Alwyn AreaNorthern North Sea / operations

the company/overview

2/two 3/three

TOTAL E&P UK Limited is one of the largest oil and gas companies in

the UK and part of the global business of the TOTAL Group, the fourth

largest integrated oil and gas company in the world. The TOTAL Group,

which has its headquarters in Paris, has operations in 130 countries and

employs almost 100,000 people worldwide.

The Groups operations cover the entire range of oil and

gas related activities, including exploration & production,

trading & shipping and refining & marketing - as well as

the manufacture and supply of a comprehensive range of

chemical products.

The UK Upstream subsidiary, TOTAL E&P UK, has its head-

quarters in Aberdeen, Europes oil and gas capital, and is

one of the largest operators on the UK Continental Shelf in

terms of production and reserves.

The company employs over 700 people, split between

its onshore sites and its offshore facilities. Being part of an international

Group means that the workforce includes both local and expatriate staff,

drawn from more than 30 countries.

With its affiliates, TOTAL E&P UK owns and operates the Alwyn North,

Dunbar, Ellon, Grant, Nuggets, Forvie, Jura and Otter fields in the Northern

North Sea. It also operates the Elgin, Franklin, West Franklin and Glenelg

Fields in the Central Graben Area of the Central North Sea.

The company and its UK affiliates also have a number of non-operated

interests in the Central and Northern North Sea including Bruce, ETAP,

Alba, Armada and Nelson and has an interest in the Sullom Voe Oil

Terminal on Shetland.

Onshore, TOTAL E&P UK operates the St Fergus Gas Terminal on the

northeast coast of Scotland, which receives and processes up to 20%

of the UKs natural gas requirements from over 20 fields in the UK and

Norway. It owns 100% of the Terminals facilities and 50% of the Common

Facilities, the remainder of the plant being owned by the Norwegian

Association, Gassled.

The company has a 100% interest in the UK Frigg pipeline (FUKA), an

interest in the SEAL (Shearwater Elgin Area Line) pipeline through Elgin

Franklin Oil and Gas Limited (EFOG), which is owned 77.5% by Elf

Exploration UK Limited and 22.5% by Gaz de France. EFOG has a 25.73

per cent share in SEAL.

people/power our success

4/four 5/five

The welfare of its workforce is TOTAL E&P UKs top priority and it conducts all its activities taking full account of the health and safety of its people, ensuring the safest possible working environment and the prevention of work-related illness. Our goal is to achieve an accident-free work environment and thinking Safety First is the responsibility of all staff at their work locations, whether onshore or offshore. Best in class environmental performance is another major goal.

TOTAL E&P UK continues to maintain its company-wide registration to ISO-14001, the international Environment Management System standard. This is globally recognised as reflecting a level of good business practice and underlines a companys genuine commitment to sustainable development. We are very proud of this achievement and through the maintenance and improvement of our management systems, hope to continue improving our environmental performance.

2008 saw the launch of TOTAL E&P UKs Safety, Health and Environment (SHE) Vision five individual elements that work together to drive our SHE performance. These five areas competence, supervision, SHE culture, risk assessment and asset integrity will give us clear platforms on which to focus our efforts in the coming years.

We set measurable safety, health and environmental objectives and work hard to improve performance, making sure that all our staff and contractors are fully equipped to understand and implement our procedures. In addition, we work with partners, suppliers, competitors, regulators and the general public in developing and testing our emergency plans, which we believe help to set and raise industry standards.

We also encourage a broad culture of openness and co-operation in the firm belief that this creates a positive attitude towards the advancement in understanding and improvement of performance in the areas of safety, health and environment all of which is reviewed and audited. Those who contribute directly to improvements are recognised and performance evaluations for all employees include safety, health and environmental aspects. This is particularly important for those employees with managerial or supervisory responsibilities.

producing safely/our top priority

6/six 7/seven

Alwyn/potential unleashed

Located in the northern North Sea some 440km to the Northeast of

Aberdeen, the Alwyn North Field lies at the heart of the Alwyn Area

Hub, a series of fields discovered and developed by TOTAL E&P UK

over more than two decades.

The fields currently developed are all 100% owned and operated by

TOTAL E&P UK and comprise Alwyn North, Dunbar, Ellon, Grant,

Nuggets, Forvie North and Jura.

The Alwyn North Platform provides

water for injection and power to the

surrounding fields and receives the

gas and produced water through a

series of inter-field cables and pipe-

lines.

Alwyn North has celebrated over

21 years of production and will

continue to act as the Hub for

developments in the area for at least another twenty years.

Over one billion barrels of oil equivalent have so far been

produced through the Hub.

