trained operators, technicians,
engineers and vessel crew. The requirements for employment and training,
detailed in the Petroleum Agreements will be met with regards to providing
employment opportunities for Ghanaian personnel. TGL’s current (August,
2011) staff levels are outlined in Table 2.6.
Table 2.6
TGL Staff Levels
Status
Expatriate
National
Total
Number of Employees
26
198
224
Percentage
12
88
100
Further employment opportunities will arise (both employee and
subcontractor) with the T.E.N. development, including project engineering
and project management opportunities. These estimated employment
numbers will be confirmed in the EIS.
2.11
EHS PROGRAMMES, PLANS AND PROCEDURES
The existing TGL EHS Management System (EHSMS) will apply equally to the
T.E.N. development as it does to current operations. Appropriate procedures,
plans and programmes will be applied to the T.E.N. development.
EHS management programmes, procedures and plans will be developed for
the T.E.N. development. In particular, the following procedures and plans
will apply to the T.E.N. development.

Safety Case. TGL will undertake safety case studies for the T.E.N
development. The Safety Case will set performance standards for the
Safety Critical Elements designed to manage associated risks (eg
shutdown systems) and these standards are now integrated into the
facility maintenance and testing procedures.
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
Oil Spill Response. The current Oil Spill Response Plan (OSRP) for
Jubilee will be updated to include additional response capability for T.E.N.
Oil spill response capability established in country will also be reviewed.
TGL is part of an association of operators for minor, medium and major oil
spill incidents.

Emergency Response Plan. An ERP will be developed for T.E.N. Prepositioned response teams have been established in Ghana and links to
Ghanaian government response, rescue and military agencies established.
The ERP is regularly tested by realistic emergency drills.

Incident Reporting and Investigation. Incident reporting guidelines will
be applied to the T.E.N. operations, including the project construction
yards and in-country operations.

Waste Management Plan. TGL will review their current WMP to
incorporate T.E.N. waste volumes.

Environment, Health and Safety Performance Indicators. TGL has
adopted a collection of Environmental, Health and Safety Performance
Indicators that are endorsed by the International Association of Oil and
Gas Producers. Adoption of these indicators will enable the project to
benchmark against industry and establish objectives to ensure top tier
performance.

Subcontractor Safety Compliance and Oversight. EHS performance
requirements have been, and will continue to be, inserted in the various
tender invitations that have been submitted to key subcontractors. The
responses to these requirements in the bids are an important part of the
bid evaluation and contract award processes.

Health. All employees, subcontractors and visitors will be provided with
a health induction and necessary medications, as required. Personnel will
also be required to be informed of and vaccinated against a range of
diseases identified as being prevalent. A medical support system in event
of medical incident, occupational health services and hospital support are
all in-place will be applied to the T.E.N. development.

Environmental Monitoring Plan. TGL will develop an Environmental
Monitoring Plan which is designed to address all issues (operational and
baseline) identified in the EIA. A framework monitoring plan will be

ISO 14001. TGL’s current ISO 140001 environmental management system
will be applied to the T.E.N. facilities and operations.
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3
LEGAL AND POLICY FRAMEWORK
3.1
INTRODUCTION
This chapter outlines the Ghanaian administrative framework and describes
the relevant Ghanaian legislation, international treaties and industry
standards, including International Finance Corporation (IFC) standards that
the T.E.N. development will comply with. Further information on the
applicability of legislation and standards will be provided in the EIS.
3.2
THE GHANAIAN CONSTITUTION
The Constitution of Ghana (Article 41(k) in Chapter 6) requires that all citizens
(employees and employers) protect and safeguard the natural environment of
the Republic of Ghana and its territorial waters.
3.3
ENVIRONMENTAL LEGISLATION
3.3.1
The Environmental Protection Act
The Environmental Protection Act (Act 490 of 1994) establishes the authority,
responsibility, structure and funding of the EPA. Part I of the Act mandates
the EPA with the formulation of environmental policy, issuing of
environmental permits and pollution abatement notices and prescribing
standards and guidelines. The Act defines the requirement for and
responsibilities of the Environmental Protection Inspectors and empowers the
EPA to request that an EIA process be undertaken.
3.3.2
Environmental Assessment Regulations
The EIA process is legislated through the Environmental Assessment Regulations
(LI1 652, 1999) as amended (2002), the principal enactment within the
Environmental Protection Act (Act 490 of 1994). The EIA Regulations require
that all activities likely to have an adverse effect on the environment must be
subject to environmental assessment and issuance of a permit before
commencement of the activity. The EIA Regulations set out the requirements
for the following:
•
•
•
•
•
•
Preliminary Environmental Assessments (PEAs);
Environmental Impact Assessments (EIAs);
Environmental Impact Statements (EISs);
Environmental Management Plans (EMPs);
Environmental Certificates; and
Environmental Permitting.
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Schedules 1 and 2 of the Regulations provide lists of activities for which an
environmental permit is required and EIA is mandatory, respectively.
3.3.3
Environmental Guidelines
The EPA has issued formal guidance on regulatory requirements and the EIA
process. The following documents are relevant to the EIA process and the
project:

EPA Guidelines for Environmental Assessment and Management in the
Offshore Oil and Gas Development (2010);

Environmental Assessment in Ghana, a Guide (1996) to Environmental
Impact Assessment Procedures (1995);

Environmental Quality Guidelines for Ambient Air (EPA);

Sector Specific Effluent Quality Guidelines for Discharges into Natural
Water Bodies (EPA); and

General Environmental Quality Standards for Industrial or Facility
Effluents, Air Quality and Noise Levels.
The EPA guidance for offshore oil and gas development states that the
proponent is required to undertake a PEA for small to medium impact scale
undertakings and a full EIA for field development and production activities.
3.4
PETROLEUM LEGISLATION
National petroleum related legislation includes the following.

The Ghana National Petroleum Corporation Act (Act 64 of 1983) established
the Ghana National Petroleum Corporation (GNPC) as mandated to
promote exploration and planned development of the petroleum resources
of the Republic of Ghana.

The Petroleum (Exploration and Production) Law (Act 84 of 1984) establishes
the legal and fiscal framework for petroleum exploration and production
activities in Ghana. The Act sets out the rights, duties and responsibilities
of contractors; details for petroleum contracts; and compensation payable
to those affected by activities in the petroleum sector.

The National Petroleum Authority Act (Act 691 of 2005) establishes the
National Petroleum Authority (NPA) of Ghana to regulate, oversee and
monitor downstream petroleum activities.
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3.5
MARITIME LEGISLATION
National maritime legislation includes the following.
3.6

The Maritime Zones (Delimitation) Law (PNDCL 159 of 1986) defines the
extent of the territorial sea and Exclusive Economic Zone (EEZ) of Ghana.
The territorial sea is defined as those waters within 12 nautical miles (nm)
(approximately 24 km) of the low waterline of the sea. The Law defines
the EEZ as the area beyond and adjacent to the territorial sea less than
200 nm (approximately 396 km) from the low waterline of the sea.

The Fisheries Act (Act 625 of 2002) repeals the Fisheries Commission Act (Act
457 of 1993) to consolidate and amend the law on fisheries. The Act
provides for the regulation, management and development of fisheries
and promotes the sustainable exploitation of fishery resources. Section 93
of the Fisheries Act stipulates that if a proponent plans to undertake an
activity which is likely to have a substantial impact on the fisheries
resources, the Fisheries Commission should be informed of such an
activity prior to commencement. The Commission may require
information from the proponent on the likely impact of the activity on the
fishery resources and possible means of preventing or minimising adverse
impacts.

The Fisheries Regulation (LI 1968 of 2010) further sets up the specific rules
and regulations for the implementation of the Fisheries Act (Act 625 of
2002). The regulations address prohibited fishing methods (eg lights to
attract fish, explosives and poisons, and pair trawling), fishing within oil
and gas infrastructure exclusion zones, minimum mesh sizes, the use of
Fish Aggregating Devices (FADs), and fishing vessel licensing
requirements.
POLLUTION CONTROL
There is currently no single integrated pollution legislation in Ghana.
Pollution control exists as part of the environmental and water resource
legislation and marine pollution is dealt with by the Oil in Navigable Waters Act
(Act 235 of 1964) (see below). The Act makes the discharge of any oil or
mixture containing oil from any vessel or from land an offence.
3.7
RADIATION PROTECTION INSTRUMENT
The Radiation Protection Instrument 1993 (LI 1559) establishes the Radiation
Protection Board, which licenses importers and users of radioactive material
and instrumentation. The Board is responsible for ensuring operations
relating to devices that use radioactive materials are carried out without risk
to the public health and safety and the installations and facilities are designed,
installed, calibrated and operated in accordance with prescribed standards.
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3.8
PROTECTION OF COASTAL AND MARINE AREAS
Ghana subscribes to a number of international conservation programmes,
however, Ghana has at present no nationally legislated coastal or marine
protected areas and there are no international protection programmes
specifically covering the project area. The Wetland Management (Ramsar Sites)
Regulations 1999 are made under the Wild Animals Preservation Act 1961 (Act
43) and provide for the establishment of Ramsar sites within Ghana. There are
five designated Ramsar wetland sites along the coast of Ghana including: Keta
Lagoon Complex; Densu Wetland; Muni-Pomadze; Sakumo; and Songor.
There is a sixth Ramsar site (Owabi Wildlife Sanctuary) situated inland.
Ghana also has one UN Biosphere Reserve and two World Heritage
Convention sites. The World Heritage Convention sites include the Asante
Traditional Buildings, located near Kumasi, as well as Forts and Castles, most
of which are located along the coast in the Central and Western Regions
(UNESCO, 2009). Ghana has more than 1,000 IUCN-management protected
areas including 317 Forest Reserves, five Game Production Reserves, seven
National Parks, two Resource Reserves, one Strict Nature Reserve, and four
Wildlife Sanctuaries (Earth trends, 2003).
3.9
STATE, CONVENTIONS AND CLASSIFICATION REQUIREMENTS
The regulatory requirements for an offshore vessel are generally set out by the
coastal state or shelf state, the flag state, international conventions and the
classification society. The drilling vessel(s) and FPSO need to satisfy all of the
requirements from these authorities before it is approved fit for purpose.
3.9.1
Coastal State Regulations
All countries have full sovereignty to regulate activities on their continental
shelves. As the drilling vessel(s) and FPSO will be operational on Ghana’s
continental shelf, Ghana regulations, as administered by the Ghana Maritime
Authority, are the governing regulations and take precedence over all flag
state and class requirements. However, many jurisdictions, including Ghana,
refer to maritime codes, rules and standards related to flag and classification
requirements as described below.
3.9.2
Flag State Regulations
Ships or offshore facilities trading internationally have to comply with the
safety regulations of the maritime authority from the country whose flag the
unit is flying. A drilling vessel or FPSO does not need a flag unless required
by the coastal state (ie GMA in Ghana) or when in transit through
international waters. The drilling vessel and FPSO will be flagged. Flag states
require classification and implementation of the safety regulations such as
those of the International Maritime Organisation (IMO).
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3.9.3
Classification Societies
The drilling vessel(s) and FPSO will be classed by a classification society that
is recognised by the maritime administrator of the flag state, such as the
American Bureau of Shipping (ABS) or Det Norske Veritas (DNV).
3.10
RELEVANT INTERNATIONAL AGREEMENTS AND CONVENTIONS
3.10.1
United Nations Convention on the Laws of the Sea
Ghana is signatory to the United Nations Convention on the Laws of the Sea
(UNCLOS). Under this convention Ghana claims rights within 12 nm of
territorial water and a 200 nm Exclusive Economic Zone (EEZ). Clearance for
project vessels travelling into the territorial waters (eg to and from the onshore
base) must be obtained from the Ghana Maritime Authority (GMA) and
notification should also be made to the Ghanaian Navy.
3.10.2
International Maritime Organisation Conventions
Ghana is signatory to the following International Maritime Organisation
(IMO) Conventions.

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 for the Prevention of Marine Pollution from
Ships, 1973, as modified by the Protocol of 1978 relating thereto (MARPOL
73/78).

International Convention of Oil Preparedness, Response and Co-operation
(OPRC), adopted 1990.
Further details of the MARPOL Convention and the OPRC Convention are
provided below.
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The MARPOL Convention
The International Convention for the Prevention of Pollution from Ships
(MARPO L 73/78) contains a number of the provisions relevant to the project.
These include general requirements regarding the control of waste oil, engine
oil discharges as well as grey and black waste water discharges. Table 3.1
provides a list of MARPOL provisions relevant to oil and gas developments.
Annexes I and II were ratified first and in 2010, Ghana ratified the remaining
Annexes III to V which will come into force in January 2011. The draft Marine
Pollution Bill to will adopt the remaining three annexes of the MARPOL
standards into Ghanaian legislation but is yet to be enacted.
Table 3.1
MARPOL 1973/1978 Provisions Relevant to Oil and Gas Exploration
Environmental
Aspect
Drainage water
Provisions of MARPOL 1973/1978
Annex
Ship must be proceeding en route, not within a 'special area'
and oil must not exceed 15 parts per million (ppm) (without
dilution). Vessel must be equipped with an oil filtering
system, automatic cut-off and an oil retention system.
I
Accidental oil
discharge
Shipboard Oil Pollution Emergency Plan (SOPEP) is
required.
I
Bulked chemicals
Prohibits the discharge of noxious liquid substances,
pollution hazard substances and associated tank washings.
Vessels require periodic inspections to ensure compliance.
All vessels must carry a Procedures and Arrangements
Manual and Cargo Record Book.
II
Sewage discharge
Discharge of sewage is permitted only if the ship has
approved sewage treatment facilities, the test result of the
facilities are documented, and the effluent will not produce
visible floating solids nor cause discoloration of the
surrounding water.
IV
Garbage
Disposal of garbage from ships and fixed or floating
platforms is prohibited. Ships must carry a garbage
management plan and shall be provided with a Garbage
Record Book.
V
Food waste
Discharge of food waste ground to pass through a 25 mm
mesh is permitted for facilities more than 12 nm from land.
V
Air pollutant
emissions
Sets limits on sulphur oxide and nitrogen oxide emissions
from ship exhausts and prohibits deliberate emissions of
ozone-depleting substances including halons and
chlorofluorocarbons. Sets limits on emissions of nitrogen
oxides from diesel engines. Prohibits the incineration of
certain products on board such as contaminated packaging
materials and polychlorinated biphenyls.
VI
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3.10.3
Other Conventions and Treaties
Ghana has also ratified the following international conventions and treaties
which may be applicable to the project.

