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Elgin / Franklin Further Development

Environmental Statement

Elgin

Franklin

Glenelg

West Franklin

OrkneyIslands

ShetlandIslands

Aberdeen

BUS-110408-62608

STANDARD INFORMATION SHEET

Project (Installation) Name: Elgin and Franklin Further Development Environmental

Statement DECC Reference number: D/4111/2011 Type of Project: Production increase and pipeline route deviation addendum Undertaker name: Total E&P UK Ltd Undertaker address: Crawpeel Road

Altens Industrial Estate Aberdeen AB12 3FG

Licensees/Owners: Total E&P UK 35.784%

BG GROUP 14.11% GDF Suez 10.389% ENI UK Limited 21.867% EON 5.2% ExxonMobil 4.375% Chevron North Sea 3.9% Dyas 2.188% Summit Petroleum 2.188%

Short description: Increase in production from the Elgin and Glenelg fields as a

result of better than expected reservoir performance and the drilling of replacement production wells for those that are currently expected to fail. New production wells will be drilled from a new Elgin Wellhead Platform, Elgin Wellhead Platform B, which will also become the host for the West Franklin Phase 2 Development.

Anticipated commencement Offshore Installation, mid 2013 of works: Significant environmental None impacts identified: Statement prepared by: Xodus Aurora

Total E&P UK Ltd

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Elgin and Franklin Further Development Environmental Statement

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TABLE OF CONTENTS Page

ABBREVIATIONS ..................................................................................................................... VII

GLOSSARY................................................................................................................................ XI

NON-TECHNICAL SUMMARY.................................................................................................. XV

S1 INTRODUCTION ........................................................................................................................ XV S1.1 Project Schedule ..........................................................................................................xvi S1.2 The Environmental Impact Assessment Process ........................................................xvi S1.3 Consideration of Alternatives ...................................................................................... xvii

S2 THE DEVELOPMENT ............................................................................................................. XVIII S2.1 Wells and Drilling..........................................................................................................xix S2.2 Installation of New Facilities.........................................................................................xix S2.3 Decommissioning .........................................................................................................xix

S3 ENVIRONMENT ......................................................................................................................... XX S3.1 Physical environment ....................................................................................................xx S3.2 Biological Environment.................................................................................................xxi S3.3 Other Sea Users.......................................................................................................... xxii S3.4 Conservation ............................................................................................................... xxii

S4 ATMOSPHERIC EMISSIONS .................................................................................................. XXII

S5 DISCHARGES TO SEA........................................................................................................... XXIII

S6 SEABED IMPACTS .................................................................................................................XXIV

S7 INTERACTIONS WITH OTHER SEA USERS .........................................................................XXV

S8 NOISE.......................................................................................................................................XXV

S9 SPILL RISK...............................................................................................................................XXV

S10 ENVIRONMENTAL MANAGEMENT.......................................................................................XXVI

S11 CONCLUSIONS .....................................................................................................................XXVII

1 INTRODUCTION....................................................................................................................1

1.1 BACKGROUND ............................................................................................................................. 1

1.2 SCHEDULE ................................................................................................................................... 2

1.3 SCOPE OF THE ENVIRONMENTAL STATEMENT..................................................................... 3

1.4 POLICY, LEGAL AND ADMINISTRATIVE FRAMEWORK........................................................... 3

1.5 TOTAL E&P UK ENVIRONMENTAL POLICY .............................................................................. 4

1.6 CONSULTATION........................................................................................................................... 5

2 PROJECT ALTERNATIVES ..................................................................................................7

2.1 INTRODUCTION ........................................................................................................................... 7

2.2 DECISIONS MADE........................................................................................................................ 7

2.3 DECISIONS REMAINING TO BE MADE ...................................................................................... 8 2.3.1 Bundle versus conventional pipeline.............................................................................. 8

3 PROJECT DESCRIPTION.....................................................................................................9

3.1 OVERVIEW ................................................................................................................................... 9

3.2 OVERVIEW OF DRILLING PROGRAMME .................................................................................. 9 3.2.1 Well design and mud programme .................................................................................. 9 3.2.2 Cuttings handling............................................................................................................ 9


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3.2.3 Cementing .................................................................................................................... 10 3.2.4 Completions and well cleanup ..................................................................................... 10 3.2.5 Workovers and interventions........................................................................................ 10

3.3 ELGIN WHP B ............................................................................................................................. 10 3.3.1 Jackets and piles.......................................................................................................... 10 3.3.2 Topsides....................................................................................................................... 11

3.4 SUBSEA FACILITIES.................................................................................................................. 11

3.5 PRODUCTION OVERVIEW ........................................................................................................ 12 3.5.1 Condensate production ................................................................................................ 12 3.5.2 Gas production ............................................................................................................. 13 3.5.3 Produced water ............................................................................................................ 16

3.6 EXISTING FACILITIES - ELGIN.................................................................................................. 17 3.6.1 Separation .................................................................................................................... 17 3.6.2 Gas process and natural gas liquids ............................................................................ 17 3.6.3 Produced water ............................................................................................................ 19 3.6.4 Amine system............................................................................................................... 19 3.6.5 Drains system............................................................................................................... 20 3.6.6 Power generation ......................................................................................................... 20 3.6.7 Flare and vent system.................................................................................................. 20 3.6.8 Other utilities ................................................................................................................ 20

3.7 NEW FACILITIES DESCRIPTION .............................................................................................. 21 3.7.1 Project Overview .......................................................................................................... 21 3.7.2 Facilities Overview ....................................................................................................... 21 3.7.3 Processing and Ancillary Equipment and Facilities ..................................................... 22

3.8 COMMISSIONING....................................................................................................................... 23

3.9 INSPECTION AND MAINTENANCE........................................................................................... 23

3.10 DECOMMISSIONING.................................................................................................................. 23

4 THE ENVIRONMENT...........................................................................................................25

4.1 INTRODUCTION ......................................................................................................................... 25

4.2 METEOROLOGY......................................................................................................................... 26

4.3 HYDROGRAPHY......................................................................................................................... 26 4.3.1 Bathymetry ................................................................................................................... 26 4.3.2 Current regime and water masses ............................................................................... 26 4.3.3 Waves .......................................................................................................................... 27 4.3.4 Temperature and salinity.............................................................................................. 27 4.3.5 Water Quality................................................................................................................ 28

4.4 SEABED SEDIMENTS ................................................................................................................ 28

4.5 THE BIOLOGICAL ENVIRONMENT........................................................................................... 29 4.5.1 Plankton ....................................................................................................................... 29 4.5.2 Benthic communities .................................................................................................... 30 4.5.3 Fish populations ........................................................................................................... 30 4.5.4 Seabirds ....................................................................................................................... 31 4.5.5 Marine mammals.......................................................................................................... 32

4.6 OTHER SEA USERS................................................................................................................... 34 4.6.1 Fisheries....................................................................................................................... 34 4.6.2 Shipping ....................................................................................................................... 36 4.6.3 Submarine cables......................................................................................................... 36 4.6.4 Wrecks ......................................................................................................................... 36 4.6.5 Oil and gas activities .................................................................................................... 37


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4.6.6 Military activity .............................................................................................................. 38

4.7 CONSERVATION........................................................................................................................ 38

5 EIA PROCESS AND METHODOLOGY...............................................................................41

5.1 OVERVIEW ................................................................................................................................. 41

5.2 CUMULATIVE ASSESSMENT.................................................................................................... 42

5.3 DATA GAPS ................................................................................................................................ 42

