Edvard Grieg development brochure

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The Edvard Grieg field was discovered in 2007 and is located in PL338 in block 16/1 in the North Sea, approximately 180 km west of Stavanger AS OF MARCH 2012, THE PL338 LICENSE GROUP CONSISTS OF: Wintershall Norge AS, 30 % Lundin Norway AS (Operator), 50 % RWE Dea AS, 20 %

Transcript of Edvard Grieg development brochure

Page 1: Edvard Grieg development brochure

The Edvard Grieg field was discovered in 2007 and is located in PL338 in block 16/1 in the North Sea, approximately 180 km west of Stavanger

as of march 2012, The pl338 license group consisTs of:

Wintershall Norge AS, 30 %

Lundin Norway AS (Operator), 50 %

RWE Dea AS, 20 %D

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Page 2: Edvard Grieg development brochure

The Edvard Grieg platform – will process and produce stabilized oil and rich gas from the Edvard Grieg deposit which contains the Luno and Tellus discoveries as well as fromfuturesatellitesfrominsidePL338andthesurroundingarea. The platform is also ready for future supply of electrical powerfromshoreviaanACseacable.

Stabilized oilwill be exported to Sture, thus connectingthe 29” outer diameter oil export pipeline from EdvardGriegtotheGraneOilPipeline.Richgaswillbeexportedto the SAGE (Scottish Area Gas Evacuation) system forfurther processing, or re-injected into the reservoir.

The reservoir fluid – is a moderately undersaturated oil with a lowGas-OilRatio.Pressuresupportisachievedprimarilybywater injection and supplemented by limited volumes of gas. The oil-water contact is at 1939 m below sea level.

InadditiontotheLunodiscovery,theTellusdiscoverywasdrilledinthefirstquarterof2011andproveda48moilcolumnin pressure communication with the Luno discovery.

Both reservoirs have highly productive sandstones overlying thick sections of less conventional reservoir types with moreuncertainflowpotential.Productionwillstartfromthe central part of the Luno discovery with pressure support fromwaterinjectorsonthewestflank.Itisestimatedthatmore than 50% of the oil reserves can be recovered by this initial seven-well development solution, providing a sound economic basis for the project.

Fifteenwells,ofwhichsevenarehorizontal,areincludedin the base case. Nine of these oil producing wells will bedrilled inthesouthandtwointhenorth. Inaddition,four down-dip water injectors will be drilled to maintain reservoir pressure. Gas injection for improved oil recovery (IOR)willbeevaluatedinduecoursetogetherwithotherIORmeasures suchas lowpressureproductionandmulti-lateral wells.

The general design parameTers are:

•Adesignlifeof30years

•Overallregularityof96%includingmaintenance

•Waterdepthof109m

•20wellslots

•Livingquarterswith100singlebedsanda capacity for 120 people on board

Norwegian regulatory requirements shall govern the

development of the Edvard Grieg field. Relevant NORSOK

standards and referenced ISO standards shall be used for design

Map of Edvard Grieg field

eDvarD grieg platform & reservoirs

united kingdom

gas exPort to sage, 90 km

Page 3: Edvard Grieg development brochure

Max. oil export rate

Max. gas export rate

Water injection capacity

Gas processing capacity

Gas lift system capacity

Produced water capacity

Total liquids capacity

Seawater makeup treatment capacity

Sm3/sd

MSm3/sd

Sm3/sd

MSm3/sd

MSm3/sd

Sm3/sd

Sm3/sd

Sm3/sd

Units PL338 PL338 w/tie-in

14 300

2.0

24 000

2.5

1.0

13 000

28 000

20 000

20 000

4.0

Unchanged

5.0

2.0

Unchanged

Unchanged

Unchanged

The Topside faciliTies’ design capaciTies are:

Edvard GriEGPLaTfOrM

LuNO & TELLuS rESErvOirS

norwaY

oil exPort to grane oil PiPeline, 42 km

grane oil PiPeline to sture

stureFuture drauPne

installation

grane

drauPnereserVoirs

Page 4: Edvard Grieg development brochure

The Luno and Tellus oil discoveries covers a wide range of reservoirsofdifferentagesandqualities.Thedifferentsub-reservoirs represent one discovery of a single accumulation with a common oil-water contact.

The oldest reservoir on the Edvard Grieg field is found in the northern segment – the Tellus area.Well 16/1-15drilledthrough a thin sandstone followed by more than 200 m with 440 million year old fractured and weathered basement rock of which almost 50 m is in the oil column.

The main part of the Luno discovery is conglomerates and sandstones deposited during the Triassic period, around 210 million years ago. A 50 m thick Triassic Aeolian sandstoneofexcellentreservoirqualitywasencountered in well 16/1-13 in the central part of the Luno basin. More than 50% of the Edvard Grieg reserves are from this sandstone.

The youngest part of the Edvard Grieg field is a shell-rich sandstone deposited in the lower Cretaceous period,around 140 million years ago.

In summary, the reservoir rocks on the Edvard Griegfield spans an age range from 440 to 140 million years, representing a range from porous basement and conglomeratestohighqualitysandstonewithexcellentproperties.

The Edvard Grieg jacket will be installed in May 2014, thereafter a jack-up drilling rig will pre-drill four wells through the pre-drilling deck installed on top of the jacket substructurepriortotopsideinstallation.Aflotelwillbeutilized during offshore hook-up and commissioningprior to first oil, which is scheduled for 1st October 2015.