Africa Convention on the Conservation of Nature and Natural Resources
(15 September 1968).

African Charter on Human and Peoples' Rights (Acceded 24 January
1989).

Convention Concerning the Protection of World Cultural and Natural
Heritage (16 November 1972).

Convention on Biological Diversity, 1992.

Convention on the Ban of the Import into Africa and the Control of
Transboundary Movement of Hazardous Wastes within Africa - Bamako
Convention (December 1991).

Convention on the Conservation of Migratory Species of Wild Animals
(23 June 1979).

Convention on Wetlands of International Importance, Especially as
Waterfowl Habitats (2 February 1971).

Framework Convention on Climate Change (June 1992).

International Convention for the Conservation of Atlantic Tunas (4 May
1966).

International Convention on Civil Liability for Oil Pollution Damage (29
November 1969).

International Convention on Oil Pollution Preparedness, Response and
Co-Operation, 1990 (2 June 2010).

International Convention on the Establishment of an International Fund
for Compensation of Oil Pollution Damage (18 December 1971).

International Covenant on Civil and Political Rights (7 September 2000).

International Covenant on Economic, Social and Cultural Rights (7
September 2000).

Montreal Protocol on Substances that Deplete the Ozone Layer (24 July
1989).
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3.11

Supplementary Convention on the Abolition of Slavery, the Slave Trade,
and Institutions and Practices Similar to Slavery (1956).

The Convention on the Control of Transboundary Movements of
Hazardous Wastes and their Disposal (Basel Convention) (30 May 2003).

The 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 (23 March 1981).
GOOD PRACTICE STANDARDS AND GUIDELINES
This section outlines good practice standards and guidelines that the T.E.N.
project will comply with.
3.11.1
IFC Performance Standards
The International Finance Corporation’s (IFC) Sustainability Framework
includes Performance Standards (PSs) on environmental and social
sustainability. The T.E.N. project has committed to complying with the
updated 2012 edition of IFC’s PSs throughout the implementation of the
project.
All eight of the IFC PSs need to be applied to funded projects, however, for the
T.E.N. development the following are considered to be the directly relevant
PSs:

PS1: Assessment and Management of Social and Environmental Risks and
Impacts;

PS2: Labour and Working Conditions;

PS3: Resource Efficiency and Pollution Prevention;

PS4: Community Health, Safety and Security; and

PS6: Biodiversity Conservation and Sustainable Management of Living
Natural Resources.
Additional guidance is contained in the Guidance Notes to the Performance
Standards. The IFC’s set of Guidance Notes corresponds to the PSs and
provide guidance on the requirements contained in the PSs, including
reference materials and on good sustainability practices to improve project
performance.
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3.11.2
IFC Environmental, Health and Safety (EHS) Guidelines
The EHS Guidelines are technical reference documents that address IFC’s
expectations regarding the industrial pollution management performance of
projects. They are designed to provide relevant industry background and
technical information. This information supports actions aimed at avoiding,
minimising, and controlling EHS impacts during the construction, operation,
and decommissioning phase of a project or facility.
The updated EHS Guidelines serve as a technical reference source to support
the implementation of the IFC PSs, particularly in those aspects related to PS3:
Resource Efficiency and Pollution Prevention, as well as certain aspects of
occupational and community health and safety.
The general EHS Guidelines contain information on cross-cutting
environmental, health, and safety issues potentially applicable to all industry
sectors and should be used together with the relevant IFC industry sector
guidelines. For the T.E.N. development, the relevant EHS Guidelines that
would apply are:




3.11.3
EHS General Guidelines;
EHS Guidelines for Offshore Oil and Gas Development;
EHS Guidelines for Shipping; and
EHS Guidelines for Crude Oil and Petroleum products Terminals.
Other Standards and Guidelines
There are several industry good practice standards and guidelines for offshore
oil and gas developments. Those of relevance to the project include the
following.

IPIECA (2004). Guide to Social Impact Assessment in the Oil and Gas
Industry.

IPIECA (2011). Guidance on Improving Social and Environmental
Performance: Good Practice Guidance for the Oil and Gas Industry.

OGP (1993) Waste Management Guidelines.

OGP (1997). Environmental Management in Oil and Gas exploration and
Production.
OGP (2005). Guide to Health Impact Assessments in the Oil and Gas
Industry.


OGP (2007). Environmental-Social-Health Risk and Impact Management
Process.
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
3.12
OGP (2010). HSE Management Guidelines for Working Together in a
Contract Environment.
PROJECT ENVIRONMENTAL STANDARDS AND GHANA INDUSTRY STANDARDS
The following project standards are based on the Ghana EPA guidance and
MARPOL, and good industry practice such as OSPAR (Oslo and Paris
Conventions for the protection of the marine environment of the North-East
Atlantic) and International IFC EHS Guidelines (IFC, 2007a and 2007b).
3.12.1
Project Environmental Standards
Table 3.2 below provides industry good practice standards applied to effluent
levels from offshore oil and gas operations. These are based on MARPOL and
OSPAR standards and are proposed by TGL for this project. These standards
are also in line with the effluent guidelines in the EPA Guidelines for
Environmental Assessment and Management in the Offshore Oil and Gas
Development (2010).
Table 3.2
Industry Good Practice Standards for Effluent Discharges
Source
Bilge Water
Completion and
Workover Fluids
Cooling Water
Deck Drainage
Desalination brine
Drilling fluid
Food Waste
Hydrotest water
Produced water
Produced sand
Sewage
Storage Displacement
Water (Ballast Water)
Industry Good Practice Standards
Treat to 15 ppm oil concentration as per MARPOL 73/78 Annex I
requirements.
Oil and grease not to exceed 42 mg/l daily maximum and 29 mg/l monthly
average. Any spent acids will be neutralised (to attain a pH of 5 or more) as
per IFC EHS Guidelines.
The effluent should result in a temperature increase of no more than 3°C at
the edge of the zone where initial mixing and dilution take place. Where the
zone is not defined, use 100 m from point of discharge as per IFC EHS
Guidelines.
requirements.
Mix with other discharge streams if feasible
Enhanced cuttings treatment to reduce oil on cuttings to less than 3% as a
weighted average. Use of low toxicity (Group III) NADF, no free oil, limits
on mercury (max 1 mg/kg) and cadmium (max 3 mg/kg) concentrations.
Discharge via a caisson at least 15 m below sea surface.
Macerate to acceptable levels and discharge in compliance with MARPOL
73/78 Annex V requirements.
Discharge offshore following environmental risk analysis, careful selection
of chemicals and reduce use of chemicals as per IFC EHS Guidelines.
Oil and grease not to exceed 42 mg/l daily max and 29 mg/l monthly
average as per IFC EHS Guidelines.
No discharge unless residual oil less than 1% by weight on dry sand as per
IFC EHS Guidelines.
Treat with approved marine sanitation unit (achieves no floating solids, no
discolouration of surrounding water) as per MARPOL Annex IV
requirements. Minimum residual chlorine of 1 mg/l as per IFC EHS
Guidelines.
requirements.
Note: MARPOL 1973/1978 = International Convention for the Prevention of Pollution from Ships
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Underwater Noise Levels
The IFC guidelines for minimising underwater noise are applicable to the
offshore oil and gas exploration including drilling activities and offshore and
near shore structural installations, eg seismic surveys, pile driving,
construction activities and marine traffic. These guidelines recommend the
following measures to reduce the risk of noise impact to marine species.

Identifying and avoiding areas sensitive for marine life such as feeding,
breeding, calving, and spawning areas.

Planning seismic surveys and offshore construction activities around
sensitive times of the year (eg breeding season).

Identifying fishing areas and reducing disturbance to these areas by
planning for seismic surveys and construction activities to be undertaken
at less productive times of the year, where possible.

Reducing operation time, where possible.

Monitoring the presence of sensitive species (if expected to be in the
project area) before the onset of noise creation activities and throughout
the seismic program or construction. Experienced observers should be
used where significant impacts to sensitive species are anticipated.
It is noted that a number of these measures are intended for noisy operations
such as seismic surveys and pile driving that are not part of the T.E.N.
development activities.
3.12.2
Ghana Oil and Gas Industry Standards
TGL is adopting the Ghana Standards Board’s Oil and Gas Industry Standards
as a set of recognised standards for the T.E.N. project.
3.13
LEGISLATION UNDER PREPARATION
It is recognised that in view of the developing petroleum exploration and
production industry, the Ghanaian government is drafting new environmental
and marine regulations and guidelines, which are now at the stage of revision
by the Parliament. These include the following.

Hazardous Waste Regulations, 2012.

Marine Pollution Bill, 2010.

Maritime Security (Amendment) Act 2010.

Offshore Petroleum (Health and Safety) Act, 2010.
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
Offshore Petroleum (Maritime Fees and Charges) Regulations 2010.

Offshore Petroleum (Maritime Pollution, Prevention, Control) Regulations
2010.

Shipping (Safety Zone and Pipeline Protection Area) Regulations, 2010.

Shipping Amendment Bill, 2010.
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4
EIA PROCESS AND SCOPING
4.1
THE EIA PROCESS
EIA is a systematic process that identifies and evaluates the potential impacts
a proposed project may have on the physical, biological, chemical, social and
human health environment and develops mitigation measures that will be
incorporated in order to eliminate, minimise or reduce these impacts.
This EIA process for the T.E.N. development is aligned with the requirements
of the Environmental Assessment Regulations (1999) and Environmental
Assessment in Ghana Guidelines (1995). The overall process and schedule for
applying for an Environmental Permit (EP) is shown schematically in
Figure 4.1.
This section outlines steps that have been completed as part of the EIA
Screening and Scoping phases. Activities that are proposed for the next
phases of the EIA are outlined in Terms of Reference in Chapter 8.
4.2
PROJECT REGISTRATION
Undertakings likely to have significant impacts on the environment (eg those
listed in Schedule 2 of the Environmental Assessment Regulations) must
register with the EPA and obtain an environmental permit before
commencement of construction and operations. The proposed T.E.N. project
was registered on 4 March 2011 with registration number EPA-CE-1828-02057.
4.3
PROJECT SCREENING
According to the Environmental Assessment Regulations, within 25 days from
the time a registration form is received the EPA will place the development at
the appropriate level of assessment. The EPA has determined that the
development falls into the category of undertakings (Regulation 3) for which
full EIA is required. This scoping report has been completed in line with
Regulation 11 of LI l652.
4.4
SCOPING PHASE
A principal objective of the scoping phase is to identify environmental, social
and health sensitivities and those project activities with the potential to
contribute to, or cause, impacts to the environmental and social receptors. At
the scoping stage the key issues are identified and understood to a level which
allows the remainder of the impact assessment to be planned. This enables
the resources for the EIA to be focused on collecting required information and
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identifying significant impacts and carrying out stakeholder engagement
activities in an effective and efficient manner.
Figure 4.1
Overview of the EIA Process
Submission of Project EIA Form
EIA Required
Resubmit
Screening
EP Declined
EP Issued
Inspection
PER Required
EP Issued
PER Review
25 Working Days
EIA Required
Scoping and TOR
TOR Revision Required
TOR Review
25 Working Days
EIA
EIS Revision Required
Submission of Draft EIS
Draft EIS Review
Public Hearing
Hearing Required
EPA Decision
75 Working Days
EP Issued
EP Declined
15 Working Days
Process Total
90 Working Days
The objectives of the scoping phase are to:

develop an understanding of the legislative, environmental,
socioeconomic and health context for the project;

identify stakeholders and plan or initiate communication with these
stakeholders;

identify potential significant impacts; and
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
develop the Terms of Reference for the EIA for approval by the Ghanaian
authorities.
The following tasks have been undertaken in the EIA Scoping phase.
4.4.1
Data Review and Desk Studies
This task comprised the following:

develop an outline description of the planned project activities;

undertake a review of relevant legislative and guidance;

identify sources and review secondary data; and

develop a stakeholder engagement plan and undertake consultations of
the Scope of the EIA.
Project Description
The project description in Chapter 2 of this EIA Scoping Report provides an
overview of the various project components, phases and activities to a level
that allows those activities with the potential to cause environmental, social
and health impacts to be identified (eg physical presence, noise, emissions,
wastes and discharges). Project planning, decision making and refinement of
the project description will continue throughout the assessment process as a
result of the development of the project and in response to the identified
impacts.
Initial Legislative Review
Chapter 3 of this EIA Scoping Report provides a review of legislation and
industry guidance relevant to the EIA for the proposed T.E.N. development.
Secondary Data Collection
Existing baseline information on the environmental and socioeconomic
context of the project area has been collected and reviewed and sources of
other existing information identified. The EIA team has undertaken an initial
review of existing information sources that contributed to an understanding of
the environmental and socioeconomic context of the project (see Chapter 6).
Available data sources have been identified for the following subjects.

Physical environment: oceanography, climate, geology, topography,
bathymetry, sediment/water quality.