5.4 ONGOING ENVIRONMENTAL ASSESSMENT ......................................................................... 42

6 ATMOSPHERIC EMISSIONS ..............................................................................................45

6.1 INTRODUCTION ......................................................................................................................... 45

6.2 REGULATORY CONTROL ......................................................................................................... 45

6.3 SUBSEA STRUCTURE/ELGIN WHP B INSTALLATION AND PIPELAY ACTIVITIES.............. 46

6.4 ELGIN WHP B EMISSIONS ........................................................................................................ 48 6.4.1 Drilling Operations........................................................................................................ 48 6.4.2 Power Generation and Flaring ..................................................................................... 49

6.5 MANAGEMENT AND MITIGATION ............................................................................................ 50

6.6 RESIDUAL, TRANSBOUNDARY AND CUMULATIVE IMPACTS.............................................. 50

7 DISCHARGES TO SEA .......................................................................................................53

7.1 INTRODUCTION ......................................................................................................................... 53

7.2 REGULATORY CONTROL ......................................................................................................... 53 7.2.1 Offshore Chemicals (Amendment) Regulations 2002 (as amended) (OCR)............... 53 7.2.2 Offshore Petroleum Activities (Oil Pollution Prevention and Control) regulations 2005

(OPPC) (as amended) ................................................................................................. 53 7.2.3 Sewage discharges...................................................................................................... 53

7.3 DRILLING DISCHARGES ........................................................................................................... 54

7.4 TOPSIDES COMMISSIONING DISCHARGES .......................................................................... 54

7.5 OPERATIONAL DISCHARGES .................................................................................................. 54

7.6 MANAGEMENT AND MITIGATION ............................................................................................ 54 7.6.1 Drilling Discharges ....................................................................................................... 54 7.6.2 Operational Discharges................................................................................................ 54

7.7 RESIDUAL IMPACTS.................................................................................................................. 55 7.7.1 Drilling Discharges ....................................................................................................... 55 7.7.2 Operational Discharges (produced water) ................................................................... 56

7.8 CUMULATIVE AND TRANSBOUNDARY IMPACTS .................................................................. 57

8 SEABED IMPACTS .............................................................................................................59

8.1 INTRODUCTION ......................................................................................................................... 59


8.3 DESCRIPTION OF POTENTIAL IMPACTS................................................................................ 59 8.3.1 Drilling .......................................................................................................................... 59 8.3.2 Pipeline installation....................................................................................................... 60 8.3.3 Jacket Installation......................................................................................................... 61

8.4 MANAGEMENT AND MITIGATION ............................................................................................ 62

8.5 CUMULATIVE IMPACTS ............................................................................................................ 62 8.5.1 Direct physical injury of benthic species ...................................................................... 62 8.5.2 Resuspension of sediments ......................................................................................... 62


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8.5.3 Localised loss/modification of seabed habitat.............................................................. 63 8.5.4 Conclusions.................................................................................................................. 63

8.6 CUMULATIVE AND TRANSBOUNDARY IMPACTS .................................................................. 63 8.6.1 Cumulative Impacts...................................................................................................... 63 8.6.2 Transboundary impacts................................................................................................ 64

9 INTERACTIONS WITH OTHER SEA USERS......................................................................65

9.1 INTRODUCTION ......................................................................................................................... 65


9.3 POTENTIAL IMPACTS................................................................................................................ 65

9.4 MANAGEMENT AND MITIGATION STRATEGY........................................................................ 67

9.5 RESIDUAL IMPACTS.................................................................................................................. 67 9.5.1 Increased vessel traffic ................................................................................................ 67 9.5.2 Fishing Interference ..................................................................................................... 67

9.6 CUMULATIVE OR TRANSBOUNDARY IMPACTS .................................................................... 68

10 NOISE..................................................................................................................................69

10.1 INTRODUCTION ......................................................................................................................... 69

10.2 LEGISLATION REVIEW.............................................................................................................. 69

10.3 THE ELGIN AREA....................................................................................................................... 70 10.3.1 Marine Mammals of the Central North Sea.................................................................. 70

10.4 NOISE SOURCES AND POTENTIAL IMPACTS........................................................................ 71 10.4.1 Noise Sources at the Elgin Development .................................................................... 71 10.4.2 Assessment of noise sources ...................................................................................... 72

10.5 MANAGEMENT AND MITIGATION MEASURES....................................................................... 73 10.5.1 Vessel Noise ................................................................................................................ 73 10.5.2 Piling Noise .................................................................................................................. 73

10.6 PILING NOISE IMPACT ON EUROPEAN PROTECTED SPECIES (EPS)................................ 74 10.6.1 The model .................................................................................................................... 74 10.6.2 Noise propagation ........................................................................................................ 74 10.6.3 Injury Impact................................................................................................................. 75 10.6.4 Disturbance Impact ...................................................................................................... 76 10.6.5 EPS License................................................................................................................. 78

10.7 RESIDUAL IMPACTS.................................................................................................................. 78 10.7.1 Vessel noise ................................................................................................................. 78 10.7.2 Piling noise ................................................................................................................... 78

10.8 CUMULATIVE AND TRANSBOUNDARY IMPACTS .................................................................. 78 10.8.1 Cumulative impacts ...................................................................................................... 78 10.8.2 Transboundary impacts................................................................................................ 79

11 SPILL RISK .........................................................................................................................81

11.1 INTRODUCTION AND BACKGROUND...................................................................................... 81

11.2 LIKELIHOOD OF SPILL .............................................................................................................. 81


11.4 OIL SPILLS.................................................................................................................................. 81 11.4.1 Drilling Rig, Installation and Supply Vessels................................................................ 82 11.4.2 Blowouts....................................................................................................................... 84 11.4.3 Multiphase Pipeline ...................................................................................................... 86

11.5 POTENTIAL OIL SPILL IMPACTS .............................................................................................. 86


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11.5.1 Overview ...................................................................................................................... 86 11.5.2 Oil Spill Modelling......................................................................................................... 86 11.5.3 Impact on environmental sensitivities .......................................................................... 89 11.5.4 Residual risks and oil spill contingency planning ......................................................... 89 11.5.5 Cumulative and transboundary impacts....................................................................... 89

11.6 CHEMICAL SPILL RISK.............................................................................................................. 90 11.6.1 Background .................................................................................................................. 90 11.6.2 Mitigation and residual risks......................................................................................... 90

12 ENVIRONMENTAL MANAGEMENT ...................................................................................91

12.1 ELGIN ENVIRONMENTAL MANAGEMENT AND COMMITMENTS.......................................... 92

12.2 ENVIRONMENTAL MONITORING ............................................................................................. 92

12.3 ENVIRONMENTAL AWARENESS AND TRAINING................................................................... 93

12.4 CONTRACTOR INTERFACE...................................................................................................... 93

13 CONCLUSIONS...................................................................................................................95

13.1 APPROACH................................................................................................................................. 95

13.2 POTENTIAL RESIDUAL ENVIRONMENTAL ISSUES ............................................................... 95 13.2.1 Atmospheric Emissions................................................................................................ 95 13.2.2 Discharges to Sea........................................................................................................ 95 13.2.3 Seabed Impacts ........................................................................................................... 95 13.2.4 Interactions with other sea users ................................................................................. 96 13.2.5 Noise ............................................................................................................................ 96 13.2.6 Spill Risk....................................................................................................................... 96 13.2.7 Environmental Management ........................................................................................ 96

13.3 TRANSBOUNDARY IMPACTS ................................................................................................... 96

13.4 CUMULATIVE IMPACTS ............................................................................................................ 96

13.5 FINAL REMARKS........................................................................................................................ 97

