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Environmental Statement 2008.FH10

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Shell Exploration &

Production Europe

2007 Annual Environmental Statement

for U.K. Activities


CONTENTS

1. INTRODUCTION

2. WHAT WE DO

2.1 Our Exploration & Production Activities and Operations

2.2 Map of our UK locations

3 ENVIRONMENTAL MANAGEMENT

3.1 Our Environmental Management System (EMS)

3.2 Royal Dutch/Shell Commitment and Policy on HSE

3.3 The Environmental Aspects of our Operations

4 ENVIRONMENTAL PERFORMANCE

4.1 Our Environmental Goals, Objectives and Targets

4.2 Reducing Emissions and Discharges

4.3 Use of Energy, Resources & Waste Management

4.4 Biodiversity and Vulnerable Areas

4.5 Monitoring Seabed Impacts

4.6 Lateral Learning and Cooperation

5 CONTACTS

APPENDIX 1

SHELL U.K. EXPLORATION & PRODUCTION EUROPE

UK - ENVIRONMENTAL DATA TABLE

APPENDIX 2

OIL AND CHEMICHAL SPILLS AND OIL DISCHARGES

APPENDIX 3

2007 DRILLING LOCATIONS

APPENDIX 4

ABBREVIATIONS


1. INTRODUCTION

By John Gallagher, Vice President Technical – Europe, Shell Exploration & Production Europe

I am pleased to introduce this Environmental Statement,

covering Shell U.K. Limited’s Exploration and Production

(EP) activities during 2007.

The purpose of this report is to explain our environmental

performance and work programmes in 2007 in the UK, and

to update our plans for improvement in 2008/9. The report

is updated annually.

In Section 2 you can see a map of our activities. In the UK

sector of the North Sea we operate 35 platforms, 3 Floating

Production Storage & Offloading (FPSO) vessels, and 18

subsea installations; in total we have interests in 61 fields (52

operated) and three onshore gas plants. Our European EP

operations, and in turn the UK assets, are an important part

of our global portfolio, and will remain so for years to come.

We operate more production in Europe than any other

International Oil Company (more than twice the second largest

IOC). We are also one of the largest investors, averaging over

$5 billion per year in Europe in the last five years and for the

next five years and we have been and we will continue to be

an industry leader in frontier technology developments.

We are particularly pleased that, at the end of 2007, our

Environmental Management System (EMS) was certified to

ISO14001. This demonstrates that we have a systematic

approach to managing our environmental risks that meets

international standards. In 2008 we are continuing to work

on improving our EMS.

Our environmental objectives reflect our key challenges – to

work with others and to provide our own contribution towards

addressing climate change, to continue to reduce emissions,

discharges and wastes from our locations and to ensure our

operations in sensitive areas take account of the expectations

of all stakeholders.

Our performance shows that this is being achieved in some

areas. There are also areas for improvement that we will act

upon.

Looking to the future, our business will continue to change.

We will move forward with adjustments to our asset portfolio

and address new challenges such as decommissioning. Our

main target areas for performance improvement are currently

in the areas of greenhouse gas (GHG) and energy management,

continuing to reduce the risk from oil and chemical discharges

and improving our environmental impact assessment processes.

These will be delivered by focusing on legal requirements and

Shell Group standards and through enhancements to our EMS.

I hope you will agree our commitment to improving

environmental performance is demonstrated throughout this

report.


2. WHAT WE DO

2.1 OUR E&P ACTIVITIES AND OPERATIONS

Our Environmental Management System covers all of our

UK activities and locations that are used in the exploration,

production and processing of hydrocarbons.

Our business is divided up into organisational units called

Assets and Functions. Assets are typically groupings of four

to six locations supported by onshore teams, and cover all

our physical facilities including offshore fields, installations

and associated wells, the onshore gas plants, and all associated

pipelines. All our UK facilities can be viewed on the UK

Map in Section 2.2. Functions typically manage the support

Click Here to find out about Shell’s EP activities in the U.K.

Figure 1 - Map of UK locations

activities required by the Assets such as engineering and

maintenance services, development planning, project planning

and execution, survey work, organizing support vessels and

helicopters, laboratory services, drilling wells and the

management of our offices.

Detailed descriptions of EP activities and operations are

provided on the shell.com website.

2.2 MAP OF U.K. LOCATIONS Click Here to view map of U.K. Locations


3. ENVIRONMENTAL MANAGEMENT IN SHELL EXPLORATION &

PRODUCTION EUROPE

3.1 OUR ENVIRONMENTAL MANAGEMENT SYSTEM (EMS)

Figure 2 - Environmental Management System

Shell Exploration & Production Europe’s Corporate

Management System (CMS) documents the way in which the

company conducts its business. The Environmental

Management System (EMS) is an integral part of the CMS.