Biological environment: benthos, fish, birds, marine mammals, turtles and
significant natural sites.
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
Socio-economic environment: fisheries, demographics and others from
census.
This secondary data review also focussed on identifying where gaps in
information exist and informed the data gathering requirements and the
Terms of Reference for the remainder of the EIA.
Stakeholder Engagement Plan
Project stakeholder engagement started at the EIA Scoping stage and will
continue throughout the assessment and through operations to ensure that
legislative requirements are met, stakeholder concerns are addressed and that
sources of existing information are identified. To ensure that engagement is
undertaken in a systematic manner and acts to improve the EIA process and
build relationships whilst managing expectations, the EIA team has developed
a plan for engaging stakeholders.
4.4.2
Stakeholder Engagement Visit
A series of consultation meetings with national stakeholders in the Accra and
stakeholders in the Western Region were undertaken to provide project
information, collect baseline data and understand key stakeholder concerns.
Details on these consultations and issues raised are provided in Chapter 5.
4.4.3
Preparing the Scoping Report
This Scoping Report, including Terms of Reference, has been compiled as part
of the EIA process in accordance with the regulatory requirements stipulated
in the Environmental Assessment Regulations (1999).
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5
SCOPING STAKEHOLDER ENGAGEMENT
5.1
INTRODUCTION
This section provides a description of the steps undertaken in the stakeholder
engagement process followed during the EIA Scoping study to date.
Stakeholder engagement activities planned for the remainder of the EIA are
outlined in Chapter 8.
5.2
OBJECTIVES
The aim of TGL’s stakeholder engagement strategy is to ensure a consistent,
comprehensive and coordinated long-term approach to stakeholder
consultation for its hydrocarbon production activities in Ghana. Within this
overall strategy the objectives of stakeholder engagement during EIA Scoping
consultations are to:
5.3

identify potential key stakeholders;

develop consultation tools (eg the stakeholder register);

consult with key stakeholders and introduce the project, obtain baseline
data and identify key issues;

produce a Scoping Report and Terms of Reference;

disclose the Scoping Report to Ministries and general public; and

obtain comment on the Scoping Report to inform the EIA.
STAKEHOLDER ENGAGEMENT ACTIVITIES
To date, 193 stakeholders have been contacted regarding the study and
provided with information on the T.E.N. development.
5.3.1
Stakeholder List
A list of key stakeholders was compiled from previous projects in the area and
by identification of new stakeholders through the stakeholder engagement
process. These stakeholders were selected on the basis that they would have
an interest in the project and would also have knowledge through which to
provide insight into possible issues and concerns related to the project. In
addition, some of the stakeholders that were engaged with had strong
connections to potentially affected local communities. A list of stakeholders
consulted to date is provided in Annex A.
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5.3.2
Notifications
A Background Information Document (BID) was distributed to stakeholders
during scoping consultations. A copy of the transmittal letter and the BID is
provided in Annex B. The BID provides an overview of the project and
outlines the key environmental and social issues that had been identified. It
also outlined ways through which additional issues and comments could be
raised with TGL and the EIA team.
5.3.3
Consultation Meetings
During scoping, a total of 26 meetings have been held with 28 stakeholder
groups or organisations (see Table 5.1). Stakeholders included national,
regional and district authorities, traditional leadership, Non-Governmental
Organisations (NGOs), the media, international organisations and fisher
association.
Table 5.1
Scoping Consultation Meetings (October/ November 2011)
#
1
2
3
4
5
6
7
8
9
10
11
12
13
14
15
16
17
18
19
20
21
22
23
24
25
26
27
28
Organisations / Groups
Environmental Protection Agency
Fisheries Commission
Current Large Marine Ecosystem (GCLME)
Ghana Maritime Authority
Wassa Association of Communities Affected
by Mining
Marine Fisheries Research Department
Ghana Navy
Wildlife Department Forestry Commission
Ghana National Canoe Fishermen Council
National Fisheries Association of Ghana
Ricerca e Cooperazione
Friends of the Earth
Environmental Protection Agency (regional)
Sekondi Takoradi Metropolitan Assembly
Friends of the Nation
Coastal Resource Centre
Ghana Ports and Harbours Authority
Western Region Chief Fishermen
Ahanta West District Assembly
Ghana Tourism Board
Ellembelle District Assembly
Nzema East Municipal Assembly
Jomoro District Assembly
Western Region House of Chiefs
Media (The Enquirer, Ghanaian Times, Daily
Guide, Daily Graphic, Beach FM, Aseda FM)
Ghana Wildlife Society
Shama District Assembly
Regional Fisheries Commission
Date
17 October 2011
18 October 2011
18 October 2011
18 October 2011
18 October 2011
Location
Accra
Accra
Accra
Accra
Accra
Attendees
6
1
2
1
1
18 October 2011
18 October 2011
19 October 2011
19 October 2011
19 October 2011
20 October 2011
20 October 2011
21 October 2011
21 October 2011
26 October 2011
26 October 2011
21 October 2011
22 October 2011
24 October 2011
24 October 2011
25 October 2011
25 October 2011
26 October 2011
27 October 2011
27 October 2011
Accra
Accra
Accra
Accra
Accra
Accra
Accra
Sekondi
Sekondi
Sekondi
Sekondi
Takoradi
Takoradi
Agona
Takoradi
Nkroful
Axim
Half Assini
Sekondi
Sekondi
1
1
4
3
1
1
2
2
12
5
2
2
43
12
1
14
14
12
32
6
11 November 2011
24 November 2011
30 November 2011
Accra
Shama
Takoradi
Total
2
9
1
193
Attendance registers were completed by those that participated in each
consultation meeting that was carried out during EIA Scoping. The
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consultation team also included translators who speak Fante and Nzema so
that the key elements of the project and the main issues arising could be
discussed with non English speaking stakeholders. Notes of the consultation
meetings, attendance registers and written comments received are provided in
Annex C.
5.3.4
Summary of Comments Emerging from Scoping Consultations
A summary of comments raised during the Scoping consultations are
provided in Table 5.2. These comments have been recorded and considered in
developing the Terms of Reference for the EIA (see Chapter 8). A full list of
issues raised during Scoping consultations is provided in an issues trail in
Annex D.
Table 5.2
Summary of Issues
Consultation / Disclosure

Suggestion for additional TGL communication at local level (ie with communities in the
Western Region) also prior to Public Hearings. EPA also suggested they may need to take
part in these consultations. Concern was expressed that communication with leadership is
not always conveyed to fishermen and members of communities.

Suggestion for TGL to communicate findings of the EIA to communities (eg disclose non
technical summary) in a simple, understandable format to help communities understand
the implications of the project.

Requirement for adequate time to review Scoping and EIA Report.

Indications that Public hearings will be required for the project.
Jubilee commitments

Have the Jubilee EIA mitigation measures been implemented?

A fisheries liaison person has not been appointed as required by the Jubilee EIA.

Concern that CSR efforts are not aligned with District development plans (eg drilling of
boreholes which deviated from district development priorities).

Lack of ongoing consultation at a local level with community members.
Incremental Development and Increased Pressure on Infrastructure

Uncontrolled development in Western Region with impacts on natural and heritage
resources.

Increased traffic in Takoradi and affects of HGVs on road integrity.

Increased pressure on port facilities due to increased oil and gas operations.

Concern over availability of water for more projects and industrial development in the
Region.
Interaction with Fisheries

Perceived impact of oil and gas activities on fishermen’s livelihood through:
 decline in fish stocks from pollution or ‘attracting’ fish to offshore installations; and
 restriction of fishing in safety zone.

Conflict with fishermen due to enforcement of safety zone and confiscation of fishing gear.

Damage to fishing nets from support vessels.

Alternative livelihoods (eg aquaculture) for fishermen due to declining fish stock and
perception that oil and gas activities are worsening the situation.

Request that Fisheries Impact Assessment be undertaken to address fisheries issues.
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Cumulative Impacts

Effect of additional restriction of fishing in safety zones due to additional oil and gas
operations.

Cumulative impact of new project with current and other ongoing oil and gas activities on
air quality, water quality and marine ecology.

Cumulative impact of expanding oil and gas industry with other industries on protected
areas, land use and water requirements.
Secondary Socio-economic Effects

Influx of foreigners for work in Takoradi.

Influx of people to seek work opportunities, sometimes leading to unemployment.

Increase in crime rates due to unemployment.

Increase in undesired social behaviour (eg prostitution).

Increased cost of living and housing in Western Region. For example, workers in oil
industry pay higher rent therefore landlords evict current tenants.

Increased demand for hotel accommodation and conferencing facilities in Takoradi
(positive).
Increase Risk of Oil Spill and Compensation

Concern over oil spill risk and limited response capabilities.

Compensation for coastal communities (especially fishermen) in case of an oil spill. It was
said that currently there is no local compensation plan (eg inventory of fishermen and
vessel, catch rates etc) if an oil spill happens.

Coordination with other stakeholders on oil spill response, eg fishermen and port operators
need to know what to do in case of a spill.
Employment and Income

Expectation of employment in oil industry (despite few opportunities available).

Requirement for preference to employ people from coastal districts rather than employing
people from elsewhere in Ghana.

Expectations to receive royalties for coastal districts as these districts are located closest to
the oil fields.
Education and Training

Concern over institutions providing training that is not recognised by oil industry.

Requests for scholarships (for children of fishermen and youth from Region in general).

Technical training so that youth can be employed in oil industry.

Concern that too many people will be trained and not enough jobs.
Communication and Managing Expectations

Requirement for Tullow presence in coastal districts. For example, people from remote
communities feel they cannot communicate with TGL regarding concerns or to obtain
information.

Need for ongoing communication with communities about Tullow operations.

Communities want to understand what is happening at the oil field as they cannot see it
from land.

Need for CLOs in communities with whom community members can communicate.
Request that a dedicated Fisheries Liaison is appointed.

Requirement to receive Jubilee monitoring results to District Assemblies (eg compliance of
discharges and waste management with standards).
Transboundary Impacts

Impacts that could affect Cote d’Ivoire from discharges and potential oil spills due to
proximity to maritime boundary.

Security issues and dispute over maritime boundary for oil resources.
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Discharges to Sea

Impacts to water quality, marine fauna and human health due to discharges to sea.

Ballast water discharge and potential biological contamination. There is concern that
ballast water will have an effect on fish and pollute the marine environment.

Algal bloom (green-green) in water and on beach (believed oil operations are causing this).

Perceived risk of sea level rise due to produced water and oil and gas infrastructure and
subsequent coastal erosion.
Air Emissions

Effect of emissions on air quality and impacts to human health.

Perceived effect of flaring on human health. Belief that flaring is causing a skin rash and
swelling of eyes.
Accidental Events

Concern over capability to respond to large scale emergency event (eg fire).

Requirement to upgrade health facilities and emergency services in Western Region to
respond to emergency event.
Waste Disposal

Lack of facilities for receiving increased waste volumes.

