Building & Expanding the Ula WAG
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1 Building & Expanding the Ula WG DEVEX, 13 May 1 Sigrun Mellemstrand, Eirik Espe, Becki van Gestel, Masoud Haajizadeh, Simon Thomas, Ingrid E.I. Øxnevad BP Norge S
2 Ula Field Overview Field History Current WG Future WG Summary S t a v a n g e r Overview Field History UL b e r d e e n U l a E k o f i s k Current WG Scheme Future WG Scheme UL T e e s i d e L o n d o n E m d e n Summary Tambar Gyda Ekofisk
3 Ula Facts Overview Field History Current WG Future WG Summary Ula Ownership: 8% - BP (operator) % - DONG E&P Norge S UL Living Q Drilling Production On stream: 1986 Tambar Field tie-in: 1 Blane Field tie-in: 7 Oselvar tie-in: 11 STOOIP BLNE TMBR ~1 billion stb (16 mill Sm 3 ) Produced as of mmstb oil (7 mill Sm 3 ) Blane Tambar 3
4 Ula Structure Overview Field History Current WG Future WG Summary Elongated four-way salt induced dip closure NF OWC - 356m NE EF OWC - 38m Reservoir dips between and 1 o Lower dips at the crest and to the south ( to 5 o ) NW-SE fault system bisects the structure Shallower oil-water contact in west flank Reservoir depth: m SW WF OWC - 35m TMBR Unit Triassic Unit SW NE 4
5 Ula Fluids Overview Field History Current WG Future WG Summary o PI ~ 4 T res ~95 o F (146 o C) Pb ~ 3 psi (159 bar) Impact of Grid Size on Distributions of Phase Saturation and Density at.5 PVI Ula Slim Tube Simulation - Vaporizing Drive P init ~ 71 psi (49 bar) P res ~ 63 psi (434 bar) MMP ~ 5 psi (345 bar) GOR ~ 5 scf/stb (89 m 3 /m 3 ) Visco ~.35 cp Viscw ~.33 cp Bo ~ 1.36 rb/stb (@Pb) Saturation 1 gas oil 5 grid blocks 1 grid blocks grid blocks C1 in Injection Gas ~ 68% 1 oil Miscible WG Works Well in Ula High SORW (35-5%) Under-saturated oil Density gr/cc gas Pres: 63 > MMP: 5 psi Fractional Distance 1 5
6 Ula Stratigraphy Overview Field History Current WG Future WG Summary Upper Jurassic, shallow marine sandstones Unit 1 Hor. Producers Reservoir Units B Perm (md) Fluids Initial fter WF Future DEPTH METRES TVD METRES SW_ 1 V/V <5cm Current WG ~ 1 m Ula Formation -4 - Oil Water Gas/Water Baffle between Unit 1 & 13 Unit 3 WG Injectors Sorw ~ 35-5% Sorm ~ 5-1% Capable of holding >1 psi (7 bar) Baffle in lower Unit Capable of holding >35 psi 6
7 Ula Historical Profiles Overview Field History Current WG Future WG Summary WI Rate mbd GOR scf/stb Oil Rate mbd arrested decline GI Rate mmscfd WCUT 7 Production increase Online 1 years after discovery WI starts Sharp decline WG Studies Unit 1 production starts WG starts Tambar tied-in More WG conversions WG oil in all WG producers Behind floodfront core First deep horizontal injector 7
8 Requirements to build the Ula WG Overview Field History Current WG Future WG Summary ppropriate water handling capacity à upgraded in 199 and 1994 Reservoir pressure above minimum miscibility pressure (~5 psi / 345 bar) 5 Injected Water, bpd Produced Water, bpd Reservoir Pressure, psi Production & injection Reservoir Pressure Oct- 86 Oct- 88 Oct- 9 Oct- 9 ppropriate gas handling capacity à 1 mmscfd gas processing (3.4 mill Sm 3 ) Gas compression à installed in for gas lift Oct- 94 Oct- 96 Oct- 98 Gas supply à Re-inject gas after export route via Cod Field lost. Tambar, Blane and Oselvar tie-in. Oct- Oct- Oct- 4 Oct- 6 Oct- 8 Conversion of water injectors to gas (WG) injectors 8
9 Current WG Scheme Overview Field History Current WG Future WG Summary 3 vertical WG producers up-dip 1 shut-in 13 3 vertical WG injectors down-dip 1st injector converted in additional injectors in 1/ following Tambar tie-in New WG injector behind WG flood front (9) in 6 1 horizontal WG injector in Unit 3 1 vertical water injector down-dip B 4 Integrity problems with gas injection Current injection capacity 18 7C Gas handling: 1 mmscf/d gas (3.4 mill Sm 3 ) Gas injection: 9 mmscf/d gas (.5 mill Sm 3 ), limited by wells 1 Water handling: 16, bbl/d water (5,4 Sm 3 ) Water injection: 5, bbl/d water (11 Sm 3 ), limited by injection pump WG Injector Water injector Unit 1 Producer WG Producer Ula Top Structure Map 9