Extensive ongoing investment in asset integrity work

and new technologies is ensuring the facilities remain safe

and capable of continued long-term operation, facilitating

the development of new significant discoveries as well as

small or technically challenging accumulations including

some discovered many years ago that would not have been

viable in the past.

By fully utilising the existing Alwyn North Platform, the Frigg

Pipeline and the St Fergus Gas Terminal near Peterhead,

North of Aberdeen, this will remain a vital production hub

for TOTAL E&P UK and potentially many other operators

and play an ever increasing role in security of supply for

the UK.

9/nine

In 1965, Exploration Licences were granted for the Alwyn Area and in 1971

drilling began. Within one year, the Dunbar, Ellon and Grant discoveries had

been made but the fields were not considered economic at that time.

Four years later, the larger Alwyn North discovery was made. Although more

viable because of its greater size it was still a very complex geological

structure and, despite considerable amounts of costly evaluation, a

decision to develop could not be taken. Five different compartments were

identified: Statfjord, containing gas and condensate; Brent North, Brent

Northwest, Brent East and Brent Southwest, all containing oil. By 1980,

the arrival of new technologies facilitated a three-dimensional seismic survey

to be conducted that provided much-needed additional information about

the structure of the field and provide the

confidence to develop. This resulted, in 1982,

in the completion of a 1,500 million plan to

develop the Statfjord and Brent reservoirs of the

field. Production began in 1987.

Brent Southwest, the most southerly reservoir

compartment, was developed as a subsea

satellite called the Alwyn North Extension and

was brought onstream in 1992. One year later a discovery was made

in the deeper Triassic reservoir beneath the original Alwyn North Brent

reservoir.

With the installation of the Alwyn North platform it became possible

to develop the earlier discoveries, using the Frigg Transportation System

(now known as the Frigg UK line or FUKA) and the St Fergus Gas

Terminal, to which gas is still exported today.

Some 700 million was spent developing Dunbar, which came

onstream in 1994 followed by Ellon in 1995 and Grant in 1998.

Improvements to the gas-handling plant on Alwyn North in

1999 increased processing capacity, enabling the development of

the nearby Nuggets Fields. In 2004 the subsea development of Forvie

North was possible via a subsea pipeline to Alwyn and in 2006 the

Grant production was temporarily rerouted to Alwyn through the Forvie

pipeline to facilitate the development of the Jura field.

Following a fast-track development, May 2008 saw gas from the new

Jura field connected to the Forvie Subsea Manifold via a 3km tie-in

and then produced through the existing infrastructure to Alwyn North.

New technology is also playing a part in maximising production of

the Alwyn Area, including multi-phase pumps on Dunbar and seismic

reprocessing that has enabled accurate and successful targeting of

undeveloped portions of Triassic and Brent reservoirs in the Alwyn

North area. Technological advancement has also helped to more

accurately identify exploration targets in the area, including the Islay

discovery in 2008.

Alwyn/the history

8/eight

11/eleven

Alwyn/North an evolving success

Alwyn North consists of two platforms (NAA and NAB) linked by a 73

metre steel bridge, which sits 31 metres above sea level. The platforms

stand in 126 metre water depth. Alwyn North A (NAA) is the drilling and

accommodation platform, while Alwyn North B (NAB) houses the

processing facilities.

Safety was the most important of many considerations when separating

the drilling and processing facilities. However, it also allowed the NAA

four-legged, steel jacket to be installed and drilling operations to

commence in 1986, a full year before the eight-legged NAB jacket was

installed.

In addition to providing crew access between the two platforms, the

bridge also allows the untreated oil and gas to be transferred from

production on NAA to the processing facilities on NAB. Once treated

the hydrocarbons are exported by oil and gas pipelines. The bridge

also carries all the common systems needed by both platforms, such

as electrical power, fire and gas control, emergency shut-down system,

process control and telecommunications.

In the 1980s a particularly innovative approach was adopted on the Alwyn

North project with the building of two platforms, putting safety

considerations at the very heart of the development plan. Further safety

measures included a thick blast wall protecting the high pressure module

from the accommodation area.

There are seven 58-man lifeboats on NAA and four 58-man lifeboats on

NAB, more than enough to hold the maximum number of staff on board.

Platform design ensured that the facilities could withstand the worst

weather the North Sea could produce, including winds of more than

160km per hour and 30 metre waves.

Further accommodation modules, added during 2009, provide 20

two-man cabins offering greater comfort and privacy for crew.

There is a continuing and extensive programme of fabric maintenance and

upgrades to the Alwyn North facilities, including produced water

re-injection and gas-lift projects. These are aimed at ensuring maximum

recovery of hydrocarbons and extending the life of the field. By ensuring

the facilities remain in

excellent condition and

installing new tech-

nologies and systems,

the Alwyn North Hub

will remain a key facility

for the development of

further discoveries in

the northern North Sea

for decades to come.