Concern over contamination of land due to disposal of hazardous waste.
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6
ENVIRONMENTAL AND SOCIAL BASELINE
6.1
INTRODUCTION
This chapter provides a brief description of the current environmental and
socio-economic baseline. It presents an overview of the aspects of the
environment relating to the surrounding area in which the development take
place, ie within the project ‘footprint’, and which may be directly or indirectly
affected by the proposed project. This includes the DWT block, including the
T.E.N. fields, the Ghana marine environment at a wider scale and the districts
of the Western Region bordering the marine environment.
The DWT block and its regional setting are shown in Figure 6.1. The project
area is approximately 140 km west-southwest of the city of Takoradi, 50 km
from the nearest shoreline of Ghana, and 30 km west of the Jubilee Field.
This chapter summarises information from previous baseline descriptions
from the Jubilee EIS (TGL, 2009). The baseline description will be updated
during the EIA with other more recent primary and secondary data, including
the T.E.N. Environmental Baseline Survey (EBS) (see Chapter 8).
6.2
ENVIRONMENTAL BASELINE
6.2.1
Climate
The regional climate is controlled by two air masses: one over the Sahara
desert (tropical continental) and the other over the Atlantic Ocean (maritime).
These two air masses meet at the Inter-Tropical Convergence Zone (ITCZ).
During the boreal winter, the tropical continental air from the northern
anticyclone over the Sahara brings in north-easterly trade winds which are dry
and have a high dust load. During the boreal summer, warm humid maritime
air reaches inland over the region. In general, the region is characterised by
two distinct climatic periods, namely the dry and wet seasons. The peak of
the rainy season occurs from May to July and again between September and
November. The maximum northern location of the ITCZ between July and
August creates an irregular dry season over the region, whereby rainfall and
temperatures decline.
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3°0'0"W
2°30'0"W
2°0'0"W
KEY:
DWT Block
!
!
!
!
Cote d'Ivoire
!
Jubilee Unit Area
EAF Nansen 2009
Survey Stations
!
(
TDI Brooks 2008
Survey Stations
Ghana
!
(
5°0'0"N
!
(
GW1
GW2
GP1
!
(
E3
E2
!
(
E1
!
!
!
!
!
!
GW3
!
!
!
(
!
GE1
!
!
J6
!
!
!
!
(
!
T5
GE4
0
GE5
!
(
!
J9
!
J8
J7
!
4°30'0"N
T6
T4
GE3
!
(
!
J7 1-4 J5
!
(!
(
!
(!
(
J3
GE2
!
!
!
(
!
oba
!
(
th
!
(
GP5
!
(
J2 J4
J1
m is
GP3
!
!
!
!
100
GW6
!
!
!
(
GW4
!
(GW5
!
(
!
(
GP2
!
!
Ü
20
Kilometres
!
!
TITLE:
!
!
!
!
!
!
!
GE6
!
(
Figure 6.1
Sampling Stations from
TDI Brooks (2008) and
EAF Nansen (2009) Surveys
CLIENT:
DATE: 22/12/2011
CHECKED: ADJ
PROJECT: 0142816
DRAWN: KM
APPROVED: MI
SCALE: As scale bar
DRAWING:
Nansen_TDI_Sampling.mxd
ERM
Norloch House
Edinburgh
EH1 2EU
United Kingdom
Telephone:+44 (0) 131 478 6000
Facsimile: +44 (0)131 656 5813
4°0'0"N
SOURCE:
3°0'0"W
2°30'0"W
2°0'0"W
SIZE:
A4
REV:
0
6.2.2
Hydrogeology and Oceanography
The oceanography of the Gulf of Guinea is largely influenced by the
meteorological and oceanographic processes of the South and North Atlantic
Oceans, principally their oceanic gyral (circular) currents (Fontaine et al., 1999;
Merle and Arnault, 1985). Surface water is warm (24 to 29 ºC) with the daily
sea surface temperature cycle showing annual variability. The thermal cycle
occurs only in the upper two elements of the water column which together
comprise the tropical surface water mass. The oceanic gyral currents of the
North and South Atlantic Oceans create a counter current, the Equatorial
Counter Current (ECC) which flows in an eastward direction. This ECC
becomes known as the Guinea Current (Figure 6.2) as it runs from Senegal to
Nigeria
During upwelling, cold nutrient-rich water from depths rises to the surface,
resulting in increased biological productivity in the surface waters. The major
upwelling season along the Ghana coast occurs from July through to
September, while a minor upwelling occurs between December and January.
The rest of the year is characterised by a strong temperature thermocline (1),
which fluctuates in depth between 10 and 40 m. During early May the
thermocline is reportedly at a depth of 30 m (EAF Nansen, 2009). The major
and minor upwellings increase primary production and attract important
pelagic (living in the water column) species into the upper layers of the water
column, thereby increasing fish catches.
Figure 6.2
The Guinea Current
Source: http://oceancurrents.rsmas.miami.edu/
(1) Layer of water exhibiting a marked change in temperature
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6.2.3
Bathymetry, Seabed Topography and Sediments
The T.E.N. fields are located off the continental shelf offshore Ghana in water
depths between approximately 1,000 m to 1,800 m. The continental shelf
(200 m water depth) is at its narrowest (20 km wide) off Cape St Paul in the
east and at its widest (90 km) between Takoradi and Cape Coast in the west
(Armah and Amlalo, 1998). The continental slope is steep and the depths
increase sharply from approximately 100 m on the shelf and drop to
approximately 1,500 m at the deepest part of the slope. The whole area is
characterised by several vertical running trenches starting from the shelf (EAF
Nansen, 2009).
Ghana’s near shore area comprises various sediment types, varying from soft
sediment (mud and sandy-mud), sandy bottoms to hard bottoms (Martos et al,
1991). On the continental shelf, seabed sediments range from coarse sand on
the inner shelf to fine sand and dark gray mud on the outer shelf (Armah et al,
2004). Sediments on the shelf and upper continental slope are predominantly
terrigenous (derived from erosion of rocks from land), with smaller amounts
of glauconite-rich (iron silicate) sediments, and biogenic carbonate from
mollusc shells. Offshore the mouth of the Volta River is a large submarine
delta formed by river deposits. This is incised by a radial canyon system
consisting of eight canyons (Nibbelink and Huggard, 2002).
Surveys undertaken by EAF Nansen (2009) within the DWT Block found that
the sea bed sediment became finer with depth with pelite dominant in depths
above 500 m (1). The results of this survey are set out in Table 6.1.
Table 6.1
Sediment Grain Size and Total Organic Matter at Sample Sites within the
DWT Block, EAF Nansen (2009)
Station
Depth
% Gravel
% Sand
% Pelite
GW3
GW4
GW5
GW6
GE-6
J7-1
J7-2
J7-3
J7-4
101
250
503
1,201
1,201
1,273
1,300
1,271
1,280
6.3
0.7
0
0
0
0
0
0
0
69.6
82.9
17.6
3.2
1.5
1.2
1.2
1.2
0.9
24.0
16.4
82.4
96.8
98.5
98.8
98.8
98.8
99.1
% Total
Organic
Matter
6.1
6.0
11.5
13.1
11.8
12.5
13.0
12.9
13.1
Geophysical and geotechnical surveys for the T.E.N. development will
provide site specific information on bathymetry, seabed topography and
sediments for the EIS.
(1) Sedimentary rock composed of fine fragments, as of clay or mud less than 0.063 mm in diameter.
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6.2.4
Water and Sediment Quality
Water Quality
A survey conducted by TDI Brooks (2008) collected water samples from the
Jubilee Field in the east of the DWT Block and the adjacent West Cape Three
Points Field. The samples were analysed for a range of determinands
including metal and nutrients. The results are set out in Table 6.2 below.
Table 6.2
Water Quality Determinands from TDI Brooks (2008) Survey
Determinand
Mercury (Hg)
Barium (Ba)
Cadmium (Cd) and
Lead (Pb)
Total Nitrogen (TN)
Total Phosphorus
(TP)
Total Suspended
Solid (TSS)
Concentrations and discussion
Most samples had Hg concentrations below the detection limit of 0.2
ng/l. Detectable concentrations ranged from 0.22 - 0.28 ng/l.
Ba was higher in the surface samples and ranged from 5.96 - 5.43 ppb
for the surface samples, and between 5.43 - 5.00 ppb. Concentrations
varied little between sampling sites.
Neither Cd or Pb were detected in any of the samples.
TN concentrations for the surface samples ranged between 0.190 - 0.044
mg/l. TN concentrations at 100 m depth ranged from 0.437 -0.181 mg/l
(J-3).
TP concentrations in sub-surface samples ranged between 0.0195 –
0.0145 mg/l. Concentrations were higher at 100 m depth (up to 0.0455
mg/l)
Concentrations of TTS in sub-surface samples ranged from 6.3 – 45.23
mg/l. Concentrations were higher at 100 m depth, ranging from 11.22
– 30.26 mg/l.
The results of Conductivity, Temperature and Depth (CTD) profiles found
salinity decreasing slightly with depth, with the maximum change observed
between the surface and 400 m water depth. There was an abrupt change in
temperature between the surface and 600 m depth. The dissolved oxygen
profile exhibited a minimum value between 200 m and 300 m depth after
which it increased with depth. Depths greater than 1,200 m recorded the
highest concentrations of dissolved oxygen, generally more than 4 ml/l,
possibly as a function of water temperature among other factors. Values for
pH were found to generally decrease with depth from the surface to 100 m
depth.
Water sampling analysis results from the 2011 T.E.N. EBS will provide recent,
site-specific data on water quality.
Sediment Quality
Sediment samples collected by EAF Nansen (2009) were analysed for a range
of determinands including metals, organics and nutrients. The results are set
out in Table 6.3 below and are reportedly comparable with sediment in similar
conditions on the Norwegian shelf (Renaud et al 2008).
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Table 6.3
Range of Determinand Levels Found in Sediment within the DWT Block (Dry
Weight) (EAF Nansen, 2009)
Determinand
Barium (Ba)
Lead (Pb)
Mercury (Hg)
Cadmium (Cd)
Copper (Cu)
Chromium (Cr)
Total Organic Carbon (TOC)
Polycyclic Aromatic Hydrocarbons (PAHs)
Total Phosphorus (TP)
Total Nitrogen (TN)
THC (C12-35)
NPD
Range*
18.3 – 172.3 ppm
3.3 – 5.3 ppm
<0.1 ppm
0.07 ppm – 0.24 ppm
2.1 – 20.4 ppm
37.3 – 58.6 ppm
12.5 - 13.1 %
<10 ng/dry g
Not analysed
Not analysed
<1 – 15 ppm
1 – 3 ppb
* Samples taken from stations GW3, GW4, GW5, GW6, J7-1, J7-2, J7-3 and J7-4.
The results show that levels measured in all sediments were low; however,
higher concentrations of barium, copper and mercury were detected at deeper
stations compared to shallower stations. For example, barium concentrations
at shallow water stations were below 20 parts per million (ppm), while
concentrations at deepwater stations ranged between 135 ppm and 185 ppm.
Higher concentrations at deepwater stations could be attributable to finer
particle sizes of sediments or possibly a result of elements released from
previous drilling discharges in the area.
Sediment analysis results from the 2011 T.E.N. EBS will provide recent, sitespecific data on sediment quality.
6.3
BIOLOGICAL BASELINE
6.3.1
Plankton
Phytoplankton and zooplankton form a fundamental link in the food chain.
Plankton community composition and abundance is variable and depends
upon water circulation into and around the Gulf of Guinea, the time of year,
nutrient availability, depth, and temperature stratification.
Information on plankton (phytoplankton and zooplankton) was sourced from
previously documented surveys in the Gulf of Guinea including EIAs for the
West Africa Gas Pipeline Project (WAGP, 2004) and other research
programmes (eg Guinea Current Large Marine Ecosystem project Fisheries
Resource Surveys, 2006-2007) and available published sources (eg Wiafe 2002).
Phytoplankton
Phytoplankton, grouped as diatoms, dinoflagellates and coccolithophores, are
microscopic and range between 30 µm and 60 µm in size. Primary production
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is linked to the amount of inorganic carbon assimilated by phytoplankton via
the process of photosynthesis.
The environmental baseline study for the West African Gas Pipeline project
(WAGP, 2004) was carried out within the nearshore area (15 to 65 m depth) of
the Gulf, between Nigeria and Ghana, and identified 69 species of
phytoplankton. The phytoplankton community was dominated by Chaetoceros
spp. possibly a result of planktonic responses to seasonality of the
hydrographic regime (Wiafe, 2002). Other planktonic species included
Dinophysis acuta, which is a harmful microalgae with the potential to cause
diarrhetic shellfish poisoning in bloom condition at high concentrations
(Anderson et al, 2001). Distribution of the species indicated that Penilia
avirostris, a cladoceran, dominated the community in terms of number of
individuals. However, a dinoflagellate species, Chaetoceros spp., occurred in
high numbers at all locations sampled. The diversity of phytoplankton
species for the WAGP study ranked highest off the shelf of Ghana compared
to the other locations studied (ie Togo, Benin, and Nigeria).
Primary production determined for the Gulf of Guinea is about 4,305 to
5,956 mgC/m2/day. Typically, productivity in the offshore ecosystems (100 to
200 m water depth) range from 10 mg C/m3/day to 100 mg C/m3/day in
terms of volume, or from 75 mgC/m2/day to 1,000 mg C/m2/day in terms of
area. Thus, the values obtained within the near shore areas indicate a system
of relatively high productivity.
The 2011 T.E.N. EBS will provide information on chlorophyll and
Phaeophytin levels in the project area.
Zooplankton
Offshore zooplankton assemblages are dominated by copepods, followed by
Ostracods (1), Appendicularians (2) and Chaetognaths (3). Maximum
abundance is during the primary upwelling although they are also abundant
during the secondary upwelling (4).
WAGP (2004) surveys in the nearshore area (15-65 m depth) identified 52
zooplankton species. Penilia avirostris, Temora stylifera and Para-Clausocalanus
spp. dominated the zooplankton community. Species of zooplankton
recorded in the nearshore environment in the Western Region of Ghana
included Cyclopoids: Oncaea, Corycaeus, Farranula; Calanoids: Acartia,
Clausocalanus, Calanoides, Temora, Centropages, cirripid nauplius, Podon, Evadne,
Penilia, Lucifer protozoa, Appendicularia/ Oikopleuara, Pontellia nauplius and
Sagitta.
(1) Ostracoda is a class of the Crustacea, sometimes known as the seed shrimp because of their appearance.
(2) Larvaceans (Class Appendicularia) are solitary, free-swimming underwater saclike filter feeders found throughout the
world's oceans.
(3) Chaetognatha is a phylum of predatory marine worms that are a major component of plankton worldwide.
(4) The major upwelling begins between late June or early July when sea surface temperatures fall below 25°C and ends
between late September or early October. The minor upwelling occurs either in December, January or February and rarely
lasts for more
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Benthic decapod larvae and large crustacean numbers are at their highest
between February and June and October and December. Carnivorous species
dominate the plankton during the warm season and diversity is high but
abundance low. Herbivorous zooplankton, dominated by Calanoides carinatus
is highly abundant in upwelling conditions. These are later replaced by
omnivorous species (eg Temora turbinate and Centropages chierchise).
6.3.2
Benthic Invertebrates
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.
Information on marine macrobenthic faunal assemblages obtained for the
Jubilee Field found moderately rich communities, with varying mixtures of
maldanid and spionid polychaete worms and bivalves in mainly siltdominated sediments. The TDI Brooks survey (2008) identified a total of 414
individuals (mean density: 95.04 indiv/m2) belonging to 124 macrobenthic
faunal taxa. Of this number, annelids, primarily polychaetes, constituted 36%,
molluscs 31%, and crustaceans 24%, echinoderms 3% and other taxa
constituted 6%. In terms of density and frequency of occurrence, the taxon
bivalvia ranked first, followed by the polychaete Prionospio sp. Samples from
shallower areas outwith the Jubilee Field along the potential future pipeline
routes found richer communities.
The EAF Nansen (2009) survey found a total of 117 individuals (mean density:
78 indiv/m2) and 49 taxa at the sampling stations within the Jubilee Field (J71, J7-2, J7-3 and J7-4). Annelids were the main taxonomic group making up
between 50 to 60% of all individuals and taxa.
The fauna in the Jubilee Field was found to contain a moderately rich
community, dominated by polychaete worms and molluscs. Distribution of
animals living in the sediment (infauna) showed a relationship to water depth
and sediment type. It can be reasonably assumed that locations within the
DWT block of a similar depth will show similar assemblages. Shallow water
stations nearer the shore were richer in biodiversity and dominated by
bivalves and amphipods in medium sand. These richer assemblages are
potentially representative of shallow water areas north of the DWT block.
The 2011 T.E.N. EBS will provide additional information on benthic ecology at
the T.E.N. fields. Results from previous benthic surveys will be consolidated
and analysed to characterise the benthic environment in the study area.
6.3.3
Chemosynthetic Communities
In water depths where there is no light penetration and where seepage of
hydrocarbons, venting of hydrothermal fluids or other geological processes
supply abundant reduced compounds, microorganisms can produce biomass
using the oxidation of inorganic molecules or methane as a source of energy,
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rather than sunlight; this process is known as chemosynthesis. Surveys
conducted for the Jubilee Field development found no evidence of
chemosynthetic communities or features likely to support them.
6.3.4
Molluscs and Crustaceans
A variety of molluscs and crustaceans are known to be found in the coastal
waters off Ghana. Species in these taxa are found on continental shelf and
slope areas to a maximum of 450 m.
The following list comprises the species known to be found in the area and, if
known, the lowest depth of their relative depth range:









common cuttlefish (Sepia officinalis) (200 m);
pink cuttlefish (Sepia orbignyana) (450 m);
common squid (Loligo vulgaris);
common octopus (Octopus vulgaris);
green (spiny) lobster (Panulirus regius);
deep-sea rose shrimp (Parapenaeus longirostris) (400 m);
southern pink shrimp (Penaeus notialis) (100 m);
Caramote prawn (Penaeus kerathurus) (75 m); and
Guinea shrimp (Parapenaeopsis atlantica) (60 m).
Of these species the highest catches are of the cuttlefish species, followed by
the crustaceans, particularly green (spiny) lobster.
6.3.5
Fish Ecology
The composition and distribution of fish species found in Ghanaian waters is
influenced by the seasonal upwelling that occurs between Nigeria and the
Ivory Coast mainly in July to September and to a lesser extent in December to
February. The transport of nutrient-rich deep waters to the nutrient-depleted
surface water stimulates high levels of primary. This in turn increases
production in zooplankton and fish. The fish species found in Ghanaian
waters can be divided into four main groups, namely pelagic species,
demersal species and deepwater species.
The fisheries study (TGL, 2011b) will provide additional information on fish
ecology for the EIS.
Pelagic Species
The pelagic fish assemblage consists of a number of species that are exploited
commercially but are also important members of the pelagic ecosystem,
providing food for a number of large predators, particularly large pelagic fish
such as tuna, billfish and sharks. The most important pelagic fish species
found in the coastal and offshore waters of Ghana are round sardinella
(Sardinella aurita), flat sardinella (S. maderensis), European anchovy (Engraulis
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encrasicolus) and chub mackerel (Scomber japonicus). These species represent
approximately 80% of the total catch landed in the country (approximately
200,000 tonnes per annum). In terms of biomass, acoustic surveys have shown
that the two sardinella species and the European anchovy represent almost
60% of the total biomass in Ghanaian waters (FAO and UNDP, 2006).
Other commercially important pelagic species (1) found in Ghanaian waters
include horse mackerel (Trachurus sp), little tunny (Euthynnus alletteratus),
bonga shad (Ethmalosa fimbriata), African moonfish (Selene dorsalis), West
African Ilisha (Ilisha africana), largehead hairtail (Triciurus lepturus), crevalle
jack (Caranx hippos), Atlantic bumper (Chloroscombrus chrysurus), barracuda
(Sphyraena sp), long-finned Herring (Opisthopterus tardoore), kingfish / West
African Spanish mackerel (Scomberomorus tritor) and frigate mackerel (Auxis
thazard).
Large pelagic fish stocks off the coast of Ghana include tuna and billfish.
These species are highly migratory and occupy the surface waters of the entire
tropical and sub-tropical Atlantic Ocean. They are important species in the
ecosystem as both predators and prey for sharks, other tuna and cetaceans as
well as providing an important commercial resource for industrial fisheries.
The tuna species are skipjack tuna (Katsuwonus pelamis), yellowfin tuna
(Thunnus albacares) and bigeye tuna (Thunnus obesus). Billfish species occur in
much lower numbers and comprise swordfish (Xiphias gladius), Atlantic blue
marlin (Makaira nigricans) and Atlantic sailfish (Istiophorus albicans). Small, but
significant shark fishery in Ghana targets blue sharks (Prionace glauca) and
hammerhead sharks (Sphyrna sp).
Demersal Species
Trawl surveys have shown that demersal fish are widespread on the
continental shelf along the entire length of the Ghanaian coastline (Koranteng
2001). Species composition is a typical tropical assemblage including the
following families.