It consists of the elements shown in Figure 2 above.

‘Policy and Strategic Objectives’ contains our HSE Policy

and the Strategic Environmental Objectives. The HSE Policy

(see Section 3.2) contains a commitment to protect the

environment and states that we have a systematic approach

to HSE management designed to ensure compliance with the

law and to achieve continuous performance improvement.

‘Organisation, Responsibilities, Resources, Competency’

describes the organisational structure and the roles and

responsibilities that deliver environmental management. The

competency of personnel carrying out roles within the EMS

are addressed and the resources necessary to ensure that the

EMS is in place and maintained. Communication processes

around environmental issues both within and outside of Shell

are detailed.

‘Risk Management’ covers the identification of environmental

aspects and legal and other requirements that relate to our

environmental aspects. It also contains the operational

framework for managing significant environmental aspects.

Environmental aspects’ are those elements of our activities

that can interact with the environment (see Section 3.3).

Leadership and Commitment

Policy and Strategic Objectives

Organisation, Responsibilities,

Resources, Competency

Risk Management

Processes, Assets and Standards

Planning

Implementation

(Reporting & Monitoring)

Assurance

(Including Management Review)

Corrective Action

‘Processes, Assets and Standards’ describes the processes

that are undertaken to support our assets and the relevant

standards. Processes and standards contain environmental

information to ensure that the EMS is effectively implemented

in the assets.

‘Planning’ contains our Health, Safety and Environmental

(HSE) Plans, which contain objectives, targets and improvement

programmes. In preparing our HSE Plans, we take into account

our environmental aspects and legal and other requirements.

This enables us to implement our HSE Policy commitments

to achieve continuous performance improvement and ensure

compliance with the law.

‘Implementation (reporting and monitoring)’ covers the

monitoring of activities that can have a significant environmental

impact and monitoring of environmental performance. This

section also covers the periodic evaluation of compliance with

legal and other requirements.

‘Assurance’ covers the internal audit process by which we

check that the EMS continues to be effectively implemented.

Management reviews are also conducted annually to ensure

the EMS is effective and delivering improvements.


3.2 HSE Commitment and Policy

Graphics, Media & Publication Services EPE : EPT-IT-EI Ref. No. 020037

We care...

Royal Dutch/Shell Group Commitment to Health, Safety and Environment

In the Group we are all committed to:

• pursue the goal of no harm to people;

• protect the environment;

• use material and energy efficiently to provide our products and services;

• develop energy resources, products and services consistent with these aims;

• publicly report on our performance;

• play a leading role on promoting best practice in our industries;

• manage HSE matters as any other critical business activity;

• promote a culture in which all Shell employees share this committment.

In this way we aim to have an HSE performance we can be proud of, to earn the confidence

of customers, shareholders and society at large, to be a good neighbour and to contribute to

sustainable development.

Royal Dutch/Shell Group Health, Safety and Environment Policy

Every Shell company:

• has a systematic approach to HSE management designed to ensure

compiance with the law and to achieve continuous performance improvement;

• sets targets for improvement and measures, appraises and reports

performance;

• requires contractors to manage HSE in line with this policy;

• requires joint ventures under its operational control to apply this policy and

uses influence to promote it in other ventures;

• includes HSE performance in the appraisal of all staff and rewards accordingly.

Endorsed by the Committee of Managing Directors, March 1997 Reviewed 2000

... all of us have a role to play

“Each of us has a right and duty to intervene with unsafe acts and conditions or

when activities are not in compliance with this HSE policy and Commitment”.

June 2004

Malcolm Brinded Thomas M. Botts

Executive Director of Exploration & Production Executive Vice President EP Europe

James M. Smith

UK Country Chairman


3.3 The Environmental Aspects of our Operations

Environmental aspects are elements of our activities, products

or services that can interact with the environment. Figure

3 illustrates the main environmental aspects we have identified

for our offshore locations. We have grouped our significant

environmental aspects into four areas:

• Atmospheric emissions

• Energy use

• Discharges to water including spills

• Waste

3.3.1 Atmospheric Emissions

We burn natural gas and sometimes diesel as fuel on our

facilities to generate the power that is required to run our

operations. In addition, our facilities are designed to ‘flare’

(burn) and ‘vent’ (release unignited) a certain amount of

hydrocarbon gas for safety reasons. Most locations have a

continuous stream of gas to flare or vent designed to stop

the ingress of air into the facilities that could cause explosive

mixtures in the process. Additional amounts are also released

through this route during installation shutdown, when all

hydrocarbon gas systems are depressurised and when certain

equipment items are out of service (either planned or

unplanned).

The majority of our emissions to air are the products of

these combustion processes. The emissions include carbondioxide,

nitrogen oxides, sulphur dioxide, carbon monoxide,

unburnt hydrocarbons and particulates. These atmospheric

pollutants have global (climate change), regional (acidification)

and local (air quality) effects.