10/ten

12/twelve 13/thirteen

Alwyn/life offshore

TOTAL E&P UK takes the health and welfare of its workforce very seriously

and provides a wide range of recreational and other facilities to ensure

the wellbeing of its entire offshore crew whether directly employed or

contracted.

Accommodation is in 108 cabins for two or, if overriding operational

reasons such as major maintenance work make it essential, three people.

An additional accommodation unit consisting of 20 two-berth cabins are

being installed in 2009. All cabins have their own shower and toilet facilities

and satellite TV.

All of the cabins are located within a safe refuge area, designed to

withstand every type of emergency and giving time for the crew to reach

the lifeboats in safety.

The platform has a cinema, a gymnasium, access to computers

for recreational and educational use, a quiet room, billiards, a

well-stocked library and a music room including electronic

keyboard and guitars. Public telephones are also available to

ensure crew members have access to friends and family

onshore.

Helicopters arrive at the platform most days bringing offshore

personnel their daily newspapers, as well as delivering a range

of smaller packages. Most supplies arrive by boat from

Aberdeen, a journey that takes about a day.

In addition to the recreational facilities there is an excellent

restaurant providing quality food and a sociable environment

in which to relax.

15/fifteen

Dunbar/Ellon and Grant fields

14/fourteen

Nuggets/cluster

The Nuggets Field lies around 20km South of Dunbar and was discovered

between 1972 and 1991 in four separate, gas-bearing accumulations. N1

has two wells and the N2, N3 and N4 each have one. Although not very

large fields in terms of recoverable reserves, production should continue for

several years to come.

The five isolated subsea wells that make up the Nuggets cluster are tied

back to the Alwyn North field via subsea pipelines, but are controlled from

the Dunbar platform. From Alwyn North, Nuggets gas is exported via the

Frigg UK line to the St Fergus Gas Terminal for processing and distribution.

Production from N1, N2 and N3 began in November 2001. N4, which is

tied back via a 13km subsea pipeline to the N3 manifold, came onstream

in October 2003. The N4 subsea tieback, at a total length of 67km to Alwyn

North, is the longest in the UK sector of the North Sea.

The Dunbar Field, located approximately 22km to the South of Alwyn

North was discovered in 1973 and came onstream in 1994.

The Dunbar platform consists of a four-legged, steel jacket 167 metres

high and located in a water depth of 145 metres. When the platform was

being designed, safety was a primary consideration. There is a specially

protected safe refuge area that contains the control room and has direct

access to the two, 45-man freefall lifeboats. These are located as far as

possible from the platforms more hazardous areas and are protected by

blast walls.

A core crew of 30 usually mans the platform but an addit ional

accommodation module was installed in 2002 allowing up to 60 berths

for use during maintenance and other special operations.

Development of the Dunbar field in 1994 made viable the development

of satellite fields, Ellon, discovered in 1973, and Grant, discovered in

1977. Both fields, located around 9km from Dunbar were developed

using subsea systems that link them to the Dunbar platform

by flowlines and control umbilicals. Ellon began production in

1994 and Grant four years later.

In 2004 the Forvie North field subsea pipeline to Alwyn was

installed. This enabled the Grant production to be temporarily

re-routed via the Forvie line during 2006, facilitating other

subsea work relating to the Jura field development. Grant was

then re-routed back through Dunbar prior to the Jura field

start-up.

In addition to working on new developments, TOTAL E&P UK

has a comprehensive programme of facility maintenance and

upgrading to ensure efficient operations and to maximise

recovery from the fields, as well as ensure their availability for

the development of future discoveries. This has included

installation of an additional 58

man lifeboat to allow the

personnel on board (POB)

to rise to 120 during major

works and the replace-

ment of the DunbarAlwyn

pipeline, a major task that

was achieved with minimal

disruption to production.

16/sixteen 17/seventeen

Discovered in 2002, and with production starting in December 2004,

the Forvie North field has shown that considerable reserves remain

to be discovered in the Alwyn area and have a significant part to play

in extending the field life of the Alwyn North facilities. The field is 100%

owned by TOTAL E&P UK and is located 16km from Dunbar and

33km from Alwyn North. Water depth is 120 metres.

Gas and condensate is produced from the Brent formation in an

elongated fault panel by a single well. It is tied back to Alwyn North by

a subsea line through the Forvie Manifold, which has been installed to

cater for Forvie North and other satellite discoveries. Plateau production

is in the order of 20,000 barrels of oil equivalent per day.