10 Ula WG Sectors Overview Field History Current WG Future WG Summary Large sectors (1km.5 km) Sectors identified through tracer program Originally with water tracers (waterflood sectors) Verified with gas tracers sectors) Initial breakthrough times Water: 11 to 55 months Gas: 15 to 35 months 3 tracer injections in 1 (WG Waterflood sectors WG sectors 5/ Tracer travel time, months 1
11 WG Works in Ula Overview Field History Current WG Future WG Summary Historically 5-1 mbd of WG oil (8-16 Sm 3 /d) / Oil rate (mstb/d) % of Ula production Currently ~ mbd WG oil, ~6-7 % of Ula production Total WG oil: ~18 mmstb (.9 mill Sm 3 ) Current scheme, including the contracted Oselvar gas, will recover over 7% of STOOIP N (~16 m3/d) Oil Rate mstb/d) Oil rate (mstb/d)
12 Ula Gas Injection Overview Field History Current WG Future WG Summary 18 bscf of injected gas (3.6 bill Sm 3 ) ~% recycled gas G as Injection, m m scfd : 39 bcf 9: 14 bcf 7C : 36 bcf 4: 11 bcf 3: 4 bcf WG Efficiency: ~7 mscf gas / bbl oil (~.8 Sm 3 oil / ksm 3 gas) WG oil produced from all 4 sectors Indicated by gas tracer data and confirmed by well test results Limited sweep in lower perm Unit B 4 7C Verified by PLTs in injectors while on gas and water injection New injectors target Unit 3 WG Injector Water injector Unit 1 Producer WG Producer WG Sector 1 1
13 9 Drilling Campaign Overview Field History Current WG Future WG Summary -1 recompleted. Came online in June 9, with higher oil rate than expected, and very high GOR. -15 redrilled close to original -15, online in November 9. High initial production rates. ccumulation of mobilized oil 1 oil rate and GOR from well tests 15 oil rate and GOR from well tests Oil Rate [stb/d], green Oil rate GOR WG effect from 7C DHSV repair TTC GOR [scf/bbl], red Oil Rate [stb/d], green WG effect from 3 Recompletion WG effect from 13 Oil rate GOR DHSV failure GOR [scf/bbl], red 1 Jan-99 Jan-1 Jan-3 Jan-5 Jan-7 Jan-9 Jan-96 Jan-98 Jan- Jan- Jan-4 Jan-6 Jan-8 Jan-1 13
14 WG Surveillance Overview Field History Current WG Future WG Summary Key to Evaluating Benefits of WG Gas tracer injection and sampling PLT in injectors Weekly WC measurements Monthly well tests Continuous THP monitoring Injectivity WG slug identification 9 core in mature WG sector 4D seismic being evaluated watercut (vol%) PLT 3 injection zones 1 W-1 (1) WC 65 6.jan. 1.mar. 18.apr. 1.jun. 11.sep. 4.des..feb.3 15.mar.3 7.mai.3 18.jun.3 19.jul.3 3.sep.3 9.okt.3 15.nov.3 7.des.3 5.feb.4 13.mar.4 13.apr.4 5.mai.4 9.jun.4.jul.4 5.sep.4 5.nov.4 3.des.4 3.feb.5 17.mar.5 3.apr.5 9.jun.5 1.jul.5 14.sep.5 6.okt.5 8.des.5 8.jan.6 11.mar.6.apr.6 31.mai.6 9.jul.6 9.sep.6.okt.6 1.des.6 Date watercut 14
15 Data acquisition behind WG flood front Overview Field History Current WG Future WG Summary Extensive Data cquisition Program in 6 9 was drilled in a mature WG sector 13 Reservoir was cored & logged 9 To evaluate effectiveness of current WG scheme To quantify S or distribution 11 meters of core (1% core recovery) B 4 7C Performed extensive study program Over 8 core plugs taken for analysis cm 15cm 3cm 15cm cm WG Injector Water injector Unit 1 Producer WG Producer 1 Routine core & fluid sample analysis Sw and GC, (well site and lab plugs) SCL m & n, Rw from w/s plugs Log nalysis 15
16 Moving to Expanded WG (XWG) Overview Field History Current WG Future WG Summary Successful current WG scheme in Ula Clear indication of mobilized oil production ~ 18 mmstb incremental oil produced Extensive data acquisition in 9 to evaluate effectiveness of WG Simulation studies on Expanded WG Indicate potential for a healthy additional incremental recovery Maximize recovery with Unit 3 horizontal injectors Clear indication of reduction of S or WG8 9 Current WG WG B 4 WG B C 18 7C WG15 1 Expanded WG 1 WG16 WG Injector Water injector Unit 1 Producer WG Producer WG Sector WG Injector Water injector Unit 1 Producer WG Producer WG18 16