3.3.2 Energy Use

In addition to atmospheric emissions, consumption of diesel

and gas to provide energy is an important issue from the

point of view of depletion of natural resources. We are

currently developing GHG and Energy Management Plans

for each of our major installations.

3.3.3 Discharges to water

Most of our discharges to water consist of surplus water

from our oil and gas wells. This "produced water" is a mixture

of naturally occurring water in the reservoir, and seawater

that has been injected into the reservoir to support the

pressure and sweep oil towards the production wells. We

separate the produced water from the oil and gas, and discharge

most of it into the sea. The separated water contains a small

amount of residual oil as well as chemicals both naturally

occurring such as salts, and others such as corrosion inhibitors

and de-oilers.

As well as produced water, many of our wells produce sand

and scale which accumulates in pipework and vessels and

needs to be cleaned out from time to time. When pipework

and vessels are cleaned, the sand and scale is also cleaned to

remove as much oil as possible before it is discharged.

Produced sand contains similar materials to produced water

and may also contain small amounts of Naturally Occurring

Radioactive Material (NORM) which may occur naturally in

an oil or gas reservoir. All discharges are monitored and

recorded.

We also use seawater for cleaning purposes. After use any

‘wash water’ is cleaned before being discharged back into the

sea via specially designed drains. Legally permitted levels of

cleaning chemicals and some oil may remain in the water

when it is discharged. Other drains on our installations

discharge surface water, such as accumulated rainwater or

seawater, which do not normally contain any oil or chemicals,

as well as emergency fire-fighting water and foam, directly

into the sea.

Finally the smallest contribution to our discharges to the sea

comes from leaks and spills from our wells and equipment.

Such spills may consist of oil, gas, chemicals, or a mixture of

the three. Continuous monitoring, adherence to procedures

and rehearsal of emergency response keeps these unintended

discharges to a minimum.

3.3.4 Waste

A variety of solid and liquid wastes are produced from both

our on and offshore operations including drilling waste such

as cuttings and spent muds; wastes such as oily rags, fluorescent

tubes and batteries, and also office and packaging wastes such

as paper, card and wood.

Some wastes can be treated and re-injected into reservoirs

e.g. drill cuttings under the appropriate legal licences. However

the majority of wastes are shipped to shore for onshore

disposal. All waste, irrespective of where it is produced, is

transferred to licensed facilities for either treatment and

disposal; or sorting and bulking prior to transportation for

final disposal.

All waste is transported and disposed of in accordance with

our European waste management policy, in particular through

application of the waste hierarchy to prevent and reduce

waste as far as possible and minimise the volume of waste

to landfill.


RAW AND

AUXILIARY

MATERIAL

ENERGY

MATERIALS

WATER

REUSE

NOISE, DUST

ODOUR OR LIGHT

PRODUCT

EXTRACTION

RADIATION

MATERIALS TO

DEEP SUBSOIL

GASEOUS

EMMISIONS

PRODUCT

WASTE

LIQUID

FLOWS

TO WATER

LIQUID FLOWS

TO THE SOIL

Figure 3 - Summary of Environmental Aspects


4. ENVIRONMENTAL PERFORMANCE

4.1 Our Environmental Goals, Objectives and Targets

Shell Exploration and Production in Europe maintains

environmental management systems that are certified to

the ISO14001 standard and we strive for continuous

environmental improvement through the following strategic

objectives, covering our significant environmental aspects

(Section 3.3):

• Reduce discharges to sea and emissions to air through

continuous improvement, operational excellence

and deployment of technological step changes.

• Manage use of energy and resources and minimize

the generation of waste.

• Work with others to maintain ecosystems and

minimise interference with biodiversity and

vulnerable areas.

• Optimise the potential for lateral learning from cooperation

with external environmental stakeholders

Improvement programmes to deliver the above cover legal

compliance and the fourteen elements of the Shell Group

Global Environmental Standards (GES).

Each objective is translated into key targets (where relevant)

and improvement programmes year on year to drive

continuous improvement across our UK operations. The

current targets, performance and improvement plans for

each objective are summarised in the sections below. More

environmental data for 2004-2007 are provided in

Appendix 1.


4.2 Reduce Emissions and Discharges

Our first objective drives our requirement to improve the

way we conduct our activities by focusing on reducing key

emissions and discharges.

4.2.1 Greenhouse Gas Management

Burning fuel gas and diesel, flaring and venting are our main

sources of GHG emissions, although there are also

contributions from transportation and office energy use.

We support the Shell Group’s publicly committed voluntary

target to have CO2 emissions in 2010 5% below the 1990

level. Annual GHG targets are established for our European

activities and these are translated into targets for each of

our assets.

