Gjøa - posisjonert for vekst
Transcript of Gjøa - posisjonert for vekst
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!