REFERENCES ...........................................................................................................................99

APPENDIX A COMMITMENTS REGISTER ......................................................................107

APPENDIX B EIA METHODOLOGY ................................................................................113

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ABBREVIATIONS

AQS Air Quality Standard

BAT Best Available Technique

BODC British Oceanographic Data Centre

BPEO Best Practicable Environmental Option

CHARM Chemical Hazard Assessment and Risk Management

CO2 Carbon Dioxide

dB Decibel

DECC Department for Energy and Climate Change

DP Dynamic Positioning

DST Drill Stem Test

DSV Diving Support Vessel

DTI Department for Trade and Industry (now DECC)

DWT Dry Weight Tonnes

EAC Ecotoxicological Assessment Criteria

EEMS Environmental Emissions Monitoring System

EIA Environmental Impact Assessment

EMS Environmental Management System

ENVID Environmental Issues Identification

EPS European Protected Species

ERD Extended Reach Drilling

ERL Effects Range Low

EWHP A Elgin Wellhead Platform A

EWHP B Elgin Wellhead Platform B

ES Environmental Statement

ESDV Emergency Shut Down Valve

EU ETS European Union Emissions Trading Scheme

H2S Hydrogen Sulphide

HMIP Her Majesty’s Inspectorate of Pollution

HIPPS High Integrity Pressure Protection System

HLV Heavy Lift Vessel

HP High Pressure

HPHT High Pressure High Temperature

HPU Hydraulic Power Unit

HSE Health and Safety Executive

Hz Hertz

IAPP International Air Pollution Certificate

ICES International Council for Exploration of the Sea

IMO International Maritime Organisation

IOPPC International Oil Pollution Prevention Certificate

IPC Integrated Pollution Control

IPCC Integrated Pollution Prevention and Control

JNCC Joint Nature Conservation Committee

kHz Kilohertz


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LAQM Local Air Quality Management

LP Low Pressure

LTS Low Temperature Separator

MDAC Methane Derived Authigenic Carbon

MDEA Methyl diethanolamine

MMO Marine Mammal Observer

MPFM Multiphase Flow Meter

MW Megawatt

NAO North Atlantic Oscillation

NGL Natural Gas Liquids

NO2 Nitrogen Dioxide

NORM Naturally Occurring Radioactive Material

NOx Nitrogen Oxides

NUI Normally Unattended Installation

OCR Offshore Chemicals Regulations

OPEP Oil Pollution Emergency Plan

OPF Oil Phase Fluids

OPPC Oil Pollution Prevention and Control

OPPS Over Pressure Protection System

OPRC Oil Pollution, Preparedness, Response and Co-operation

OSIS Oil Spill Information System

OSPAR Oslo/Paris convention (for the Protection of the Marine Environment of the North-East Atlantic)

PAH Polycyclic Aromatic Hydrocarbon

PCB Polychlorinated Bi-phenyl

PON Petroleum Operations Notice

PPC Pollution Prevention and Control

PUQ Production and Utilities Quarter

PWA Pipeline Works Authorisation

RGV Rowan Gorilla V

ROV Remotely Operated Vehicle

RQ Risk Quotient

SAC Special Area of Conservation

SAST Seabirds at Sea

SEA Strategic Environmental Assessment

SHE Safety, Health and Environment

SO2 Sulphur Dioxide

SOPEPS Shipboard Oil Pollution Emergency Plan

SOR Statement of Requirements

SOx Sulphur Oxides

SPA Special Protected Area

SSSI Site of Special Scientific Interest

TBT Tributyltin

TEG Triethylene Glycol

TOC Total Organic Carbon


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TTS Temporary Threshold Shift

TUTU Topsides Umbilical Termination Unit

TVDSS True Vertical Depth Subsea

TWMA Total Waste Management Alliance

UK United Kingdom

UKAPP United Kingdom Air Pollution Certificate

UKCS United Kingdom Continental Shelf

UKDMAP United Kingdom Digital Marine Atlas

UKHO United Kingdom Hydrographic Office

UKOOA United Kingdom Offshore Operators Association (Now Oil and Gas UK)

UKOPPC UK Oil Pollution Prevention Certificate

US CEQ United States Council on Environment Quality

VSP Vertical Seismic Profiling

WFD Waste Framework Directive

WHP Wellhead Platform

WPF Water Phase Fluids


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GLOSSARY

Appraisal well A well drilled to confirm size or quality of an oil discovery. Before Development, a discovery is likely to need at least two or three such wells.

Atmospheric emissions

Collective term for gases released to the earths atmosphere.

Backfill Replacing the earth dug from a ditch or trench; or the earth removed from an excavation.

Baleen whales Whales that feed by means of a horny material, that hangs in a fine fringe from the roof of the mouth. This is used to sieve plankton and small fish from the water.

Barite A very heavy substance used as a main component of drilling mud to increase its density (mud weight) and counter-balance hydrostatic pressures.

Bathymetry The measurement of water depths in oceans, seas and lakes.

Benthos/Benthic The plant and animal community of the bottom of the sea, including littoral and sublittoral components.

Biodiversity/ Diversity

The diversity of plant and animal life. Diversity is the measure of the variety of species contained within a habitat.

Biotope The combination of species and their assemblages, and the physical space or habitat in which they live.

Bivalve Class of mollusc that includes clams, oysters, mussels and scallops, i.e. has two hinged ‘valves’.

Bryozoan Of the phylum Bryozoan that reproduce by budding and form moss-like or branching colonies permanently attached to stones or seaweed.

Cement Used to set casing in the well bore and seal off unproductive formations and apertures. It is also used as a coating to add weight to submarine pipelines.

Cetaceans Collective term for whales, dolphins and porpoises.

Commissioning Preparatory work, servicing etc. usually on newly installed equipment and all testing prior to full production.

Communities An ecological unit composed of the various populations of micro-organisms, plants and animals that inhabit a particular area.

Condensate Light hydrocarbon fractions produced with natural gas, which condense into liquid at normal temperature and pressures associated with surface production equipment.

Control umbilical Flexible line containing chemical injection hoses, electrical control cables etc, which permits control of subsea infrastructure from a Floating Production, Storage and Offloading facility (FPSO) or platform.

Continental shelf The gently sloping sea floor around landmasses. The shelf area is terminated by the continental slope at depths of between 120 and 370 m.

Crustacean Class of arthropods including crabs, shrimps, lobsters and barnacles.

Cumulative impacts Cumulative impacts are “changes in the environment that are caused by an action in combination with other past, present and future human activities”.

Cumulative impact assessment

Systematic review of the cumulative impacts a proposed project may have on its surrounding environment.

Decibel (dB) A unit used in the comparison of two power levels relating to sound (one tenth of a Bel).

Decommissioning Shutdown of subsea and surface facilities with system cleaning and dismantling of facilities.

Development well Any well drilled in the course of extraction of reservoir hydrocarbons, whether specifically a production well or injection well.

Drilling The process of excavating the seabed for the purpose of exploiting a hydrocarbon reservoir.

Drill cuttings Chips and small fragments of rock as the result of drilling that are brought to the surface by the flow of the drilling mud as it is circulated.

Drilling mud

Special clay, water and chemical additives, pumped downhole through the drill pipe and drill bit. The mud cools the rapidly rotating bit, lubricates the drill pipe as it turns in the well bore, carries rock cuttings to the surface and serves as a plaster to prevent the wall of the borehole from collapsing.

Dynamic positioning

Use of thrusters instead of anchors to maintain the position of a vessel.

Echolocation The location of objects using reflected sound.


