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Home My WebLink About2011 Greater Kuparuk AreaConocoPhillips Alaska, Inc. Greater Kuparuk Area 2011 Annual Reservoir Surveillance Reports Kuparuk, Meltwater, Tabasco, Tarn, & West Sak Oil Pools Reporting Period January 1 to December 31, 2011 2011 GREATER KUPARUK AREA ANNUAL SURVEILLANCE REPORTS Table of Contents KUPARUK RIVER OIL POOL REPORT SUMMARY OF EOR PROJECT................................................................... ATTACHMENT 1 Map of EOR Program Status Plot of Incremental EOR Oil Rate PRODUCED FLUID VOLUMES ................................ INJECTED FLUID VOLUMES ................................... RESERVOIR PRESSURE SURVEYS ...................... PROPOSED PRESSURE SURVEY PLAN RESERVOIR PRESSURE SURVEY REPORT PROPOSED INJECTION PROFILE SURVEY PLAN INJECTION SURVEY DATA ..................................... PRODUCTION SURVEY DATA ................................ MISCIBLE INJECTANT COMPOSITION .................. CPF1 MI Composition CPF2 MI Composition ..... ATTACHMENT 2 ..... ATTACHMENT 3 ..... ATTACHMENT 4 ATTACHMENT 5 ATTACHMENT 6 ATTACHMENT 7 KUPARUK LSEOR DEVELOPMENT PLAN ................................................. ATTACHMENT 8 MELTWATER OIL POOL REPORT SUMMARY OF EOR PROJECT & RESERVOIR MANAGEMENT ............... ATTACHMENT 1 PRODUCED FLUID VOLUMES.................................................................... ATTACHMENT 2 INJECTED FLUID VOLUMES....................................................................... ATTACHMENT 3 RESERVOIR PRESSURE SURVEYS.......................................................... ATTACHMENT 4 PROPOSED PRESSURE SURVEY PLAN RESERVOIR PRESSURE SURVEY REPORT PRODUCTION & SPECIAL SURVEYS........................................................ ATTACHMENT 5 WELL ALLOCATION & SHALLOW GAS SPECIAL MONITORING .............. ATTACHMENT 6 Meltwater OA Pressure Survey for 2011 DEVELOPMENT PLANS & OPERATIONAL REVIEW ................................. ATTACHMENT 7 MAP SHOWING DEVELOPMENT AS OF 12/31/2011 ................................. ATTACHMENT 8 TABASCO OIL POOL REPORT SUMMARY OF EOR PROJECT................................................................... ATTACHMENT 1 PRODUCED FLUID VOLUMES.................................................................... ATTACHMENT 2 INJECTED FLUID VOLUMES....................................................................... ATTACHMENT 3 PROPOSED PRESSURE SURVEY PLAN RESERVOIR PRESSURE SURVEYS.......................................................... ATTACHMENT 4 PRODUCTION LOGS & SPECIAL SURVEYS ............................................. ATTACHMENT 5 WELL ALLOCATION & TEST EVALUATION SUMMARY ............................ ATTACHMENT 6 DEVELOPMENT PLANS & OPERATIONAL REVIEW ................................. ATTACHMENT 7 TARN OIL POOL REPORT SUMMARY OF EOR PROJECT................................................................... ATTACHMENT 1 PRODUCED FLUID VOLUMES.................................................................... ATTACHMENT 2 INJECTED FLUID VOLUMES....................................................................... ATTACHMENT 3 PROPOSED PRESSURE SURVEY PLAN RESERVOIR PRESSURE SURVEYS.......................................................... ATTACHMENT 4 PRODUCTION LOGS & SPECIAL SURVEYS ............................................. ATTACHMENT 5 PRODUCTION ALLOCATION FACTORS .................................................... ATTACHMENT 6 DEVELOPMENT PLANS & OPERATIONAL REVIEW ................................. ATTACHMENT 7 MAP SHOWING RECENT DEVELOPMENT WELLS ................................... ATTACHMENT 8 WEST SAK OIL POOL REPORT SUMMARY OF EOR PROJECT................................................................... ATTACHMENT 1 PRODUCED FLUID VOLUMES.................................................................... ATTACHMENT 2 INJECTED FLUID VOLUMES....................................................................... ATTACHMENT 3 PROPOSED PRESSURE SURVEY PLAN RESERVOIR PRESSURE SURVEYS.......................................................... ATTACHMENT 4 INJECTION SURVEY DATA......................................................................... ATTACHMENT 5 PRODUCTION SURVEY DATA.................................................................... ATTACHMENT 6 GEOCHEMICAL OIL PRODUCTION SPLITS .............................................. ATTACHMENT 7 PRODUCTION ALLOCATION FACTORS .................................................... ATTACHMENT 8 DEVELOPMENT PLANS & OPERATIONAL REVIEW ................................. ATTACHMENT 9 KUPARUK GAS OFFTAKE TABLE OF MONTHLY GAS OFFTAKE........................................................ ATTACHMENT 1 lFrAll :"A WI IN James T. Rodgers ConocoPhillips Manager, Development Greater Kuparuk Area ConocoPhillips Alaska, Inc. ATO -1326 PO Box 100360 Anchorage AK 99510-0360 Phone (907) 263-4027 Fax: (907) 265-6133 March 31, 2012 Mr. Dan Seamount, Commissioner Alaska Oil and Gas Conservation Commission 333 West 7th Ave. Suite 100 Anchorage, Alaska 99501-3539 Re: 2011 Kuparuk Oil Pool Annual Reservoir Surveillance Report Dear Commissioner Seamount, In compliance with Rule 3, Conservation Order No. 19813, ConocoPhillips Alaska, Inc., operator of the Kuparuk River Unit, is hereby submitting the annual surveillance report on the Kuparuk River Oil Pool. This report documents the required information pertinent to the field development and enhanced recovery operations from January through December 2011. The following is an outline of the information provided.- a. rovided:a. A summary of the enhanced recovery project (Attachment 1). b. Voidage balance, by month, for produced and injected fluids, including low molecular weight hydrocarbons (Attachments 2 and 3). c. Analysis of reservoir pressure surveys taken in 2011 (Attachment 4). d. A tabulation of both injection (Attachment 5) and production (Attachment 6) logs and surveys analyzed during 2011 from wells in the Kuparuk permit area. e. Composition of enriched gas injected during 2011 and estimate of MMP (Attachment 7). f. Kuparuk LSEOR development plan (Attachment 8). If you have any questions concerning this data, please contact Mark Kovar at 265-6097. i J mes T. Rodgers Manager, GKA Development Greater Kuparuk Area ATTACHMENT 1 Kuparuk River Oil Pool 2011 Annual Reservoir Surveillance Report Summary of the Enhanced Recovery Project Enhanced Recovery Miscible water -alternating -gas (MWAG) continues to serve as the main enhanced oil recovery process for the Kuparuk field. Thirty MWAG/IWAG drill sites service the Kuparuk reservoir which includes 257 available EOR patterns. Some mature patterns generally no longer receive miscible injectant (MI) but are available for use as lean gas injection wells when plant upsets occur and when the drillsites are converted to lean gas chase. The field continues to manufacture miscible injectant at two of its Central Processing Facilities (CPFs). MI manufacture occurs by blending together produced lean gas and natural gas liquids (NGLs). The NGLs originate from two sources: (1) the Kuparuk field itself (known as indigenous NGLs), and (2) those NGLs imported from the Prudhoe Bay Field Central Gas Facility. Importation from Prudhoe Bay is utilized to fill any shortfall between the total NGL requirement and the available indigenous NGL production. From a flood management perspective, the majority of available lean gas after fuel use is blended with these two NGL streams to maximize the daily volume of MI generated in the field. During 2011, the MWAG project operated in full MI production mode for most of the 30 MWAG drillsites. Three mature MWAG drillsites (drillsites 2U, 2V and 2W) were converted to lean gas chase (LGC) in 2007 and continued to conduct LGC through 2011. The purpose of this lean gas injection, in the format of immiscible water alternating gas or IWAG, is to recover NGLs left behind by the original MWAG process, and collect data to evaluate post-MWAG options. The observations from these three drillsites indicated potential for increasing returning NGL sales. Drillsites 1A, 1Y and 2X were subsequently converted to lean gas chase mid -2009, followed by drillsites 1 G and 1 R later in that year, after seeing positive response from drillsites 2U, 2V and 2W. See next page for further discussion on drillsites 1 G, 1 R, and 2X. Drillsite 1 D started MI injection in October of 2008 upon completion of an EOR expansion project. Very positive response of the MI injection has continued in many patterns in drillsite 1D during 2011. The 2011 annual average incremental oil production rate from drillsite 1D was 1,609 STB/d. During the year 2011, Kuparuk imported an average of 17,178 barrels per day of Prudhoe NGLs. Import NGLs and indigenous NGLs blended with available lean gas generated an average of 180 MMSCFD of MI. The annual average MI injection rate into the Kuparuk Field was 134 MMSCFD. The remainder was utilized for Greater Kuparuk Area satellite fields, including 25 MMSCFD as injection and 17 MMSCFD as lift gas in Tarn and Meltwater and 4 MMSCFD as injection at West Sak. A small amount of MI (-3 MMSCFD) is used as lift gas in drillsite 3S. West Sak 1J and 1E started VRWAG (viscosity reduction water alternating gas) testing and used a tiny amount (-0.3 MMSCFD) of MI. The estimated incremental oil sales in year 2011 from the ongoing Kuparuk MWAG project is 28 MBO/day. As in the past years, due to the lack of the base line water flood performance data, the incremental oil production from Tarn and Meltwater MWAG is not split from their total oil. The priority for gas management at the Kuparuk field during 2011 was to continue to balance solvent injection between the A -Sand and C -Sand. This maximizes total EOR and returned NGL rates while avoiding excessive gas production rates, which would cause production impacts due to gas handling limitations. Total GKA annual average gas production rate in 2011 was 237 MMSCFD, down from 266 MMSCFD during 2010. MWAG Small Scale EOR (SSEOR and SSEORX) Drillsite 2Z continued on MI injection; drillsites 1A, 1Y, and 2X no longer receive MI injection. The 2011 average MI injection rate at Drillsite 2Z was 3 MMSCFD. Large Scale EOR (LSEOR) The original LSEOR Drill Sites include: 1 F, 1 G, 1 Q, 1 R, 2A, 213, 2C, 2D, 2F, 2G, 2H, 2K, 2M, 2T, 2U, 2V, 2W, 2X and 3F. The total MI injection rate into these drill sites averaged 41 MMSCFD in 2011. EOR Expansions Expansions to the original LSEOR occurred over multiple phases and now include Drill Sites 1 B, 1 C, 1 D, 1 E, 1 L, 313, 3G, 3H, 30, 3Q and 3S. During 2011, the average MI injection rate into these expansion drill sites was 90 MMSCFD. �t During 2011 operations, the Kuparuk EOR project continued to maximize the volume of available MI by blending a majority of available lean gas with Kuparuk-sourced and imported NGL. IWAG operations were continued in drillsites 1A, 1Y, 2U, 2V & 2W. IWAG at drillsites 1G and 1R was discontinued in April 2010 after the gas injection line was converted to water injection. [WAG was discontinued at drillsite 2X in January 2011 after the gas injection line was converted to water injection service. These drillsite will operate with water injection only for the foreseeable future. 