17 XWG Screening Overview Field History 5 XWG targets screened and ranked according to recoverable resources -13 WG 8-7 WG 1 7 /1-3 Possible pre-producers. WG 9-3 WG 3-14 WG 14-7B W G /1 - -1B WG 1 WG 4 W G 1 7 / WG C WG Water Injector WG 18 WG Injector S uspended o r bandoned Well t rajectory m s sl F WL m s sl F WL m s sl F WL WG 17 WG /1-9 W G 15 7C 18 W G /1-8 WG Injector Water injector W G 14 4 W G 16-5 WG WG /1-4 17B 17B -7C WG 5 Oil P roducer Leg end /1-3 XWG targets chosen for recoverable resources, location, drillability from existing slots, & good geologic understanding -8 7 /1-6 WG XWG targets chosen for recoverable resources, and location (sweep) Summary X-WG Horisontal Injector -3 WG 7 Future WG Reserves by for s ingle w ell cases, c onstant g as injection of 6 m mscfd 13 W G 8 WG Current WG W G 18 WG Injector Water injector Unit 1 Producer Unit 1 Producer WG Producer WG Producer m s sl F WL m s sl F WL 17
18 XWG Enablers Overview Field History Current WG Future WG Summary 6: 9 WG injector drilled & cored behind flood front (1% S orm ) 7-8: Increase gas handling capacity with Ula Gas Upgrade (UGU) Gas handling 6 mmscfd à 1 mmscfd (3.4 mill Sm 3 /d) 7: Identify locations & slots for new WG injectors 7-8: Investigate passive downhole flow control for uniform injection in horizontal wells 8-1: Replace water injection pumps à 14, bbls/d (k Sm 3 /d) 8: Commitment to purchase Oselvar gas volumes from 11 9: Bring back WG Producers 1: First XWG type well drilled Blane Future gas for Ula WG Scheme: >15 bcf Oselvar Tambar Base Tambar MPP Tambar East 18
19 XWG Plans Overview Field History Current WG Future WG Summary new horizontal injectors in Unit 3 (1&1) Target deeper injection in Unit 3 Long, horizontal injectors ~1m with passive downhole flow control & isolation packers for uniform injection Potential for 5 more horizontal injectors Install new wellhead platform Continue injection in Unit 3 with long, horizontal wells Evaluate additional sources of gas for long term WG Injector B 4 7C WG14 WG Full project has potential to increase recovery by ~1% of STOOIP Bring total recovery to ~7% through technology Water injector Unit 1 Producer WG Producer Enable Ula to produce past 8 19
20 XWG Challenges and Mitigations Overview Field History Current WG Future WG Summary Commerciality - high early investment and late pay-back Project phasing 13 WG8 3rd Party tie-ins (Oselvar) Completion conformance WG13 9 Passive downhole flow control Evaluation of concept needed Reservoir response prediction Comprehensive uncertainty analysis to understand range of outcome Life of field surveillance plan Surveillance commitment WG1 15 WG Injector Water injector Unit 1 Producer WG Producer B 4 WG15 7C WG16 WG18
21 Summary Overview Field History Current WG Future WG Summary Ula forms a strategic hub in the Norwegian North Sea Successful tie-ins of Tambar, Blane, tie-in of Oselvar in 11 Miscible WG is an effective process in Ula Clear indication of mobilized oil production from WG producers Clear indication of reduced S or (down to 1%) in WG flooded zone from 9 core/log data Recovery increased and lifetime extended WG Expansion will realize a healthy additional incremental recovery of ~1% STOOIP Enables production at current levels beyond license period of 8 14 WI GI/WG arrested decline
22 cknowledgements Thanks to BP Norge S and DONG E&P Norge S for allowing this information to be shared. Thanks the Ula team, Eirik Espe, Becki van Gestel, Masoud Haajizadeh, Simon Thomas, Ingrid E.I. Øxnevad
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