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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 %D
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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
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
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
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
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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