2L, 2N (Tarn) 2P (MW) 2011 EOR Program Status ® SSEOR and SSEORX LSEOR and LSEORX EORX1 Expansion in 2001 - EORX1 Expansion in 2002 — 4 Wells ® GKA Satellites 1998-2002 EORX1 Expansion in 2003 1 C WSak EOR Pilot 2003 - 1 D EOR Expansion in 2008 GKA Active EOR Patterns • 257 KRU • 5 Tarn • 6 Meltwater • 4 West Sak 45000 40000 35000 30000 25000 0 (L O m 20000 15000 10000 5000 0 OA Q�b O O) O) O� (Z§b O� O� ,�O ,�O 0 0 ,N ,N ,�N ,^ Cp 2005-2011 Kuparuk EOR+NGL Sales Production ■ DS3S ■ DS3R ■ DS3Q ■ DS30 ■ DS3N ■ DS3K ■ DS3J ■ DS3H ■ DS3G IN DS3F ■ DS3C ■ DS3B ❑ DS3A ❑ DS2Z ■ DS2X ■ DS2W ■ DS2V ❑ DS2U ® DS2T © DS2M 13 DS2K ❑ DS2H ❑ DS2G ❑ DS2F ■ DS2D ■ DS2C ■ DS2B ■ DS2A ■ DS1Y ■DS1R ❑ DS1Q Attachment 2 Kuparuk River Oil Pool 2011 Annual Reservoir Surveillance Report Produced Fluid Volumes Cumulatives at Dec 31, 2010 2,222,682 2,935,245 Produced Fluid Volumes (Reservoir Units) CUM GAS OIL GAS WATER CUM OIL CUM GAS CUM WATER MO YR MSTB MMSCF MSTB MSTB MMSCF MSTB 1 2011 2,303 5,879 11,854 2,224,985 2,941,124 3,569,253 2 2011 2,495 6,280 12,845 2,227,480 2,947,404 3,582,097 3 2011 2,939 7,323 15,301 2,230,419 2,954,728 3,597,398 4 2011 2,739 6,743 14,362 2,233,158 2,961,470 3,611,760 5 2011 2,886 6,946 15,132 2,236,045 2,968,417 3,626,892 6 2011 2,656 5,866 13,560 2,238,700 2,974,282 3,640,452 7 2011 2,712 5,433 13,992 2,241,412 2,979,715 3,654,443 8 2011 2,826 6,093 15,051 2,244,238 2,985,808 3,669,494 9 2011 2,917 5,645 15,199 2,247,155 2,991,453 3,684,693 10 2011 3,013 5,853 16,020 2,250,168 2,997,306 3,700,713 11 2011 2,907 5,900 15,721 2,253,075 3,003,206 3,716,434 12 2011 2,965 6,344 16,394 2011 TOTAL 33,358 74,306 175,430 Cumulatives at Dec 31, 2010 2,222,682 2,935,245 Produced Fluid Volumes (Reservoir Units) 3,557,398 CUM OIL CUM GAS OIL GAS WATER MO YR MRVB MRVB MRVB 1 2011 2,842 4,244 12,079 2 2011 3,078 4,518 13,089 3 2011 3,627 5,256 15,592 4 2011 3,380 4,825 14,635 5 2011 3,562 4,943 15,420 6 2011 3,277 4,081 13,817 7 2011 3,346 3,673 14,257 8 2011 3,488 4,210 15,337 9 2011 3,599 3,774 15,488 10 2011 3,718 3,918 16,324 11 2011 3,587 4,005 16,020 12 2011 3,659 4,375 16,706 2011 TOTAL 41,164 51,823 178,763 3,557,398 CUM OIL CUM GAS CUM WATER MRVB MRVB MRVB 2,745,632 1,665,325 3,637,068 2,748,710 1,669,843 3,650,157 2,752,337 1,675,099 3,665,748 2,755,718 1,679,925 3,680,383 2,759,280 1,684,868 3,695,803 2,762,557 1,688,950 3,709,620 2,765,903 1,692,622 3,723,878 2,769,391 1,696,833 3,739,215 2,772,990 1,700,606 3,754,702 2,776,708 1,704,524 3,771,026 2,780,295 1,708,529 3,787,046 0°: t Cumulatives at Dec 31, 2010 2,742,790 1,661,081 3,624,989 MO 1 2 3 4 5 6 7 8 9 10 11 12 MO 1 2 3 4 5 6 7 8 9 10 11 12 Attachment 3 Kuparuk River Oil Pool 2011 Annual Reservoir Surveillance Report Injected Fluid Volumes Cumulatives at Dec 31, 2010 5,852,393 1,173,924 1,155,255 Injected Fluid Volumes (Reservoir Units) WATER GAS MI CUM WATER CUM GAS CUM MI YR MSTB MMSCF MMSCF MSTB MMSCF MMSCF 2011 16,814 428 4,292 5,869,207 1,174,352 1,159,548 2011 17,044 345 4,910 5,886,251 1,174,696 1,164,458 2011 19,806 902 4,485 5,906,056 1,175,598 1,168,943 2011 17,178 876 4,264 5,923,234 1,176,474 1,173,207 2011 18,122 714 5,005 5,941,356 1,177,188 1,178,212 2011 16,267 180 4,654 5,957,624 1,177,368 1,182,866 2011 16,818 833 3,433 5,974,442 1,178,201 1,186,299 2011 17,859 900 3,635 5,992,300 1,179,100 1,189,933 2011 16,126 519 3,720 6,008,427 1,179,619 1,193,654 2011 17,150 220 4,047 6,025,576 1,179,839 1,197,700 2011 17,022 326 3,675 6,042,598 1,180,165 1,201,375 2011 19,513 222 4,103 6 p; 2011 TOTAL 209,718 6,464 50,223 Cumulatives at Dec 31, 2010 5,852,393 1,173,924 1,155,255 Injected Fluid Volumes (Reservoir Units) Cumulatives at Dec 31, 2010 5,963,588 1,037,224 627,783 WATER GAS MI CUM WATER CUM GAS CUM MI YR MRVB MRVB MRVB MRVB MRVB MRVB 2011 17,133 381 3 5,980,721 1,037,605 627,787 2011 17,368 307 4 5,998,088 1,037,912 627,790 2011 20,182 801 3 6,018,270 1,038,713 627,794 2011 17,504 779 3 6,035,774 1,039,492 627,797 2011 18,466 635 4 6,054,241 1,040,127 627,801 2011 16,577 160 4 6,070,817 1,040,286 627,804 2011 17,138 741 3 6,087,955 1,041,027 627,807 2011 18,198 800 3 6,106,153 1,041,827 627,810 2011 16,433 461 3 6,122,586 1,042,288 627,813 2011 17,475 195 3 6,140,061 1,042,483 627,816 2011 17,345 290 3 6,157,406 1,042,773 627,818 2011 19,884 197 3 2011 TOTAL 213,702 5,746 38 Cumulatives at Dec 31, 2010 5,963,588 1,037,224 627,783 ATTACHMENT 4 Kuparuk River Oil Pool 2011 Annual Reservoir Surveillance Report Reservoir Pressure Surveys ConocoPhillips March 31, 2012 Mr. Dan Seamount, Commissioner Alaska Oil and Gas Conservation Commission 333 West 7th Ave. Suite 100 Anchorage, Alaska 99501-3539 Re: Kuparuk River Oil Pool — Proposed Pressure Survey Plan for 2012 James T. Rodgers Manager, GKA Development Greater Kuparuk Area ConocoPhillips Alaska, Inc. ATO -1326 PO Box 100360 Anchorage AK 99510-0360 Phone (907) 263-4027 Fax: (907) 265-6133 Dear Commissioner Seamount, In compliance with Rule 8, Conservation Order No. 432, ConocoPhillips Alaska, Inc., operator of the Kuparuk River Oil Pool, is hereby submitting the proposed pressure survey plan for 2012. There were 282 pressure surveys reported for the Kuparuk River Oil Pool to the AOGCC in 2011. In 2012, we expect to conduct approximately 150 pressure surveys, including initial surveys for new wells prior to initial sustained production. If you have any questions concerning this data, please contact Mark Kovar at 265-6097. Sincerely, 1 ---- James T. Rodgers Manager, GKA Development Greater Kuparuk Area Form STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION RESERVOIR PRESSURE REPORT 1. Operator. 2. Address: ConocoPhilli s Alaska Inc. P. O'Box 100360, Anchorage, AK 99510-0360 3. Unit or Lease Name: 4. Field and Pool: 5. Datum Reference: 6. Oil Gravity: 7. Gas Gravity. Kuparuk River Unit Kupruk River Oil Pool -62W SS 0.91 (water= 1.0 0.71 8. Well Name and 9. API Number 10. Type 11. AOGCC 12. Zone 13. Perforated 14. Final Test 15. Shut -In 16. Press. 17. B.H. 18. Depth Tool 19. Final 20. Datum 21. Pressure 22. Pressure at Number. 50=10 XXXXTxC See Pool Code Intervals Top Date Time, Hours Surv. Type Temp. TVDSS Observed TVDSS (input) Gradient, psi/ft. Datum (cal) NO DASHES Instructions - Bottom TVDSS (see Pressure at instructions for Tool Depth codes) 1A-01 50029229840000 OIL 490100 C -5951--5992, 01/29/11 503 SBHP 152 5994 2057 6,200 0.355 2130 -6003--6014, -6029--6037, -6169 - -6179, 6186--6208 1A-01 50029229840000 OIL 490100 A -5951 --5992, 01/30/11 503 SBHP 152 6144 2411 6,200 0.355 2431 -6003 - -6014, -6029 - -6037, -6169--6179, -6186--6208 1A-05 50029206030000 MWAG 490100 AC -5899--6006, 09/28/11 249 SBHP 120 6126 3989 6,200 0.475 4024 -6029--6033, -6039 - -6045, -6090 - -6092, -6129--6133, 6142--6169 1A-09 50029231730000 MWAG 490100 A -5999--6053, 09/20/11 120 SBHP 129 6105 3130 6,200 0.350 3163 -6169--6177, -6185--6214 1A-09 50029206030000 MWAG 490100 AC -5999--6053, 09/21/11 1560 SBHP 129 6113 2649 6,200 0.350 2679 -6169--6177, -6185 - -6214 1A-11 50029224650100 MWAG 490100 AC -6004--6031, 10/11/11 554 SBHP 123 6115 3361 6,200 0.454 3400 -6039 - -6154, 6164--6194 1A-12 50029224570000 MWAG 490100 AC -5837--5932, 10/10/11 538 SBHP 130 6066 3270 6,200 0.457 3331 -5936--5944, -5969 - -5972, -5986 - -5990, -6023 - -6025, -6073 - -6076, -6085--6111 1A-14 50029224750000 MWAG 490100 A -6037--6077, 02/01/11 9648 SBHP 139 5933 2805 6,200 0.090 2829 -6081 - -6087, -6091 - -6096, -6111 - -6128, -6258 - -6267, 6275--6300 1A-17 50029231640000 OIL 490100 AC -5900--5947, 04/17/11 99 SBHP 156 6053 2085 6,200 0.390 2143 -5979 - -5992, -6151 - -6172, -6192--6203 1A-18 50029230340000 OIL 490100 C -6058- -6102, 11/28/11 60 SBHP 154 6092 1540 6,200 0.363 1579 -6142 - -6158, -6289 - -6293, -6303--6327 1A-18 50029230150000 OIL 490100 A -6058--6102, 11/29/11 65 SBHP 158 6251 2104 6,200 0.350 2086 -6142--6158, -6289 - -6293, -6303--6327 1A-26 50029229340000 OIL 490100 A -5864--5883, 12/08/11 1037 SBHP 158 6095 2281 6,200 0.360 2319 -6075--6080, -6090--6116 [M�TPI lrTllbjq rw PF:N/r F?.qp:.qlr)p bmit in Duplicate Form STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION RESERVOIR PRESSURE REPORT 1. Operator: 2. Address: ConocoPhillips Alaska Inc. I P. O. Box 100360, Anchorage, AK 99510-0360 3. Unit or Lease Name: 4. Field and Pool: 5. Datum Reference: 6. Oil Gravity: 7. Gas Gravity. Ku aruk River Unit Kupruk River Oil Pool -6209 SS 0.91 (water= 1.0 0.71 8. Well Name and 9. API Number 10. Type 11. AOGCC 12. Zone 13. Perforated 14. Final Test 15. Shut -In 16. Press. 17. B.H. 18. Depth Tool 19. Final 20. Datum 21. Pressure 22. Pressure at Number: 50� See Pool Code Intervals Top Date Time, Hours Surv. Type Temp. TVDSS Observed TVDSS (input) Gradient, psi/ft. Datum (cal) NO DASHES Instructions - Bottom TVDSS (see Pressure at instructions for Tool Depth codes) 1B-02 50029231590100 MWAG 490100 AC -6167--6209, 03/22/11 14733 SBHP 143 6191 2588 6,200 0.344 2591 -6213--6220, -6225--6232, -6236 - -6242, -6246 - -6252, -6265--6303, -6308--6321, -6473 - -6502, 6475 - -6499 1B-06 50029203930000 OIL 490100 A -6269--6286, 03/03/11 230 SBHP 172 6407 2347 6,200 0.350 2275 -6290 - -6324, -6332 - -6337, -6344 - -6367, -6499 - -6508, -6513 - -6519, -6522--6537 1B-06 50029232700000 OIL 490100 C -6269--6286, 03/04/11 231 SBHP 157 6317 2189 6,200 0.304 2153 -6290--6324, -6332--6337, -6344--6367, -6499--6508, -6513--6519, -6522--6537 1B-09 50029204080000 MWAG 490100 A -6208--6268, 11/07/11 366 SBHP 145 6413 2718 6,200 0.450 2622 -6267--6271, -6319--6340, -6486 - -6499, -6603- -6537 1B-09 50029204290000 MWAG 490100 C -6208--6268, 11/08/11 360 SBHP 123 6274 2575 6,200 0.450 2542 -6267--6271, -6319 - -6340, -6486--6499, 6503--6537 1B-10 50029204300000 OIL 490100 AC -6253--6299, 02/27/11 1318 SBHP 155 6387 2637 6,200 0.418 2559 -6378--6396 1B-10 50029204180000 OIL 490100 AC -6253--6299, 05/19/11 6586 SBHP 154 6387 2642 6,200 0.432 2561 -6378--6396 1B-13 50029229200100 OIL 490100 AC -6181--6215, 02/24/11 174 SBHP 168 6247 1921 6,200 0.041 1919 -6218--6225, -6228--6229, -6258--6270, 6442--6473 1B-19 50029229190000 OIL 490100 C -6148--6182, 01/27/11 3062 SBHP 147 6019 2667 6,200 0.479 2754 -6323- -6354 1C-02 50029229150000 OIL 490100 C -6329- -6418, 07/06/11 2233 SBHP 153 6347 2754 6,200 0.425 2692 -6438 - -6457 1C -03A 50029229050000 OIL 490100 C -6375--6425 07/29/11 72 SBHP 157 6268 2710 6,200 0.430 2681 1C -07A 50029229140000 OIL 490100 C -6432--6375 02/12/11 395 SBHP 1581 6364 2849 6,200 0.4371 2777 1C-10 50029229040100 MWAG 490100 C -6376--6399, 08/13/11 4 SBHP 130 6405 4057 6,200 0.340 3987 -6403--6435 1C-13 50029228300000 OIL 490100 C -6347--6423, 06/21/11 147 SBHP 157 6385 2404 6,200 0.430 2325 -6505--6523 1 50029228910000 MWAG 490100 C -6475--6515 139 6244 3576 6,200 0.380 355 bmit in Duplicate STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION RESERVOIR PRESSURE REPORT 1. Operator: 2. Address: ConocoPhillips Alaska Inc. I P. O. Box 100360, Anchorage, AK 99510-0360 3. Unit or Lease Name: 4. Field and Pool: 5. Datum Reference: 6. Oil Gravity: 7. Gas Gravity. Kuparuk River Unit Kupruk River Oil Pool -6200' SS 0.91 (water= 1.0 0.71 8. Well Name and 9. API Number 10. Type 11. AOGCC 12. Zone 13. Perforated 14. Final Test 15, Shut -In 16. Press. 17, B.H. 18. Depth Tool 19. Final 20. Datum 21. Pressure 22. Pressure at Number: 50X)XXXX>00(XXX See Pool Code Intervals Top Date Time, Hours Surv. Type Temp. TVDSS Observed TVDSS (input) Gradient, psi/ft. Datum (cal) NO DASHES Instructions - Bottom TVDSS (see Pressure at instructions for Tool Depth codes) 1C-19 50029229610000 OIL 490100 C -6464--6489 05/08/11 2872 SBHP 160 6447 3546 6,200 0.435 3439 1C-20 50029229690100 MWAG 490100 C -6487--6497, 09/19/11 116 SBHP 135 6384 3358 6,200 0.443 3276 -6501 - -6482, -6488--6484, -6495 - -6508, -6513--6521, 6532--6541 1C-22 50029204790000 MWAG 490100 C -6541 --6558 07/26/11 936 SBHP 137 6561 3481 6,200 0.437 3323 1C-25 50029204960000 MWAG 490100 C -6343--6364, 09/26/11 65 SBHP 130 6313 4494 6,200 0.440 4444 -6370 - -6376, -6450 - -6462 113-27 50029204960000 MWAG 490100 C -6287--6350, 09/30/11 235 SBHP 136 6275 4333 6,200 0.460 4299 -6338 - -6317 1C-28 50029207360000 OIL 490100 C -6409--6426, 01/19/11 263 SBHP 150 6283 2974 6,200 0.410 2940 -6441 - -6476, -6475--6464 1D-03 50029207360000 PW 490100 C -6200--6279, 08/02/11 122 SBHP 142 6228 3012 6,200 0.440 3000 -6219--6231, -6284--6289, -6295--6300, -6309--6318, -6489 - -6506, 6514--6534 1D -04A 50029232080000 OIL 490100 C -6419 - -6357 04/20/11 166 SBHP 146 5915 26961 6,200 0.469 2830 1D-08 50029207690000 OIL 490100 C -6275--6363, 01/15/11 162 SBHP 158 6291 2674 6,200 0.430 2635 -6370--6375, -6527 - -6532, -6535 - -6543 1D-30 50029208370000 OIL 490100 C -6428--6446, 01/12/11 87 SBHP 154 6265 2163 6,200 0.350 2140 -6444--6453, 6446--6448 1D-34 50029208320000 OIL 490100 C -6418--6430, 07/16/11 9926 SBHP 157 6424 3005 6,200 0.367 2923 -6446--6466 1 E-01 50029208280000 MWAG 490100 A -5967 - -6037, 04/24/11 100 PBU 144 6103 3485 6,200 0.450 3529 -6172 - -6188, -6206--6222 1 E-01 50029208280000 MWAG 490100 C -5967 - -6037, 04/24/11 114 SBHP 128 6002 2699 6,200 0.450 2788 -6172--6188, 6206--6222 1E-06 50029210080000 OIL 490100 AC -6067--6129, 04/21/11 193 SBHP 158 6098 2766 6,200 0.430 2810 -6257--6273, -6281 - -6319 1E-06 50029226610000 OIL 490100 C -6067--6129, 07/22/11 332 SBHP 156 6098 2867 6,200 0.444 2912 -6257--6273, -6281 - -6319 1E-07 50029223280000 OIL 490100 A -6145--6260, 01/05/11 352 PBU 159 6311 2505 6,200 0.350 2466 -6278--6282, -6295 - -6299, -6306 - -6310, -6462--6478, 6485--6511 Form 10-412 Rev. 1212008 INSTRUCTIONS ON REVERSE SIDE Submit in Duplicate STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION RESERVOIR PRESSURE REPORT 1. Operator. 2, Address: ConocoPhillips Alaska Inc. P. 0. Box 100360, Anchorage, AK 99510-0360 3. Unit or Lease Name: 4. Field and Pool: 5. Datum Reference: 6. Oil Gravity: 7, Gas Gravity. Ku aruk River Unit Ku ruk River Oil Pool -62M SS 0.91 (water= l.0 0.71 8. Well Name and 9. API Number 10. Type 11. AOGCC 12. Zone 13. Perforated 14. Final Test 15, Shut -In 16. Press. 17. B.H. 18. Depth Tool 19. Final 20. Datum 21. Pressure 22. Pressure at Number. 