Porgies or Seabreams (Sparidae) (eg bluespotted seabream Pagrus
caeruleostictus, Angola dentex Dentex angolensis, Congo dentex Dentex
congoensis, canary dentex Dentex canariensis and pink dentex Dentex
gibbosus).

Grunts (Haemulidae) (eg bigeye grunt Brachydeuterus auritus and to a
lesser degree sompat grunt Pomadasys jubelini and bastard grunt Pomadasys
incisus).

Croakers or drums (Sciaenidae) (eg red pandora Pellagus bellottii, Cassava
croaker Pseudotolithus senegalensis).
(1) ‘Other pelagic species’ include those listed in Jubilee Phase 1 EIS and verified during consultations in Ghana in
April 2011 as part of the Fisheries study.
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
Goatfishes (Mullidae) (eg West African goatfish/red mullet Pseudupeneus
prayensis).

Snappers (Lutjanidae) (golden African snapper Lutjanus fulgens, Goreean
Snapper Lutjanus goreensis).

Groupers (Serranidae) (eg white grouper Epinephelus aeneus).

Threadfins (Polynemidae) (eg lesser African threadfin Galeoides
decadactylus).

Emperors (Lethrinidae) (eg Atlantic emperor Lethrinus atlanticus).

Triggerfish (eg grey triggerfish Balistes capriscus).
The seasonal upwelling provokes changes in the geographical distribution of
many of the demersal fish species. During the upwelling season, the
bathymetric extension of the croakers is reduced to a minimum, while the
deep water porgies are found nearer the coast than at other times of the year.
The demersal species that are most important commercially (in terms of catch
volumes) are cassava croaker (Pseudotolithus senegalensis), bigeye grunt
(Brachydeuterus auritus), red pandora (Pellagus bellottii), Angola dentex (Dentex
angolensis), Congo dentex (Dentex congoensis) and West African Goatfish
(Pseudupeneus prayensis). The cassava croaker is considered the most
commercially important demersal fish in West African waters, although it is
reported that in recent years in Ghana their importance has declined (Froese
and Pauly, 2009). They are distributed along the west coast of Africa as far
south as Namibia and as far north as Morocco. They are a demersal species
occupying both marine and brackish water down to a depth of 70 m. They are
mainly found in coastal waters over muddy, sandy or rocky bottoms.
Deep Sea Species
Froese and Pauly (2009) lists 89 deep-sea fish species from 28 families
including Alepocephalidae, Gonostomatidae, Myctophodae and Stomiidae
that are likely to be found in Ghanaian waters. Information on the
distribution of specific deep water species is in Ghanaian waters is limited.
Protected or Endangered Species
The sensitive species in Ghanaian waters according to the International Union
for Conservation of Nature (IUCN) red list (IUCN, 2011) are presented in
Table 6.4. A number of these species are commercially important and are
subjected to heavy exploitation, particularly Albacore tuna and swordfish. It
should be noted that Albacore catches in Ghanaian waters are not currently
recorded (ICCAT Fishstat data).
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In the global context there is concern about the bigeye tuna stocks. The
International Commission for the Conservation of Atlantic Tunas (ICCAT) has
listed it as the species of greatest concern, after the bluefin, in terms of its
population status and the unsustainable levels of exploitation exacted on this
species.
Table 6.4
Threatened Fish Species in Ghanian Waters (IUCN, 2011)
Scientific name
Cephalopholis taeniops
Dasyatis margarita
Epinephelus aeneus
Epinephelus caninus
Epinephelus costae
Epinephelus goreensis
Epinephelus haifensis
Epinephelus itajara
Epinephelus marginatus
Hippocampus algiricus
Pristis pectinata
Pristis perotteti
Raja undulata
Rhinobatos cemiculus
Rhinobatos rhinobatos
Rhynchobatus luebberti
Rostroraja alba
Sphyrna lewini
Thunnus alalunga
Thunnus albacares
Thunnus obesus
Xiphius gladius
6.3.6
Common name
African Hind
Ray species
White Grouper
Dogtooth Grouper
Goldblotch Grouper
Dungat Grouper
Haifa Grouper
Goliath Grouper
Dusky Grouper
West African Seahorse
Wide Sawfish
Largetooth Sawfish
Undulate Ray
Blackchin Guitarfish
Common Guitarfish
Lubbert’s Guitarfish
Bottlenose Skate
Scalloped Hammerhead
Albacore Tuna
Yellowfin tuna
Bigeye Tuna
Swordfish
Red List Category
Data Deficient
Endangered
Near Threatened
Data Deficient
Data Deficient
Data Deficient
Data Deficient
Critically Endangered
Endangered
Data Deficient
Critically endangered
Endangered
Endangered
Endangered
Endangered
Endangered
Endangered
Data Deficient
Lower Risk
Vulnerable
Data Deficient
Marine Mammals
The ecological significance of Ghana’s coastal waters for dolphins and whales
has only recently become the subject of scientific studies, which partially
explains the lack of population abundance estimates and why their natural
history in the region remains largely unknown. The conditions created by the
seasonal upwelling in the northern Gulf of Guinea are likely to create
conditions favourable for marine mammals as well as for fisheries.
Specimens derived from by-catches and stranding show Ghana to have
moderately diverse cetacean fauna, comprising at least 18 species belonging to
five families: 14 species of Delphinidae (dolphins) and one species each of
families Ziphiidae (beaked whales), Physeteridae (sperm whales), Kogiidae
(pygmy sperm whales) and Balaenopteridae (rorquals). These species and the
IUCN conservation status and sensitivity are set out in Table 6.5.
Marine mammal sighting records from the Jubilee field will be used to
supplement the description of marine mammals in the EIS.
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Table 6.5
Dolphins and Whales of Ghana and IUCN Conservation Status
Species
Delphinidae
Common bottlenose dolphin (Tursiops truncatus)
Clymene dolphin (Stenella clymene)
Spinner dolphin (Stenella longirostris)
Pantropical spotted dolphin (Stenella attenuate)
Atlantic spotted dolphin (Stenella frontalis) (G. Cuvier, 1829)
Long-beaked common dolphin ( Delphinus capensis)
Fraser's dolphin (Lagenodelphis hosei)
Rough-toothed dolphin (Steno bredanensis)
Risso's dolphin (Grampus griseus)
Melon-headed whale (Peponocephala electra)
Pygmy killer whale (Feresa attenuata)
Short-finned pilot whale (Globicephala macrorhynchus
Killer whale (Orcinus orca)
False killer whale (Pseudorca crassidens)
Ziphiidae (beaked whales)
Cuvier's beaked whale (Ziphius cavirostris)
Kogiidae (pygmy sperm whales)
Dwarf sperm whale (Kogia sima)
Physeteridae (sperm whales)
Sperm whale (Physeter macrocephalus or Physeter catodon)
Balaenopteridae (rorquals)
Humpback whale (Megaptera novaeangliae)
6.3.7
IUCN Status
Least Concern
Data Deficient
Data Deficient
Least Concern
Data Deficient
Data Deficient
Least Concern
Least Concern
Least Concern
Least Concern
Data Deficient
Data Deficient
Data Deficient
Data Deficient
Least Concern
Data Deficient
Vulnerable
Least Concern
Turtles
The Gulf of Guinea serves as an important migration route, feeding ground
and nesting site for sea turtles. Five species of sea turtles have been confirmed
for Ghana, namely the loggerhead (Caretta caretta), the olive ridley
(Lepidochelys olivacea), the hawksbill (Erectmochelys imbricata), the green turtle
(Chelonia mydas), and the leatherback (Dermochelys coriacea) (Armah et al, 1997,
Fretey, 2001). All five species of sea turtles are listed by the CITES and
National Wildlife Conservation Regulations under Schedule I. IUCN status is
set out in Table 6.6.
Table 6.6
Turtles in the Gulf of Guinea, IUCN Conservation Status
Species
Loggerhead (Caretta caretta)
Olive ridley (Lepidochelys olivacea)
Hawksbill (Erectmochelys imbricata),
Green turtle (Chelonia mydas),
Leatherback (Dermochelys coriacea)
IUCN Status
Endangered
Vulnerable
Endangered
Marine turtles spend most of their life at sea, but during the breeding season
they go ashore and lay their eggs on sandy beaches. The beaches of Ghana
from Keta to Half-Assini are important nesting areas for sea turtle species.
Approximately 70% of Ghana’s coastline is found suitable as nesting habitat
for sea turtles, and three species; the green turtle, olive ridley and leatherback
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turtles are actually known to nest (Armah et al, 1997; Amiteye, 2002). The
olive ridley is the most abundant turtle species in Ghana. Population
estimates from four previous surveys of these turtle species are provided in
Table 6.7. The nesting period stretches from July to December, with a peak in
November (Armah et al, 1997). In Ghana, the majority nests observed (86.3%)
are those of the olive ridley.
Table 6.7
Population of Sea Turtle Species that Nest on Beaches of Ghana
Author, year
Amiteye, 2002
Agyemang, 2005
Allman, 2007
Agyekumhene, 2009
Average
Leatherback
46
30
418
74
142
Olive ridley
412
190
134
103
210
Green Turtle
32
10
0
0
21
Source: Armah et al (1997)
6.3.8
Birds
The west coast of Africa forms an important section of the East Atlantic
Flyway, an internationally-important migration route for a range of bird
species, especially shore birds and seabirds (Boere et al, 2006, Flegg 2004). A
number of species that breed in higher northern latitudes winter along the
West African coast and many fly along the coast on migration. Seabirds
known to follow this migration route include a number of tern species (Sterna
spp), skuas (Stercorarius and Catharacta spp) and petrels (Hydrobatidae).
The distance of the migration routes of these species from the shore depends
on prey distribution and availability (eg the abundance and distribution of
shoals of anchovies or sardines) (Flegg 2004). Species of waders known to
migrate along the flyway include sanderling (Calidris alba) and knot (Calidris
canuta). The highest concentrations of seabirds are experienced during the
spring and autumn migrations, around March and April, and September and
October. Waders are present during the winter months between October and
March. The marine birds of Ghana include storm petrels (Oceanodroma castro)
and Ascension frigatebirds (Fregata aquila). Records dating back to the 1960s
reveal only limited sightings of a few species (Elgood et al, 1994). The rarity of
oceanic birds may be attributable to the absence of suitable breeding sites (eg
remote islands and rocky cliffs) off the Ghana coast and in the Gulf of Guinea.
During the environmental baseline studies research cruise for the West
African Gas Pipeline (WAGP, 2004) in 2002/2003, the survey crew recorded
several sightings of black tern (Chlidonias niger), white winged black tern
(Chlidonias leucopterus), royal tern (Sterna maxima), common tern (Sterna
hirundo), Sandwich tern (Sterna sandvicensis), great black-back gull (Larus
marinus), lesser black-back gull (Larus fuscus), pomarine skua (Stercorarius
pomarinus) and great skua (Catharacta skua). The two species of skua are
predominant in the Western offshore environment. Black terns were mainly
recorded at nearshore locations close to estuaries and/or lagoons. These
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species leave the onshore areas to feed at sea during the afternoon. The
general low diversity of marine birds may be ascribed to lack of suitable
habitats and availability of food resources in the offshore area. There are 40
Important Bird Areas (IBAs) designated by Birdlife International within
Ghana (Birdlife International, 2011); one of which, the Amansuri wetland, is
located along the western coastline within the project sphere of influence.
Bird sighting records from the Jubilee field will be used to update the
description on seabirds in the EIS.
6.4
FISHERIES BASELINE
This section provides an overview of fisheries offshore Ghana from previous
baseline descriptions. A fisheries study conducted by ERM in 2011 (TGL,
2011b) will provide more recent data for the EIA on fisheries offshore Ghana.
6.4.1
Introduction
The fishing industry in Ghana is based on resources from both marine and
inland (freshwater) waters and from coastal lagoons and aquaculture
(Quaatey, 1997; NAFAG, 2007). The fisheries sector accounts for
approximately 5% of the agricultural Gross Domestic Product (GDP)
(agriculture accounts for 45 to 50% of total Ghanaian GDP). There is a long
tradition of both artisanal and distant-water fishing fleets, the latter a unique
feature amongst West African countries (Alder and Sumaila 2004). Most
commercial marine fishing undertaken by Ghanaian vessels takes place within
the Ghanaian 200 miles EEZ.
The traditional artisanal inshore fishery in Ghana is well developed and
provides about 70% of the total marine fisheries production in the country
(Korateng 1998). Fishing occurs year round but shows some seasonality. The
fish landings from coastal lagoons or estuaries provide reasonable quantities
of fish products for subsistence. Inshore fishing involves substantial number
of fishers using small scale gear such as gill nets, throw nets and weirs.
Marine fishing activity in Ghana is strongly linked with the seasonal
upwellings (1) that occur in coastal waters. Two upwelling seasons (major and
minor) occur annually in Ghanaian coastal waters. The major upwelling
begins between late June or early July when sea surface temperatures fall
below 25°C and ends between late September or early October. The minor
upwelling occurs either in December, January or February and rarely lasts for
more than three weeks. During the upwelling periods, biological activity is
increased due to greater concentrations of nutrients in the water column that
have been drawn up from deeper waters. Most fish spawn during this period
(1) An upwelling involves wind-driven motion of dense, cooler, and usually nutrient-rich water towards the ocean surface,
replacing the warmer, usually nutrient-depleted surface water.
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and stocks are more readily available to the fishers. For the rest of the year,
catches are lower and more sporadic.
6.4.2
Fish Landings
Landing Facilities
There are three deep-water ports and harbours in Ghana at Tema, Sekondi
and Takoradi that provide berthing facilities for both industrial fishing vessels
and inshore vessels. There are four other ports at Apam, Mumford, Elmina
and Axim that provide reasonably good landing facilities for inshore vessels.
Physical landing facilities for artisanal fishing crafts are not as well developed.
Canoes usually operate from open beaches. There are about 300 landing
centres along the coast for marine canoes. Each landing site is under the
control of a Chief Fisherman.
Total Landings
Overall landings in the last decade (1998 to 2007) have shown a declining
trend with a number of the most important species showing particularly
marked declines particularly the main pelagic resources such as anchovies
and sardinellas (see Figure 6.3). Declines in less important pelagic resources,
such as chub mackerel, Cunene horse mackerel and Crevelle jack have also
contributed to the overall downward trend. However, demersal species show
some increases, with grunts, Atlantic bumper, red pandora, crustaceans and
demersal resources in general showing marked increases over the last ten
years. From Figure 6.3 large pelagic species, namely bigeye tuna, yellowfin
tuna and skipjack tuna appear to have increased slightly. Landings of
molluscs and crustaceans have remained constantly low.
6.4.3
Fishing Fleets
Artisanal Fishery
The artisanal sector of the industry accounts for over 70% of annual marine
fish production and dominates the Ghanaian fishing industry (Mensah and
Koranteng, 1988). Artisanal fishing boats operate out of 304 landing centres in
180 fishing villages located along the coast (Sarpong et al, 2005 and FAO,
2011). These vessels use a wide variety of fishing gear and target a number of
different species. This sector provides employment in coastal communities,
engaging over 100,000 fishermen.
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Total Landings of Major Target Groups by Ghanaian Fisheries 1998 to 2007
West African ilisha
450,000
Seabreams
Largehead hairtail
400,000
Landings (tonnes)
Figure 6.3
Red pandora
350,000
Cunene horse mackerel
300,000
Atlantic bumper
Crevalle jack
Dentex
Chub mackerel
250,000
European anchovy
200,000
Sardinellas
Grunts
150,000
Elasmobranchs
Tuna
100,000
Billfish
Crustaceans
50,000
Cephalopods
Other demersal
0
1998
1999
2000
2001
2002
2003
2004
2005
2006
2007
Other pelagic
Other fish
Source: FAO, 2007
The artisanal fishing community target a wide range of species from pelagic
and demersal fish species and molluscs and crustaceans. Small pelagic species
are mainly exploited by the artisanal purse seines and beach seines targeting
species such as Sardinella species, chub mackerel and anchovies. Hook and
line, and beach seines are the main artisanal gears used to exploit demersal
resources to around 80 m. The main species they target are porgies or
seabreams (Sparidae) (eg Dentex gibbosus, Pagrus caeruleostictus and Dentex
canariensis), snappers (Lutjanidae) (eg Lutjanus fulgens, Lutjanus goreensis) and
groupers (Serranidae) (eg Epinephelus aeneus). The beach seine fleet exploits
both adult and juvenile demersal fish but mainly juvenile fish. Some of their
