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Home My WebLink About2008 BadamiEs Emeka Emembolu ACT Manager, Base Management Alaska Consolidated Team IACTi March 31, 2009 John K. Norman Commissioner and Chair Alaska Oil and Gas Conservation Commission 333 W. 7th Ave #100 Anchorage, Alaska, 99501-3539 EP Exploration (Alaska) Inc 000 East Benson Boulevard PO Bax 196612 Anchorage, AK 99519-6612 (907) 564-5111 Phone: (907) 564-5536 Fax: (907) 564-4440 Email Emeka.Emembolu ®bp.com Web: www.bp.com RE: Badami Field, Badami Oil Pool Annual Reservoir Performance Report Dear Mr. Norman: BP Exploration (Alaska) Inc., as operator of the Badami Unit, hereby submits the attached Annual Reservoir Performance Report in accordance with the requirements of Rule 9 of the Badami Oil Pool Area Injection Order, dated August 26, 1998, and 20 AAC.25.115. This report covers the period January 1 through December 31, 2008. This report provides a summary of the enhanced oil recovery operations at Badami, and addresses the following: • Progress of the enhanced recovery project and reservoir management summary including engineering and geological parameters. • Voidage balance by month of produced fluids and injected fluids. • Analysis of reservoir pressure surveys within the pool. • Results and where appropriate, analysis of production and injection logs, tracer surveys and observation well surveys. • Special monitoring. • Evaluation of well testing and allocation. • Future development plans. • Review of Annual Plan of Operations and Development. BP reserves the right to alter the content of the analyses contained in this report at any time based upon the most recent surveillance information obtained. Please contact John Garing (564-5167) if there are any other questions. Sincerely, Emeka Emembolu cc: Kevin Banks, DNR R. L. Skillern, BP Badami File .,ItL .. r, •. REPORT JANUARY 2008 - DECEMBER 2008 Table of Contents 1. Introduction 2. Summary of Reservoir Management and Enhanced Recovery 3. Voidage Balance 4. Reservoir Pressure Monitoring 5. Production Logging 6. Special Monitoring 7. Evaluation of Well Testing and Allocation 8. Future Development Plans 9. Review of Annual Plan of Operations and Development 10. Status of wells shut-in for 365 Days or More Appendices 3 3 4 4 4 4 5 5 5 5 Table 1 Badami Well Disposition Table 2 Badami Production/Injection - Surface Units Table 3 Badami Production/Injection - Reservoir Units Table 4 Badami Pressure Monitoring Summaries Table 5 Badami Well Testing Frequency Summaries Figure 1 Field Production History Figure 2 Field Gas Disposition Histories ANNUAL RESERVOIR SURVEILLANCE REPORT BADAMI OIL POOL January 2008 — December 2008 1. Introduction As required by Rule 9 of the Badami Oil Pool Area Injection Order, dated August 26, 1998, this report provides a summary of the enhanced oil recovery operations at Badami. It will address the following: ® Progress of the enhanced recovery project and reservoir management summary including engineering and geological parameters. ® Voidage balance by month of produced fluids and injected fluids. ® Analysis of reservoir pressure surveys within the pool. ® Results and where appropriate, analysis of production and injection logs, tracer surveys and observation well surveys. ® Special monitoring. ® Evaluation of well testing and allocation. ® Future development plans. ® Review of Annual Plan of Operations and Development. 