50XXXXXXXXXXXX See Pool Code Intervals Top Date Time, Hours Surv. Type Temp. TVDSS Observed TVDSS (input) Gradient, psi/ft. Datum (cal) NO DASHES Instructions - Bottom TVDSS (see Pressure at instructions for Tool Depth codes) 1E-07 50029229450000 OIL 490100 C -6145--6260, 01/05/11 352 SBHP 168 6203 2633 6,200 0.280 2632 -6278--6282, -6295--6299, -6306 --6310, -6462--6478, 6485--6511 1E-07 50029232860000 OIL 490100 C -6145--6260, 05/17/11 1849 SBHP 154 6203 2709 6,200 0.344 2708 -6278--6282, -6295 - -6299, -6306 - -6310, -6462 - -6478, -6485 - -6511 1E-07 50029233490000 OIL 490100 C -6145--6260, 07/08/11 3092 SBHP 153 6274 2957 6,200 0.450 2924 -6278 - -6282, -6295 - -6299, -6306 - -6310, -6462 - -6478, 6485--6511 1E -07A 50029233560000 OIL 490100 C -6145--6260, 07/08/11 1000 SBHP 0 6274 2957 6,200 0.350 2931 -6234 - -6136, -6263--6234, -6278 - -6282, -6294 - -6298, -6306--6310 2E-08 50103205970000 OIL 490100 AC -5867--5883, 04/26/11 4170 SBHP 155 5953 1754 6,200 0.350 1840 5940--5961 1E -08A 50029233600000 SW 490100 A -6266--6278, 04/23/11 9000 SBHP 145 6020 2963 6,200 0.680 3085 -6294 - -6300, -6343 - -6349 1E -08A 50029211960000 SW 490100 A -6266--6278, 07/13/11 430 SBHP 152 6020 2385 6,200 0.350 2448 -6294--6300, -6343--6349 1E -08A 50029211960000 SW 490100 A -6266--6278, 09/16/11 77 SBHP 132 6020 3646 6,200 0.330 3705 -6294--6300, -6343--6349 1E-23 50029211710000 MWAG 490100 C -5950--6025, 11108/11 96 SBHP 124 6003 2844 6,200 0.450 2933 -6144 - -6157, -6175 - -6184 1E-23 50029211550000 MWAG 490100 A -5950--6025, 11/09/11 100 PBU 128 6073 4060 6,200 0.450 4117 -6144--6157, -6175--6184 1E -24A 50029211710000 OIL 490100 AC -4586--4594, 10/23/11 178 SBHP 150 6008 2314 6,200 0.360 2383 4881 - -4885, -5973--5994, -5999--6008, -6013--6018, -6019--6023, -6027--6032, -6055--6069, -6187 - -6196, 6214--6223 Form 10.412 Rev. 12/2008 INSTRUCTIONS ON REVERSE SIDE Submit in Duplicate STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION RESERVOIR PRESSURE REPORT 1. Operator. 2. Address: ConocoPhillips Alaska Inc. I P. O. Box 100360, Anchorage, AK 99510-0360 3. Unit or Lease Name: 4. Feld and Pool: 5. Datum Reference: 6. Oil Gravity: 7. Gas Gravity Kuparuk River Unit Kupruk River Oil Pool -6200' SS 0.91 (water= 1.0 0.71 8. Well Name and 9. API Number 10. Type 11. AOGCC 12. Zone 13. Perforated 14. Final Test 15. Shut -In 16. Press. 17. B.H. 18, Depth Tool 19. Final 20. Datum 21. Pressure 22. Pressure at Number. 50X)0Vxx)C00(XX See Pool Code Intervals Top Date Time, Hours Surv. Type Temp. TVDSS Observed TVDSS (input) Gradient, psi/ft. Datum (cal) NO DASHES Instructions - Bottom TVDSS (see Pressure at instructions for Tool Depth codes) 1E-27 50029220260000 OIL 490100 A -5926--5967, 04/19/11 120 SBHP 121 6032 3724 6,200 0.450 3800 -5976--5983, -6028--6030, -6114--6123, -6139--6161, 6169--6172 1E-27 50029220260000 OIL 490100 A -5926--5967, 08/01/11 3048 SBHP 113 6136 3281 6,200 0.440 3309 -5976--5983, -6028 - -6030, -6114--6123, -6139 --6161, -6169--6172 1E-27 50029221320000 OIL 490100 A -5926--5967, 09/24/11 4620 SBHP 127 6005 3415 6,200 0.490 3510 -5976--5983, -6028--6030, -6114--6123, -6139 - -6161, 6169--6172 1E-32 50029212020000 MWAG 490100 C -5981 --5992, 06/30/11 738 SBHP 90 6050 2465 6,200 0.430 2530 -6000--6015, -6044--6057, -6056--6068 1E-34 50029212020000 OIL 490100 C -5930--5946, 01/14/11 141 SBHP 152 5944 2244 6,200 0.310 2323 -5952--5956, -5970--5970, -5964--5960, 5959--5972 1E-35 50029220439000 MWAG 490100 C -6027--6042 07/28/11 37410 SBHP 135 6016 2318 6,200 0.440 2399 2E-11 50103205970000 OIL 490100 AC -5856--5868, 10/13/11 624 SBHP 160 5924 2957 6,200 0.440 3078 -5912--5925, -5941 --5961, -5975--5980 1E-12 50029211820100 OIL 490100 A -6054--6120, 07/06/11 625 SBHP 158 6136 2193 6,200 0.317 2213 -6167--6169, -6211 --6217, -6211--6218, -6229 - -6245, -6231 - -6248, -6231 --6240, 6254 - -6259 2E-15 50103202720100 OIL 490100 A -5982--5998, 04/27/11 4215 SBHP 158 6030 1811 6,200 0.380 1876 -6017 - -6040 1F -01A 50029221740100 OIL 490100 AC -5983 - -6052 10/17/11 22968 SBHP 154 5800 2585 6,200 0.500 2785 1F-05 50029212490000 MWAG 490100 AC -5928--5965, 12/07/11 124 SBHP 118 5946 3792 6,200 0.460 3909 -5986 - -5999, -6064 - -6074, -6083--6116 1F-06 50029212490100 OIL 490100 AC -6019--6064, 12/09/11 191 SBHP 157 6039 2124 6,200 0.350 2180 -6193 - -6237, -6193--6232 Form 10412 Rev. 12/2008 INSTRUCTIONS ON REVERSE SIDE Submit in Duplicate STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION RESERVOIR PRESSURE REPORT 1. Operator: 2. Address: ConocoPhillips Alaska Inc. P. O. Box 100360, Anchorage, AK 99510-0360 3. Unit or Lease Name: 4. Field and Pool: 5. Datum Reference: 6. Oil Gravity: 7. Gas Gravity: Kuparuk River Unit Kupruk River Oil Pool -620Y SS 0.91 (water= 1.0 0.71 8. Well Name and 9. API Number 10. Type 11. AOGCC 12. Zone 13. Perforated 14. Final Test 15. Shut -In 16. Press. 17. B.H. 18. Depth Tool 19. Final 20. Datum 21. Pressure 22. Pressure at Number: 50xxxxxx>000(xx See Pool Code Intervals Top Date Time, Hours Surv. Type Temp. TVDSS Observed TVDSS (input) Gradient, psi/ft. Datum (cal) NO DASHES Instructions - Bottom TVDSS (see Pressure at instructions for Tool Depth codes) 1F-07 50029212100000 OIL 490100 AC -5870--5919, 12/08/11 171 SBHP 153 5825 2401 6,200 0.390 2547 -5929--5933, -5939--5951, -6043 - -6053, -6065 - -6087, 6093 - -6097 1F-11 50029213090000 MWAG 490100 C -5819--5886, 12/23/11 9999 SBHP 138 5851 2655 6,200 0.280 2753 -5973 - -5979, -5991--6019 1F-11 50029213090000 MWAG 490100 A -5819--5886, 12124/11 9999 SBHP 139 5933 2671 6,200 0.280 2746 -5973 - -5979, -5991--6019 1F -16A 50029225910000 MWAG 490100 A -5802--5818, 11/26/11 40512 SBHP 123 5114 2674 6,200 0.440 3152 -5821 - -5837, -5939 - -5950, -5940 - -5948, -5967 - -5988, -5969--5977 1G-01 50029225960000 MWAG 490100 C -6119--6158, 10/21/11 267 SBHP 148 6305 2386 6,200 0.409 2343 -6193 - -6226, -6380 - -6383, -6391 - -6405, -6419--6432 1G-04 50029214040200 MWAG 490100 AC -6291 --6295, 10/22/11 3778 SBHP 139 6596 2685 6,200 0.456 2505 -6299 - -6326, -6334 - -6340, -6388 - -6425, -6611--6624, -6638 - -6652 1G-05 50029214040200 MWAG 490100 AC -6144--6199, 12/08/11 2582 SBHP 134 6293 2445 6,200 0.030 2442 -6232--6259, -6408--6411, -6420--6442 1G -08A 50029214050000 OIL 490100 AC -6299--6300, 07/03/11 1577 SBHP 161 6009 1980 6,200 0.278 2033 -6311--6314, -6327--6329, -6656--6663 1G -10A 50029213300000 OIL 490100 AC -6255--6266, 08/02/11 195 SBHP 154 6239 2453 6,200 0.370 2439 -6266--6275, -6285--6290, -6297--6304, -6514 - -6541 113-17 50029213300000 OIL 490100 AC -6071 --6080, 07/17/11 1577 SBHP 154 6232 2217 6,200 0.304 2207 -6088--6096, -6139--6148, 6323--6354 1H-02 50029213310000 OIL 490100 A -6248--6313, 02/05/11 691 SBHP 162 6469 2497 6,200 0.350 2403 -6356--6378, -6522 - -6550 1H-02 10029213310000101L 490100 C -6248--6313, 02/06/11 480 SBHP 156 6312 2460 6,200 0.305 2426 -6356--6378, -6522 - -6550 Form 10-412 Rev. 1212008 INSTRUCTIONS ON REVERSE SIDE Submit in Duplicate STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION RESERVOIR PRESSURE REPORT 1. Operator: 2. Address: I ConocoPhillips Alaska Inc. P. O. Box 100360, Anchorage, AK 99510-0360 3. Unit or Lease Name: 4. Field and Pool: 5. Datum Reference: 6. Oil Gravity-, 7. Gas Gravity: Ku aruk River Unit Kupruk River Oil Pool -6200' SS 0.91 (water= 1.D 0.71 8. Well Name and 9. API Number 10. Type 11. AOGCC 12. Zane 13. Perforated 14. Final Test 15. Shut -In 16. Press. 17. B.H. 18. Depth Tool 19. Final 20. Datum 21. Pressure 22. Pressure at Number: 50XXX)0000(XXXX See Pool Code Intervals Top Date Time, Hours Surv. Type Temp. TVDSS Observed TVDSS (input) Gradient, psi/ft. Datum (cal) NO DASHES Instructions - Bottom TVDSS (see Pressure at instructions for Tool Depth codes) 1H-06 50029213310100 OIL 490100 AC -6267--6295, 04/01/11 1001 SBHP 160 6539 2999 6,200 0.354 2879 -5299 - -6305, -6312 - -6323, -6367 - -6391, -6529 - -6536, -6542 - -6551 1 H-06 50029213310000 OIL 490100 A -6267 - -6295, 05/19/11 757 SBHP 159 6539 2999 6,200 0.354 2879 -6299--6305, -6312--6323, -6367--6391, -6529--6536, -6542--6551 1H-19 50029213320000 PW 490100 C -6345--6392, 01/30/11 263 SBHP 135 6393 2866 6,200 0.423 2781 -6411--6441, -6591--6606, 6616--6631 1H-19 50029213310100 PW 490100 A -6345--6392, 02/01/11 312 SBHP 147 6527 4442 6,200 0.450 4295 -6411--6441, -6591--6606, -6616--6631 1H-22 50029213520000 PW 490100 C -6265--6325, 01/20/11 70 SBHP 136 6294 2977 6,200 0.433 2936 -6374--6397, -6535 - -6573 1H-22 50029213520000 PW 490100 A -6265--6325, 01/26/11 205 SBHP 139 6461 2994 6,200 0.450 2748 -6374--6397, 6535--6573 1J-03 50029213530000 OIL 490100 C -6363--6369, 07/25/11 5268 SBHP 154 6305 2812 6,200 0.340 2776 -6491 - -6496 11-09 50029213530000 OIL 490100 C -6109--6122, 04/19/11 144 SBHP 152 6102 2129 6,200 0.426 2171 -6118 - -6133, -6133 - -6146 11-10 50029213860000 OIL 490100 C -5959--5971, 04/19/11 150 SBHP 150 5880 2351 6,200 0.382 2473 6091--6104 1L-09 50029213880000 OIL 490100 AC -5802--5862, 01/12/11 93 SBHP 148 5832 2059 6,200 0.073 2086 -5868--5873, -5982--6001, -6021--6025, -6051 - -6059 1L-15 50029221880000 OIL 490100 AC -5806--5816, 09/12/11 243 SBHP 156 5932 3208 6,200 0.155 3250 -5816--5832, 5927--5944 1L-23 50029222110000 OIL 490100 AC -5862--5906, 01/01/11 24820 SBHP 168 5987 3410 6,200 0.449 3506 -5980--6001, -6058--6063 1Q-09 50029222000000 MWAG 490100 A -5912--5954, 06/12/11 1568 SBHP 62 6845 2384 6,200 0.350 2158 -5990 - -6002, -6135 - -6189, -6227--6242 1Q-09 50029222060100 MWAG 490100 A -5912--5954, 07/26/11 1577 SBHP 96 6188 3837 6,200 0.350 3841 -5990 - -6002, -6135--6189, 6227--6242 Form 10-412 Rev. 12/2008 INSTRUCTIONS ON REVERSE SIDE Submit in Duplicate STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION RESERVOIR PRESSURE REPORT 1. Operator: 2. Address: ConocoPhilli s Alaska Inc. R 0. Box 100360, Anchorage, AK 99510-0360 3. Unit or Lease Name: 4. Field and Pool: 5, Datum Reference: 6. Oil Gravity: 7. Gas Gravity Kuparuk River Unit Kupruk River Oil Pool -6200' SS 0.91 (water= 10, 0.71 8. Well Name and 9. API Number 10. Type 11. AOGCC 12. Zone 13. Perforated 14. Final Test 15. Shut -In 16. Press. 17. B.H. 18, Depth Tool 19. Final 20. Datum 21. Pressure 22. Pressure at Number. 50X)OOVIX)COGIM See Pool Code Intervals Top Date Time, Hours Surv. Type Temp. TVDSS Observed TVDSS (input) Gradient, psi/ft. Datum (cal) NO DASHES Instructions - Bottom TVDSS (see Pressure at instructions for Tool Depth codes) 1R-02 50029222010000 OIL 490100 C -6318--6319, 09/16/11 122 SBHP 154 6335 2485 6,200 0.350 2438 -6356 - -6377, -6448 - -6450, -6528--6541, -6550--6571 1R-02 50029221530000 OIL 490100 A -6318--6319, 09/19/11 201 SBHP 158 6498 2261 6,200 0.350 2157 -6356 - -6377, -6448--6450, -6528--6541, -6550--6571 1R-09 50029221950000 IWAG 490100 A -6306--6335, 06/16/11 7414 SBHP 111 6457 4152 6,200 0.470 4031 -6428 - -6434, -6440--6463, 6486--6489 1R-10 50029225380000 MWAG 490100 AC -6298--6328, 06/16/11 672 SBHP 116 6458 4089 6,200 0.434 3977 -6416 - -6431, -6436 - -6454, -6471--6476, -6507 - -6513 1R-17 50029225340000 MWAG 490100 AC -6429--6439, 07/28/11 11500 SBHP 137 6399 2509 6,200 0.076 2494 -6535--6571, 6587 - -6589 1R-20 50029230500000 OIL 490100 AC -6517--6541, 06/30/11 38000 SBHP 157 6472 2961 6,200 0.368 2861 -6672--6708 1R-21 50029230500000 OIL 490100 AC -6450--6463, 01113/11 113 SBHP 167 6401 1842 6,200 0.058 1830 -6583 - -6593, -6594 - -6583, -6604--6625 1R-25 50029223820000 OIL 490100 AC -6614--6642, 01/05/11 19540 SBHP 165 6793 2704 6,200 0.352 2495 -6792--6799 1R-26 50029207410000 MWAG 490100 AC -6495--6517, 08/29/11 2478 SBHP 141 6441 4200 6,200 458.000 4089 -6662 - -6672, -6682--6699 1R-33 50103200230100 MWAG 490100 A -6588--6610, 08/11/11 11638 SBHP 109 4985 3525 6,200 0.231 3806 -6625--6642 1R-36 50103200420000 MWAG 490100 AC -6536--6548, 08/02/11 1836 SBHP 126 6686 3964 6,200 0.075 3928 -6670 - -6685, -6685 - -6702, 6722--6727 1Y-03 50029211520000 MWAG 490100 A -5913--5955, 01/09/11 1577 SBHP 147 6016 2209 6,200 0.300 2264 -5993 - -6006, -6136 - -6149, -6159--6185 1Y-19 50029210800000 OIL 490100 A -5881--5942, 03/30/11 1577 SBHP 158 6085 2186 6,200 0.430 2236 -6057 - -6060, -6066--6074, -6086--6111 1Y-21 50029211380000 OIL 490100 C -5959--6017, 12/29/11 5563 SBHP 154 6017 2279 6,200 0.359 2345 -6176 - -6179, -6188 - -6200, -6211--6229 1Y -24A 50029210700000 OIL 490100 C -6021--6011 03/30/11 123 SBHP 148 5613 2378 6,200 0.365 2592 Form 10.412 Rev, 1212008 INSTRUCTIONS ON REVERSE SIDE Submit in Duplicate STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION RESERVOIR PRESSURE REPORT 1. Operator: 2. Address: I ConocoPhillips Alaska Inc. P. O. Box 100360, Anchorage, AK 99510-0360 3. Unit or Lease Name: 4. Field and Pool: 5. Datum Reference: 6. Oil Gravity: 7. Gas Gravity: Kuparuk River Unit Kupruk River Oil Pool -6200' SS 0.91 (water= 1.0 0.71 6. Well Name and 9. API Number 10. Type 11. AOGCC 12. Zone 13. Perforated 14. Final Test 15. Shut -In 16. Press. 