target species include grunts (Haemulidae) (eg Brachydeuterus auritus),
goatfishes (Mullidae) (eg Pseudupeneus prayensis), mullets (Mugil spp) and
cutlassfish (Trichiuridae) (eg Trichiurus lepturus).
Some drift gill nets deployed by artisanal fishers are used to target the small
pelagic species, but other drift gill nets are used offshore to exploit mainly
large pelagic species such as tunas (eg Thunnus albacares, Thunnus obesus),
sailfish (Istiophorus albicans), swordfish (Xiphias gladius) and sharks
(Carcharhinus spp).
Artisanal gears are also used to exploit molluscs and crustaceans. Beach
seines are used to exploit shrimps, mainly adult and juvenile Guinea/white
shrimp (Parapaeneopsis atlantica) and tiger shrimp/camarote prawn (Penaeus
kerathurus) and juvenile pink/candied shrimp (Penaeus notialis) as they move
from the estuaries into marine waters. Lobster set nets target green (spiny)
lobster (Panulirus regius), on rocky bottoms and in depths of about 40 m.
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The Inshore Fishery
There are approximately 300 semi-industrial vessels presently involved in the
inshore fishing sector operating from seven landing centres. The majority of
these semi-industrial vessels are locally built using wood and carry both purse
seine and trawl gear. The semi-industrial fleet exploits both small pelagic and
demersal species.
Between July and September vessels use their purse seines target small pelagic
species including sardinella species, chub mackerel, sparids, big-eye grunt,
cassava croaker (Pseudotolithus senegalensis), lesser African threadfin (Galeoides
decadactylus) and common cuttlefish (Sepia officinalis). Trawling is carried out
for the remaining part of the year targeting demersal species when pelagic
resources are less numerous; targeted species include grey triggerfish (Balistes
capriscus), seabreams, snappers, grunts and croakers (FAO, 2010).
Harbour facilities for large trawlers are available at two landing sites located
along the coastline; Tema and Takoradi while mooring for smaller trawlers is
available at Winneba, Apam, Mumford, Elmina and Sekondi.
Offshore Trawling/Distant Water Fleet
Fishermen of the industrial sector use imported steel fishing vessels. The fleet
consists of trawlers, shrimpers and tuna boats and fishing trips may last up to
one month. There are approximately 90 vessels in the industrial fleet, made
up of around 60 trawlers and about 29 tuna boats (FAO, 2010 and ICCAT,
2009).
The industrial trawlers target semi pelagic and demersal species including
porgies or seabreams, jacks (Carangidae) (eg Caranx rhonchus), groupers,
snappers, croakers (eg Pseudotolithus senegalensis), goatfish (eg Pseudupeneus
prayensis), sole and flounders (Soleidae) as well as cuttlefish (eg Sepia
officinalis). The industrial shrimpers operate in designated areas within
Ghanaian waters between Shama and Axim. The number of shrimp vessels
was reduced to two in 2007 and neither have been operational since 2009
(MFRD, 2011b).
The potential yield of demersal fishes on Ghana’s continental shelf is
estimated to be up to 55,000 tonnes annually. There has been a progressive
increase in demersal landings since 2000 with catches in the region of 70,000
tonnes in 2007 (FAO, 2007), above the estimated total yield of demersal fish
species of approximately 50,000 tonnes annually. This data represents the
total annual catches and does not indicate fishing effort which will influence
the total catches.
Tuna Fleet
The Gulf of Guinea is one of the most productive tuna fishing areas in the
Atlantic Ocean due to the presence of spawning areas for yellowfin and
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bigeye tuna, high densities of prey and water temperatures that suit the tuna
species. The main tuna species targeted by the tuna boats of the industrial
fleet, are skipjack tuna (over 50%), yellowfin tuna and bigeye tuna. Total
annual landings of the three species are between 60,000 and 80,000 tonnes.
Total Ghanaian annual landings of all these three species have fluctuated
between approximately 51,000 and 88,000 tonnes over that past decade (see
Figure 6.4).
ICCAT carry out regular population assessments of exploited populations
within their convention area and assess the status of the entire Atlantic
populations of each species. The most recent population assessments indicate
that yellowfin and bigeye tuna resources in the Atlantic are being fully
exploited and any increase in catches would be detrimental to the fish
populations. The status of skipjack tuna populations is difficult to assess with
traditional stock assessment models due to their particular biological and
fishery characteristics, but currently the stock is not thought to be being
overexploited (ICCAT, 2009).
Figure 6.4
Annual Landings of Three Tuna Species by Ghanaian Fleet (1998-2009)
Source: FAO, 2011
Shark Fishing
The exploitation of shark fins has become a widespread business in Ghana.
The sharks are caught using driftnet (locally known as Anifa-anifa or Nifanifa) and species mostly comprise of silky shark (Carcharhinus falsiformis),
black tip shark (Carcharhinus limbatus), oceanic whitetip shark (Carcharhinus
longimanus), sandbar shark (Carcharhinus plumbeus) and night shark
(Carcharhinus signatus). In Ghana, shark fishing is a year-round operation with
a peak season in October and December (Ghana, Post Harvest Fisheries
Overview, 2003) and may involve as many as 150,000 fishermen (Mensah, et al,
2006).
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6.4.4
Commercially Important Shellfish
A variety of invertebrate species known from the wider/coastal area include
cuttle-fish (Sepia officinalis), squid (Loligo vulgaris), octopus (Octopus
vulgaris), lobster (Panulirus regius), deep-sea rose prawn (Parapenaeus
longistrostris) and shrimps (mainly Penaeus notialis, Penaeus kerathurus,
Parapeneopsis atlantica).
Catches are of cuttlefish species are highest, followed by the crustaceans,
particularly decapod crustaceans such as Panulirus regius. Prawns are of lesser
importance and catches in recent years have shown some decline. However,
these species are important food items for a number of fish species and other
predators within the Ghanaian coastal and marine ecosystem.
The cuttlefish species, the common cuttlefish (Sepia officinalis) and the pink
cuttlefish (Sepia orbignyana), are both caught in Ghanaian waters and are both
eastern Atlantic species. The deep-sea rose prawn (Parapenaeus longirostris) is
found on the continental shelf and upper slope, between 50 and 400 m depth
over sandy sea beds. The shrimp species, southern pink shrimp (Penaeus
notialis), Caramote prawn (Penaeus kerathurus) and Guinea shrimp
(Parapenaeopsis atlantica) constitute the majority of the shrimp catch in
Ghanaian waters. They are generally associated with sandy and muddy
bottoms on the continental shelf, southern pink shrimp to a depth of 100 m,
Caramot prawn to 75 m, and Guinea shrimp to 60 m.
6.5
SOCIO-ECONOMIC BASELINE
6.5.1
Administrative Structures
The government structure in Ghana is made up of ten administrative regions
subdivided into 170 metropolitan, municipal and districts areas, each with an
administrative assembly comprised of a combination of appointed (a third)
and elected (two-thirds) officials. Each area has a District Chief Executive
(DCE) who heads the local assembly. The DCE is nominated by the President
of the country and is confirmed by the assembly through balloting. The local
government is made up of the Regional Coordinating Council (RCC), four-tier
Metropolitan and three-tier Municipal/District Assemblies with
Urban/Town/Area/Zonal Councils. Each Electoral Area (EA) is represented
at the assembly by an elected assembly member and has a Unit Committee.
The Paramount Chiefs are the traditional heads of the people and carry great
influence.
The Western Region (the Region closest to the project) currently comprises 14
districts, two municipalities, and one metropolis, the latter being SekondiTakoradi Metropolitan Assembly (STMA). The STMA was established during
restructuring in 2008. It was formed when the former Shama Ahanta East
Metropolitan Assembly (SAEMA) was split into Shama District and STMA.
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6.5.2
Demographics
The population of Ghana is approximately 23 million (July 2008 estimate) with
the Western Region having approximately 2.5 million people. The Western
Region has experienced accelerated population growth over the years likely
linked to in-migration resulting from increased economic activity, particularly
between 1984 and 2000, when the region experienced a boom in both the
mining and the cocoa industries. Over one third (36%) of the Western Region
is urbanised with the remaining 64% being rural.
The population of Sekondi-Takoradi Metropolis (STM) was reported as
approximately 370,000 in the year 2000. It is the most populated area in the
Western Region, comprising about 15% of the region’s total population and
approximately 80,000 people from neighbouring districts commute to the area
for work.
The population of the Western Region is relatively young, with approximately
43% of the population 15 years old or younger and 5% of the population are
more than 64 years old. STM has the largest proportion of the population
(58%) in the working age group (15 to 64 years) in the region likely due to
migration of young adults to the commercial and mining towns.
6.5.3
Economic Activity
Overview
Ghana’s domestic economy currently revolves around agriculture (which
includes fishing). This accounts for about 45 to 50% of GDP and employs
about 55% of the work force, mainly small landholders and fishers. Other
major sources of employment include mining and quarrying (employing
approximately 15% of the population), and manufacturing, employing
approximately 11% of the population.
The major economic activities in STM are related to the port. The STM is the
third largest industrialised centre in the country and there are other significant
industrial and commercial activities in the manufacturing sector (food
processing, spirits production, textiles, metal fabrication) and resources sector
(timber, clay). The area has a large food and goods market which is a centre
for small and medium size trading enterprises. Fisheries and tourism are the
two most important activities in relation to the project and are discussed in
further detail below. Other economic activities include agriculture, mining,
forestry and coastal salt production.
The poverty incidence in the Western Region of Ghana ranked third highest in
the country and contributed about 6.5% to the national poverty level. The
levels of unemployment in the Western Region are also considered to be high.
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Agriculture and Processing of Agricultural Products
In the Western Region both commercial and subsistence farming is practiced.
The region is the largest commercial producer of cocoa and timber and has the
largest rubber plantation in the country and its only rubber-processing factory
which processes the rubber into a semi finished product for export. Coconut
and oil palm are cultivated on a large scale for commercial production of
vegetable oil. Subsistence farming is practiced to produce food crops such as
cassava, maize, rice, cocoyam, plantain, pepper and tomatoes, and rice is
grown in some low-lying areas.
Mining
Mineral mining is extensively practiced in the Western Region. Minerals
mined, include gold, manganese and bauxite. The Western Region is the
second highest producer of gold in the country. There are five major gold
mines in the Region namely AngloGold Ashanti Iduaprem, Golden Star
Resources Prestea and Bogoso, Tarkwa Gold Fields and and Aboso Gold
Fields. Mining is undertaken by multinational companies. There are also
some artisanal miners operating in the Region. The country’s only bauxite
mine currently in production is located at Awaso in the Bibiani-AhweasoBekwai District. There are other potential deposits in the Region however
these have not as yet been fully explored for exploitation. Deposits of alluvial
diamonds in the Bonsa River Basin were exploited by small-scale miners in the
1940s and 1950s. There is, however, potential that the river basin could still be
prospected for diamonds in the future.
Salt Production
It is estimated that salt production occurs in approximately 14 coastal lagoons
along the Ghanaian coast and provides employment opportunities to coastal
villages. Salt is collected from lagoon flats in the dry season when salt
crystallises out of the super-saturated lagoon water. In addition, dedicated
man-made saltpans with low dikes are used (Armah et al, 2004). Salt
production is not widely practiced in the coastal Districts of the Western
Region.
Import/ Export
The deep-water port at Takoradi handles about 62% of total national export
and 20% of total national imports annually. The main exports are manganese,
bauxite, cocoa beans and forest products (mainly sawn timber). The main
imports are clinker (for cement production), containerised cargo, lime
products, petroleum products and wheat.
Tourism and Cultural Heritage
According to the Ghana Investment Promotion Centre (2010), Ghana’s tourism
sector is expected to grow at an average rate of 4.1% per annum over the next
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two decades. Since the late 1980s tourism has received considerable attention
in the economic development strategy of Ghana. The number of tourist
arrivals and amount of tourists’ expenditure has steadily increased, while both
public and private investment activity in various tourism sub-sectors have
expanded (GIPC, 2010).
Ghana has a wide range of natural, cultural and historical attractions, which
provides the basis for the growing tourism industry. The tourism potential in
the Western Region is related to the number and extent of pristine tropical
beaches as well as wildlife parks and forest and game reserves featuring
tropical rainforests, inland lakes and rivers. Some of the most popular
recreational beaches along the western coastline are located at Biriwa, Brenu
Akyinim, Busua, Butre, Cape Coast, Egyembra, Elmina, Komeda, Sekondi and
Takoradi (GTB, 2010). Hotels are generally located at popular beach
destination and at commercial centres.
6.5.4
Other Marine Infrastructure
Oil and Gas
Exploration and appraisal drilling activities in the Deepwater Tano and West
Cape Three Points concession blocks are ongoing during 2011. In the Jubilee
Field subsea equipment (wellheads, manifolds, umbilicals and flow lines) has
been installed since January 2010 and the FPSO Kwame Nkrumah is currently
located on site at 4°35’47.930” north, 2°53’30.934” west. Production started in
November 2010 and by November 2011, Phase 1 well completions should
have finished, comprising a total of 17 wells. Crude oil stored on the FPSO is
transferred to an export tanker approximately every five to seven days at peak
production. A 1 km safety exclusion zone centred at the FPSO turret and a
further 10 km radius advisory zone covers the entire Jubilee Unit operational
area.
Pipelines and Cables
There are several existing and planned submarine cables and pipelines
offshore Ghana although none are in the vicinity of the DWT Block.
Ports and Harbours
The Port of Takoradi was built as the first commercial port of Ghana in 1928 to
handle imports and exports to and from the country. The port currently has a
covered storage area of 140,000 m2 and has an open storage area of 250,000 m2.
It has a wide range of vessels supporting its operations including tugboats,
lighter tugs, a water barge and a patrol boat. The port handles both domestic
and transit cargoes and currently handles about 600 vessels annually, which is
37% of the total national seaborne traffic, 62% of total national export and 20%
of total national imports annually. Almost 160,000 tonnes of cargo are
handled annually at the port. The Port of Takoradi also has a fishing harbour
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located at Sekondi, which has an ice plant that can accommodate vessels with
up to 3 m draft.
Shipping and Navigation
Figure 6.5 presents data from commercial vessel movements off West Africa
during 2005 showing the general shipping lanes. It can be seen that most
commercial shipping approaches Ghana south of the DWT Block.
Figure 6.5
Shipping Lanes off West Africa
Source: http://www.nceas.ucsb.edu/GlobalMarine/impacts
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7
IDENTIFICATION OF POTENTIAL IMPACTS
7.1
INTRODUCTION
Scoping in EIA serves principally to identify those impacts most likely to be
significant and therefore need to be addressed in the EIA. The main project
activities associated with offshore oil field developments are well established
and the main potential issues are generally well understood. Scoping also
includes elements of consultation with stakeholders to identify specific
sensitivities and key issues, resources and receptors that may be affected by
the project.
In undertaking the EIA Scoping phase, the EIA team has drawn upon:
7.2