Figure 4 shows the mass of GHG emitted from each of the

main sources on each of our major platforms and onshore

plants during 2007. In 2007 we emitted 3.51 million tonnes

of GHG from our UK operations and activities.

Approximately 78% of the GHG emissions came from

combustion and 22% from flaring and venting. After taking

into account the effect of portfolio changes (we sold Auk

and Fulmar fields in November 2006), GHG emissions were

2.1% lower than in 2006.

In 2007, we flared 230,000 tonnes of hydrocarbon gas. This

is significantly lower than the 272,000 tonnes flared in 2006

GHG Breakdown tonnes

350,000

300,000

250,000

200,000

150,000

100,000

50,000

0

(2006 figures corrected for portfolio changes). Reductions

were seen on most installations, Cormorant Alpha being the

only installation flaring significantly more than in 2006. This

rise was due to a failure of the main compressor bundle

which resulted in flaring of associated gas for several weeks

During 2007 we operated under Phase 1 of the mandatory

EU Emissions Trading Scheme for CO2 (EU ETS). It

should be noted that in 2008 the EU ETS will be expanded

to Phase 2 which will include CO2 from flaring. Work is in

progress to upgrade flare monitoring and reporting to achieve

the higher accuracies needed for EU ETS.

There are programmes underway in the business aimed at

future reductions in GHG from our facilities, including:

• Increased focus on operational flaring. Following our

adoption of the new Shell Global Environmental

Standards, we have enhanced our controls on operational

flaring.

• Implementation of recommendations made by energy

efficiency assessments made as part of PPC permit

applications. In 2008, we plan to implement 16 different

projects.

Fuel Gas

Diesel

Flare and Vent

Other

Anasuria

Brent Alpha

Brent Bravo

Brent Charlie

Brent Delta

Cormorant Alpha

Curlew

Dunlin

Eider

Gannet

Leman

Nelson

North Cormorant

Pierce

Sean

Shearwater

Solepit Clipper

Tern

Mobile Rigs

Bacton

Fife

St Fergus

Figure 4 - Greenhouse Gas Emissions


4.2.2 Oil in Produced Water

An annual oil in produced water target is established for our

European activities and is translated into targets for each of

our assets. These discharges are subject to the

recommendations under the OSPAR Convention implemented

in the UK through The Offshore Petroleum Activities (Oil

Pollution Prevention and Control) Regulations 2006 and also

our own Shell Group Environmental Standards. In 2001

OSPAR set a goal to ensure that the total quantity of oil in

produced water discharged into the sea in the year 2006 from

all offshore installations within the jurisdiction of each OSPAR

member country should be reduced by a minimum of 15%

compared to the equivalent discharge in the year 2000. In

2007 our installations discharged 868 tonnes of oil in produced

water to sea compared with 1,800 tonnes in 2000, a reduction

Oil to Sea (tonnes)

200

180 Actual Oil to Sea (tonnes)

160

2007 Target (tonnes)

140

120

100

80

60

40

20

0

Anasuria

Brent Bravo

Brent Charlie

Brent Delta

Cormorant Alpha

Curlew

Dunlin (Incl. Osprey Merlin)

Eider

Gannet

Leman

Nelson

North Cormorant

Pierce

Sean

Shearwater

Solepit Clipper

Tern (Incl. Hudson)

Figure 5 - Oil Discharged to Sea

of more than 50% (although we have divested some assets

* in the period).

The chart below shows the actual amount of oil discharged

to sea by each of our installations compared to our targets.

Most of our installations discharged below our targets and

the total oil to sea was well within our overall company target

for 2007. However, the Dunlin platform went over target

owing to less than expected performance of the chemical deoiler

and low production volumes passing through the separate

Osprey/Merlin process which reduces separation of oil.

Nelson missed its target because the Produced Water Re-

Injection (PWRI) system was not working to its full capacity.

* Kittiwake field divested November 2003, Ketch & Schooner fields divested March 2005,

Auk and Fulmar fields divested November 2006


Figure 6 shows the actual volume of produced water discharged

to sea by each of our installations and the average measured

concentration of oil dispersed within it. On three installations;

Sean, Shearwater and Solepit Clipper, although the volume

of discharge is small, the concentration of oil in produced

water is well above 30 mg/l.

The Sean field is a swing gas producer and started-up

production for only two months at the end of 2007, the

average OIW concentration was 159 mg/l.

On Shearwater there has been a decrease in OIPW overboard

Water Discharged 000’s m3

9,000

8,000

7,000

6,000

5,000

4,000

3,000

2,000

1,000

0

Anasuria

Brent Bravo

quality in 2007 due to excess sand production and bringing

on line production from satellite fields which cools down the

production process and hence impairs the oil water separation

process. In 2008, we will continue to search for a solution.