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Ecosystem Describes the interrelationship between all organisms in a given area, and their relationships to the non-living materials.

Environmental Impacts Assessment

Systematic review of the environmental effects a proposed project may have on its surrounding environment.

Environmental Management System

System established to manage an organisation’s processes and resultant environmental impacts.

Environmental Statement

Formal document presenting the findings of an EIA process for a proposed project. Issued for public consultation in accordance with the Offshore Petroleum Production and Pipelines (Assessment of Environmental Effects) Regulations, 1999.

Epifauna Species that cling to rocks and other animals, such as crabs, fish, oysters, sea anemones, echinoderms and corals.

Exclusion zones Defined areas, usually 500m diameter circles, around certain surface and subsea structures for the purpose of restricting access to maintain safety.

Flare A vent for burning of unwanted gases or to burn off hydrocarbons which, due to temporary malfunction or maintenance of process plant, cannot be safely stored or retained in process vessels.

Flaring Process of venting unwanted gases through the flare. Flowlines Pipe through which fluids pass connecting two subsea facilities.

Footprint The area of influence of a certain activity/ emission. Including short, medium and long term effects.

Frequency range Range of frequencies which can be received or emitted by a given operation or animal.

Greenhouse gases Gases believed to contribute to the greenhouse effect, including carbon dioxide, water vapour and methane.

Habitat An area where particular animal or plant species and assemblages are found, defined by environmental parameters.

Habitats Directive

European directive on the conservation of natural habitats and of wild fauna and flora. It obliges member states to participate in running an ecological network of SACs. The network is entitled “'Natura 2000,” and comprises sites that host representative types of natural habitat and the habitats of vulnerable species.

Hydrocarbons

Organic chemical compounds of carbon and hydrogen atoms. There are a vast number of these compounds and the form the basis of all petroleum products. They may exist as gases, liquids, and examples include methane, hexane and asphalt.

Infauna Species which live within the sediments of the seafloor. Infrastructure Subsea pipelines, wellhead and manifold network installed on the seabed.

Macrofauna Benthic animals retained after washing sediment sample over a sieve mesh of 1.0 mm or 0.5 mm.

Manifold A piping arrangement which allows one stream of liquid or gas to be divided into two or more streams, or which allows several streams to be collected into one.

Mattress A large flexible mat made of concrete segments linked by steel or nylon cables; used to support and protect subsea facilities.

Mitigation measures Processes that would make a consequence less severe. Mollusc Phylum of invertebrates encased in calcareous shells.

Odontocetes Toothed whales, which include amongst others all dolphins and porpoises, sperm whales and beaked whales. They feed on fish, squid and in a few cases marine mammals.

Piling Operation during which tubular steel shafts are driven into the seabed to anchor a structure. Piles are usually driven through the centre of tubular platform legs or through external sleeves or skirts attached to legs

Pinnipeds Marine mammals that include the seals, sea lions and walruses; all have four swimming flippers.

Pipelines A rigid or flexible linear structure through which material is transported.

Platform A surface structure, which can take a number of forms, through which hydrocarbons are processed.


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Polychaetes A class of phylum annelida comprising the segmented worms. The outstanding characteristic of the polychaetes is the presence of parapodia or projections on the body that bear setae (bristles).

PON 15D Application to DECC seeking direction that an ES is not required for production operations, or that there are no expected significant impacts and/or seeking a permit for the use and discharge of chemicals during production operations.

Produced water Water, usually containing salts and metals produced with oil or gas/condensate in a producing well.

Production The full scale extraction of hydrocarbon reserves.

Production well A Development well specifically for the extraction of reservoir fluids. Production is the full-scale extraction of oil and gas reserves.

Power generation Is the process of burning fuel for energy to run the platform and associated machinery.

Re-entry The re-entry of a previously suspended well. May involve drilling through cement plugs and discharge of fluids left in the well.

Reservoir A porous, permeable sedimentary rock formation containing quantities of oil and/or gas enclosed or surrounded by layers of less permeable or impervious rock.

Rock dump The intentional deposition of rock material to enhance stability and provide protection of subsea facilities, particularly pipelines.

Scale Generic term for the precipitated material formed within pipelines and process equipment by the mixing of waters from different fields.

Scale inhibitor Chemicals designed to reduce the build up of scale on equipment or facilities.

Scope Term used to describe the range of information/investigation that a study will cover.

Sessile An organism that is attached to another structure by its base and is unable to move freely.

Shutdown Shutdown occurs when essential maintenance work is required or if a problem has arisen within the subsea or surface facilities.

S-lay S-lay is a pipeline installation method whereby the pipe joints are welded together on the barge and laid over a stringer at the stern of the vessel creating an S catenary from the vessel to the seabed.

Source level Defined as the sound pressure level that would be measured at a standard reference distance (e.g. 1 m) from an ideal acoustic point source radiating the same amount of sound as the actual source being measured.

Spawning Reproductive stage of fish and other marine animals when eggs are released into the water column or deposited on to the seabed or other substrata.

Special Area of Conservation (SAC)

Areas considered important for certain habitats and non-bird species of interest in a European context. One of the main mechanisms by which the EC Habitats and Species Directive 1992 is implemented. pSAC is a possible site that is being considered by the UK to ascertain whether it warrants presentation to the EC as a cSAC. cSAC is a site put forward by EC member states for consideration at European level for designation as a SAC.

Special Protection Area (SPA)

Sites designated under the EU Birds Directive as a Special Protection Area. A pSPA is a site being considered at European level for designation as an SPA.

Stakeholder Any individual or groups of people who are affected by, or have interest in, the activities and/or outcome of a project.

Toxicity Is the ability of a material to inflict damage to living tissue.

Transboundary Pertaining to any impact which originates within the boundaries of one party and which travels within the boundaries of another party, i.e. any impact which has the potential to cross boundaries.

Trawling Method of fishing in which a large bag-shaped net is dragged or trawled. Mouth of the bag is kept open by a variety of methods including wooden beams (beam trawl) or a large flat (otter) board (otter trawl).

Trenching The activity of excavating a passage in the seabed through which a pipeline can be laid.

Umbilical Flexible flowline, which provides power supply and chemical injection support to subsea facilities.

Upheaval Buckling

Operation that occurs when trenched pipelines are subjected to compressive forces as a result of high temperature and pressure. The pipeline experiences a large vertical displacement and push up through the sediment cover, leaving the pipeline exposed.


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Well A hole drilled or bored into the earth, usually cased with metal pipe, for the production of gas or oil. Also, a hole for the injection under pressure of water or gas into a subsurface rock formation.

Wellhead A top of casing and the attached control and flow valves. The wellhead is where the control valves, testing equipment and take-off piping are located.

Well testing

Testing in an exploration or appraisal well is directed at estimating reserves in communication with that well, in addition to well productivity. Testing in a production well also monitors the effects of cumulative production on the formation.

Zooplankton Free floating planktonic animals.


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NON-TECHNICAL SUMMARY

S1 INTRODUCTION

Total E&P UK and its partners wish to increase the production through the Elgin Complex, and reroute the proposed West Franklin Phase 2 pipeline to a new wellhead platform at Elgin, bridge linked to the existing Elgin wellhead platform. The Elgin Complex is located in UKCS blocks 22/30c and 22/30b, approximately 6 km to the north west of the West Franklin field in Block 29/05b. The West Franklin field is an adjacent structure to the western margin of Franklin field in the Central Graben area of the North Sea. The Elgin Complex is approximately 225 km from the coast of Scotland and 33 km from the UK Norway transboundary line (Figure S1).