its knowledge of sources of potential impact associated with offshore oil
and gas development and production;

its experience gained through undertaking the Jubilee Phase 1 EIA and
reviewing further operational monitoring data;

an identification of the main environmental and social resources and
receptors from the preliminary baseline data collection work; and

the results of the initial scoping consultation.
ENVIRONMENTAL AND SOCIAL RESOURCES AND RECEPTORS
For this project the following main resource / receptor types were identified.
7.3

Physical Environment: including the seabed, sediment quality, water
quality, hydrodynamics and air quality.

Natural Environment: including plankton, benthic communities, pelagic
and demersal fish, marine mammals, turtles, birds, ecosystems (marine
and coastal).

Human Environment: including coastal communities, fishing (artisanal,
semi-industrial and industrial), navigation/shipping, tourism/recreation,
land use, infrastructure/services, the economy, including employment
and business opportunities and occupational health and safety.
IDENTIFICATION OF POTENTIAL INTERACTIONS
The interactions of project activities with resources and receptors that might
occur during the project are shown in Table 7.1, Table 7.2 and Table 7.3 for
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drilling, construction and installation/commissioning, and operations
respectively. Interactions that may occur as a result of decommissioning will
be similar to those of installation and commissioning. Potential significant
interactions have been indicated in green.
The probable environmental impacts associated with an oil and gas
development are generally narrower in scope that the possible interactions
identified in these tables due to the mitigation measures that will be built into
the project design but this identification process is intended to be broad at this
stage so as to consider the wide range of possibilities.
7.4
IDENTIFICATION OF IMPACTS
Based on the interactions between project activities or aspects and
environmental receptors or resources discussed in Section 7.3, development of
the project will result in associated impacts (ie those that will occur to some
degree) and in the potential for impacts (ie those that might occur). The
impacts that will be assessed in detail in the EIA can be grouped as follows.









Physical footprint (physical presence, noise and light).
Routine discharges.
Non-routine discharges.
Air emissions.
Waste management.
Oil spill risk.
Socio-economic impacts.
T.E.N. project activities onshore.
Cumulative and transboundary impacts.
No importance should to be given to the grouping of the issues into these
categories or to the order in which they are presented.
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Table 7.1
Drilling Interactions
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Table 7.2
Construction, Installation and Commissioning Interactions
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Table 7.3
Operations Interactions
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7.4.1
Physical Footprint
The key impacts identified include the following.
7.4.2

Physical impact on the seabed and benthic communities through
placement / presence of subsea infrastructure.

Interaction from vessel or helicopter movements and underwater sound
and potential for impact on marine fauna (marine mammals, turtles, fish,
birds).

Potential impact on fish ecology due the presence of the vessel and its fish
attracting quality.

Installation of subsea infrastructure may disturb deepwater species.

Presence of subsea infrastructure will provide new seabed habitat.

Presence of surface installations and vessels may impact fishing and
shipping activities.
Routine Discharges
7.4.3

Discharges from drilling vessels, FPSO and project vessels contaminated
with traces of hydrocarbons could affect water quality and cause
secondary impacts on marine fauna.

Black, grey water and food waste discharges from drilling vessels, FPSO
and project vessel could affect water quality with secondary impacts on
marine fauna.

Discharge of ballast waters (from export tankers and other vessels) could
impact on water quality and marine fauna and introduce invasive species.

Discharge of produced water containing hydrocarbons could impact on
water quality and cause secondary impacts on marine fauna.

Hydraulic fluid from daily subsea valve activation could impact on water
quality.
Non-routine Discharges

Discharge of cuttings and residual drilling fluid could impact on water
and sediment quality and cause secondary impacts on marine fauna.
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7.4.4

Discharge of completion fluids and occasional discharge of workover
fluids from the drilling vessels could impact on water quality and cause
secondary impacts on marine fauna.

Chemically treated hydrotest waters discharged during commissioning
and could have a detrimental impact on water quality and secondary
impact on marine fauna.

Potential leaks or accidental releases from tanks, pipes, hoses and pumps,
including during loading and unloading from the shore base could impact
soil and groundwater quality.
Air Emissions
7.4.5

Emissions from flaring during well testing and completion operations
have the potential to impact air quality.

Exhaust emissions from drilling vessel and support vessels and from
power generation from gas turbines on the T.E.N. FPSO have the potential
to impact air quality.

Emissions from gas flaring during commissioning, maintenance
shutdowns and from process vents have the potential to impact air
quality.
Waste Management
Non-hazardous and hazardous wastes will be generated that will require to be
transported and disposed of in a manner protective of the natural and human
environment.
7.4.6
Oil Spill Risk
An oil spill has the potential to impact marine and coastal habitats and animal
species (seabird, coastal birds, marine mammals, marine turtles and fish) and
livelihoods depending on the coast and marine environment impacted.
7.4.7
Socio-economic Development
Key positive and negative socio-economic impacts on human receptors
include the following.
Macro-economy

Revenue generated by the project through oil sales, taxes and royalties will
be a source of income for the government.
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Livelihoods and Local Economy

Procurement of goods and services has the potential to result in positive
impacts by stimulating local small and medium sized business
development and generation of profits.

Direct employment by the project and indirect employment in the supply
chain by contractors and suppliers will have a positive impact on those
people employed, their families and their local communities from wages
and other benefits. Similarly, skills development and training in the oil
and gas sector will benefit those involved.

Project demands for goods and services have the potential to lead to
shortages and price increases placing greater financial pressure on the
local population.
Infrastructure and Services

There may be increased strain on the capacity of the public infrastructure
(eg roads) and services (eg water supply) due project related activities.
Fisheries and Navigation

Loss of access to fishing grounds (through safety exclusion zones),
attraction of fish to the drilling vessel and FPSO and disturbance and
damage to fishing gear from project support vessels have the potential to
impact fishing activities.

Additional vessel movements associated with the project has the potential
to disrupt existing commercial shipping.
Health and Safety

The presence of non-local workers and other project- related workers
could introduce communicable diseases and sexually transmitted diseases.

The may be health impacts to nearby communities from onshore
operations if unmanaged project discharges or emissions result in reduced
local air or water quality.

The presence of non-local workers and other project- related workers may
lead to an increase in social pathologies such as prostitution and the
potential influx of job seekers and associate unemployment may lead to an
increase in crime levels.
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CSR Investment and Community Relations
7.4.8

There is the potential for increased grievances and tension within
communities and between communities and the government, TGL and
third parties caused by expectations not being met. For example, in
employment opportunities, investment in local infrastructure and the level
of CSR investment.

Differential benefits received across the six coastal districts may result in
increased grievances and tension in the Western Region.
T.E.N. Project Activities Onshore
In addition to the social-economic impacts described above, a range of
activities likely to be undertaken at the onshore bases and yards can result in
disturbance or damage to the health and wellbeing of local communities. The
key impacts identified include the following.
7.4.9

Elevated noise levels from shore base operations and increased traffic on
local roads.

Storage, handling and transport of solid and liquid wastes at onshore
bases can lead to loss of containment and spillages which could give rise to
ground and ground water contamination.

Air quality impacts from emissions, for example from combustion of fuel
(eg NOx / SOx), dust from ground disturbance and transportation or
smoke from hot works.
Cumulative and Transboundary Impacts
An EIA requires consideration of the direct effects and any indirect, secondary
and cumulative effects of a project. A cumulative impact is defined as an
impact that results from incremental changes caused by other past, present or
reasonably foreseeable actions together with the proposed project. The
following categories of cumulative impacts will be addressed in the EIA:
•
•
•
•
biodiversity;
environmental quality;
infrastructure and services; and
socio-economic effects.
The resources and receptors that may be subject to cumulative impacts include
those that have been identified as potentially impacted by the T.E.N.
development at the offshore project location, the onshore logistics bases and
the transit routes between these, and coastal areas that could be affected by
routine discharges as well as accidents events such as an oil spill. The T.E.N.
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EIA will, in particular, consider cumulative impacts from the Jubilee
development.
The project is located near the border with Cote d’Ivoire and ecological
systems are connected so some interaction may occur. Transboundary
impacts will therefore also be addressed in the EIA.
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8
TERMS OF REFERENCE FOR EIA
8.1
INTRODUCTION
This chapter provides the proposed Terms of Reference for the EIA and in
structured as follows.
•
•
•
•
•
8.2
Next steps required to complete the EIA process.
Proposed baseline studies.
Stakeholder engagement.
Outline structure of the EIS.
Provisional schedule for the EIA process.
NEXT STEPS TO COMPLETE THE EIA PROCESS
Following submission of the Scoping Report to EPA, the EIA team will
undertake the following tasks.

The project description will be updated and finalised as further
engineering details become available from the FEED studies. The EIA
team will work with TGL’s drilling, FPSO and subsea engineering
contractors and confirm parameters for the modelling studies and impact
assessment.

Baseline data collection and specialist studies (including modelling
studies) will be completed and reported in an environmental and social
baseline chapter as part of the EIA report (see Section 8.3 below).

Impact assessment will be undertaken to determine significance ratings
according to predefined impact assessment methodology. The proposed
impact assessment methodology is attached in Annex E.

Mitigation and monitoring measures will be developed and an outline
Environmental Management Plan (EMP) as part of the EIA (see Annex E).

Stakeholder engagement will continue throughout the EIA process (see
Section 8.4 below).