2. Summary of Reservoir Management and Enhanced Recovery Production at Badami was restarted September 15, 2005 after a field wide shut-in since August 2003. Production since the 2005 restart was from five wells with gas injection into one well. The field has returned to warm shutdown status starting in late August 2007. Following the field shutdown, static bottom -hole pressures were obtained in 131- 11A, B1-14, 131-18, Bi -21, and B1-36. Two sets of static bottomhole pressures were obtained in B1-18, B1-21, and B1-36 during this reporting period. Table 4 contains a summary of the static bottom -hole pressures acquired in 2008. There was no production and injection from or to the Badami reservoir during this reporting period, because of the warm shutdown. No new wells were drilled or completed in 2008. Well disposition is detailed in Table 1. 3 The production and gas disposition history of the field during the report period is shown in Figures 1 and 2. I Voidage Balance Since no production or injection occurred during the reporting period, Tables 2 and 3 contain only zeros. Cumulative voidage for year 2008 was 0 reservoir barrels. 4. Reservoir Pressure Monitoring Six static pressures were taken at Badami during the report period and are listed in Table 4. These statics show that the pressures in the individual lobes of the reservoir have increased since warm shutdown in 2007. Well B1-21, as with the other wells, showed an increase since warm shutdown, but also a small decrease between its February and August static pressures. 5. Production Logging No production logging was performed during the report period on wells completed in the Badami reservoir. 6. Special Monitoring Other than static bottom hole pressures outlined in Table 4 and daily monitoring of wellhead pressures, no other special monitoring was done during the reporting period. 7. Evaluation of Well Testing and Allocation Table 5 is a summary of well testing frequency for each of the Badami wells. Due to the warm shutdown no well testing was done during the reporting period S. Future Development Plans In 2008, BP and Savant Alaska concluded a farm -out agreement covering BP's interest in the Badami Unit. As part of this agreement, Savant Alaska plans to drill at least one well to the Red Wolf prospect within the Badami Unit during the '09 winter drilling season. This prospect is targeting Kekituk (Endicott type) reservoirs. Additional drilling options, in '09 or '10, will be reviewed following the results on the Red Wolf exploration well. Plans for further Badami activity will be reviewed following the results of the exploration well. No major changes to the current infrastructure are planned. Monitoring of well integrity and surveillance activity on the Class 1 disposal well, BI -01, will continue as required. Reservoir pressure data will be acquired during 2009 to monitor Badami reservoir recharge. 9. Review of Annual Plan of Operations and Development The field was granted a 7"' POD by the Department of Natural Resources in July 25th of 2008, which expires August 15, 2011. 