On Solepit Clipper, despite installing two centrifuges in 2005

at a cost of some £1.9 million, the problem persists particularly

during periods of less water throughput. Therefore we are

now planning to install PWRI surface facilities in 2008 and

then prepare a well and commence produced water re-injection

into a subsurface reservoir in 2009.

Brent Charlie

Brent Delta

Cormorant Alpha

Curlew

Dunlin (inc Osprey Merlin)

Eider

Gannet

Leman

Nelson

North Cormorant

Pierce

Sean

Shearwater

Solepit Clipper

Tern (inc Hudson)

Figure 6 - Produced Water Discharged to Sea

4.2.3 Accidental spills

All loss of containment (whether it reaches the sea or is

contained and recovered on the location) is reported through

our incident reporting system and subject to assessment and

incident investigation depending on the risk posed to the

environment. See Appendix 2 for more details of reportable

spills.

Analysis of our spills shows an increase from an average of

around 10 significant spills (oil, gas & chemicals > 100 kg)

over recent years to 20 in 2007. The causes of these spills

Water Discharged 000’s m3

OIW Concentration mg/l

fall into three main categories: equipment failure, human

error and corrosion. We have instigated a programme to

review these spills in order to understand the root causes

better.

For 2008 onwards, an annual target for significant oil spills

(>100 kg) of 24 tonnes has been established for our European

activities. Because of their variable nature, this is not translated

into targets for each of our assets.

140

120

100

80

60

40

20

0


4.2.4 Chemical Management

Our use and discharge of chemicals in production and drilling

operations is subject to The Offshore Chemicals Regulations

2002 (OCR) and our own Shell Group Standards. The historic

trend in production chemical discharge is relatively stable.

This is the result of two counteracting trends where our

efforts to switch to better chemicals and reduce treatment

concentrations are balanced by greater consumption due to

increasing water production.

Chemicals Discharged tonnes

2,000

1,800

1,600

1,400

1,200

1,000

800

600

400

200

0

Production chemical use and discharge varies amongst our

installations. Those in the Southern North Sea (Clipper,

Leman, Sean) use relatively little because they are predominantly

gas processing facilities; whereas our Northern North Sea

installations use more owing to factors like reservoir chemistry,

water cut and high produced and injected water volumes. As

can be seen from the chart, we predominantly use low

risk/hazard products, but some platforms use a higher level

of SUBs mainly corrosion inhibitors that are highly effective

but carry substitution warnings. We are committed to phasing

out these chemicals. Our substitution programme is delivering

an overall decline in the use of SUBs, but the numbers fluctuate

as a result of the re-classifying of products when new rules

are applied to the screening process by CEFAS, or when new

data is submitted to CEFAS by the chemical vendors.

E/D/Gold Discharged Others Discharged SUB Discharged

Figure 7 shows the total weight of chemicals discharged to

sea by each of our installations. Discharges have been grouped

into two categories, with the green colour representing the

'low risk/hazard' groups and the red depicting the 'more

hazardous/higher risk' groups. Overlying this is a line that

represents ‘SUB’s – chemicals which have been flagged with

a Substitution Warning by the Centre for Environment,

Fisheries and Aquaculture Science (CEFAS).

Anasuria

Brent Alpha

Brent Bravo

Brent Charlie

Brent Delta

Clipper

Cormorant Alpha

Curlew

Dunlin

Eider

Gannet

Goldeneye

Leman

Nelson

North Cormorant

Pierce

Sean

Shearwater

Tern

Figure 7 - Production Chemicals Disharged

Offshore Chemical Notification

Scheme (OCNS)

CHARM Model Hazard Quotient

Highest Risk

Lowest Risk

Non-CHARM Model Letter Grouping

Highest hazard

Poses Little

or No Risk

Purple

Orange

Blue

White

Silver

Gold

A

B

C

D

E


4.3 Use of Energy, Resource and Waste Minimisation

4.3.1 Energy Use and Resource Management

The efficient use of energy and the minimisation of upset

flaring is an integral part of our operational excellence

philosophy to minimise the waste from our operations and

conserve valuable natural resource. They also represent the

main areas of improvement with regard to reducing our

emissions of GHG as described in Section 4.2.1 above.

Energy use is mainly from power generation on our locations

where we burn fuel gas or diesel to run pumps, compressors,

engines, heaters and general platform services. We also report

on electrical energy purchased onto sites and offices. A

certain amount of flaring is a design feature at most of our

locations for safety reasons during steady operations, but

additional amounts of ‘process upset’ flaring occurs when

equipment fails or during planned shutdown of facilities for

maintenance work.

Although energy use has reduced, production rates have

dropped at a faster rate leading to an increase in energy

intensity over the last two years. Increasing energy intensity

is characteristic of maturing fields in the North Sea and is

caused by such factors as reducing reservoir pressures and

increasing water cuts of the wells. Improvement programmes

have already been described under 4.2.1 GHG Management.