The findings of the EIA will be reported in a comprehensive EIS will be
EIS for regulator review and public comment. A final EIS will be
submitted addressing regulator and public comments.
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8.3
PROPOSED BASELINE STUDIES
During the EIA, information will be collated and reviewed and studies will be
undertaken to provide additional information on the current environmental
and socio-economic baseline against which the identified potential impacts
will be assessed. Specialist studies will also be undertaken to assess key issues
identified during the EIA Scoping study. The scope of these specialist studies
are presented below. Spatial data collected or created during the EIA will be
stored in a Geographical Information System (GIS) for subsequent
combination and analysis and the graphical presentation of the results in the
EIS.
8.3.1
Environmental Baseline
The EIA team will obtain and review existing data and primary data being
collected by TGL as part of the T.E.N. project and from previous studies in the
area. The EIA team will update secondary data sets with new data that may
be available for those sources. In particular, results from the following studies
will be used to update secondary datasets.

CSA (2011a) T.E.N. Environmental Baseline Study. The EBS involved
sampling at 15 sampling stations within DWT block as shown in Figure 8.1.
The EBS included water and sediment sampling, and seafloor
photography. The water column was sampled for chemical, hydrographic
and biological parameters. Sediment sampling included analysis of
chemical, physical and biological parameters. The T.E.N. EBS results,
together with previous Jubilee and regional EBS studies, will provide
sufficient data to characterise the offshore benthic environment in the
vicinity of the T.E.N. development including the pipeline route between
T.E.N. and the Jubilee FPSO.

CSA (2011b) Drill Cuttings Study. The aim of the study was to verify the
Jubilee Phase 1 drilling discharge modelling predictions and the effects of
drill cuttings discharge in terms of environmental impacts. The study
included desktop review of drilling discharges in deepwater environments
and a marine survey and analysis of sediment samples to determine the
level of contamination from cuttings (if any) and the extent of impact. The
results of this study will provide additional information on regional
sediment quality and baseline conditions.

TGL (2011b) Fisheries Study. This study, prepared by ERM and ESL for
TGL updated information on fish resources and fisheries off the Western
Region of Ghana using published data from Ghanaian and international
sources and from consultations with fisheries regulations and fisher
associations.
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3°0'0"W
2°30'0"W
2°0'0"W
KEY:
DWT Block
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20
Kilometres
TITLE:
Figure 8.1
Benthic sampling station locations
in relation to DWT block
CLIENT:
4°0'0"N
DATE: 22/12/2011
CHECKED: ADJ
PROJECT: 0142816
DRAWN: KM
APPROVED: MI
SCALE: As scale bar
DRAWING:
Surveys.mxd
ERM
Norloch House
Edinburgh
EH1 2EU
United Kingdom
Telephone:+44 (0) 131 478 6000
Facsimile: +44 (0)131 656 5813
SOURCE:
3°0'0"W
2°30'0"W
2°0'0"W
SIZE:
A4
REV:
0

8.3.2
Gardline Environmental (2011) Marine Mammal and Turtle Observation Report.
The report presents the findings from incidental and ad hoc sightings of
marine mammals and turtles between 17 November 2009 and 31 January
2011. All observations were conducted by TGL personnel onboard various
vessels operating in the Jubilee Field, including the MV Orient and MV
Oceanix Orion. This data will augment secondary data that is available on
these topics.
Socio-economic Baseline
Socio-economic data collection will be undertaken by ERM, ESL and SRC and
supported by TGL. Data will be collected using a range of methods, including
review of secondary data and supplemented with primary data collection
through, for example, key informant and focus group interviews.
The primary baseline data will be used to ground-truth available secondary
data and characterise the communities, as well as to contextualise the socioeconomic, socio-cultural, political environment and overall quality of life. The
data collection process will focus on gathering information based around
several data categories including the following.

Demographics (eg total population, age, gender, ethnicity, language,
religion, household size and structure).

Economic overview (eg contribution to GDP, levels of employment/
unemployment, poverty).

Economic and livelihood activities (eg fishing, farming, commercial)
specifying the nature, extent and capacity of these activities.

Social organisation and community governance, including socio-political
context and relevant governmental institutions.

Health and education overview.

Economic/ development trends and context.

Cultural and religious practices/sensitivities.

Vulnerable/marginalised people.

Availability and quality of infrastructure and services (eg housing, water,
energy, transport).
The data collection work will focus on providing a description of the socioeconomic status and condition of potentially affected communities and
stakeholders. Findings of the consultation process will also inform the
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assessment of socio-economic impacts. The study area will focus on the six
coastal districts in the Western Region.
8.3.3
Baseline Reporting
Following completion of the baseline studies, the EIA team report the finding
in the EIS. This will provide a description of the existing environmental and
social conditions in the main EIS supported by more detailed information in
annexes as required. The aim of the baseline reporting will be to provide
sufficient information to undertake the following tasks.
8.3.4

Identify the key environmental and social conditions in areas potentially
affected by the project and highlight those that may be vulnerable to
aspects of the project.

Describe their characteristics (nature, condition, quality, extent, etc) now
and in the future in the absence of the project.

Provide sufficient data to inform judgments about the importance, value
and sensitivity/ vulnerability or resources and receptors to allow the
prediction and evaluation of potential impacts.
Quantitative Specialist Studies
Modelling studies will be undertaken to provide quantitative information on
drilling discharges, produced water discharges, oil spills and air emissions to
inform the EIA. These studies will include the following.

Modelling of oil spills potentially resulting from accidental events (ie
collisions, ruptures, blowout, etc).

Aquatic dispersion modelling of operational discharges, including drill
cuttings discharges and produced water discharges.

Atmospheric dispersion modelling of project emissions to air will be
undertaken to determine the extent of possible impacts on air quality
under prevailing meteorological conditions.
Marine Modelling Studies
Oil spill and aquatic discharge modelling will be undertaken by Applied
Science Associates (ASA) which undertook similar studies for the Jubilee Field
Phase 1 Development EIA. The following activities will be undertaken for the
modelling work.
Input Data and Hydrodynamic Modelling
An assessment of the hydrodynamic field and the dominant wind patterns in
the study area will be undertaken to determine the best hydrodynamic data
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available to suit the local and regional circulation features and utilise these
currents for the modelling tasks. Additionally, data from previous studies
will be gathered and integrated, including any in situ or remote measurements
provided by TGL.
Drilling Discharge Simulations
ASA’s MUDMAP model will simulate the drilling fluid and cuttings
discharges, reproducing the dispersion and sea bottom sedimentation of bulk
discharges during the drilling programme. Each modelling scenario will
assume a particular discharge from a site location (eg single well or
combination) and can reproduce different drilling sections and their
corresponding disposals on the seabed or on the water surface accordingly to
a single drilling program.
Drilling discharge dispersion modelling outputs will provide:

a description of sea bottom deposition at the end of the assumed drilling
programme, expressed as accumulated bottom thickness; and

water column concentration (time series and iso-contours) of drilling
fluids.
Crude Oil and Diesel Surface Spill Simulations
The modelling study will include several surface (two dimensional) oil and
diesel spill simulations. Scenarios will reproduce different spill conditions,
products, volumes, locations and seasonal periods. A realistic combination of
scenarios will be confirmed with TGL.
ASA’s OILMAP model will be used in both stochastic and deterministic mode
to compute sea surface and shoreline contact of surface oil for releases from
the specified spill sites, as well as weathering calculations. Crude oil and
diesel spill model results will provide probability of surface oiling and spill
travel-time contours. For each (stochastic) spill scenario, a representative or
‘worst case’ will be determined, typically the shortest time to shore.
Blowout Spill Simulations
Three-dimensional blowout simulations will be performed including a near
field analysis, describing the oil/gas plume generated by the blowout and the
far field long term transport and weathering of released hydrocarbons.
The near field analysis will be performed using a plume model that will
describe the vertical and horizontal extent of the oil/gas/condensate mixture
plume. Depending on the blowout conditions, the far field analysis can be
completed using a surface two-dimensional or full three-dimensional
approach. The output from both options provide surface oiling probabilities,
spill travel-time contours and trajectories of representative cases.
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Produced Water Discharge Simulations
ASA’s CHEMMAP will be used to model the dispersion and fate of the release
of produced water from the site. The produce water continuous discharges
will be simulated as a conservative constituent. Concentrations of produced
water as it is transported throughout the receiving waters will be tracked to a
concentration or dilution factor. The results of each simulation will be
presented in figures presenting a characteristic spatial profile of the produced
water concentration field.
Assessment of Emissions to Atmosphere and Dispersion Modelling
Atmospheric dispersion modelling will be undertaken to support the
assessment. The aim will be to assess the additional impact of the T.E.N. on
regional air quality and, in particular focus on potential impacts on coastal
communities as these are considered to be the most significant potential
receptors that could be exposed to long term impacts as a result of the
prevalent wind directions in the area. The assessment will also consider
cumulative emissions with simultaneous production operations at the Jubilee
Field.
The assessment will utilise the AERMOD dispersion model. This model
utilises a number of parameters including details of emissions, emission point
characteristics and meteorological information to predict the dispersion of
emissions and subsequent impacts at ground level. AERMOD is promulgated
by the United States Environmental Protection Agency and is widely
recognised as being suitable for this type of assessment.
Emissions to atmosphere from the T.E.N. development will arise primarily
from the combustion of fossil fuels, but also from the cold venting of
hydrocarbons. The dispersion modelling study will therefore focus on the
parameters below.







Nitrogen dioxide (NO 2 ).
Nitric oxide (NO).
Sulphur Dioxide (SO 2 ).
Carbon Monoxide (CO).
Particles <10µm in aerodynamic diameter (PM 10 ).
Particles <2.5µm in aerodynamic diameter (PM 2.5 ).
Volatile Organic Compounds (VOCs).
The dispersion study will be carried out to international standards, such as
IFC EHS guidelines. Where appropriate, reference will also be made to other
international air quality standards and Ghanaian air quality standards.
8.3.5
Fisheries Impact Assessment
Section 93 of the Fisheries Act stipulates that if a proponent plans to undertake
an activity which is likely to have a substantial impact on the fisheries
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resources, the Fisheries Commission should be informed of such an activity
prior to commencement. The Commission may require information from the
proponent on the likely impact of the activity on the fishery resources and
possible means of preventing or minimising adverse impacts. As such, the
Fisheries Commission has been consulted as a key stakeholder in the EIA and
potential impacts on fisheries resources will be assessed as part of the T.E.N.
EIA. The fisheries study (TGL, 2011b) will provide an up to date baseline on
fish ecology and fisheries activities against which potential fisheries impacts
can be assessed. Potential impacts that will be assessed are outlined in
Chapter 7.
8.3.6
Tema Fabrication Yard Consultations and Baseline Data
The existing Tema shipyard has been identified as a potential site for an
onshore fabrication facility. Information on TGL’s proposals for investing in
Tema port is provided in Section 2.7.5.
Consultations will be undertaken to inform relevant stakeholders about the
proposed developments at the Tema fabrication yard and to obtain their
views. Consultation meetings will be held with the GPHA as well as the
Tema metropolitan assembly.
The EIA team will undertake a site reconnaissance and review of existing
information on the baseline environmental and socio-economic conditions of
the site and surrounding area. No primary data collection is envisaged at this
stage as the development is within an established industrial zone.
8.4
STAKEHOLDER ENGAGEMENT
Having completed scoping consultation, as discussed in Chapter 5, further
consultation will be undertaken during the following stages:



Disclosure of Scoping Report;
Baseline Studies;
Draft EIS Disclosure, Public Hearings and Final EIS Disclosure.
Disclosure of Scoping Report
The Scoping Report has been submitted to the EPA for review. Following
approval of the Scoping Report the EPA will issue a letter to inform TGL that
the process can proceed to EIA phase. The letter will also include comments
on the Scoping Report and proposed Terms of Reference for the EIA.
The Scoping Report will be disclosed by EPA to Ministries and by TGL to the
general other stakeholders subsequent to the EPA’s approval. An
advertisement announcing the release of the Scoping Report for comment will
be published. Copies of the Scoping Report will also be placed at central
00002-E78-ES-RPT-0005 – REV0
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locations for public review. Copies of the Scoping Report will likely be placed
at the following locations (subject to EPA advice):
•
•
•
•
EPA library, Accra;
Tullow Offices, Accra;
Tullow Offices, Takoradi; and
Sekondi Public Library.
More copies will be distributed to key stakeholders, including the six coastal
districts in the Western Region. A website will be created with up-to-date
information on the T.E.N. development and the EIA process. Copies of the
Scoping Report and BID will be available for download from the project
website.
Baseline Studies
Further, local level engagement activities, will be undertaken during the socioeconomic baseline studies. This will involve focus group meetings with
representative of coastal communities and consultation with District
leadership. The primary aim of these consultations will be data collection,
however, stakeholder views and concerns will continued to be gathered
during these engagements.
Draft EIS Disclosure, Public Hearings and Final EIS Disclosure
Disclosure of the Draft EIS will provide detailed information about the
proposed project activities, an assessment of the potential impacts and the
planned mitigation and monitoring measures. The Draft EIS will be issued to
EPA and advertised. Copies of the Draft EIS will be made available at a
number of locations for public review and comment. The Draft EIS will
include a non-technical summary which will present the EIA findings in a
non-technical format. TGL will support the distribution process as required
and directed by the EPA.
Given the nature and scale of the proposals it is expected that Public Hearings
will be required which will be organised by the EPA and attended by TGL
and members of the EIA team as required. Following the Public Hearings the
comments received on the Draft EIS will be addressed and a Final EIS
submitted to EPA for decision-making on the Environmental Permit
application.
8.5
OUTLINE STRUCTURE OF THE EIS
An outline of the proposed contents of the main volume of the EIS is provided
in Annex F. The proposed contents follow previous EPA guidance on EIS
report structure. The content may altered during the evolution of the project
or based on the findings of on-going consultation, however it is anticipated
00002-E78-ES-RPT-0005 – REV0
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that the contents of the EIS will align broadly within the suggested
framework.
8.6
PROVISIONAL SCHEDULE FOR THE EIA PROCESS
A provisional schedule for the EIA is provided in Table 8.1.
Table 8.1
EIA Schedule
Activity
Start
EPA Review of Scoping Report
Disclosure of Scoping Report
Baseline and Specialist Studies
Compile Draft EIS
Submission of Draft EIS
EPA review of Daft EIS
Disclosure of EIS and Public Hearings
Decision on Final EIS
February 2012
January 2012
March 2012
May 2012
June 2012
Timing
Finish
January 2012
February 2012
February 2012
April 2012
May 2012
June 2012
July 2012
August 2012
00002-E78-ES-RPT-0005 – REV0
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9
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