10. Status of Wells Shut-in for 365 Days or More (20 AAC 25.115) The following wells were shut --in all of 2008. Badami Shy hr Well. gnnr L xaasons for +incl] Shut -In A High CAR, coready uwornpetrttvt to prod_e doe to fat ihty,:Q:6; Sant. ar, kn<,,c-r. raec3x�atal Era{.;trt r B High water, currently uaecanamrc to produce- no known mochanKal proNerrs C Low prodw tion rata, no known mechawat FrdAe= D. 24scbanrcal PraLem E GeLer (Sptcrfy under comipants) 2 OrreathfechamealCondtn,;,n Briefly dercnbe the current mechaaual con itma mctuding the candiwn of witAxed tubing am,; crag s��ga 3 Future lTtddy 1 Evaluating remedial, a0ctrack mr &or redri.9 %perruatties 2. Fxmedial well work planned 3 Long Vrm Shut-in wellf 2Io inune&atr plans 4 $Opended well 5 P&A planned f 002" (Spactfy under commenu) Date Shut- Reason far well Current Mechanical Condition of Future Utility Pians & Sw Name In Shut -Int wall, Possibilities' Comments BI -11A Avg -07 E. Field Warm Shutdown Secured with TTP & 8PV. 1. Possible Sidetrack B1-14 Aug -07 E. Field Warm Secured with TTP 8 BPV. 6. Produce Post Warm Shutdown Shutdown 81.15 Jan -07 D. Mechanical Secured for TxIA communication 2. Possible tubing patch Problem 4129/07. Secured with TTP & BPV. candidate BI -16 Ade -07 y C. Low Production Secured with BPV. 6. Produce Post Warm Rate Shutdown 81'18 Aug -07 E. Field Warm Secured with TTP &BPV. 6. Produce Post Warm Shutdown Shutdown 8f 21 Aug 07 E. Field Warm Secured with TTP & 8PV. 6. Produce Post Warm Shutdown Shutdown Collapsed tubing and casing at 4504' Bi Mechanical Dchanical MD. Halliburton 9.518' Fasddll @ 3. Long term shut-in -25 Jul -0.3. 2450'w/ 50' Arctic Set Cement and 9- well / No immediate 518' Fialliburton EZSV 0 2347' ND w/ plans 50' of Artic Set Cement above plug. 81-28 Jul -03 D. Mechanical TKA communication. Secured with 3. Longterm shut-in Problem tubing tail plug and BPV well! No immediate fans Bl-36Au g •07 E• Field Wama Secured with TTP &BPV. 6. Produce Past Warm Shutdown Shutdown L xaasons for +incl] Shut -In A High CAR, coready uwornpetrttvt to prod_e doe to fat ihty,:Q:6; Sant. ar, kn<,,c-r. raec3x�atal Era{.;trt r B High water, currently uaecanamrc to produce- no known mochanKal proNerrs C Low prodw tion rata, no known mechawat FrdAe= D. 24scbanrcal PraLem E GeLer (Sptcrfy under comipants) 2 OrreathfechamealCondtn,;,n Briefly dercnbe the current mechaaual con itma mctuding the candiwn of witAxed tubing am,; crag s��ga 3 Future lTtddy 1 Evaluating remedial, a0ctrack mr &or redri.9 %perruatties 2. Fxmedial well work planned 3 Long Vrm Shut-in wellf 2Io inune&atr plans 4 $Opended well 5 P&A planned f 002" (Spactfy under commenu) Table 1 Badami Well Disposition Well Completion Disposition Comment Date B1-01 8/19/98 Class 1 Disposal Well Com feted MIT in 2007 131-11A 3/4/98 Pre -produced injector Producer 8/24/98 to present. cased and prop fracced. Secured with TTP & BPV. B1-14 5/1/98 Gas injector, cased. Injector 8/24/98 to 9/29/98. Producer 9/30/98 to 11/29/98. Injector 9/30/98 to present. Secured with TTP & BPV. B1-15 7/31/98 Producer, trilateral. Trilateral dedicated producer. Secured for TxIA communication 4/29/07. Secured with TTP & BPV. B1-16 6/13/98 Pre -produced injector, Injector 8/24/98 to 9/25/98. cased, prop fracced. Producer 9/26/98 to 10/21/98. Will not sustain flow, well contains fill, tbg restricted with paraffin, and unable to pump into well. Secured with BPV. B1-18 4/3/98 Producer, cased and Dedicated producer. prop fracced. Secured with TTP & BPV. B1-21 1/6/98 Pre -produced gas Producer 8/24/98 to 11/30/98. injector, fracced, no Injector 12/01/98 to Aug 2003. proppant. Converted Producer Oct 2005 to present. back to producer. Secured with TTP & BPV. B1-25 11/20/98 Producer, unilateral Dedicated producer. open hole. Secured/safed out due to collapsed tubing and casing. B1-28 