17. B.H. 16. Depth Tool 19. Final 20. Datum 21. Pressure 22. Pressure at Number: 50xxx)000(xx)= See Pool Code Intervals Top Date Time, Hours Surv. Type Temp. TVDSS Observed TVDSS (input) Gradient, psi/ft. Datum (cal) NO DASHES Instructions - Bottom TVDSS (see Pressure at instructions for Tool Depth codes) 1Y-27 50029210580000 OIL 490100 C -5975--6021, 12/21/11 4805 SBHP 151 6058 2181 6,200 0.350 2231 -6052--6065, -6182--6196, -6207--6224 1Y-27 50029210620000 OIL 490100 A -5975--6021, 12/23/11 4846 SBHP 154 6131 2268 6,200 0.350 2292 -6052 - -6065, -6182 - -6196, -6207--6224 2A-08 50029210650000 MWAG 490100 AC -5722--5770, 08/28/11 2724 SBHP 129 5817 2872 6,200 0.460 3048 -5806--5828 2A-11 50029210320000 OIL 490100 AC -5769--5794, 10/04/11 120 SBHP 147 5355 2225 6,200 0.430 2588 -5844--5852, -5863--5884 2A-14 50029210350000 OIL 490100 AC -5747--5800, 01/14/11 142 SBHP 160 5773 2540 6,200 0.380 2702 -5872--5903 2A-15 50029210520000 OIL 490100 AC -5779--5820, 06/26/11 6840 SBHP 137 5356 2494 6,200 0.350 2789 -5906--5944 2A-17 50029227310000 OIL 490100 AC -5715--5744, 01/13/11 116 SBHP 155 5759 2783 6,200 0.430 2972 -5777 - -5805 2A-18 50029227200000 OIL 490100 A -5823--5861, 08/30/11 72 SBHP 155 5688 2295 6,200 0.430 2515 -5945--5964 2A-23 50029211210000 MWAG 490100 AC -5735--5743, 07/30/11 454 SBHP 120 5604 3200 6,200 0.350 3409 -5768- -5793 2A-23 50103200530000 MWAG 490100 AC -5735--5743, 08/29/11 1185 SBHP 119 5771 3159 6,200 0.350 3309 -5768--5793 2A-24 50103200370000 OIL 490100 AC -5707--5740, 01/14/11 137 SBHP 155 5758 2742 6,200 0.420 2928 -5782--5810 2A-26 50103201110000 OIL 490100 A -5912--5918, 01/16/11 185 SBHP 159 5948 2966 6,200 0.430 3075 -5924--5939, 5956--5984 28-06 50103201160000 MWAG 490100 AC -5778 - -5797, 10/12/11 960 SBHP 133 5776 2744 6,200 0.350 2892 -5854--5860, -5871 - -5896 2B-14 50103201150000 OIL 490100 AC -5699--5725, 10/06/11 600 SBHP 153 5606 2429 6,200 0.350 2637 -5792--5797, -5806--5828, -5843--5864 2C-01 50103201210000 MWAG 490100 AC -5802--5809, 08/28/11 1730 SBHP 114 5832 4306 6,200 0.350 4435 5820--5845 2C-02 50103201170000 MWAG 490100 A -5711 --5729, 09/28/11 625 SBHP 112 5787 4131 6,200 0.450 4317 -5815--5819, -5830--5850, -5874 - -5881 Form 10-412 Rev. 12/2008 INSTRUCTIONS ON REVERSE SIDE Submit in Duplicate Form STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION RESERVOIR PRESSURE REPORT 1. Operator: 2. Address: ConocoPhillips Alaska Inc. P. O. Box 100360, Anchorage, AK 99510-0360 3. Unit or Lease Name: 4. Field and Pool: S. Datum Reference: 6. Oil Gravity: 7. Gas Gravity: Ku aruk River Unit Kupruk River Oil Pool -6200' SS 0.91 water= 1.0 0.71 8. Well Name and 9. API Number 10, Type 11. AOGCC 12. Zone 13. Perforated 14. Final as 15. Shut -In 16. Press.Depth Tool 19. Final 20. Datum 21. Pressure 22. Pressure at Number: 50� See Pool Code Intervals Top Date Time, Hours Surv. Type Temp. TVDSS Observed TVDSS (input) Gradient, psi/ft. Datum (cal) NO DASHES Instructions - Bottom TVDSS (see Pressure at instructions for Tool Depth codes) 210-04 50103201180000 MWAG 490100 AC -5575--5577, 09/07/11 120 SBHP 127 5724 2780 6,200 0.440 2989 -5633 - -5675, -5648 - -5648, -5649 - -5649, -5653 - -5653, -5659 - -5662, -5664 - -5666, -5670 - -5673, -5696--5701, -5697 - -5700, -5706 - -5712, -5708 - -5708, -5709 - -5709, -5710 - -5710, 5756 - -5757, 2C-05 50103201200000 MWAG 490100 AC -5656--5684, 09/28/11 625 SBHP 125 5821 3062 6,200 0.440 3229 -5684 - -5692, -5697 - -5702, -5706--5711, -5793 - -5796, -5807 - -5821, -5840 - -5855 2C-07 50103201190000 IWAG 490100 AC -5728--5743, 09/29/11 226 SBHP 112 5832 4409 6,200 0.450 4575 -5812 - -5819, 5829--5857 2D-02 50103205880000 MWAG 490100 A -5845--5846, 10/12/11 275 SBHP 119 5878 4484 6,200 0.450 4629 -5864 - -5865, -5867 - -5869, -5876 - -5877, -5880 - -5882, -5884 - -5888, -5891--5893 2D-04 50103206130000 MWAG 490100 A -5848--5849, 10/12/11 275 SBHP 124 5906 4898 6,200 0.460 5033 -5873 - -5875, -5893 - -5896, -5907 - -5912, -5907 - -5912, -5917--5919 2D-05 50103205210000 MWAG 490100 A -5824--5863, 12/28/11 10204 SBHP 134 5980 3116 6,200 0.440 3213 -5952--5961, 5972--6010 2D-07 50103204690000 MWAG 490100 C -5775--5804, 12/16/11 596 SBHP 130 5794 4234 6,200 0.450 4417 -5863 - -5872, -5883--5919 2D-07 50103206160000 MWAG 490100 A -5775--5804, 12/17/11 192 SBHP 110 5841 4410 6,200 0.350 4536 -5863--5872, -5883 - -5919 2D-16 50103202750000 IWAG 490100 AC -5758--5758, 05/06/11 6000 SBHP 121 5812 3206 6,200 0.360 3346 -5759 - -5759, -5761--5761, -5762 - -5762, -5763--5763, -5810--5819, -5830--5866 ibmit in Duplicate STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION RESERVOIR PRESSURE REPORT 1. Operator. 2. Address: ConocoPhillips Alaska Inc. P. O. Box 100360, Anchorage, AK 99510-0360 3. Unit or Lease Name: 4. Field and Pool: 5. Datum Reference: 6. Oil Gravity: 7, Gas Gravity. Kuparuk River Unit Kupruk River Oil Pool -6200' SS 0.91 (water=l.0 0.71 8. Well Name and 9. API Number 10. Type 11. AOGCC 12. Zone 13. Perforated 14. Final Test 15. Shut -In 16, Press. 17. B.H. 18. Depth Tool 19. Final 20. Datum 21. Pressure 22. Pressure at Number. 50xxxxX See Pool Code Intervals Top Date Time, Hours Surv. Type Temp. TVDSS Observed TVDSS (input) Gradient, psi/ft. Datum (cal) NO DASHES Instructions - Bottom TVDSS (see Pressure at instructions for Tool Depth codes) 2F -05X 50103205540000 OIL 490100 A -5831 --5840, 01/12/11 96 SBHP 163 5851 3094 6,200 0.350 3216 -5849--5873 2F-07 50103201510000 OIL 490100 AC -5785--5792, 01/12/11 96 SBHP 126 5883 2800 6,200 0.350 2911 -5842--5854, -5866 - -5902, 5937--5941 2G-03 50103201860000 MWAG 490100 AC -5877--5890, 10/20/11 526 SBHP 110 5960 4462 6,200 0.460 4572 -5956--5965, -5977--6003 2G-10 50103203820000 MWAG 490100 A -5975--5987, 10/20/11 530 SBHP 114 6015 4929 6,200 0.450 5012 -6000 - -6029 2G-11 50103205470000 OIL 490100 AC -5916--5923, 02/17/11 730 SBHP 157 5984 2936 6,200 0.350 3012 -5926 - -5928, -6002 - -6016, 6030 - -6051 2G-17 50103204840000 OIL 490100 C -5985--5992 01/29/11 68000 SBHP 154 5988 3257 6,200 0.3501 3331 21H-02 50103203830000 MWAG 490100 AC -5857--5858, 12/21/11 2610 SBHP 116 5886 2960 6,200 0.350 3070 -5859 - -5859, -5860 - -5861, -5862 - -5863, -5931 - -5936, -5944 - -5962, 5975 - -6003 2H-04 50103204200000 MWAG 490100 A -5880--5890, 04/27/11 120 SBHP 118 5960 4683 6,200 0.350 4767 -5918 - -5920, -5932 - -5938, -5947--5974, -5994 - -6000, -6004--6012 2H-07 50103204670000 OIL 490100 AC -5882--5906, 06/19/11 45 SBHP 157 5970 2874 6,200 0.350 2954 -5946 - -5953, 5964--5985 2H-09 50103204070000 OIL 490100 AC -5855--5881, 06/19/11 47 SBHP 159 5953 2917 6,200 0.350 3004 -5928 - -5938, -5954 - -5979 2K-03 50103204870000 MWAG 490100 A -5995--6020 04/03/11 2130 SBHP 136 5991 3870 6,200 0.350 3943 2K-06 50103204870000 MWAG 490100 AC -5978--5993, 01/09/11 845 SBHP 134 6003 4336 6,200 0.350 4405 -6028--6044, -6028--6066 2K-08 50103204020000 OIL 490100 AC -5141 --5147, 01/27/11 1800 SBHP 157 5958 4008 6,200 0.350 4093 -6019--6037, -6025--6030, -6066--6087 2K-10 50103200600000 MWAG 490100 A -5997--6007, 04/03/11 2130 SBHP 129 6037 4299 6,200 0.350 4356 -6019--6054 2K-11 50103203340100 OIL 490100 A -6094 - -6119 09/13/11 160 SBHP 134 5928 2305 6,200 0.350 2400 2K-12 50103202220100 MWAG 490100 A -5984--5989, 02/08/11 1550 SBHP 111 6066 4535 6,200 0.350 4582 -6028--6038, -6052--6081 2K-13 50103205280000 OIL 490100 AC -6047--6057, 01/14/11 1706 SBHP 138 5968 4079 6,200 0.430 4179 -6087 - -6109, 6087--6104 Form 10-412 Rev. 1212008 INSTRUCTIONS ON REVERSE SIDE Submit in Duplicate STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION RESERVOIR PRESSURE REPORT 1. Operator: 2. Address: I ConocoPhillips Alaska Inc. P. O. Box 10036% Anchorage, AK 99510.0360 3. Unit or Lease Name: 4. Field and Pool: 5. Datum Reference: 6. Oil Gravity: 7. Gas Gravity: Kuparuk River Unit Kupruk River Oil Pool -6200' SS 0.91 (water =1.0 0.71 B. Well Name and 9. API Number 10. Type 11. AOGCC 12. Zone 13. Perforated 14. Final Test 15. Shut -In 16. Press. 17. B.H. 18. Depth Tool 19. Final 20. Datum 21. Pressure 22. Pressure at Number: 50XY)V1XXX>00= See Pool Code Intervals Top Date Time, Hours Surv. Type Temp. TVDSS Observed TVDSS (input) Gradient, psi/ft. Datum (cal) NO DASHES Instructions - Bottom TVDSS (see Pressure at instructions for Tool Depth codes) 2K-13 50103202190000 OIL 490100 AC -6047--6057, 03/28/11 3600 RFT 118 6077 4005 6,200 0.350 4048 -6087--6104, 6087--6109 2K -13A 50029212810000 SW 490100 A -6047--6057, 06/12/11 9999 SBHP 136 5936 3799 6,200 0.600 3958 -6096--6081 2K -13A 50103205280000 SW 490100 A -6047--6057, 09/08/11 170 SBHP 144 5921 2675 6,200 0.350 2773 -6096 - -6081 2K -13A 50029212690000 SW 490100 A -6047--6057, 11/07/11 430 SBHP 144 5936 2875 6,200 0.350 2967 -6096 - -6081 2K-14 50029213030000 OIL 490100 AC -6020--6031, 01/13/11 117 SBHP 164 6093 2478 6,200 0.380 2519 6083 - -6115 2K-19 50029210550000 OIL 490100 A -6114--6115, 03/29/11 672 SBHP 165 6200 2976 6,200 0.350 2976 -6121 - -6133, -6123 - -6129, -6146--6170 2K -19A 50029213000000 OIL 490100 A -6114--6115, 05/19/11 9999 SBHP 155 6022 3508 6,200 0.460 3590 -6121 - -6123 2K-20 50029212750000 IWAG 490100 A -6119--6125, 04/01/11 2470 SBHP 137 6125 3650 6,200 0.350 3676 6146--6168 2K -21A 50029212350000 OIL 490100 A -6112--6117, 01/27/11 168 SBHP 157 5924 2323 6,200 0,350 2420 -6144 - -6152, -6162--6169 2K-22 50029212520000 OIL 490100 A -6090--6091, 03/29/11 2740 SBHP 156 5919 3391 6,200 0.350 3489 -6135--6141, -6175--6184, -6190--6191, -6209 - -6226 2K-22 50029212530000 OIL 490100 A -6090--6091, 09/10/11 211 SBHP 164 6182 3359 6,200 0.350 3365 -6135--6141, -6175--6184, -6190--6191, 6209--6226 2K -22A 50029212530000 OIL 490100 A -6090--6091, 11/18/11 9999 SBHP 155 6025 3485 6,200 0.548 3581 -6135--6141, -6175--6184, -6190 - -6191, -6225--6163 2K-24 50029211870000 IWAG 490100 A -6143--6153, 08/18/11 440 SBHP 127 6193 4680 6,200 0.350 4682 -6189 - -6199, 6218-=6238 2K-25 50029226080000 MWAG 490100 A -6081 --6090, 04/09/11 10215 SBHP 141 5919 4483 6,200 0.450 4610 -6131 - -6144, -6164--6186, -6167 - -6184 2K-28 50029213770000 MWAG 490100 A -6056--6061, 03/24/11 79 SPFO 0 6121 4675 6,200 0.450 4711 -6094 - -6108, -6121 - -6138 2K-28 50029218770000 MWAG 490100 A -6056--6061, 04/02/11 2850 SBHP 138 6129 4228 6,200 0.350 4253 -6095--6108, 6122--6138 2K-28 50029213790000 MWAG 490100 A -6056--6061, 07/05/11 5125 SBHP 123 6129 4086 6,200 0.500 4121 -6095--6108, -6122--6138 Form 10-412 Rev. 1212008 INSTRUCTIONS ON REVERSE SIDE Submit in Duplicate STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION RESERVOIR PRESSURE REPORT 1. Operator: 2. Address: ConocoPhilli s Alaska Inc. I P. 0. Box 100350, Anchorage, AK 99510-0360 3. Unit or Lease Name: 4. Field and Pool: 5. Datum Reference: 6. Oil Gravity: 7. Gas Gravity: Kuparuk River Unit Kupruk River Oil Pool -62098S 0.91 (water= 1.0 0.71 8. Well Name and 9. API Number 10. Type 11. AOGCC 12, Zone 13. Perforated 14. Final Test 15. Shut -In 16. Press. 17. B.H. 18. Depth Tooll 19. Final 20. Datum 21. Pressure 22. Pressure at Number. 50M)000)MIXX CX See Pool Code Intervals Top Date Time, Hours Surv. Type Temp. TVDSS Observed TVDSS (input) Gradient, psi/ft. Datum (cal) NO DASHES Instructions - Bottom TVDSS (see Pressure at instructions for Tool Depth codes) 2K-28 50029218770000 MWAG 490100 A -6056--6061, 08/18/11 6120 SBHP 142 6100 4027 6,200 0.350 4062 -6095--6108, -6138 1-6122-6138 2K-28 50029213610000 MWAG 490100 AC -6056--6061, 10/31/11 7920 SBHP 0 6062 3958 6,200 0.350 4006 -6094--6108, -6121 --6138 2K -28A 50029225440000 MWAG 490100 A -6169--6136, 12/28/11 9999 SBHP 145 6065 3921 6,200 0.340 3967 -6136 - -6113 2M-13 50029226910000 OIL 490100 A -5798--5812, 05/04/11 90 SBHP 154 5811 3086 6,200 0.410 3245 -5812--5825 2M-14 50029226910000 MWAG 490100 AC -5974--5985, 11/22/11 652 SBHP 120 6017 4602 6,200 0.430 4680 -5994 - -6013, 6032 - -6057 2M-19 50029226910000 MWAG 490100 AC -5777--5783, 12/13/11 2429 SBHP 127 5813 3729 6,200 0.440 3899 -5797--5801, -5806 - -5816, -5826--5851 2T-03 50029214630000 OIL 490100 A -5665--5677, 12/28/11 9999 SBHP 155 5672 3041 6,200 0.410 3257 -5673--5696, -5677--5695, -5719--5730, -5726--5728 2T-10 50029214630000 MWAG 490100 A -5716--5747, 10/17/11 19680 SBHP 131 5782 3088 6,200 0.440 3272 -5795--5835, -5795 - -5830, -5795--5835, -5853--5874 2T-18 50029215000000 MWAG 490100 AC -5737--5747, 11/11/11 1030 SBHP 127 5767 3208 6,200 0.400 3381 -5760--5764, -5767--5791, 5810--5818 2T-29 50103201460000 MWAG 490100 A -5612--5613, 02/25/11 100 SBHP 0 3095 3400 6,200 0.350 4487 -5695--5707, -5724--5734, -5739--5749 2T-40 50103201430000 OIL 490100 A -5733--5741, 03/05/11 2630 SBHP 154 5743 2393 6,200 0.350 2553 -5747--5755 2U-01 50103201320000 OIL 490100 AC -5683--5738, 07/03/11 635 SBHP 150 5532 2590 6,200 0.440 2884 -5740--5744, -5845--5892, 5938--5943 21.1-07A 50103201320000 MWAG 490100 A -5731 --5774, 12/03/11 37214 SBHP 119 5773 3106 6,200 0.460 3303 -5792 - -5795, -5797--5800, -5807--5810, -5815--5817, -5832--5835 2U-08 50103201340000 OIL 490100 AC -5690--5715, 10/01/11 72 SBHP 161 5817 2491 6,200 0.350 2625 -5797--5802, 5805--5838 2U-09 50103201340000 OIL 490100 IA -5708--5744, 10/01/11 456 SBHP 157 5733 2361 6,200 0.420 2557 -5756--5783 Form 10-412 Rev, 12/2008 INSTRUCTIONS ON REVERSE SIDE Submit in Duplicate STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION RESERVOIR PRESSURE REPORT 1. Operator. 2. Address: ConocoPhillips Alaska Inc. P. 0. Box 100360, Anchorage, AK 99510-0360 3. Unit or Lease Name: 4. Field and Pool: 5. Datum Reference: 6. Oil Gravity: 7. Gas Gravity: Kuparuk River Unit Kupruk River Oil Pool -62W SS 0.91 water = 1.0' 0.71 6. Well Name and 9. API Number10. Type 11. AOGCC 12. Zone 13. Perforated 14. Final Test 15. Shut-in 16. Press. 