MOST

FAVOURED

OPTION

LEAST

FAVOURED

OPTION

Figure 8 - The Waste Hierarchy

4.3.2 Waste Minimisation

In order to move waste disposal up the waste hierarchy, we

work closely with our contractors to reduce the volume of

waste going to landfill. While our overall tonnage of waste

production increased by 10% from 2006 to 2007, the

proportion sent to landfill was reduced by 30%. This can be

attributed mainly to the success of a mud treatment process

developed by our waste contractors. Prior to this development,

waste drilling fluids were mixed with solids and land-filled,

thereby actually increasing the volume of waste to landfill.

The new process reduces the requirement for landfill to less

than 30% of the original volume.

During 2007, our assets were encouraged to segregate their

waste effectively, thereby ensuring legal compliance and

maximising recycling opportunities. A series of skip

segregation exercises were held throughout the year and the

results fed back to the assets to demonstrate areas for

improvement. Proven to be a very useful tool for raising

awareness, the number of these audits has been doubled in

2008.

Other smaller changes to reduce waste in the offices have

been introduced and similar initiatives are being developed

in 2008 which will encourage our staff awareness on waste

management and give further success in years to come.

PREVENTION

MINIMISATION

REUSE

RECYCLING

ENERGY RECOVERY

DISPOSAL


tonnes

1,200

1,000

800

600

400

200

0

Figure 9 shows the weight of waste produced on each

of our production installations grouped into hazardous

and non-hazardous categories. On Brent Delta the high

level of hazardous waste was mostly drilling fluids from

increased well engineering activities, namely one well on

DISCHARGE

41%

Hazardous Waste tonnes

Non-Hazardous Waste tonnes

Anasuria

Brent Alpha

Brent Bravo

Brent Charlie

Brent Delta

Cormorant Alpha

Curlew

Dunlin

Eider

Gannet

Leman

Nelson

North Cormorant

Pierce

Sean

Shearwater

Solepit Clipper

Tern

Figure 9 - Waste Production

TREATMENT

10%

a satellite field (Barnacle) developed by a third party

(Energy Development Partners) responsible for its own

permits. On Cormorant Alpha, the peak was from around

300 tonnes of steel tubulars and 300 tonnes of nonhazardous

chemicals.

REUSE

6%

RECYCLING

16%

LANDFILL

20%

This chart shows how we managed our waste in 2007 by showing the proportion going to

each disposal route.

Figure 10 - Summary of Waste Fates

WASTE

TO ENERGY

7%

INCINERATION

0%


4.4 BIodiversity and Vulnerable Areas

The Shell Group Biodiversity Policy and Commitment states

our commitment to work with others to maintain ecosystems

and respect protected areas through the application of

environmental impact assessment and development of

biodiversity action plans for operations in the areas of high

biodiversity value.

Two of our onshore facilities (Braefoot Bay Terminal and

Bacton Gas Plant) operate in close proximity to (though not

actually in) environmentally sensitive areas. In addition, several

of our offshore installations and pipelines are located in the

areas of potentially sensitive marine habitats. These sensitive

sites and locations are recognised internally as “High

Biodiversity Value Areas” according to the Shell Group

Standards. We support these areas through membership of

local forums and consultation with relevant national agencies.

Using the Environmental Impact Assessment process, we

apply appropriate controls for plants and installations and

projects that have the potential to impact on these areas.

4.5 Monitoring Seabed Impacts

Environmental seabed surveys are one way to monitor the

impacts of our activities. Contaminants enter the marine

environment through discharge of cuttings, muds, produced

water, and even deposition from the atmosphere. Seabed

sediments provide a sink for these contaminants. Sediment

quality and diversity of seabed plants and creatures are good

indicators of impacts and recovery. It is important for us

to have scientific evidence to evaluate our impacts, especially

around older installations and those in proposed conservation

areas. In 2007 we developed a long term seabed monitoring

programme. Using a risk-based approach, several sites were

selected for three and six year monitoring. The programme

was reviewed and supported by BERR and JNCC. We started

in 2007 with surveys around Brent and Gannet fields. Leman

and Clipper fields are scheduled for surveying in 2008.

4.6 Lateral Learning and Cooperation

We believe in being involved in the environmental agenda in

the local areas where we operate and in addressing wider

regional and global concerns where we have a role to play.

To this end, we participate in various stakeholder, government

and industry fora and provide resources and expertise in key

areas to help define our role in environmental protection.

In addition, we jointly fund research and technology

Paguridae (hermit crab) at Gannet D

Anemones at Indefatigable J

programmes in areas where more information or design work

is required to enable us to decide the best way forward. For

example, in 2007 we sponsored a Joint Industry study to

investigate a metric for the assessment of the behavioural

and audiological effects on underwater animals of man-made

underwater noise.