More wells will then be drilled simultaneously alongside production. Gas and oil export pipelines for transfer ofsaleable products from the Edvard Grieg platform will be installed 2014/2015.

eDvarD grieg progress

Contract Award

Engineering / Procurement

Construction / Assembly

Load out / Seafastening & Marine Operations

Pipelaying

Offshore Hook-up / Commissioning

Drilling

reservoir roCks spanning 300 million years

edvard grieg reservoir levels

1. 16/1-13, 16/1-15 & 15 A T2 (Tellus)

2. 16/1-8 (Luno)

3. 16/1-8, 16/1-10, 16/1-13 (Luno)

4. Basement 16/1-15 & 15 A T2 (Tellus)

millions of years

500

300

400

200

100

0

ZenoZoic

creTaceous

jurassic

Triassic

permiancarboniferousdevoniansilurian

ordovician

1

2

3

4

jackeT

Topside

heavy lifT

oil exporT pipeline

gas exporT pipeline

pre drilling & drilling

20122013

20142015

a simplified overall schedule shoWing The major conTracTs and acTiviTies

first oil

sture

Page 5: Edvard Grieg development brochure

Drilling, Completion & Well intervention

eDvarD griegJaCket & topsiDe

Drilling RigThe drilling and completion operations will be carried out by a Rowan Drilling Keppel Fels N-class jack-up rig built in Singapore in 2010/2011. The rig will be located beside the Edvard Grieg platform and then skid the drilling cantilever over the well slots.

Wells15 wells will be drilled, of which 12 will target the Luno area and three will target the Tellus area• IntheLunoarea,nineoilproducingwells and three wells that can alternate between gas injectors and water injectors are planned• IntheTellusarea,therewillbetwooilproducers and a single water alternating gas well• Sevenoilproducingwellswillbedrilledhorizontally in the reservoir section• Thelongestwellwillbeanestimated5.5kminlength• Intotalthe15wellswillrequire61kmofdrilling

Jacket The Edvard Grieg platform substructure will consist of a four legged launch-installed jacket steel structure with a vertical clean face towards platform south to allow access for a jack-up drilling unit. A pre-drilling deck will be installed on top of the jacket after it has been piled to the seabed.

Topside Thetopsideisamodularizedprocessingplant,consistingof amaindeck framewith equipment (C00), a processmodule (P00)with separately installedflare stack (F00)andautilitymodulewithintegratedlivingquarters(U00).

• Thecompletionofthe15wellsisestimatedtotake 1150 days in total• Theoilproductionwellsaredesignedforgasliftto increase overall recovery

Simultaneous OperationsThe Edvard Grieg platform is designed such that well intervention operations (coiled tubing,wirelinework,etc.)canbeperformedsimultaneouslywhilethedrillingrig carries out drilling and completion operations.

Reservoirs Formations There will be four different types of reservoirs drilled:1. Sandstone2. Conglomeraticsandstone(beingsandstonewith integratedgranitestonesofdifferentsizes)3. Conglomerate4. Weatheredandfracturedbasement(Tellus)

The main properTies of The jackeT:

The main properTies of The Topside:

1 32 4

Reservoirs Formations

Dimensions:

Height:

Weight:

Dimensions:

Height:

Weight:

46x27.5m(top),66x50m(total)

134 m

13000tons(dry)19500tons(operation)

90x27.5m(top),110x43m(total)

68m

20800tons(dry)24000tons(operation)

Major Offshore Lifts

u00P00

C00

F00

Predrill deCk

Page 6: Edvard Grieg development brochure

Lundin Norway

Strandveien 50D

NO–1366Lysaker

Norway

Future Riser / J-tubes

Gas

Oil

Water

Cooler

Heater

Pump

Valve

M

M

M

M

M

M

Fuel gas

prod. Well

Lift gas

Gas Export

Gas Injection

Gas Injection Compressor

From HP Flare

To Primary Water Injection Pump

To Secondary Water Injection Pump

2nd Stage ExpCompressors

NNF

TEG

NNF

To TegRegeNeRaTioNTo iNleT

SepaRaToRSTo 2Nd Sep.

pRi iNleT Sep.

Sec iNleT Sep.

TeST Sep.

degaSSeR

degaSSeR

2Nd Sep.

3Rd Sep.

coaleSceR

To 3Rd Sep

RecycleS

1st Stage ExpCompressors

2nd Stage Recompressor

1st Stage Recompressor

TesTmanifolds

fuTure Tie-ins

producTion manifolds

draupne floWlines

TEG Contactor

Process Syste

m

proCess system

The facilities will be designed with two parallel inlet separators and a test separator with shared downstream trains foroil stabilizationandgas treatment.Liftgasrequiredforwellproductionwillbetakenoffdownstreamfromthesecondstageexportcompressor.

The separation system will be a three stage separation process with an electrostatic coalescer due to energy efficiencyandtolimitthesizeoftherecyclestreams.

Normally the produced water will be re-injected into the reservoir after passing through a redundant treatment system consisting of hydrocyclones and degassing drums. This is to ensure a low oil content in the water.

Tel:(47)67107250

Fax:(47)67107251

E-mail: [email protected]

www.lundin-norway.no Rev. 01 Desi

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