17. B.H. 18. Depth Tool 19. Final 20. Datum 21. Pressure 22. Pressure at Number. 50XXXXXXXXXXXX See Pool Code Intervals Top Date Time, Hours Surv, Type Temp. TVDSS Observed TVDSS (input) Gradient, psi/ft. Datum (cal) NO DASHES Instructions - Bottom TVDSS (see Pressure at instructions for Tool Depth codes) 2U-13 50103200800000 OIL 490100 AC -5667--5738, 07/16/11 600 SBHP 155 5892 2634 6,200 0.350 2742 -5890--5894, -5900--5935, -5968--5972, 5994--5998 2V-12 50103200860000 OIL 490100 AC -5710--5739, 01/15/11 160 SBHP 162 5797 2561 6,200 0.350 2702 -5818--5825, -5832--5849, -5861--5883 2V-15 501032008702000 OIL 490100 AC -5665--5688, 08/18/11 420 SBHP 161 5776 2633 6,200 0.350 2781 -5795 - -5804, -5816 - -5854, 5895--5904 2V-16 50103203220000 OIL 490100 C -5664--5684, 01/27/11 80 SBHP 157 5686 2498 6,200 0.440 2724 -5790--5798, -5804--5836, -5877--5885 2V-16 50103200900000 OIL 490100 A -5664--5684, 01/30/11 264 SBHP 158 5731 2579 6,200 0.350 2743 -5790--5798, -5804--5836, 5877--5885 2W-01 50029215140000 OIL 490100 AC -5785--5843, 01/14/11 140 SBHP 151 5913 2228 6,200 0.340 2325 -5934--5938, -5951 --5982, -6030 - -6041 2W-06 50029215160000 OIL 490100 A -5698--5771, 04/12/11 123 SBHP 153 5920 2013 6,200 0.050 2027 -5901 --5910, -5919--5940, -5942--5945, 6004--6007 2W-06 50029215140000 OIL 490100 C -5698--5771, 04/13/11 3072 SBHP 152 5785 2377 6,200 0.310 2506 -5901 --5910, -5919--5940, -5942--5945, -6004 - -6007 2X-01 50029215160000 MWAG 490100 AC -5737--5816, 11/30/11 2151 SBHP 133 5220 2260 6,200 0.350 2603 -5984--5993, 6003--6028 2X-02 50029215170000 MWAG 490100 AC -5722--5815, 07/25/11 4680 SBHP 142 5953 2889 6,200 0.350 2975 -5956--5965, -5979--6002 2X-03 50029215460000 MWAG 490100 AC -5718--5798, 07/28/11 4824 SBHP 126 5876 2796 6,200 0.350 2909 -5936--5950, -5961 --5970 2X-05 50029215500000 MWAG 490100 A -5635--5704, 08/31/11 5604 SBHP 118 5825 3359 6,200 0.160 3419 -5710--5724, -5801--5804, -5813 - -5826, 5838 - -5872 Form 10.412 Rev. 12/2008 INSTRUCTIONS ON REVERSE SIDE Submit in Duplicate STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION RESERVOIR PRESSURE REPORT 1. Operator: 2. Address: ConocoPhillips Alaska Inc. I P. 0. Box 100360, Anchorage, AK 99510-0360 3. Unit or Lease Name: 4. Feld and Pool: 5. Datum Reference: 6. Oil Gravity: 7. Gas Gravity: Kuparuk River Unit Ku ruk River Oil Pool -6200' SS 0.91 (water= 1.0 0.71 8. Well Name and 9. API Number 10. Type 11. AOGCC 12. Zone 13, Perforated 14. Final Test 15. Shut -In 16. Press, 17. B.H. 18. Depth Tooll 19. Final 20, Datum 21. Pressure 22. Pressure at Number: 50X)OVIXXX)DOM See Pool Code - Intervals Top Date Time, Hours Surv. Type Temp. TVDSS Observed TVDSS (input) Gradient, Psi/ft. Datum (cal) NO DASHES Instructions - Bottom TVDSS (see Pressure at instructions for Tool Depth codes) 2X -12A 50029219340000 OIL 490100 AC -5722--5754, 09/25/11 72 SBHP 156 5735 2400 6,200 0.350 2563 -5784--5785, -5812--5827, -5819--5820, -5993--6004, 6004--6014 2X-17 50029219320000 OIL 490100 C -5751 --5816, 07/30/11 48 SBHP 153 5796 1998 6,200 0.040 2014 -5797--5803, -5838--5859, -6035--6061 2X-17 50029219320000 OIL 490100 C -5751 --5816, 08/01/11 96 SBHP 150 5755 2072 6,200 0.049 2094 -5797--5803, -5838--5859, 6035 - -6061 2X-18 50029219320100 OIL 490100 A -5716--5751, 01/03/11 1152 SBHP 155 5910 2433 6,200 0.350 2535 -5902 - -5918, -5940 - -5954 2X-18 50029214670000 OIL 490100 A -5716- -5751, 02/18/11 9999 SBHP 163 5765 3457 6,200 0.450 3653 -5902 - -5918, -5940 - -5954 2Z -01A 50029214970000 OIL 490100 1A -5923--5940 11/30/11 5261 1SI3HP 145 5549 4092 6,200 0.320 4300 2Z-02 50029216180000 MWAG 490100 A -5764--5804, 01/12/11 1560 SBHP 128 5944 3700 6,200 0.350 3789 -5920 - -5928, -5920 - -5930, -5920 - -5925, -5935 - -5967, -5936 - -5960, -5936 - -5963, 5948--5960 2Z-03 50029216200000 MWAG 490100 A -5778--5843, 04/23/11 70000 SBHP 157 6006 2778 6,200 0.350 2846 -5978 - -5999, -6018--6024 2Z-04 50029216210000 MWAG 490100 A -5777--5833, 02/02/11 96 SBHP 121 5988 3554 6,200 0.350 3628 -5956 - -5960, -5969 - -5988, -6009 - -6015, 6018--6021 2Z-19 50029216210000 OIL 490100 AC -5798--5819, 04/25/11 35000 SBHP 152 5780 2627 6,200 0.350 2774 -5825--5861, -5980 - -5987, -5994--6014, -6037 - -6046 2Z -23A 50029216560100 MWAG 490100 A -5712--5726, 01/04/11 1800 SBHP 131 5749 2982 6,200 0.350 3140 -5746--5784, -5952 - -5962, 5962--5961 2Z -23A 50029216560200 MWAG 490100 A -5712--5726, 06/16/11 720 SBHP 135 5749 2202 6,200 0.350 2360 -5746--5784, -5952 - -5962, -5962--5961 3A -03B 50029216560200 OIL 490100 AC -6064--- 11/21/11 7139 SBHP 159 6090 3329 6,200 0.482 3382 6121 Form 10-412 Rev, 1212008 INSTRUCTIONS ON REVERSE SIDE Submit in Duplicate Form STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION RESERVOIR PRESSURE REPORT 1. Operator: 2. Address: I ConocoPhiilips Alaska Inc. P. O. Box 100360, Anchorage, AK 99510-0360 3. Unit or Lease Name: 4. Field and Pool: 5. Datum Reference: 6. Oil Gravity: 7. Gas Gravity: Ku aruk River Unit Kupruk River Oil Pool -6200' SS 0.91 (water= 1.0 0.71 S. Well Name and 9. API Number 10. Type 11. AOGCC 12. Zone 13. Perforated 14. Final Test 15. Shut -In 16. Press. 17. B.H. 18. Depth Tool 19. Final 20. Datum 21. Pressure 22. Pressure at Number: 50)0(XXXXXXXXXX See Pool Code Intervals Top Date Time, Hours Surv. Type Temp. TVDSS Observed TVDSS (input) Gradient, psi/ft. Datum (cal) NO DASHES Instructions - Bottom TVDSS (see Pressure at instructions for Tool Depth codes) 3A-05 50029216530000 OIL 490100 A -5953--5986, 08/23/11 137 SBHP 157 6113 2236 6,200 0.357 2267 -6086--6105, 6117--6144 3A-07 50029216530000 SW 490100 AC -5921 --5947, 03/06/11 4153 SBHP 98 5944 3090 6,200 0.440 3203 -6000 - -6016, -6026--6054, -6098 - -6106 3A-08 50029216540000 OIL 490100 A -5873--5902, 08/23/11 137 SBHP 156 5889 2792 6,200 0.444 2930 -5981 --5995, -6005--6046, 6074--6079 3A-18 50029216550000 OIL 490100 AC -5954--5962, 08/23/11 137 SBHP 154 6032 2304 6,200 0.054 2313 -6070--6094, -6096 - -6119 313-02 50029216550000 MWAG 490100 C -5955--5959, 10/24/11 19344 SBHP 123 6032 3562 6,200 0.370 3624 -5978--5988, -5995 - -6006, -6027 - -6033, -6118 - -6142, -6149--6171, 6188 - -6195 3B-02 50029216550000 MWAG 490100 A -5955--5959, 10/29/11 19464 SBHP 121 6065 3505 6,200 0.350 3552 -5978 - -5988, -5995 - -6006, -6027 - -6033, -6118 - -6142, -6149--6171, -6188--6195 313-05 50029216550000 PW 490100 A -6357--6368, 08/22/11 32000 SBHP 115 6468 3014 6,200 0.456 2892 -6379 - -6387, -6517 - -6539, 6552--6583 313-06 50029216550000 OIL 490100 AC -6423--6443, 08/22111 107 SBHP 164 6537 2498 6,200 0.132 2453 -6590 - -6610, -6600 - -6630, -6623--6652 3C-08 50029216550000 OIL 490100 A -6541--6552, 08/23/11 124 SBHP 161 6553 2552 6,200 0.431 2400 -6564--6574, 6589 - -6607 3F-09 50029216300000 OIL 490100 C -5717--5791, 03/08/11 9000 SBHP 155 5796 3077 6,200 0.430 3251 -5856--5880 3F-09 50029216300000 OIL 490100 A -5717--5791, 03/23/11 9000 SBHP 157 5835 2887 6,200 0.350 3015 -5856 - -5880 3F-17 50029216300000 OIL 490100 A -5941 --5959, 08/20/11 72 SBHP 157 5935 1484 6,200 0.530 1625 -5976 - -5987 3G-13 50029227710000 MWAG 490100 AC -5751 --- 08/23/11 144 SBHP 130 5786 4147 6,200 0.440 4329 5790, -5801 - 5826 3G-13 50029216420000 MWAG 490100 AC -5751 --5790, 11/06/11 1176 SBHP 123 5786 3978 6,200 0.350 4123 -5801 - -5826 3G-13 50029216300000 MWAG 490100 AC -5751 --5790, 12/24/11 2328 SBHP 134 5771 3953 6,200 0.360 4107 -5801--5826 3G-15 50029228820000 MWAG 490100 A -5749--5783 09/12/11 96 SBHP 126 5765 44161 6,200 1 0.450 4612 50029229350000 MWAG 490100 A -5749 - -5783 120 5765 41301 6,200 1 0.350 428 bmit in Duplicate STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION RESERVOIR PRESSURE REPORT 1. Operator: 2. Address: ConocoPhillips Alaska Inc. P. O. Box 100360, Anchorage, AK 99510.0360 3. Unit or Lease Name: 4. Field and Pool: 5. Datum Reference: 6. Oil Gravity: 7. Gas Gravity: Kuparuk River Unit Kupruk River Oil Pool -62W SS 0.91 (water =1.0 0.71 8. Well Name and 9. API Number 10. Type 11. AOGCC 12. Zone 13. Perforated 14, Final Test 15. Shut -In 16. Press. 17. B.H. 18. Depth Tool 19. Final 20. Datum 21. Pressure 22. Pressure at Number. 50XXXXXX)000(XX See Pool Code Intervals Top Date Time, Hours Surv. Type Temp. TVDSS Observed TVDSS (input) Gradient, psilft. Datum (cal) NO DASHES Instructions - Bottom TVDSS (see Pressure at instructions for Tool Depth codes) 3G-22 50029227750000 OIL 490100 AC -5774 - -5823 08/04/11 96 SBHP 1571 5798 3598 6,200 0.430 3771 3G-22 50029217260000 OIL 490100 AC -5774--5823 11/22/11 48 SBHP 157 5798 3387 6,200 0.430 3560 3G-23 50029215380000 PW 490100 A -5742--5753, 09/12/11 75000 SBHP 140 5769 4326 6,200 0.360 4481 5765--5797 3G-23 50029226410100 PW 490100 A -5742--5753, 11/07/11 76368 SBHP 140 5769 4134 6,200 0.350 4285 -5765--5797 3G -25X 50029215820000 OIL 490100 AC -5677--5687, 01/18/11 240 SBHP 152 5673 2187 6,200 0.350 2371 -5693 - -5699, -5708--5723 3H-09 50029215820000 MWAG 490100 C -5869--5925, 05/13/11 15 SBHP 83 5991 3568 6,200 0.440 3660 -5956--5966, -5977--5997, -5999--6005, -6007--6015, -6009--6027, 6015 - -6029 3H-09 50029215920000 MWAG 490100 C -5869--5925, 07/01/11 1192 SBHP 106 5899 3510 6,200 0.784 3746 -5956 - -5966, -5977 - -5997, -5999 - -6005, -6007 - -6027, -6009 - -6015, -6015 - -6029, 31-1-09 50029215920000 MWAG 490100 A -5869--5925, 07/02/11 1213 SBHP 98 5985 4092 6,200 0.686 4239 -5956 - -5966, -5977 - -5997, -5999 - -6005, -6007 - -6015, -6009 - -6027, 6015--6029 31-1-10B 50029215930100 OIL 490100 AC -5877--5894, 06/27/11 452 SBHP 153 5879 3265 6,200 0.344 3375 -5903--5921, -5952 - -5970, -5979 - -5987, -6010--6019 31-1-10C 50029215930100 OIL 490100 A -5877--6008, 08/10/11 1509 SBHP 132 5235 3332 6,200 0.569 3881 -6039 - -6052 3H -12A 50029230560000 OIL 490100 AC -5166--5170, 07/06/11 838 SBHP 103 5976 3714 6,200 0.350 3792 -5922 - -5933, 5984--5981 31-1-12A 50029230560000 OIL 490100 A -5166--5170, 09/03/11 1577 SBHP 128 5799 3561 6,200 0.350 3701 -5922 - -5933, -5984 - -5981 31-1-17 50029218260000 SW 490100 A -5976--5983, 05/19/11 4923 SBHP 102 6028 4365 6,200 0.465 4445 -5977 - -5980, -6017--6024, -6035--6043, -6065--6079 31-1-17 50029218250000 SW 490100 AC -5976--5983, 12/10/11 11463 SBHP 105 6028 3992 6,200 0.374 4057 -5977--5980, -6017--6024, -6035 - -6043, -6065--6079 Form 10.412 Rev. 12/2008 INSTRUCTIONS ON REVERSE SIDE Submit in Duplicate STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION RESERVOIR PRESSURE REPORT 1. Operator: 2. Address: ConocoPhillips Alaska Inc. I P. O. Box 100360, Anchorage, AK 99510-0360 3. Unit or Lease Name: 4. Field and Pool: 5. Datum Reference: 6. Oil Gravity: 7. Gas Gravity: Kuparuk River Unit Kupruk River Oil Pool -6200' SS 0.91 water = 1.0 0.71 8. Well Name and 9. API Number 10. Type 11. AOGCC 12. Zone 13. Perforated 14. Final Test 15. Shut -In 16. Press. 17. B.H. 18. Depth Tool 19. Final 20. Datum 21. Pressure 22. Pressure at Number: 50)0(XX)000V1)= See Pool Code Intervals Top Date Time, Hours Surv. Type Temp. TVDSS Observed TVDSS (input) Gradient, psi/ft. Datum (cal) NO DASHES Instructions - Bottom TVDSS (see Pressure at instructions for Tool Depth codes) 31-06 50029216830000 SW 490100 A -6115--6123, 10/09/11 1350 SBHP 85 6171 4711 6,200 0.449 4724 -6165 - -6178, 6184--6210 31-07 50029216650000 SW 490100 C -6153--6164, 06/17/11 1197 SBHP 84 6191 4325 6,200 0.404 4329 -6159 - -6159, -6171 - -6185, -6174--6174, -6179 - -6179, -6185 - -6198, -6206 - -6213, 6229--6229 31-08 50029222680000 OIL 490100 A -6183--6198, 04/29/11 16470 SBHP 155 6211 4214 6,200 0.427 4209 -6191 --6191, -6197--6197, -6207--6240 31-08 50029222390100 OIL 490100 A -6183--6198, 07/01/11 18065 SBHP 156 6202 4230 6,200 0.445 4229 -6191 --6191, -6197--6197, 6207--6240 3J-19 50029222580000 OIL 490100 AC 6185--6196, 01/13/11 120 SBHP 156 6307 1774 6,200 0.343 1737 -6290 - -6325, 6326 - -6336 3K-01 50029222500000 OIL 490100 A -6573--6596, 01/11/11 63 SBHP 161 6574 2206 6,200 0.430 2045 -6577 - -6592, -6582 - -6582, -6584 - -6585, -6586 - -6587, -6596 - -6629, -6602 - -6602, -6607--6607, -6610 - -6610, -6612 - -6613, -6615 - -6615, 6618 - -6627 3K-06 50029222630000 OIL 490100 A -6490--6503, 01/16/11 194 SBHP 161 6570 1621 6,200 0.320 1503 -6566 - -6582, -6566 - -6600, -6570 - -6570, -6574--6574, -6578 - -6578, -6582 - -6600, -6582 - -6582, -6585 - -6586, -6589 - -6590, -6593--6594, -6597--6597, -6630--6643 Form 10-412 Rev. 12/2008 INSTRUCTIONS ON REVERSE SIDE Submit in Duplicate STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION RESERVOIR PRESSURE REPORT 1. Operator. 2. Address: I ConocoPhillips Alaska Inc. P. 0. Box 100360, Anchorage, AK 99510-0360 3. Unit or Lease Name: 4. Field and Pool: 5. Datum Reference: 6. Oil Gravity: 7. Gas Gravity: Ku aruk River Unit Kupruk River Oil Pool -6200' SS 0.91 (water= 1. 0.71 8. Well Name and 9. API Number 10. Type 11. AOGCC 12. Zone 13. Perforated 14. Final Test 15. Shut -In 16. Press. 17. B.H. 18. Depth Tool 19. Final 20. Datum 21. Pressure 22. Pressure at Number. 