Vekst i Vest 2015

Gjøa – posisjonert for vekst 29. oktober 2015

CONTENTS

Chapter 1 GDF SUEZ becomes ENGIE

Chapter 2 Gjøa today

Chapter 3 Looking forward in the Gjøa area

GDF SUEZ becomes

ENGIE

GDF SUEZ group is now ENGIE

The GDF SUEZ Group is now ENGIE,

and we have a new logo

The new name and logo of the group

symbolize the group’s transformation and

corporate ambition

ENGIE aspires to be the benchmark

energy player in fast growing markets

and the energy transition leader in

Europe

GDF SUEZ E&P Norge AS is part of the

ENGIE Group. Our company name will

remain the same until further notice.

For more information:

http://gdfsuezep.no/en/News/GDF-SUEZ-

becomes-ENGIE/

ENGIE at a glance

GDF SUEZ E&P INTERNATIONAL

E&P activity

E&P main assets or projects

Participation in liquefaction plant

Touat

Absheron

Jangkrik

Cygnus Gjøa

Snøhvit

G16a-B

Römerberg

Amstel

6

GDF SUEZ E&P Norge production portfolio

Fram (North Sea)

Njord (Norwegian Sea) Snøhvit (Barents Sea)

Gudrun (North Sea) Gjøa (North Sea)

Gjøa today

Gjøa

Key milestones

PDO approved June 2007

Platform on location June 2010

Production start-up and transfer of operatorship

November 2010

License and ownership

PL153 discovered 1989. Acquired 2003.

GDF SUEZ: 30% (Operator)

Petoro: 30%

Wintershall: 20%

Shell: 12%

RWE Dea: 8%

Gross recoverable reserves

Liquid recovery: 13.2 MSm³

Gas recovery: 39.7 GSm³

Development concept

Semi submersible platform with 4 subsea

(4-slot) templates and 1 satellite well

11 wells, 7 oil producers and 4 gas producers

Gas export capacity 17 MSm³/d and oil export

capacity 87000 bbl/d

Rich gas export through FLAGS to St. Fergus

and oil export through TOR2 to Mongstad

Power from shore – Mongstad

Vega field is tied back to Gjøa for processing

No serious incidents

No significant gas leaks

since start-up

Low emission to air due to

power from shore

Good control of discharges

to sea

HSE

High regularity after initial

replacement of one gas

export riser and repair of

Gjøa 1st Stage Separator

Turnaround frequency

changed from every 2nd to

every 3rd year

Gas and oil capacity

increased compared to

original design

Regularity

Low benchmark on unit cost

in 2013.

Unit cost increase due to

declining production

Gjøa Optimization and

Efficiency project managed

to reduce operating cost by

12%. Work will continue to

optimize further.

Cost

HSE, Regularity, Cost - three important topics

10

Spend and cost savings initiatives

Activities in Sogn & Fjordane and our spend:

— In 2014, our activities created about 8% spend of our total spend to companies located in Sogn &

Fjordane

— 2015 show the same prognosis

Cost saving initiatives:

— Cooperation with other Operators

— Demand management internally

— Innovative solutions: in cooperation with our vendors, find new ways of working together creating win-

win solutions

11

Looking forward in the Gjøa area

Good HSE result

Increased capacity compared

to design capacity

Good regularity

Facilities have proved to work good

Designed for tie-ins

— Deck space reserved for tie-in

— Additional weight capacity

— Extra riser slots

Gjøa/Vega on decline and

processing capacity

becoming available

Available capacity for 3rd party tie-in

Drilling in exploration

license 636 Cara autumn

2016 in planning

Work ongoing to increase

our cost efficiency in several

areas

New opportunities

5 years after start-up of Gjøa

13

The future is bright!