Figure S1 Elgin Complex and West Franklin Location

The Elgin and Franklin fields are comprised of high pressure, high temperature (HPHT) gas condensate reservoirs located in the Central Graben Area of the U.K. Continental Shelf (UKCS). Gas produced from the fields is transported via pipeline to Bacton on the east coast of England. Liquids (condensate) are transported through the Forties Pipeline System to Kinneil, on the Firth of Forth. An Environmental Impact Assessment (EIA) as reported in this ES has been carried out in accordance with the requirements of the Offshore Petroleum Production and Pipelines (Assessment of Environmental Effects) Regulations 1999. These regulations require the undertaking of an EIA and the production of an ES for certain types of offshore oil and gas Developments likely to have a significant effect on the environment. The ES considers impacts from the following (Figure S2):

• Installation and commissioning of the new Elgin WHP B; • Increased production from the Elgin and Glenelg fields; and • Modification of the West Franklin Phase 2 pipeline route from Elgin WPB A to Elgin WHP B.


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Figure S2 Schematic of the Proposed Elgin Complex Overview

S1.1 Project Schedule

Fabrication, installation and commissioning of the new offshore facilities will begin in 2011 and continue until mid 2013. First production is expected in the 4

th Quarter of 2013 with an estimated field life of up to 25 years.

S1.2 The Environmental Impact Assessment Process

An EIA is a process designed to identify, interpret, predict and communicate information about the impact of a human action. The completion of an EIA is a legal requirement for projects of this type. The Environmental Statement (this document), is the documented output of the process, however, elements of the process continue through the Development of the project and into operation through Total E&P UK’s environmental management system (EMS). As the project progresses through detailed design, construction, installation and subsequent operations, environmental assessment will be ongoing. The outcome of this and those final decisions remaining to be made will be reported in the appropriate detailed consent submissions to DECC as appropriate. An overview of the EIA process is provided below in Figure S3.


Rev A01 – April 2011 Page xvii

Figure S3 EIA Process

Central to a pro-active environmental assessment is the requirement to identify issues that could have an impact on the environment and potential cumulative impacts. Once identified, these issues have to be assessed to define the level of potential risk they present to the environment, so that possible measures can be taken to remove such risk through design or operational measures (known as mitigation measures).

S1.3 Consideration of Alternatives

A key element of the EIA process is the consideration of alternatives prior to selecting the preferred option; this ensures that the environmental impacts and benefits of different options are fully explored, taking into consideration cost, safety and operability issues. The alternative Development options for the field were heavily influenced by the existence of the current Elgin and Franklin facilities, where utilising the existing facilities as far as possible was preferable in every respect to the construction of new facilities. The main options considered were 1. New High pressure / High Temperature (HP/HT) subsea wells tied back to Elgin Well Head Platform A

(Elgin WHP A); 2. Slot recovery of existing slots as wells fail or slot recovery of old exploration slots, G1, G2 and G3; 3. Addition of internal slots on the Elgin WHP A; 4. Addition of external slots on Elgin WHP A, and 5. Installation of a new WHP (Elgin WHP B) bridge linked to Elgin WHP A. A new wellhead platform Elgin B (Elgin WHP B), bridge linked to Elgin WHP A was carried forward as the preferred Development option for a number of reasons, including the following:

• There is an opportunity to add 6, 9 or 12 slots, and 5 or 6 wells can be drilled before the end of 2016; • It is technically feasible and a relatively simple option as it is similar to existing Elgin WHP A engineering

and design;

• De-risks West Franklin Brownfield (work to extend economic producing life of the field) scope;

• Efficient use of rig time, and • Less work is required on Elgin WHP A and the well intervention scope will be less impacted.


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S2 THE DEVELOPMENT

The increase in production will produce the following estimated volumes of gas and liquids.

Table S1 Annual Average Condensate Production Profiles

Year Elgin condensate

production thousand (thousand m

3/day)

Elgin production consent

(thousand m3/day)

Glenelg condensate production

(thousand m3/day)

Glenelg condensate production consent

(m3/day)

2011 5.13 6.3 0.098 0.35

2012 5.17 3.8 0.552 �

2013 5.01 3.2 0.553 �

2014 4.27 2.8 0.570 �

2015 3.82 2.7 0.383 �

2016 3.37 2.4 0.330 �

2017 2.97 0.223 2018 2.67 0.186 2019 2.38 0.150 2020 2.29 0.127 2021 2.05 0.000 2022 1.91 0.000 2023 1.78 0.000 2024 1.67 0.000 2025 1.55 0.000 2026 1.45 0.000 2027 1.36 0.000 2028 1.25 0.000 2029 1.11 0.000 2030 1.04 0.000 2031 0.98 0.000 2032 0.91 0.000 2033 0.85 0.000

Table S2 Annual Average Gas Production Profiles

Year Elgin gas production

(thousand m3/day)

Elgin gas production consent

(thousand m3/day)

Glenelg gas production

(thousand m3/day)

Glenelg gas production consent (thousand m

3/day)

2011 3932 3,880 119 116

2012 4474 2,550 683 �

2013 4616 2,330 685 �

2014 4226 2,180 705 �

2015 4016 2,240 474 �

2016 3697 2,070 409 �

2017 3378 276 2018 3120 230 2019 2830 185 2020 2776 157 2021 2509 0 2022 2352 0 2023 2195 0 2024 2055 0 2025 1905 0 2026 1771 0 2027 1651 0 2028 1497 0 2029 1317 0 2030 1221 0


Rev A01 – April 2011 Page xix

Year Elgin gas production

(thousand m3/day)

Elgin gas production consent

(thousand m3/day)

Glenelg gas production

(thousand m3/day)

Glenelg gas production consent (thousand m

3/day)

2031 1127 0 2032 1036 0 2033 953 0

There will also be a small incremental increase in water production associated with increased production (see S5).

S2.1 Wells and Drilling

The Elgin wells will be drilled by a jack-up rig. A jack-up is a floating barge fitted with long support legs that can be raised or lowered. The jack-up is towed (or self propelled) onto location with its legs up and the barge section floating on the water. Upon arrival at the drilling location, the legs are jacked down onto the seafloor. Wells will be drilled using different types of drilling muds according to the depth, including water based and oil based muds. It is expected that the drilling rig will be equipped with a Rotomill unit which evaporates the oil from drill cuttings, leaving solids as a dried, inert powder which can then be discharged to sea. As a contingency, provision for shipping oily cuttings to shore will be made in case the unit fails or cannot meet demand. The evaporated fluids are retained and further processes to separate out the oil and water. The recovered oil is recycled into the drilling mud system and the water is discharged overboard. With relevant legal permits in place, water based biodegradable / low toxicity mud and cuttings can be discharged overboard. Steel casings are installed throughout the drilling operation to provide structural strength and isolate instable formation fluids. Each casing is cemented to form a seal between the casing and the formation. Most cement remains in the wellbore, but small amounts will be discharged to the seabed during the setting of the top section. There may be additional small volumes of cement discharges associated with the cleaning of the cement unit between cementing operations. These discharges will be subject to approval by DECC as part of the permitting process under the Offshore Chemicals Regulations 2002 (as amended). Only once clean gas and condensate are produced from the well can they be sent for processing and export. Test fluids will therefore be flared and the well cleaned up during a flowing period of approximately 24 hours. These produced fluids will be flared through either through the Elgin PUQ facilities or the drilling rig prior to bringing new wells on stream.