50� See Pool Code Intervals Top Date Time, Hours Surv. Type Temp. TVDSS Observed TVDSS (input) Gradient, psi/ft. Datum (cal) NO DASHES Instructions - Bottom TVDSS (see Pressure at instructions for Tool Depth codes) 3K-10 50103204560100 OIL 490100 A -6643--6645, 10/09/11 475 SBHP 152 6658 1738 6,200 0.459 1528 -6646 - -6659, -6671--6693, -6697--6697, -6700--6701, -6703--6704, -6706--6707, -6709--6712 3K-10 50103204320000 OIL 490100 A -6494--6498, 11/12/11 1567 SBHP 158 6658 1902 6,200 0.473 1685 -6605--6609, -6643--6659, -6645--6646, -6647--6648, -6654--6655, -6657--6658, -6672--6694, -6676--6677, -6682--6682, -6686--6687, -6690--6691, -6697--6698, -6700--6701, 6704--6704, 3K-23 50103204780000 OIL 490100 A -6502--6604 01/11/11 78 SBHP 1591 6428 2844 6,200 0.417 2749 3K-25 50103204890000 PW 490100 A -6536--6551, 08/22/11 33384 SBHP 132 6569 2402 6,200 0.430 2244 -6559--6602. 3K-30 50103203530000 PW 490100 AC -6609--6623, 09/28/11 4416 SWHP 152 -75 3211 6,200 0.350 5407 -6635--6649, -6651--6665 50103202500000101L 490100 AC -6562--6580, 08/23/11 132 SBHP 160 6562 3690 6,200 0.431 3534 6596--6613 50103202500100 OIL 490100 A -6188--6205, 11/13/11 528 SBHP 156 6186 4245 6,200 0.480 4252 -6384 - -6401, -6412--6421, -6428 - -6437, -6437 - -6443, -6454 - -6476, ]3M_06 -6481 - -6484 50103202950000 OIL 490100 A -6106--6116, 01/17/11 209 SBHP 167 6129 3984 6,200 0.430 4015 -6110 - -6112, -6116--6141, -6119 - -6140, -6147 - -6149, 6152--6154 50103205920000 SW 490100 A -6141 --6150, 11/14/11 220 SBHP 111 6233 5331 6,200 0.480 5315 -6160--6180, -6185--6188 3M-11 50103205920000 OIL 490100 A -6136--6155 01/11/11 41160 SBHP 159 5951 3977 6,200 0.330 4059 3M-13 50103205920000 OIL 490100 AC -6140--6165, 01/16/11 188 SBHP 164 5950 3659 6,200 0.430 3766 -6168--6186, -6177--6179, -6190--6220, 6191 --6219 Form 10-412 Rev. 12/2008 INSTRUCTIONS ON REVERSE SIDE Submit in Duplicate STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION RESERVOIR PRESSURE REPORT 1. Operator. 2. Address: I ConocoPhillips Alaska Inc. P. O. Box 100360, Anchorage, AK 99510-0360 3. Unit or Lease Name: 4. Field and Pool: 5. Datum Reference: 6. Oil Gravity: 7. Gas Gravity: Kuparuk River Unit Kupruk River Oil Pool -6204 SS 0.91 (water= 1.0' 0.71 8. Well Name and 9. API Number 10. Type 11. AOGCC 12. Zone 13. Perforated 14. Final Test 15. Shut -In 16. Press. 17. B.H. 18. Depth Tool 19. Final 20. Datum 21. Pressure 22. Pressure at Number. 50� See Pool Code Intervals Top Date Time, Hours Surv. Type Temp. TVDSS Observed TVDSS (input) Gradient, psi/ft. Datum (cal) NO DASHES Instructions - Bottom TVDSS (see Pressure at instructions for Tool Depth codes) 3M-13 50103205920000 OIL 490100 AC -6140--6165, 08/04/11 3192 SBHP 150 5956 3172 6,200 0.440 3279 -6168--6186, -6177--6179, -6190--6220, 6191--6219 3M-14 50103205120000 OIL 490100 A -6177--6179, 11/14/11 46056 SBHP 156 6143 4869 6,200 0.390 4891 -6181 - -6182, -6184 - -6185, -6189--6221 3M-17 50103205120000 OIL 490100 AC -6243--6268 01/11/11 64 SBHP 169 6151 3665 6,200 0.035 3667 3M-27 50103204230000 OIL 490100 AC -6131--6140, 01/16/11 194 SBHP 100 3282 2460 6,200 0.310 3365 -6152--6167, 6182--6197 3N-01 50103203770000 OIL 490100 A -6259--6271, 01/11/11 65 SBHP 157 6281 2640 6,200 0.420 2606 -6278--6291, -6287--6287, -6291--6305 3N-04 50103204740000 SW 490100 AC -6207--6216, 11/15/11 4080 SBHP 124 6237 3898 6,200 0.350 3885 -6240--6243, -6243--6246, -6243--6243, -6246--6249, -6252--6258, 6264--6269 3N-05 50103204590000 SW 490100 A -6116--6128, 01/31/11 3936 SBHP 119 6150 5014 6,200 0.450 5036 -6124--6125, -6135--6148, -6142 - -6143, -6145--6148, -6165--6186 3N-05 50103204570000 SW 490100 A -6116--6128, 11/01/11 10512 SBHP 123 6126 4704 6,200 0.460 4738 -6124--6125, -6135 - -6148, -6142 - -6143, -6145 - -6148, -6165--6186 3N-07 50103206110000 OIL 490100 AC -6335--6341, 03/12/11 3984 SBHP 158 6298 4264 6,200 0.370 4228 -6379--6394, -6389--6389, -6390--6390, -6406--6422 3N-07 50103206030000 OIL 490100 AC -6335--6341, 07/18/11 7056 SBHP 157 6298 4271 6,200 0.370 4235 -6379--6394, -6389 - -6389, -6390 - -6390, -6406 - -6422 3N-10 50103206150000 SW 490100 C -6329--6354, 08/25/11 174 SBHP 118 6338 4863 6,200 0.434 4803 -6438 - -6453, -6449--6451, -6452 - -6452, -6463--6467 Form 10-412 Rev. 12/2008 INSTRUCTIONS ON REVERSE SIDE Submit in Duplicate STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION RESERVOIR PRESSURE REPORT 1. Operator: 2. Address: ConocoPhiilips Alaska Inc. P. O. Box 100360, Anchorage, AK 99510-0360 3. Unit or Lease Name: 4. Field and Pool: 5. Datum Reference: 6. Oil Gravity: 7. Gas Gravity: Kuparuk River Unit Kupruk River Oil Pool -62OU SS 0.91 (water= 1.0 0.71 8. Well Name and 9. API Number 10. Type 11. AOGCC 12. Zone 13. Perforated 14. Final Test 15. Shut -In 16. Press. 17. B.H. 18. Depth Tool 19. Final 20. Datum 21. Pressure 22. Pressure at Number: 50X)V1YXDC0V1X" See Pool Code Intervals Top Date Time, Hours Surv. Type Temp. TVDSS Observed TVDSS (input) Gradient. psi/ft. Datum (cal) NO DASHES Instructions - Bottom TVDSS (see Pressure at instructions for Tool Depth codes) 3N-10 50103205410000 SW 490100 A -6329--6354, 08/26/11 136 SBHP 115 6397 4760 6,200 0.350 4691 -6438 - -6453, -6449--6451, -6452 - -6452, 6463 - -6467 311-11 50103206090000 OIL 490100 AC -6306--6316, 11/16/11 672 SBHP 118 6365 4269 6,200 0.490 4188 -6345 - -6356, -6361 - -6375, -6364 - -6365, -6368 - -6369, -6370 - -6370, -6379 - -6380, -6391--6405, -6399--6400, -6403 - -6404, -6406 - -6407, -6409 - -6426 3N-11 50103206090000 OIL 490100 A -6305--6316, 12/25/11 25 SBHP 104 6365 3438 6,200 0.430 3367 -6344--6355, -6361--6375, -6378--6379, -6391--6406, -6408--6425 3N-13 50103206170000 OIL 490100 AC -6303--6318, 11/16/11 4104 SBHP 115 6367 4344 6,200 0.410 4275 -6358--6369, -6362 - -6362, -6365--6365, -6366--6366, -6368--6368, -6375--6393, -6384--6384, -6387--6387, -6390--6390, -6391 --6391, -6395--6395, 6407--6432 3N-15 50103206170000 OIL 490100 A -6423--6436, 08/22/11 108 SBHP 157 6407 2039 6,200 0.370 1963 -6430--6434, -6444 - -6460, -6451 - -6452, -6454--6456, -6458 - -6458, -6462--6472 30-20 50103206120000 OIL 490100 A -6516--6530, 01/18/11 240 SBHP 160 6526 2153 6,200 0.420 2016 6538--6560 3Q-02 50103205430100 MWAG 490100 A -6169--6179, 01/11/11 66 SBHP 94 3965 3562 6,200 0.480 4635 -6185--6206, -6185--6218 3Q-10 50103205430100 OIL 490100 A -6326--6357 08/21/11 84 SBHP 163 6328 3547 6,200 0.370 3500 3Q-11 50103205220100 OIL 490100 A -6279--6291, 08/21/11 89 SBHP 161 6309 3382 6,200 0.380 3341 -6294 - -6310, -6315--6341 3R-25 50103205590100 PW 490100 A 6623--6671 04/18/11 1-2-01 SBHP 135 6547 4624 6,200 0.350 4503 Form 10.412 Rev. 12/2008 INSTRUCTIONS ON REVERSE SIDE Submit in Duplicate 1. Operator: STATE OF ALASKA ConocoPhillips Alaska Inc. RESERVOIR 3. Unit or Lease Name: 0.91 (water= 1.0 0.71 Kuparuk River Unit 2. Address: 8. Well Name and 9. API Number 10. Type 11. AOGCC Number: 5oxxxxxxxxxxxx See Pool Code NO DASHES Instructions Gradient, psi/ft. Datum (cal) Kupruk River Oil Pool Zone 13. Perforated 3R-26 50103204140100 OIL 490100 q 3S-03 50103205370000 OIL 490100 C 3S -08C 50103205370000 OIL 490100 C 490100 490100 490100 490100 I hereby certify that the fo oin 's true and correct to st y Signature Printed Name /r ,��. �.Ydi��•YkI Datum Reference: STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION RESERVOIR PRESSURE REPORT 0.91 (water= 1.0 0.71 . Depth Tool 2. Address: 20. Datum 21. Pressure 22. Pressure at P. O. Box 100360, Anchoragi Observed 4. Field and Pool: Gradient, psi/ft. Datum (cal) Kupruk River Oil Pool Zone 13. Perforated 14. Final Test 15. Shut -In 16. Press. 17. B.H. Intervals Top Date Time, Hours Surv. Type Temp. - Bottom TVDSS (see instructions for 2805 codes) -6502--6530, 01/13/11 120 SBHP 165 -6539 - -6560 -5803 - -583208/22/11 120 SBHP 160 -5789--5793, 02/16/11 1488 SBHP 152 -5789 - -5789, -5792--5792, -5814--5814, -5810--5810, -5808--5808, -5807--5807, -5806 - -5805, -5808 - -5809, -5806--5806, -5801--5801, -5815--5815 5791 --5810 08/20/11 72 SBHP 137 �.Ydi��•YkI Datum Reference: 6. Oil Gravity: 7. Gas Gravity: 200' SS 0.91 (water= 1.0 0.71 . Depth Tool 19. Final 20. Datum 21. Pressure 22. Pressure at TVDSS Observed TVDSS (input) Gradient, psi/ft. Datum (cal) Pressure at Tool Depth 6531 2805 6,200 0.440 2659 57211 18121 6,200 1 0.3001 19561 2989 1371 58271 2640 Title � -{ 0('V Q4i *\(•f M G%"'Y. Date 3f ��/� -2- s7rM i1golI Form Form 10-412 Rev. 12/2008 INSTRUCTIONS ON REVERSE SIDE Submit in Duplicate ConocoPhillips March 31, 2012 Mr. Dan Seamount, Commissioner Alaska Oil and Gas Conservation Commission 333 West 7th Ave. Suite 100 Anchorage, Alaska 99501-3539 James T. Rodgers Manager, GKA Development Greater Kuparuk Area ConocoPhillips Alaska, Inc. ATO -1326 PO Box 100360 Anchorage AK 99510-0360 Phone (907) 263-4027 Fax: (907) 265-6133 Re: Kuparuk River Oil Pool — Proposed Injection Profile Survey Plan for 2012 Dear Commissioner Seamount, In compliance with Rule 4, Conservation Order No. 19813, ConocoPhillips Alaska, Inc., operator of the Kuparuk River Oil Pool, is hereby submitting the proposed injection profile survey plan for 2012. There were 48 injection surveys reported for the Kuparuk River Oil Pool to the AOGCC in 2011. In 2012, we expect to conduct approximately 40 injection surveys, including initial surveys for new wells prior to initial sustained injection. If you have any questions concerning this data, please contact Mark Kovar at 265-6097. Sincerely, 1 ` gimes T. Rodgers Manager, GKA Development Greater Kuparuk Area 1 of 4 ATTACHMENT KUPARUK RIVER UNIT KUPARUK RIVER OIL POOL CONSERVATION ORDER 198B RULE 3d - INJECTIVITY PROFILES 2011 ANNUAL SUBMITTAL WELL API DATE OF DATE OF DATA TYPE REASON FOR WELL ZONES INJECTION NUMBER NUMBER INITIAL PROFILE/ PROFILE/ PROFILE/ COMPLETION TAKING BWPD / 50- INJECTION SURVEY SURVEY SURVEY INJECTION MSCFD 1A-14 0292070600-00 02/83 09/01/11 SZT OPEN C SANDS Selective AC 3160 A 1000 113-12 0292236500-00 11/93 06/04/11 SPINNER A/C SPLITS Single C 6831 1L-16 0292120200-00 09/85 06/21/11 SPINNER A/C SPLITS Selective AC 179 A 258 1Q-09 0292120900-00 07/96 12/11/11 SPINNER CLOSE C SANDS Selective A 3083 1Q-24 0292258400-00 04/96 11/27/11 SPINNER PERF C SANDS Single AC 4434 A 2015 2A -01A 1032002301-00 03/88 02/09/11 SPINNER A/C SPLITS Selective AC 5567 A 0 2A-04 1032002600-00 03/85 03/20/11 SPINNER A/C SPLITS Selective AC 4850 A 1649 213-06 0292107800-00 11/85 04/08/11 SPINNER A/C SPLITS Selective AC 2550 A 128 213-08 0292107900-00 11/85 08/26/11 SPINNER A/C SPLITS Selective A 1500 213-09 0292108200-00 11/85 12/27/11 SPINNER A/C SPLITS Selective AC 4000 A 1000 26-09 0292108200-00 11/85 10/02/11 SPINNER A/C SPLITS Selective AC 5100 A 663 2B-10 0292108400-00 11/86 04/22/11 SPINNER A/C SPLITS Selective AC 3700 A 2553 213-12 0292109200-00 11/85 03/19/11 SPINNER A/C SPLITS Selective AC 8000 A 1600 213-12 0292109200-00 11/85 12/29/11 SPINNER A/C SPLITS Selective AC 3000 A 1740 ___ 2 of 4 ATTACHMENT KUPARUK RIVER UNIT KUPARUK RIVER OIL POOL CONSERVATION ORDER 198B RULE 3d - INJECTIVITY PROFILES 2011 ANNUAL SUBMITTAL WELL API DATE OF DATE OF DATA TYPE REASON FOR WELL ZONES INJECTION NUMBER NUMBER INITIAL PROFILE/ PROFILE/ PROFILE/ COMPLETION TAKING BWPD / 50- INJECTION SURVEY SURVEY SURVEY INJECTION MSCFD 2C-02 0292097200-00 11/85 05/02/11 SZT CLOSE C SANDS Selective A 0 2C-04 0292097300-00 11/85 08/01/11 SPINNER A/C SPLITS Selective AC 5483 A 4057 2C-05 0292097800-00 11/85 08/03/11 SPINNER A/C SPLITS Selective AC 3493 A 175 2C-07 0292097500-00 11/85 07/03/11 SPINNER FOLLOW-UP Selective A 1150 2C-08 0292097400-00 11/85 07/05/11 SPINNER FOLLOW-UP Single AC 830 A 365 2C-08 0292097400-00 11/85 07/04/11 SPINNER A/C SPLITS Single AC 900 A 333 2F-03 0292106200-00 11/85 11/21/11 SPINNER A/C SPLITS Single AC 2730 A 1528 2F-13 0292103200-00 11/85 12/16/11 SPINNER A/C SPLITS Single AC 1494 A 1419 2G-03 0292116500-00 11/85 09/23/11 SPINNER A/C SPLITS Single AC 1470 A 323 21-1-02 1032003200-00 11/87 01/27/11 SPINNER A/C SPLITS Single AC 4607 A 0 2K-12 1032010900-00 04/91 07/09/11 SPINNER A/C SPLITS Single AC 1379 A 1379 2K-24 1032012200-00 11/91 07/23/11 SPINNER A/C SPLITS Single AC 700 A 28 21M-03 1032016000-00 12/92 10/24/11 SPINNER A/C SPLITS Single AC 2193 A 2193 3 of 4 ATTACHMENT 5 KUPARUK RIVER UNIT KUPARUK RIVER OIL POOL CONSERVATION ORDER 1988 RULE 3d - INJECTIVITY PROFILES 2011 ANNUAL SUBMITTAL WELL API DATE OF DATE OF DATA TYPE REASON FOR WELL ZONES INJECTION NUMBER NUMBER INITIAL PROFILE/ PROFILE/ PROFILE/ COMPLETION TAKING BWPD / 50- INJECTION SURVEY SURVEY SURVEY INJECTION MSCFD 2T-28 1032022500-00 09/95 12/03/11 SPINNER A/C SPLITS Single AC 2738 A 1432 2U-05 0292128100-00 11/86 04/01/11 SPINNER A/C SPLITS Selective AC 1930 A 714 2V-01 0292103400-00 11/84 11/20/11 SPINNER A/C SPLITS Selective AC 3850 A 0 2V-06 0292105400-00 12/85 09/02/11 SPINNER A/C SPLITS Selective AC 4646 A 3300 2W-09 0292123500-00 01/86 06/30/11 SPINNER FOLLOW-UP Selective AC 5000 A 800 2W-14 0292125300-00 11/85 04/02/11 SPINNER A/C SPLITS Selective AC 3796 A 