5. Contacts

This report aims to summarise the environmental controls, performance and programmes of Shell Exploration & Production

Europe, as applicable to our UK operations and activities. This report will be updated and published annually on our external

website.

Our preferred route of publication is electronic although hard copies can be printed off as required by individuals accessing

our external website.

Further information can be obtained by contacting:

EPE Environmental Discipline Lead – Ross Clephan

HSE Department

Shell U.K. Limited

1 Altens Farm Road

Aberdeen AB12 3FY

Or calling (UK) 01224 882000 and asking for Ross Clephan or Alistair Cameron


APPENDIX 1 – SHELL EXPLORATION & PRODUCTION EUROPE

UK – ENVIRONMENTAL DATA TABLE

GHG (tonnes CO2 equivalent)

Total Gas to Flare - incl. CO2 etc. (tonnes)

Total Fuel Gas Used (tonnes)

Total Diesel Used (tonnes)

Energy Efficiency (GJ/tonne HC Equivalent)

OIPW Oil to Sea (tonnes)

Hazardous Waste (tonnes)

Non-Hazardous Waste (tonnes)

Production Chemical Use (tonnes)

% Discharge

Wells Chemical Use (tonnes)

% Discharge

Fines

2004

4,480,172

326,582

1,117,155

73,171

1.44

1,274

26,572

14,560

14,297

60%

46,481

20%

£7,000

2005

4,261,907

358,112

1,084,724

70,098

tonnes

Scope: The figures shown above relate to all Shell operated offshore installations and 3rd Party fields that produce to them

plus onshore plants and mobile rigs in the UK – all as reported to EEMS. Some changes are due to asset divestment.

Global Warming Potential: The 2007 figure is lower than trend owing to divestments and several prolonged shutdowns.

In 2008, the figures will be affected by:

• Norwegian gas being piped to St Fergus

• Nelson PWRI load and improved reliability

• Further divestments

Production Chemicals: 2007 chemical use was relatively high due to a single once-off activity on the Dunlin platform where

15,000 tonnes of a foaming chemical was used to displace 'attic' oil from the seabed storage cells. In Figure 3 these are

coloured orange at the base of the platform. The cells are now decommissioned and filled with water. Before decommissioning,

the foaming chemical was used to displace oil downwards to the level of the withdrawal pipe within the cells. This single

activity accounts for the higher use and the drop in percentage discharge. Without it chemical use and discharge would be

very similar to 2006.

1.68

1,215

10,760

8,752

12,079

75%

19,770

22%

£3,000

2006

4,066,604

318,428

1,046,907

74,297

1.95

1,067

33,094

10,678

11,853

75%

48,003

6%

£0

2007

3,510,783

300,875

906,955

66,558

2.03

868

36,177

11,390

26,908

29%

35,106

11%

£0


APPENDIX 2 - OIL AND CHEMICAL SPILLS AND OIL DISCHARGES

Notifiable (PON 1) Oil and Chemical Spills Number

Notifiable (PON 1) Oil and Chemical Spills Total Mass (tonnes)

Spill of Sodium Bicarbonate solution due to a loading hose failure on Dunlin when pumping from a supply

vessel.

Subsea leak of crude oil from Gannet C due to a weld failure while carrying out pigging operations.

Subsea leak of hydraulic fluid from Gannet D.

Subsea leak of hydraulic fluid from Pierce.

Spill of Monoethylene Glycol (MEG) on Goldeneye due to a pipe failure.

Failure of bellows on cooling medium system on Shearwater resulted in the cooling system leaking onto the

platform deck and then into the open drains system.

While filling the Caravel Monotower, there was a leak of bentonite (natural clay) gel from a bellows installed

around the gas export riser at the point where it exits the monotower a little above the seabed.

PON 1 = Petroleum Operations Notice No.1

We are required to notify the relevant authorities of all accidental/unplanned discharges or spills of oil or chemicals to sea,

regardless of volume, using a PON1 to:

• nearest Coastguard Station

• Department for Business, Enterprise and Regulatory Reform;

• Joint Nature Conservation Committee (JNCC)

• any relevant Statutory Nature Conservation Agency

The list of spills above shows only those greater than 2 tonnes.