S2.2 Installation of New Facilities

Once fabricated onshore, the main section of the steel platform (known as the jacket) will be transported to the Development area by towed cargo barges. The jacket will be lifted into position using a heavy lift vessel. The jacket will then be placed on the seabed. Foundation piles will be used to fix the jacket in place, using an underwater hydraulic hammer to drive the piles into the seabed. Prior to jacket installation some conditioning of the seabed may be required primarily to assure a level surface and to remove significant drill cuttings mounds. This is not expected to require significant works, if required at all. After jacket installation, the topsides (the decks and equipment) will be installed on top of the jacket legs, again by a towed cargo barge and installed using a single lift operation and subsequently secured by welding of the leg sections.

S2.3 Decommissioning

The infrastructure associated with the Development will be decommissioned when operations are no longer economically viable. The lifespan of the Development is expected to be in the order of 25 years. Within this timeframe there will probably be changes to statutory decommissioning requirements as well as advances in


Rev A01 – April 2011 Page xx

technology and knowledge. Total E&P UK will therefore aim to utilise best recognised environmental practice during all decommissioning operations. Prior to decommissioning process, re-use and recycling alternatives will be considered where feasible. In advance of the decommissioning process an inventory of all project equipment will be made and an examination for further re-use will be carried out.

S3 ENVIRONMENT

S3.1 Physical environment

Meteorology

Meterological data for the central North Sea for the period 1854 – 1994 show that winds originate from all directions, but winds from the south and south-west are most dominant. The highest frequency of gales (greater than 17.5 m/s) occurred during the winter months (November – March).

Hydrology

Water movement within the North Sea circulates in a generally anti-clockwise direction, entering between the Orkney and Shetland and to the east of the Shetlands. The predominant current in the region is an inflow of vertically well-mixed coastal and Atlantic water known as the Fair Isle or Dooley Current. This flows around the north of Orkney and then heads south until it reaches the 100 meter depth contour of the Fladen ground where it changes to an easterly flow. This results in an anti-cyclonic (anti-clockwise) circulation. Tides in the region are predominantly semi-diurnal, typically with their axis in a north/south direction. Wind driven and other episodic currents can reach velocities of 1.3 m/s at the surface and 0.49 m/s at the seabed. During the summer months, a thermocline will occur between 30 and 70 m below the surface due to warming of surface waters. Meteorological patterns in the area are typical of the northern North Sea. The predominant wind direction is from the South and Southwest. Tidal currents in the vicinity are typical of the central North Sea; the maximum tidal current speed (mean spring tides) in the location is of the order of 0.26 m/s (BODC, 1998). Tidal currents flow approximately southeast and northwest. Residual (non-tidal) currents are unpredictable in this area of the North Sea. The average sea surface temperature in the Elgin Complex and West Franklin field area varies seasonally between 8 and 8.5˚C in winter and between 14.5 and 15˚C in the summer. In contrast, sea bottom temperatures remain relatively constant throughout the year, ranging between 6.5˚C in the winter and 7˚C in the summer. The salinity in the vicinity of the Development is between 35.0 and 35.10 ppt throughout the year (BODC, 1998).

Seabed sediments and features

Fugro carried out a rig site survey for West Franklin in 2009. The geophysical survey acquired analogue data using single beam and multi beam echo sounders, side scan sonar, hull mounted pinger and mini airgun. The survey area consisted of 26 main lines and 19 cross lines covering a 3.2 km by 2.1 km survey area. The survey found seabed sediments across the survey area to be uniform and comprised mainly of fine sand (Fugro, 2010). As part of the Rig Site Survey an environmental survey collected data from 7 stations using a drop down method to collect stills and footage. The survey did not identify any Annex 1 habitats in the survey area (Fugro, 2010). Fugro (2010), report total organic carbon (TOC) within the sediments around the West Franklin area to be between 1.9 and 2.5 % which is comparable to surveys in adjacent blocks. Mean concentrations of metals including arsenic, barium, chromium, lead, mercury and zinc in sediments around the West Franklin area were reported to vary little across the survey area. Copper and zinc levels were found to be higher than the UKOOA (2010) mean concentrations and mercury was found to be below detection levels at all stations (Fugro, 2010). The sum of all poly aromatic hydrocarbon (PAH) fractions at all stations sampled around the West Franklin location were found to be below the limit of detection (<1 ng.g-1) (Fugro, 2010). This level of total PAHs is considerably less than both the effects range low (ERL) (NOAA, 1999) and the Ecotoxicological Assessment Criteria (EAC) minimum for total PAHs (1.050 µgg-1) (OSPAR, 2000). Overall, the total hydrocarbon concentration in the area ranged between 3.9-5.9 �g.g-1.


Rev A01 – April 2011 Page xxi

S3.2 Biological Environment

Plankton

Plankton form the basis of the marine food chain. The composition and abundance of plankton communities varies throughout the year and is influenced by physical parameters such as temperature, salinity and water inflow. The planktonic assemblage in the central North Sea is mainly made up of northern intermediate (mixed water) and neritic (coastal water) species (ERT, 1996). In both the northern and central areas of the North Sea, the dinoflagellate genus Ceratium dominates the phytoplankton community. There has been a gradual decrease in the abundance of the majority of diatom species (except Thalassiosira which has remained quite constant) whereas the dinoflagellate component continued to increase (Edwards et al, 2002). The copepod Calanus finmarchicus has historically dominated the zooplankton of the North Sea, but its abundance has declined dramatically over the last 30 years. Marine Scotland, formerly the Fisheries Research Service (FRS, 2004) have noted a 50% decline in their biomass from the 1960s to the 1990s. This decrease is thought to be correlated with the increasing sea surface temperatures in the North Sea (Edwards et al., 2010).

Benthic communities

The biota living near, on or in the seabed is collectively termed “benthos”. Water depth, temperature, salinity and type of local substrate all have an affect on the diversity and abundance of the benthos. Fugro, 2010 reported a sparse epifaunal community, with the seapen Pennatula phosphorea being the most prominent of the sessile epifauna. Of the infaunal taxa recorded, annelids dominated, representing 73.8% of the infauna, followed by echinoderms which made up 8.3%. Crustacea contributed 8.1%, molluscs contributed 6.9% and other taxa contributed 2.9% of the total abundance. Polychaetes dominated the species composition: overall Paramphinome jeffreysii was the most abundant polychaete, while Ampharete falcate, Galathowenia oculata, Notomastus, Pterolysippe vanelli, Nephtys hystricis, Lumbrineris gracilis, Spiophanes kroyeri and Terebellides stroemi were also part of the dominant taxa. In addition the brittle star Amphiura filiformis was a commonly encountered characteristic species of the benthic communities encountered.

Fish populations

A number of commercially important fish species are encountered in the vicinity of the Development area. In addition, the area it is located within spawning grounds of mackerel Scomber scombrus, Norway pout Trisopterus esmarkii and lemon sole Microstomus kitt (Coull et al., 1998). This area is also used as a nursery ground by Norway pout and haddock Melanogrammus aeglefinus (Coull et al., 1998). Although there is fish spawning and nursery activity in the vicinity of the Development area at certain times of the year, the spawning and nursery areas are part of larger offshore areas.

Seabirds

The distribution of seabirds in the vicinity of the Development area varies throughout the year, with lower abundance during the breeding season. The species which are most likely to be encountered in the vicinity of the Elgin Complex and Development area are guillemot (Uria aalge), Northern fulmar (Fulmarus glacialis) and kittiwake (Rissa tridactyla), which are likely to be present for the majority of the year. Gannet (Sula bassana) and puffin (Fratercula arctica) are also likely to be present in summer months, whilst herring gull (Larus argentatus), glaucus gull (Larus hyperboreus) and great black-backed gull (Larus marinus) are known to use the area in winter months (DECC, 2009). The highest seabird vulnerability in Block 29/5 occurs in January and November (high), with moderate vulnerability in July, September, October and December. Seabirds have low sensitivity to pollution for the remainder of the year (JNCC, 1999).