3796 2X-04 0292099500-00 11/85 07/21/11 SPINNER A/C SPLITS Selective AC 3334 A 4382 2X-08 0292099200-00 02/86 09/27/11 SPINNER A/C SPLITS Selective AC 3985 A 335 2Z-04 0292096500-00 06/89 5/20/2011 SPINNER A/C SPLITS Selective A 2400 2Z-06 0292095700-00 11/85 4/30/2011 SPINNER A/C SPLITS Selective AC 3000 A 1110 2Z-06 0292095700-00 11/85 7/27/2011 SPINNER A/C SPLITS Selective AC 3290 A 1468 2Z-11 0292137900-00 11/85 4/26/2011 SPINNER A/C SPLITS Selective AC 3700 A 3589 3A-07 0292144400-00 01/91 1/31/2011 SZT CLOSE C SANDS Selective A 4000 4 of 4 48 >>Total IPROF Count for 2011 ATTACHMENT KUPARUK RIVER UNIT KUPARUK RIVER OIL POOL CONSERVATION ORDER 198B RULE 3d - INJECTIVITY PROFILES 2011 ANNUAL SUBMITTAL WELL API DATE OF DATE OF DATA TYPE REASON FOR WELL ZONES INJECTION NUMBER NUMBER INITIAL PROFILE/ PROFILE/ PROFILE/ COMPLETION TAKING BWPD / 50- INJECTION SURVEY SURVEY SURVEY INJECTION MSCFD 3B-01 0292131800-00 01/87 12/18/11 SPINNER A/C SPLITS Selective AC 1506 A 2279 313-12 0292137000-00 01/87 6/18/2011 SPINNER A/C SPLITS Selective AC 5821 A 1632 313-16 0292128900-00 12/85 9/22/2011 SPINNER A/C SPLITS Selective AC 5145 A 1481 3G-16 1032013500-00 09/91 6/23/2011 SPINNER A/C SPLITS Selective AC 1787 A 1055 3H-09 1032008600-00 12/88 11/19/2011 SZT Choked C sands BOL Single AC 4546 A 1119 3H-09 1032008600-00 12/88 8/9/2011 SZT RWO to install select Single A 1150 3K-15 0292163200-00 11/87 6/5/2011 SPINNER A/C SPLITS Single AC 586 A 64 3R-20 0292225000-00 10/92 4/4/2011 SPINNER A/C SPLITS Single AC 2094 48 >>Total IPROF Count for 2011 ATTACMENT6 KUPARUK RIVER UNIT KUPARUK RIVER OIL POOL CONSERVATION ORDER 432 RULE 9 - PRODUCTIVITY PROFILES ANNUAL 2011 SUBMITTAL WELL API DATE OF DATE OF DATA TYPE REASON FOR WELL ZONES PRODUCTION NUMBER NUMBER INITIAL PROFILE/ PROFILE/ PROFILE/ COMPLETION PROD- OIL WATER GAS 50- PRODUCTION SURVEY SURVEY SURVEY TYPE UCING BOPD BWPD MSCFD 1A-24 0292298400 - 00 02101 04/09/11 SZT CLOSE C SANDS Monobore A 0 1600 1400 140 115 120 113-19 0292247500 - 00 09/94 01/01/11 SZT CLOSE C SANDS Single C 170 460 185 170 460 185 1E-03 0292047700-00 12181 02/10/11 SPINNER A/C SPLITS Selective AC 292 724 279 A 29 72 28 1Q-16 0292130900 - 00 06/85 12/26/11 SPINNER OPEN C SANDS Selective AC 377 2326 454 340 2237 213 113-16 0292138800-00 11185 03/21/11 SPINNER A/C SPLITS Selective AC 112 1672 132 92 0 37 1Y-27 0292237900 - 00 12193 01/30/11 SPINNER A/C SPLITS Triple AC 123 1612 320 120 230 510 1Y-30 0292185100 - 00 04189 01/02/11 SZT CLOSE C SANDS Selective A 100 3400 2300 100 500 1400 2A-17 1032019300 - 00 05194 06/13/11 SPINNER A/C SPLITS Single AC 410 3346 3209 A 212 409 162 28-13 0292113800 - 00 11/84 11/21/11 SPINNER A/C SPLITS Selective AC 375 970 590 A 337 873 531 2H-09 1032005000 - 00 12/85 11/19/11 SPINNER A/C SPLITS Selective AC 237 529 200 A 166 480 92 2H-12 1032005300 - 00 12185 11/20/11 SPINNER A/C SPLITS Selective AC 54 1086 100 A 31 183 57 2M-24 1032017100 - 00 10/92 06/07/11 SPINNER A/C SPLITS Single AC 217 490 242 A 206 424 189 ATTACMENT6 KUPARUK RIVER UNIT KUPARUK RIVER OIL POOL CONSERVATION ORDER 432 RULE 9 - PRODUCTIVITY PROFILES ANNUAL 2011 SUBMITTAL WELL API DATE OF DATE OF DATA TYPE REASON FOR WELL ZONES PRODUCTION NUMBER NUMBER INITIAL PROFILE/ PROFILE/ PROFILE/ COMPLETION PROD- OIL WATER GAS 50- PRODUCTION SURVEY SURVEY SURVEY TYPE UCING BOPD BWPD MSCFD 2T-17 1032006000-00 11/86 10/17/11 SPINNER A/C SPLITS Selective AC 429 1996 452 A 47 220 50 2W-06 0292121100 - 00 02/85 04/14/11 SZT OPEN C SANDS Selective AC 409 479 9807 A 409 479 9807 2Z-07 0292094600 - 00 06/83 04/28/11 SPINNER A/C SPLITS Selective AC 252 760 270 A 196 390 121 313-04 0292132300-00 06/85 05/28/11 SPINNER A/C SPLITS Selective AC 499 548 2297 A 80 91 491 36-13 0292128600 - 00 06/85 07/18/11 SPINNER A/C SPLITS Selective AC 233 2521 292 A 97 2067 83 313-14 0292128700 - 00 06/85 01/31/11 SPINNER A/C SPLITS Single AC 362 1316 456 A 267 318 165 3F-06 0292146200 - 00 12/85 06/11/11 SPINNER A/C SPLITS Selective AC 704 5005 4224 A 305 583 242 3H -10C 1032008703 - 00 08/11 08/11/11 SZT OPEN A SANDS Single A 277 534 648 277 534 648 3H -12A 1032008801 - 00 06/88 11/18/11 SZT OPEN A SANDS Single A 299 650 530 299 650 530 21 >> Total PPROF Count for 2011 Attachment 7 Kuparuk River Oil Pool 2011 Annual Reservoir Surveillance Report Miscible Injectant Composition Miscible Injectant (MI) is manufactured at CPF-1 and CPF-2. The compositions of both the lean gas, enriching fluids (NGLs) and the resulting MI are measured periodically throughout the year to ensure that the MI meets the design Minimum Miscible Pressure (MMP). The detailed compositional analysis of the MI from each CPF is provided in tabular form on the following pages, together with the Minimum Miscible Pressures (MMP). The target MMP is 3300 psia. A lower MMP means higher NGL content in MI. KUPARUK RIVER UNIT MI COMPOSITION: CPF-1 Date Facility CO2 I N2 I Cl I C2 C3 i 4 n 4 I iC5 1 n C6 C7 + (Calc), psia 1/2212011 CPF-1 1.088 0.295 71.146 6.543 4.729 2.851 6.689 2.103 1.722 1.720 1.530 0.967 3388 2/412011 CPF-1 0.992 0.275 67.762 6.065 4.485 3.213 7.725 2.691 2.129 2.350 2.177 1.404 2670 2/23/2011 CPF-1 1.061 0.334 68.130 6.247_ 4.844 3.327 7.803 2.553 2.074 2.097 1.829 1.096 2844 3/4/2011 _CPF-1 1.076 0.280 69.375 6.471 4.700 3.080 7.259 2.367 1.907 1.957 1.757 1.128_ 3057 3125/2011 CPF-1 0.999 0.302 69.524 6.196 4.493 3.103 7.365 2.426 1.934 2.011 1.807 1.143 3040 4/2/2011 _CPF-1 1.066 0.290 71.074 6.218 4.274 2.931 6.860 2.229 1.791 1.843 1.669 1.111 3289 4/17/2011 5/12/2011 5/31/2011 CPF-1 CPF-1 CPF-1 1.037 1.078 1.079_ 0.259 0.276 0.263 68.478 69.806 68.038 6.334 6.536 6.553 4.797 4.842 5.077 3.279 3.068 3.016 7.690 7.312 7.927 2.439 2.259 2.497 1.979 1.861 2.044 1.997 1.7811.560 1.994 1.821 _ 1.7_64_ 1.185 _0.976 1.091 2905 3185 2878 6/21/2011 7/14/2011 CPF-1 CPF-1 1.067 1.119 0.279 0.298 68.164 69.426 6.174 6.326 4.719 4.769 3.017 2.864 7.972 7.385 2.557 2.432 2.068 1.973 2.071 2.002 1.917 1.775 1.340 1.048 2796 3050 8/14/2011 CPF-1 1.142 0.288 70.987 -6361-1---4.504 5.018 2.520 7.052 2.338_ 1.914 1.839 1.576 0.909 3315 9/9/2011 CPF-1 1.075 0.288 66.479 --6.-092-T-4.925 7.017 4.713 3.148 8.258 2.873 2.299 2.427 2.164 1.335 2491 10/2/2011 CPF-1 1.128 0.285 69.773 6.227 4.446 2.926 7.497 2.373 1.901 1.986 1.780 1.092 3078 10/15/2011 CPF-1 1.078 0.282 68.304 6.095 4.626 3.189 8.060 2.583 2.084 2.112 1.857 1.091 2842 11/10/2011 CPF-1 1.085 0.279 69.946 6.175 4.615 3.117 7.281 2.334 1.894 1.890 1.671 1.078 3132 1113012011 CPF-1 1.067 0.305 68.414 6.299 4.891 3.063 7.759 2.539 2.089 2.045 1.767 1.133 2892 12/15/2011 CPF-1 1.112 4.269 70.395 6.457 4.513_ 2.777 7.091 2.250 1.849 1.799 1.564 1.005 3252 12/23/2011 CPF-1 1.126 0.282 69.401 6.401 4.872 3.039 7.394 2.347 1.929 1.903 1.666 1.049 3080 12/15/2011 CPF-2 0.942 0.208 69.601 7.771 5.435 2.623 7.011 2.073 1.658 1.564 1 1.383 AVG MMP Target 3010 3300 KUPARUK RIVER UNIT MI COMPOSITION: CPF-2 Date Facility CO2 N2 Cl C2 C3 iC4 nC4 iCS nC5 C6 C7 C8+ MMP (Calc), psia 1/22/2011 CPF-2 1 0.923 0.259 69.345 7.381 5.105 3.267 7.460 1.980 1.555 1.567 1.505 0.836 3271 _ 2/4/2011 CPF-2 0.971 0.296 69.590 8.034 5.732 3.049 7.096 1.810 1.478 1.290 1.188 0.733_ 3448 2/23/2011 CPF-2 0.919 0.281 66.019 7.191 5.137 3.579 8.234 2.467 1.879 2.111 2.028 1.356 2599 3/4/2011 0.946 0.223 69.284 7.509 5.216 3.039 6.977 1.986 1.519 1.683 1.658 1.128 w_.._�. 3213 3/25/2011 _CPF-2 CPF-2 0.907 0.215 69.177 7.578 5.042 3.034 6.972 2.049 1.550 1.756 1.705 1.138 3186 4/2/2011 CPF-2 0.948 0.244 70.766 7.299 5.072 2.813 6.720 1.976 1.568 1.498 1.374 0.915 3467 4/17/2011 CPF-2 0.935 0.270 69.596 7.406 5.283 2.935 6.975 2.083 1.647 1.622 1.485 0.966 3286 5/12/2011 CPF-2 0.926 0.236 68.234 7.208 5.038 3.119 7.636 2.292 1.806 1.826 1.704 1.136 2998 5/31/2011 CPF-2 1.014 0.235 69.768 7.257 5.018 2.823 7.382 2.093 1.658 1.601 1.482 0.917_ 3289 6/21/2011 CPF-2 0.905 0.229 67.785 7.017 4.713 2.782 7.665 2.517 1.963 2.077 2.011 1.470 2800 7/14/2011 CPF-2 1.036 0.238 72.579 7.382 4.976 2.412 6.237 1.778 1.424 1.327 1.196 0.688 3789 8/14/2011 CPF-2 0.922 0.274 66.569 7.121 4.832 2.556 1 8.282 2.885 2.263 2.266 2.004 1.222 2632 91912011 10/2/2011CPF-2 CPF-2 1.056 0.914 0.234 0.258 70.124 69.742 7.802 7.479 5.782 5.302 2.647 2.869 6.818 7.144 1.921 2.131 1.552 1.704 1.349 1.538 1.223 1.327 0.782 0.763 3478_ 3359 10/15/2011_ CPF-2 0.941 0.211 68.032 7.481 5.388 3.110 7.711 2.288 1.823 1.715 1.502 0.948 3056 11/10/2011 CPF-2 0.930 0.217 67.829 7.258 5.239 3.254 7.797 2.333 1.848 1.779 1.595 1.069 2974 11130!2011 CPF-2 0.900 0.218 68.631 7.547_ 5.395 2.849 7.380 2.249 1.792 1.695 1 1.486 1 0.976 3150 12/15/2011 CPF-2 0.942 0.208 69.601 7.771 5.435 2.623 7.011 2.073 1.658 1.564 1 1.383 1 0.882 3344 12/2312011 CPF-2 0.935 0.208 68.027 7.616 5.492 2.850 7.567 2.279 1.815 1 1.745 1 1.570 1 1.039 3048 AVG MMP Target 3178 3300 Attachment 8 Kuparuk River Unit Kuparuk River Oil Pool 2011 Annual Reservoir Surveillance Report LSEOR Development Plan During 2011, the Greater Kuparuk Area (GKA) averaged 17,178 BPD of PBU NGL imports and 7,403 BPD of indigenous NGLs for an annual average of 180 MMSCFD of Miscible Injectant (MI) manufactured. Of the total MI production in 2011, 134 MMSCFD was injected into the Kuparuk Field. Within the main Kuparuk Field, the 134 MMSCFD was allocated as: 3 MMSCFD for the SSEOR and SSEORX drillsites, 41 MMSCFD to the LSEOR drillsites and 90 MMSCFD to the LSEOR expansion drillsites. LSEOR expansion drillsites include drillsites: 1 B, 1 C, 1 D, 1 E, 1 L, 3B, 3G, 3H, 30, 3Q and 3S. Further drilling activity in the Kuparuk River Oil Pool potentially provides new opportunities to maximize field recovery while preventing physical waste. Drilling opportunities, along with their associated miscible gas EOR potential, are under constant evaluation as the field matures, geologic and reservoir performance information is assimilated and as technology improves. Although drillsite 1D is the only recent drillsite-level expansion project, the Kuparuk EOR project may be expanded to include any new wells. MWAG expansion to drillsite 1D was completed during 2008, as part of the LSEOR expansions. Very positive responses from the MI injection have been observed since implementation. 16 1:4oftyiv/:l94V James T. Rodgers Manager, Development ConocoPhillips Greater Kuparuk Area ConocoPhillips Alaska, Inc. ATO -1326 PO Box 100360 Anchorage AK 99510-0360 Phone (907) 263-4027 Fax: (907) 265-6133 March 31, 2012 Mr. Dan Seamount, Commissioner Alaska Oil and Gas Conservation Commission 333 West 7th Ave. Suite 100 Anchorage, Alaska 99501-3539 Re: 2011 Meltwater Oil Pool Annual Reservoir Surveillance Report Dear Commissioner Seamount, In compliance with Rule 10, Conservation Order No. 456, ConocoPhillips Alaska, Inc., operator of the Kuparuk River Field, is hereby submitting the annual surveillance report on the Meltwater Oil Pool. This report documents the required information pertinent to the field development and enhanced recovery operations from January through December 2011. The following is an outline of the information provided: a. Progress of EOR project and reservoir management summary (Attachment 1). b. Voidage balance, by month, for produced and injected fluids (Attachments 2 and 3). c. Analysis of reservoir pressure surveys taken in 2011 (Attachment 4). d. Results of production surveys, and any special surveys, taken on the Meltwater Oil Pool in 2011 (Attachment 5). e. Results of well allocation and test evaluation for Rule 7, and any other special monitoring (Attachment 6). f. Development Plans and Operation Review (Attachments 7 and 8). If you have any questions concerning this data, please contact Mark Kovar at (907) 265-6097. Sincerely, J mes T. Rodgers Manager, GKA Development Greater Kuparuk Area ATTACHMENT 7 Meltwater Oil Pool 2011 Annual Reservoir Surveillance Report Summary of EOR Project and Reservoir Management Summary Background In 2001, CPAI received approvals for formation of the Meltwater Oil Pool in the Kuparuk River Unit, an Area Injection Order for Meltwater, expansion of the Kuparuk River Unit, and formation of the Meltwater Participating Area. The Meltwater Pool Rules and Area Injection Order were approved on August 1, 2001. The Unit Expansion and Participating area were approved effective June 1, 2001. Injection of miscible injectant (MI) began in January 2002 and the MWAG (miscible water alternating gas) process was implemented during May 2003. The Meltwater MWAG process uses Kuparuk spec MI which is injected above the minimum miscibility pressure. For compositional analysis of the Kuparuk spec MI, refer to the Kuparuk section of the annual surveillance report. The Meltwater field currently has 19 total wells (13 producers and 6 injectors). See Attachment 8 for well locations. Progress of EOR Project Development activities in 2011 followed the plans described in the Pool Rules, Area Injection Order, Unit Expansion, and Participating Area (PA) applications. Below is a listing of the key events related to the Meltwater Pool and PA in 2011: Water injection ceased in the Meltwater Field on October 15, 2009. On this date the water injection line to the Meltwater field was declared unsuitable for continued operation due to internal corrosion. Miscible gas injection (MI) continues to maintain voidage replacement for production in the field. At this time there are no near-term plans to restore water injection service to Meltwater. ConocoPhillips does not anticipate any recovery impacts as little pressure support has been observed to date from water injection. Studies are ongoing to determine the future development options for the highly compartmentalized Meltwater reservoir in light of the de -rated water injection pipeline. 