In 2006 TOTAL E&P UK discovered the Jura field, containing some

170 million barrels of oil equivalent. This very substantial, High Pressure/

High Temperature (HP/HT) discovery was brought on-stream through

two wells only 17 months after discovery due to unique technological

and commercial innovations, including a pipeline bundle assembly

and the first subsea use of a High Integrity Process Protection

System (HIPPS).

Dunbar/innovation

Whilst safety is always paramount, minimising cost has also been a factor

in the development and continued production from Dunbar - so innovative

solutions are constantly being considered. Two multiphase pumps were

installed at a cost of 55 million and are an excellent example of successful

innovative planning. Housed in a 650 tonne module on the Dunbar

platform, they are the largest pumps of their kind in the world.

As the field matures and well pressures drop, increasing quantities of water

have to be pumped into the reservoir to maintain pressure. The pumped

water improves production from Dunbar and Ellon by keeping the pressure

of the oil, water and gas consistent, without the need for the three being

separated for treatment. Each pump can accommodate around 40,000

barrels of liquid and 1.5 - 3.5 million cubic metres of gas per day.

The oil and gas from Ellon arrives at Dunbar through 6 flowlines with all

operations at the subsea wellheads controlled through two umbilicals. Gas

from Dunbar and Ellon goes to Alwyn North for processing before joining

the Frigg UK line and being sent to the St Fergus Gas Terminal. Oil is

exported by pipeline to the Sullom Voe Terminal on Shetland.

The main Jura towhead was the

largest ever built for a towed

bundle and the subsea control

equipment was especially

designed to cope with high

pressure and wide temperature

variations, while maintaining

the highest industrial safety

standards. Production plateau

is in the order of 50,000 barrels

of oil equivalent.

Jura has shown that large

reserves can still be found in the

Greater Alwyn Area and brought

successfully onto production

through innovative and resourceful

teams, even under challenging

HP/HT conditions.

Forvie/North and JURA

18/eighteen 19/nineteen

Alwyn/the future

In June 2008, shortly after production start up from Jura, TOTAL E&P UK

announced yet another discovery in the Alwyn Area. The Islay field, wholly

owned by TOTAL E&P UK, is located in Block 3/15 just 3km East of Jura

and lies in 120 metres of water.

The well was drilled to a depth of more than 4,000 metres and the Brent

reservoir was successfully tested for gas at rates of 1.22 million cubic

metres per day or 8,800 barrels of oil equivalent including condensates.

Studies are under way to bring forward development of this field by tie

back to the Alwyn facilities.

Several other exploration targets have been identified in the Greater Alwyn

Area and form part of the company strategy to maximise the value of

existing production facilities by exploring for satellite accumulations.

ALWYN AREA

TOTAL E&P UK Limited 100%

ALWYN NORTH

DUNBAR

ELLON

GRANT

FORVIE NORTH

JURA

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OTTER

Fina Exploration Ltd* Operator

58.476%

Fina Petroleum Development Limited* 22.520%

Dana Petroleum (North Sea) Limited 19.004%

----------------------------------------------------------------------------------

* Wholly owned subsidiaries of Total Upstream UK Limited

Otter field/delivers deep down

Otter is located 150km Northeast of Shetland and in a water depth of

182 metres. Although not actually produced through the Alwyn Area

Hub, the Otter Field is important in being one of the most northerly and

deepest subsea tiebacks in the North Sea. Oil was first produced there

in October 2002, with a plateau production rate of around 30,000

barrels of oil equivalent per day.

Production became possible by the bold use of dual Electric Submersible

Pumps (ESP) in a subsea tieback, which at 21.5km is the longest in the

UK to use ESP technology. The artificial lift provided by these pumps

accelerates production and increases overall recovery of reserves.

The field consists of a five-well development, three oil producers and

two water injectors, and is tied-back to the Eider platform. Oil is then

exported to the Sullom Voe Terminal on Shetland via the Brent system,

while gas is exported to the St Fergus Gas terminal via the FLAGS

pipeline system.

Otter is an excellent example of

how stranded reserves can be

un locked by techno log ica l

innovation combined with

commercial efficiency. The Otter

development not only adds new

reserves but extends the field life

of Eider.

Photography: Franois Lacour, Ken Taylor

Design by Mearns & Gill, Aberdeen

Copyright TOTAL E&P UK Limited 2009

All rights reserved, no part of this publication may be reproduced, stored in a

retrieval system or transmitted in any form by any means, electronic, mechanical,

photocopying, recording or otherwise without the permission of the copyright holder.

TOTAL E&P UK Limited

Crawpeel Road, Altens, Aberdeen AB12 3FG

Tel: +44 (0) 1224 297000

Fax: +44 (0) 1224 298999

www.total.com