Marine mammals

The area of the North Sea containing the Development area is not considered to be particularly important for cetaceans, although several species have been recorded in the area. These include minke whale Balaenoptera acutorostrata, harbour porpoise Phocoena phocoena, white beaked dolphin Lagenorhynchus albirostris and Atlantic white-sided dolphin Lagenorhynchus acutus. Cetacean sightings are most frequently recorded during the period June - October which may be a consequence of the calmer summer sea conditions making cetaceans easier to observe at this time of year. Given the distance of the Development area from the coast it is unlikely that any pinnipeds will be encountered in the vicinity in any significant numbers (Hammond et al., 2001; Reid et al., 2003).


Rev A01 – April 2011 Page xxii

S3.3 Other Sea Users

The Elgin Complex and West Franklin fields are located in ICES Area IVb in Rectangle 42F1. In 2009 in rectangle 42F1, landings by Scottish vessels were 23.1 % demersal and 76.9 % shellfish. In 2009 demersal landings had a liveweight tonnage of 103.7 tonnes and an economic value of £161,392 and shellfish landings for rectangle 42F1 had a liveweight tonnage of 345 tonnes and an economic value of £875,073. Norway lobster Nephrops was the most landed and the most valuable species in rectangle 42F1 in 2009 (Scottish Government, 2011). Overall the relative value of the area is categorised as low (Coull et al., 1998).

Oil and gas

Oil and gas activities are both common in the central North Sea and there are a number of installations and pipelines within the vicinity of the Development area, the closest being Shearwater, approximately 9 km away.

Other

There are no submarine cables, military activities or designated wrecks in the vicinity of the Development area.

S3.4 Conservation

The JNCC has been commissioned by the UK government to identify areas that may qualify as possible offshore Special Areas of Conservation (SACs) and Special Protected Areas (SPAs) under the EU Habitats Directive (92/43/EEC as amended by 97/62/EC). The nearest conservation area to the West Franklin field is the Scanner pockmark Site of Community Importance (SCI) located approximately 149 km to the north-west. Annex II species recorded to be present in offshore areas of the UK that qualify for protection include the grey seal Halichoerus grypus, harbour porpoise Phocoena phocoena and bottlenose dolphin Tursiops truncates. None of these species are likely to be found in significant numbers in the Development area.

S4 ATMOSPHERIC EMISSIONS

Consideration has been given in the EIA to all sources of atmospheric emissions which might be influenced by the proposed Development, and these fall into three broad categories:

• Marine vessel activities during installation and commissioning; • Drilling and well testing activities; and

• Operational emissions (for example, combustion gases from power generation, flaring and venting). All vessels employed during drilling and installation activities will comply with relevant merchant shipping regulations which will ensure the levels of pollutants entering the atmosphere are minimised. Furthermore, all combustion equipment will be subject to regular monitoring and inspections to ensure an effective maintenance regime is in place, ensuring all combustion equipment runs as efficiently as possible. Prior to being brought into production, the new wells will be cleaned up either via the Elgin PUQ process system, or via the drilling rig. All routine power generation requirements will be met by the existing combustion equipment at Elgin. Emissions will therefore not increase above any historical peaks, and as production decreases, as will atmospheric emissions. Furthermore, ongoing monitoring of emissions and regular energy efficiency reviews will be carried out in order to identify additional opportunities for reducing atmospheric emissions, and aid with future emissions predictions. The potential cumulative effects associated with the atmospheric emissions produced by the vessels above include climate change (greenhouse gases), acidification (acid rain) and local air pollution. Localised impacts may include elevated levels of atmospheric emissions in the immediate area of the vessels. The projected emissions both collectively and individually do not represent a significant proportion of UK offshore emissions, contributing to a total of 0.026% of the overall UK total, however, this figure is considered to be conservative, and actual emissions are expected to be lower, and are not expected to present a significant environmental risk in cumulative terms.


Rev A01 – April 2011 Page xxiii

With the distance from the mainland and the strong dispersive regime of the area, it is not expected that atmospheric emissions will have detrimental impacts on the local environment.

S5 DISCHARGES TO SEA

Throughout the drilling, installation, commissioning and operational phases of the Elgin and Franklin Further Development there are a number of potential discharges to sea: • Vessels

• Drainage; • Sewage; and

• Grey and black water discharges.

• Drilling discharges • Mud and cuttings;

• Cement; and • Clean up and completion chemicals.

• Commissioning discharges • Pipeline commissioning discharges; and • Topsides commissioning discharges.

• Operational Discharges • Drainage discharges; and

• Produced water discharges.

Those discharges associated with vessels operations (e.g. sewage) are considered to have only a negligible environmental impact. There is likely be limited commissioning operations offshore which may result in small chemical discharges offshore. Increased production will result in the requirement for increased production chemical use and discharge, and produced water discharge at the Elgin facilities. In line with Total E&P UK policy, the following will be addressed during well design and final chemical selection for all well related operations:

• Careful selection of chemicals with least environmental impact in line with the requirements of the Total E&P UK Chemicals Management Strategy;

• Environmental risk assessment on the use and discharge of chemicals and identification of mitigation measures to reduce risk; and

• Re-use of the OPF mud to reduce discharge.

All relevant legal permits will be in place prior to operation. The permitted overboard discharge of water based mud and cuttings will result in a temporary effluent plume containing drill cuttings with a thin coating of associated mud. This plume of material will be rapidly carried away from the platform and the dissolved constituents, consisting of non-toxic and biodegradable chemicals will be quickly diluted. The accumulation of these cuttings, drilling mud and cement at the drilling location is likely to change the seabed community in the immediate area by burying some animals and impairing the feeding and respiration of others. Produced water may contain residues of reservoir hydrocarbons as well as chemicals added during the production process, along with dissolved organic and inorganic compounds that were present in the geological formation. Concentrated discharges of produced water could result in some toxicological effects to organisms, however, laboratory tests indicate these discharges do not adversely effect marine life around platforms.


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No significant cumulative or transboundary impacts are expected from the Elgin and Franklin Further Development. The drilling footprint is not expected to overlap that from other Developments, and any increase in produced water discharge and chemical use and discharge associated with the Development is expected to be limited.

S6 SEABED IMPACTS

A number of drilling and installation activities will have the potential to impact the seabed. In addition, a number of structures may be placed on or in the seabed, either for the duration of the work programme or for the lifetime of the Development itself. The key activities that may interact with the seabed are:

• Pipeline installation • Trenching and backfilling;

• Anchoring; • Rock dumping; and

• Cuttings pile disturbance.

• Jacket installation • Placement of jacket on seabed.

• Flotel (temporary accommodation) installation • Anchoring.

The above activities have the potential to lead to changes in the seabed, which would have positive or negative impacts on the biota of the region, including:

• Direct physical injury; • Smothering or clogging of communities through sediment and drill cuttings deposition;

• Loss of habitat; and • Habitat modification.