10/20/98 Producer, trilateral Dedicated producer. open hole. Secured for TxIA communication 4/18/05. Secured with TTP & BPV. B 1-36 5/23/99 Producer. Dedicated producer. Secured with TTP & BPV. As of December 31, 2008 Table 2 Badami Production/Injection - Surface Units Table 2 Badami Production/Injection - Surface Units BADAMI PRODUCTION I INJECTION - SURFACE UNITS 2008 PRODUCTION Jan Feb Mar April May June July Aug Sept Oct Nov Dec 2008 Total Oil (stb) 0 0 0 0 0 0 0 0 0 0 0 0 0 Associated Gas (mscf) 0 0 0 0 0 0 0 0 0 0 0 0 0 Free Gas (mscfl 0 0 0 0 0 0 0 0 0 0 0 0 0 Water (stb) 0 0 0 0 0 0 0 0 0 0 0 0 0 2008 INJECTION Water (stb) 0 0 0 0 0 0 0 0 0 0 0 0 0 Gas (mscf) 0 0 0 0 0 0 0 0 0 0 0 0 0 Notes: (1) Per a discussion between Jack Hartz and Anna Dube on 3122100, a solution GOP, of 586 was determined using production data from 8198 to 2199 and is used in calculating volumes of associated gas. This was done to address the fact there are different types of oil in the reservoirwith different GOR. (2) Volumes of produced water are reported here although they are not reported in other production allocations and injection reporting due to not being of significant volume. Volumes here are based on tank levels when the waterwas pumped into the disposal well and are not the actual water production for any given month. 2 Fable 3 Badami Production/Injection - Reservoir Units Table 3 Badami Prod uctionllnjection - Reservoir Units BADAMI PRODUCTION t INJECTION -RESERVOIR UNITS 2008 PRODUCTION Jan Feb Mar April May June July Aug Sept Oct Nov Dec 2008 Total Oil (rb) 0 0 0 0 0 0 0 0 0 0 0 0 0 Free Gas (rb) 0 0 0 0 0 0 0 0 0 0 0 0 0 Water (rb) 0 0 0 0 0 0 0 0 0 0 0 0 0 All Fluids (rb) 0 0 0 0 0 0 0 0 0 0 0 0 0 2008 INJECTION Water (rb) 0 0 0 0 0 0 0 0 0 0 0 0 0 Gas (rb) 0 0 0 0 0 0 0 0 0 0 0 0 0 All Fluids (rb) 0 0 0 0 0 0 0 0 0 0 0 0 0 Voiclage (rb) 0 0 0 0 0 0 0 0 0 0 0 0 0 Oil Formation Volume Factor, Bo 1.300 rblstb Gas Formation Volume Factor, Bg 0.000583 rbfscf 0.003276 voUvol Water Formation Volume Factor. Bw 1.0101 rblstb Notes: (1) So from Average of Badami 91 and Badami 45 (lower sand) PVT analysis. (2) Bg calculation based on gas composition of sample taken 9118198 (reservoir temperature 185 degrees F, reservoir pressure: 6400 psi) 1 0 Table 4 2008 Badami Pressure Monitoring Well Date Operation Pressure At Datum (psia) B1-18 212108 Pressure Static 1,462 B1-21 2/3108 Pressure Static 3,165 B1-36 211/08 Pressure Static 2,631 B1-18 817/08 Pressure Static 1,617 B1-21 8/5108 Pressure Static 3,032 B1-36 814/08 Pressure Static 2,787 Datum is 10,500' TVDss ii Table 5 Badami Well Testing Frequency Summary Well Number of Well Tests in 2003 Number of Well Tests in 2004 Number of Well Tests in 2005 Number of Well Tests in 2006 Number of Well Tests in 2007 Number of Well Tests in 2008 B1 -11A 11 0 29 84 33 0 BI -15 3 0 15 43 0 0 B1-16 0 0 0 1 1 0 B1-18 1 0 18 64 19 0 BI -21 0 0 22 35 18 0 B1-25 8 0 0 0 0 0 B1-28 9 0 0 0 0 0 B1-36 7 0 25 90 36 0 12 Figure 1 18,00( 16,000 14,000 12,000 Q. 0 2 Q? 10,000 E 0 7 8,000 A i� 6,000 Field Production History Badami Field Oil Production 4,000. 2,000 0-1 8124198 8124199 8123100 8123101 8123102 8123103 8122/04 8122105 8/22106 8122107 8121/08 13 Figure 2 Field Gas Disposition Histories 35,000 30,000 25,000 r. V o. cs 20,000 a� ;r 0 15,000 t� a 10,000 5,000 0 Badami Field Gas Disposition 8124198 8124199 8123100 8/23101 8123102 8123103 8122104 8/22/05 8/22/06 8122107 8121108 14