79

319

Brief Descriptions – Oil and Chemical Spills > 2 tonnes tonnes

157

3.2

8.2

41.8

26.0

39.5

32.2


APPENDIX 3 - 2007 DRILLING LOCATIONS

Well Start Date Rig Well Name

19/05/06

05/09/06

05/09/06

02/10/06

16/10/06

22/10/06

15/11/06

15/12/06

19/12/06

20/12/06

21/12/06

27/12/06

29/01/07

08/02/07

13/02/07

21/02/07

10/03/07

22/03/07

25/03/07

26/03/07

02/05/07

04/05/07

06/05/07

06/05/07

11/05/07

JW McLean

GSF Magellan

GSF Monarch

Cormorant A

JW McLean

GSF Arctic 3

Nelson

TO 711

GSF Britannia

MSV Seawell

Ocean Guardian

MSV Seawell

MSV Seawell

MSV Seawell

GSF Magellan

GSF Monarch

GSF Monarch

GSF Monarch

GSF Monarch

GSF Monarch

GSF Magellan

GSF Monarch

MSV Seawell

MSV Seawell

JW McLean

Merganser A01 (ME)

Shearwater A5s1

Galleon PG10/05

Cormorant A35s4 + s5

Teal P2 + s1

Gannet D A05s2 + s3

Nelson N26W / X / Y

Pierce 23/22a-LA3

Carrack QA-06

Corm AU-W4s1

Penguin D3

Corm AU-P7s1

Corm AU-P2s5

Corm AU-P4s3

Shearwater A8s1

Galleon PG07/04

Inde L1225

Inde L1215

Inde L1210

Inde L1200

Shearwater A4

Inde L1220

Gannet C A101s2

Gannet C A103

Starling 29/3-PW

Well Start Date Rig Well Name

17/05/07

20/05/07

22/05/07

26/05/07

01/06/07

11/06/07

18/06/07

21/06/07

09/07/07

22/07/07

24/07/07

31/07/07

10/08/07

12/08/07

18/08/07

19/08/07

29/08/07

31/08/07

02/09/07

17/09/07

22/09/07

09/10/07

29/10/07

23/11/07

07/12/07

MSV Seawell

GSF Arctic 4

MSV Seawell

GSF Monarch

MSV Seawell

MSV Seawell

MSV Seawell

JW McLean

MSV Seawell

MSV Seawell

MSV Seawell

MSV Seawell

MSV Seawell

JW McLean

Tern Alpha

MSV Seawell

GSF Britannia

MSV Seawell

GSF Britannia

JW McLean

GSF Magellan

JW McLean

MSV Seawell

GSF Magellan

MSV Seawell

Gannet C A102

Curlew D-P4 + P4A

Gannet C A202

Inde L1205

Kingfisher BP1.1

Osprey U-P1s2

Osprey U-W4s1

Starling 29/3-PE

Merlin P11

Pierce A2Y

Pierce A5

Pierce A4

Pierce B2

Corm AU-P8s1

Tern A09s1

Pelican U-P12s1

Caravel AB QR02/02

Pelican U-P11

Caravel AH QR01/04

Corm AU-W3s1

Shearwater A9

Corm AU-W2

Bittern A3

Shearwater A9

Gannet B A01s1


APPENDIX 4 -ABBREVIATIONS

Asset Use internally in Shell to describe a collection of locations, typically four to six offshore platforms and

supporting services, but also includes onshore plants and interconnecting pipelines.

Associated Gas Gas liberated from oil as the pressure is reduced from subsurface conditions to the surface separation

facilities.

Benthos Flora (plants) and fauna (animals) found at the bottom of ocean, sea or lake.

Bentonite Natural clay used to thicken/gel well engineering and completion fluids.

BERR Department for Business Enterprise & Regulatory Reform (formerly Department of Trade and Industry

DTI).

CEFAS Centre for Environment, Fisheries & Aquaculture Science

CMS Corporate Management System

De-oiler Chemical used in the production process to promote separation of oil from produced water

EEMS Environmental Emissions Monitoring System (Oil & Gas UK)

EU ETS Council Directive 2003/87/EC establishing a scheme for greenhouse gas emission allowance trading

with the community

EMS Environmental Management System

EP Exploration and Production

FPSO Floating Production, Storage and Offloading vessel

GES Shell Group Global Environmental Standards

GHG Greenhouse Gases (mainly carbon dioxide, methane, nitrous oxide, CFC’s and HCFC’s)

ISO14001 International Standard Specification for Environmental Management Systems.

JNCC Joint Nature Conservation Committee

MEG Monoethylene Glycol

NUI Normally Unmanned Installation

OCNS Offshore Chemical Notification Scheme

OIPN Oil In Produced Water

OPPC Offshore Petroleum Activities (Oil Pollution Prevention and Control) Regulations 2005

OSPAR Convention for the Protection of the Marine Environment of the North-East Atlantic. In 1998 this

replaced the Oslo Convention (for the Prevention of Marine Pollution by Dumping from Ships and

Aircraft) and the Paris Convention (for the Prevention of Marine Pollution from Land-Based Sources).

PPC Pollution Prevention and Control Act 1999 and Offshore Combustion Installations (Prevention and

Control of Pollution) Regulations 2001

PWRI Produced Water Re-Injection

TEG Triethylene Glycol (antifreeze)

UMC Underwater Manifold Centre (Subsea production)

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