Installation of the jacket is likely to result in some direct physical injury to seabed fauna, and a loss of habitat over the seabed on which it is placed, and introduce a new hard substrate for colonisation. Depending on the vessel used for jacket installation, and the number of cranes onboard, it may be necessary to place the jacket on the seabed in a horizontal position before lifting it from the top into its final vertical position. During brownfield modifications at Elgin, and potentially during tie-in and commissioning operations, an anchored flotel will be used. Anchor placement will have a direct impact on the seabed. It is expected that the disturbed muddy sediments will begin to recover almost immediately with the settlement of re-suspended fine particles. Biological communities are in a continual state of flux and are able to either adjust to disrupted conditions or rapidly re-colonise an area that has been disturbed. The dynamic nature of the seabed will aid with the recovery of the disturbed areas, although some seabed impacts may persist in the medium term e.g. anchor scars, although recovery of the seabed is dependent both on the strength of the seabed soils and the ability of the currents to rework sediments and return the seabed to its original contours. Although it is expected that the Development will have some impact upon the seabed in general over which the Development will take place, the adoption of suitable mitigation measures and a best-practice approach to installation would mean that any residual risks associated with the Development are not considered significant.


Rev A01 – April 2011 Page xxv

S7 INTERACTIONS WITH OTHER SEA USERS

There will be an increase in vessel activity for the transportation of the jacket, topsides and brownfield modifications at Elgin. There will be considerable, although short-lived, vessel activity along the pipeline route during the pipelay programme; the physical presence of a pipelay vessel and support vessels will present a collision risk to other sea users. Disturbance may continue to be felt after the vessels have been removed if there is an impact upon activities such as trawling. The physical presence of a drilling rig and associated support vessels has the potential to interfere with other shipping that may be present in the area. In addition to statutory requirements, Total E&P UK has established lines of communication to inform other sea users, including fishermen, of their offshore activities. Normal routes of communication will be used by statutory organisations to notify shipping of the presence of increased levels of vessel activity, usually through the issue of a Notice to Mariners, and all vessel personnel will have the appropriate competencies and authorities required to mitigate against collision risks. To minimise the risk of fishing gear interaction, it should be ensured that fishermen are aware of drilling activities and the Elgin WHP B subsea structure through consultation with local associations and circulation of information via admiralty charts and kingfisher charts. Furthermore, any anchor mounds of significant concern to the fishing industry will be remediated. During the lifetime of the pipeline, regular maintenance and pipeline route inspection surveys will be undertaken.

S8 NOISE

There is potential for the sound produced by oil and gas activities to cause detrimental effects to marine life in the North Sea. Potentially significant sources of noise include:

• Drilling; • Pile driving;

• Vessel movements and operations; • Aircraft noise; • Rock dumping; and

• Pipeline and cable laying. Although a number of cetaceans are expected to be found in the Elgin and Franklin Development area, it is not likely that a large proportion of the geographical population of any individual species will be affected. A range of measures can be applied to reduce noise impacts: • Delaying the start of operations if cetaceans are detected within 500 metres until cetaceans have moved

away (not sighted for at least 20 minutes);

• Minimising the duration of noisy activities; • Building up power slowly (soft-start) over at least 20 minutes to allow adequate time for any cetaceans to

move away from the area before full power is reached;

• Minimising the sound energy released into the water column by reducing source levels to a minimum possible, for example through careful selection of hammer type, size and driving rate); and

• Considering the use of sound dampening material that may be deployed between the hammer and piles.

S9 SPILL RISK

All offshore oil production and export operations carry with them some risk of accidental hydrocarbon or chemical spill. Potential sources include:


Rev A01 – April 2011 Page xxvi

• Bunkering and cargo loading/handling (including mud handling) operations; • Upsets in bilge treatment systems;

• Storage tank failure of lube oils, fuel oil, oil based muds, base oil and chemicals; • Spills during maintenance activities including equipment removal and lubrication; and

• Damage sustained during a collision, grounding or fire.

A number of spill prevention measures will be in place to reduce the likelihood of oil spills from drilling rigs and installation and supply vessels: • All vessels and drilling rigs will comply with industry codes for prevention of oil pollution and vessels will

have onboard Shipboard Oil Pollution Emergency Plans;

• Environmental awareness training of vessel crews, including spill prevention; • Regular maintenance and inspection of equipment and high spill risk points (in particular bunkering

hoses, bunds, storage tank valves etc); • Procedures in place for bunker transfer, other bulk storage transfers and mud-handling in order to

minimise the risk of spillage;

• Availability of absorbent material onboard vessels to clean up any deck spills or leaks and suitable storage and disposal procedures for waste oil.

A blowout (uncontrolled release of fluids from the reservoir) is a highly unlikely event, but would result in mud and cuttings being released to the seabed and water column, and large volumes of condensate and gas would be discharged to the marine environment. A number of spill prevention measures will be in place to minimise the risk of spills:

• 500 m safety zone around the West Franklin and Elgin facilities, reducing the likelihood of vessel collisions;

• Use of corrosion resistant material in pipeline construction; and • Regular external visual inspection of pipelines as part of routine inspection and maintenance programme.

The most likely fate of spilled condensate is for transportation in a north easterly, or easterly direction towards the median line, and although a spill is not expected to beach, it is anticipated that there may be some transboundary impacts. In addition to the oil spill risk, there is also the risk of a chemical spill from drilling activities and throughout operation of the facilities. Chemical spills may occur during chemical transfer (e.g. between supply vessel and drilling rig), chemical/mud handling, or through mechanical chemical failure. Spill prevention measures in place will encompass both hydrocarbon and chemical spills. Pre-mobilisation audits and bridging documentation will ensure that these prevention procedures are in place on drilling rigs, installation and supply vessels. Personnel will also be given full training in environmental awareness and spill prevention methods. The worst-case spill risk would be the loss of containment of chemicals, which would release a volume of contaminants into the marine environment. In the event of a spill, the majority of contaminants are likely to be quickly dispersed in the high energy marine environment of the area, thus posing an insignificant risk to the marine environment.

S10 ENVIRONMENTAL MANAGEMENT

Total E&P UK has established an independently verified Environmental Management System (EMS) which covers all production operations.


Rev A01 – April 2011 Page xxvii

Figure S5 Total E&P UK’s Environmental Management System Framework

The EMS provides a framework to ensure compliance with environmental legislation, the prevention of pollution, and achievement of continuous improvement of environmental performance. The EMS is continually under review in order to adapt to changing statutory requirements, corporate aspirations and new/evolving scientific knowledge and techniques. The EMS achieved third party certification against the internationally recognised EMS standard ISO14001. A Commitments Log has been developed for each aspect of the Development. The Commitments Log summarises all mitigation and management measures identified during the EIA process, including where appropriate the requirement to undertake further environmental assessment during the ongoing design process. This commitments log will be integrated into an Environmental Management plan for the project and will evolve and be updated as each element of the project continues into the execution and subsequent operational phases. Monitoring of performance will be ongoing through the life of the project. To ensure that on-site project personnel understand the part they can play in contributing to environmental protection Total E&P UK provides environmental training; such training helps to raise environmental awareness. Training is delivered through a range of techniques; E-learning, formal courses with hands-on techniques (e.g. spill response), toolbox talks and poster campaigns. Commitments, objectives and targets set for the Elgin and Franklin Further Development will be communicated to contractors at the start of operations, and contractor performance will be monitored on a monthly basis (e.g. waste generation and chemical usage). Environmental awareness presentations are also included in contractor induction sessions. A Total E&P UK representative will be onboard the drilling rig and key installation vessels during drilling and installation phase.

S11 CONCLUSIONS

Based on the findings of this EIA and the identification and subsequent application of the mitigation measures identified for each potentially significant environmental impact, it is concluded that the Development will not result in any significant environmental impacts. The carrying forward of the findings and recommendations of this EIA through formal ‘commitments’ will provide a transparent and auditable means of ensuring the measures identified will be delivered through Total E&P UK’s externally verified environmental management system.

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