2. Due to the high reservoir pressure and lack of clear interactions with offset producers, well 2P- 434 was shut in August 2007. In June 2008, two additional injection wells, 2P-419 and 2P-432, were shut in. In order to facilitate pressure reductions that would allow wells to potentially be safely sidetracked in this area of the reservoir, it was decided to flowback these injectors through the surface header facilities of long term shut-in producers. The initial goal of the project was to reduce pressure in these area to less than 3,300 psi. Well 2P-432, with a bottom hole pressure of 4,366 psi began flowback in February 2009. Plant constraints dictate when the other injectors can commence flowbacks. Shut-in bottomhole pressure for this well was 3,021 psi as of September 2010. The flowback of 2P-432 was discontinued in May 2011 after meeting the stated project objectives. See Page 2 of this report for more details. 3. A total of seven wells including five producers are currently shut-in. Wells 2P -415A, 2P -448A and 2P-451 are shut-in due to insufficient pressure support (reservoir compartmentalization). Well 2P- 438 suffered early water breakthrough in 2007 and has been shut in since. Well 2P-443 is shut-in due to high GOR and appears to be well connected to the injector 2P-420. Well 2P-406 is temporarily shut-in after a hole was detected in the surface casing. It is undergoing repairs and should be back online by the end 2012. Well 2P-443 has a history of severe paraffin deposition and freezing problems and it will be an intermittent producer for the foreseeable future. 4. While most producer/injector patterns see fairly limited communication, several producers have shown strong responses to gas injection. Well 2P -424A saw a relatively strong response beginning December 2008. This production response is suspected to be a result of offset gas injection into 2P-427 which commenced in June 2008. This improved performance has been observed since 2009 and continues through 2011. In early 2009, well 2P-417 started responding in a similar way to MI injection into well 2P-420 that commenced in June 2008. Well 2P -417's incremental oil rate associated to this event peaked at approximately 1,000 bopd in December 2009 and began to decline steadily. Well 2P-417 is again producing in excess of 1,000 bopd likely due to the restart of gas injection in 2P-429 following the end of the injector flowback in well 2P-432. 2P-441 resumed production in April 2011 at an initial rate in excess of 2,000 bopd and has been declining since. This is likely due to offset injection support. Significant Studies in Progress Work is ongoing to rebuild the Meltwater subsurface model. Much of the work involves analyzing the new seismic data obtained during winter 2007-2008. The analysis of this 4D seismic data should provide a better interpretation of the reservoir architecture and communication between producers and injectors. Preliminary studies of certain 4D effects, such as changes in amplitudes and velocities, show clear trends of anomalies in the form of lineaments that match the location of active injectors and trend in a NNW -SSE direction. The hydraulic significance of these trends cannot be fully understood from seismic analysis and an extensive pressure monitoring and well interaction analysis was initiated to understand their significance to development planning. The direction of the anomalies observed in the new seismic data coincides with the direction of preferential flow from injectors to producers that has been identified at the Tarn and Meltwater fields by means of production surveillance and well interaction analyses. Fluids injected into the reservoir above parting pressure (required to achieve adequate injectivity) probably propagate quickly along the plane perpendicular to the minimum stress opening fractures or traveling in a pre-existing fracture system. Producers aligned on this trend with injectors are susceptible to early water breakthrough and multiple injectors aligned on this axis may link up forming a single injection line. 2. As mentioned earlier in this document, a flowback from the injection well 213-432 was started in February 2009 in an attempt to decrease reservoir pressures to levels at which sidetracks could be drilled. Well 2P-432 initially flowed at approximately 3,000 bbl/day with 100% water showing only traces of oil and gas. Pressure surveys early in 2009 indicated no change in reservoir pressure. In addition, the three injection wells (2P-429, 2P-432, and 2P-434) along the central anomaly showed nearly identical reservoir pressures suggesting they were hydraulically connected. When injection water supply to Meltwater ceased on October 15, 2009, the injection well 2P-429 that was still injecting water at that time was shut in. After an initial spike in oil production, watercut stabilized at ^-90% while gas -oil ratio increased. This confirmed their hydraulic connection and these three wells effectively act as one line -drive injector when in water injection service. The last pressure survey (September 4, 2010) showed that the pressure decreased approximately 1200 psi to 3021 psi after injection in well 2P-429. The flowback at 2P-432 contributes to higher fluid velocities in the produced oil line helping to minimize corrosion in this valuable pipeline and higher temperatures will reduce backpressure at the drillsite thereby minimizing production impacts. However, in late 2010 and early 2011, it was suspected that inability to inject gas into the central conduit due to the hydraulic connection between injectors was significantly impacting offset producers. The flowback of 2P-432 was discontinued in May 2011 to allow for the restart of gas injection in 2P-429. In addition, a long-term pressure interaction survey between 2P-434 and 2P-429 was initiated to understand the impact of gas injection on the hydraulic connection between these wells. This study will conclude in Q1 2012. 3. Outer annuli pressures in 2P-406, 2P-417, 2P-431, 2P-432, 2P-438, 2P-447, 2P -448A, and 2P- 451 remained at elevated levels in 2011. Fluid levels continue to be shot monthly for these wells and the calculated pressures at the C-80 interval are still below the measured/calculated leak off (refer to table of elevated OA pressures in Meltwater -Attachment 6). Reservoir Management Summary Meltwater came on-line in November of 2001 and has cumulatively produced 16.1 MMBO, 3.21 MMBW, and 39.2 BCF of gas by year-end 2011. Miscible gas injection began in 2002 with water injection beginning in 2003 (MWAG cycles). Cumulative injection through year-end 2011 at Meltwater has been 25.1 MMBW and 54.8 BCF of gas (48.9 BCF of MI gas and 5.9 BCF of lean gas). Water injection ceased on October 15, 2009 when the water injection line had to be taken out of service due to operational constraints caused by areas of excessive under -deposit corrosion pitting. When phase II injection wells were drilled in 2004, cumulative injection/withdrawal (IM) for the field was approximately 0.75. INV rates for subsequent years were approximately 1.5 to restore adequate voidage replacement. In late 2004, cumulative INV reached 1.0 and climbed to a peak of 1.3 by 2009. Despite three injectors being taken off-line in 2008, instantaneous INV remained above 2.0 for much of 2008. While it would have been advantageous to continue decreasing injection at that time, a minimum amount of both gas and water had to be transported to Meltwater to maintain line velocities in order to minimize corrosion in the water line and freezing in the gas line. Despite these efforts, the water injection line to Meltwater had to be taken out of service on October 15, 2009 based on results obtained from a "smart pig" run and additional follow-up surveys completed during 2009. Currently, the plan is to balance voidage with gas injection. (Refer to letters to AOGCC dated December 21, 2009 and December 15, 2010). The cumulative year-end 2011 INV ratio is 1.21. Attachment 2 Meltwater Oil Pool 2011 Annual Reservoir Surveillance Report Produced Fluid Volumes 2011 TOTAL 974843 3603469 214855 Cumulatives at Dec 31, 2010 15105781 35611749 2957987 Produced Fluid Volumes (Reservoir Units) OIL GAS WATER CUM OIL CUM GAS CUM WATER MO YR STB MSCF STB STB MSCF STB 1 2011 67795 340562 48777 15173576 35952311 3006764 2 2011 62759 334765 41351 15236335 36287076 3048115 3 2011 65049 343630 42460 15301384 36630706 3090575 4 2011 91926 370655 35995 15393310 37001361 3126570 5 2011 93528 346538 21682 15486838 37347899 3148252 6 2011 94515 278262 4350 15581353 37626161 3152602 7 2011 73858 226261 1917 15655211 37852422 3154519 8 2011 86186 288394 2817 15741397 38140816 3157336 9 2011 79296 305795 4055 15820693 38446611 3161391 10 2011 83926 263445 4723 15904619 38710056 3166114 11 2011 80423 233141 2349 15985042 38943197 3168463 12 2011 95582 272021 43790 Q -i 8F' 2011 TOTAL 974843 3603469 214855 Cumulatives at Dec 31, 2010 15105781 35611749 2957987 Produced Fluid Volumes (Reservoir Units) 2011 TOTAL 1301415 2271769 217863 Cumulatives at Dec 31, 2010 20124910 23964256 2993655 OIL GAS WATER CUM OIL CUM GAS CUM WATER MO YR RVB RVB RVB RVB RVB RVB 1 2011 90506 226089 49460 20215417 24190345 3043114 2 2011 83783 224057 41930 20299200 24414402 3085044 3 2011 86840. 229696 43054 20386040 24644098 3128099 4 2011 122721 237580 36499 20508762 24881678 3164598 5 2011 124860 218574 21986 20633622 25100253 3186583 6 2011 126178 166428 4411 20759799 25266681 3190994 7 2011 98600 136727 1944 20858399 25403408 3192938 8 2011 115058 177994 2856 20973458 25581402 3195795 9 2011 105860 194390 4112 21079318 25775792 3199906 10 2011 112041 160165 4789 21191359 25935957 3204695 11 2011 107365 138864 2382 21298724 26074821 3207077 12 2011 127602 161204 4440 ON27 ,,.. 2011 TOTAL 1301415 2271769 217863 Cumulatives at Dec 31, 2010 20124910 23964256 2993655 Attachment 3 Meltwater Oil Pool 2011 Annual Reservoir Surveillance Report Injected Fluid Volumes 2011 TOTAL 0 113,710 5,837,343 Cumulatives at Dec 31, 2010 25,136,450 5,805,077 43,110,559 Injected Fluid Volumes (Reservoir Units) WATER GAS MI CUM WATER CUM GAS CUM MI MO YR STB MSCF MSCF STB MSCF MSCF 1 2011 0 0 283,467 25,136,450 5,805,077 43,394,026 2 2011 0 0 363,202 25,136,450 5,805,077 43,757,228 3 2011 0 0 612,176 25,136,450 5,805,077 44,369,404 4 2011 0 0 495,497 25,136,450 5,805,077 44,864,901 5 2011 0 0 491,601 25,136,450 5,805,077 45,356,502 6 2011 0 0 511,418 25,136,450 5,805,077 45,867,920 7 2011 0 113,710 341,128 25,136,450 5,918,787 46,209,048 8 2011 0 0 586,117 25,136,450 5,918,787 46,795,165 9 2011 0 0 456,242 25,136,450 5,918,787 47,251,407 10 2011 0 0 541,520 25,136,450 5,918,787 47,792,927 11 2011 0 0 552,888 25,136,450 5,918,787 48,345,815 12 2011 0 0 602,087 0 0 2011 TOTAL 0 113,710 5,837,343 Cumulatives at Dec 31, 2010 25,136,450 5,805,077 43,110,559 Injected Fluid Volumes (Reservoir Units) 2011 TOTAL 0 126,104 4,418,869 Cumulatives at Dec 31, 2010 25,488,360 6,929,995 36,637,138 WATER GAS MI CUM WATER CUM GAS CUM MI MO YR RVB RVB RVB RVB RVB RVB 1 2011 0 0 214,585 25,488,360 6,929,995 36,851,722 2 2011 0 0 274,944 25,488,360 6,929,995 37,126,666 3 2011 0 0 463,417 25,488,360 6,929,995 37,590,083 4 2011 0 0 375,091 25,488,360 6,929,995 37,965,175 5 2011 0 0 372,142 25,488,360 6,929,995 38,337,317 6 2011 0 0 387,143 25,488,360 6,929,995 38,724,460 7 2011 0 126,104 258,234 25,488,360 7,056,099 38,982,694 8 2011 0 0 443,691 25,488,360 7,056,099 39,426,385 9 2011 0 0 345,375 25,488,360 7,056,099 39,771,760 10 2011 0 0 409,931 25,488,360 7,056,099 40,181,690 11 2011 0 0 418,536 25,488,360 7,056,099 40,600,227 12 2011 0 0 455,780 0 2011 TOTAL 0 126,104 4,418,869 Cumulatives at Dec 31, 2010 25,488,360 6,929,995 36,637,138 ATTACHMENT 4 Meltwater Oil Pool 2011 Annual Reservoir Surveillance Report Reservoir Pressure Surveys ConocoPhillips March 31, 2012 Mr. Dan Seamount, Commissioner Alaska Oil and Gas Conservation Commission 333 West 7th Ave. Suite 100 Anchorage, Alaska 99501-3539 Re: Meltwater Oil Pool — Proposed Pressure Survey Plan for 2012 James T. Rodgers Manager, GKA Development Greater Kuparuk Area ConocoPhillips Alaska, Inc. ATO -1326 PO Box 100360 Anchorage AK 99510-0360 Phone (907) 263-4027 Fax: (907) 265-6133 Dear Commissioner Seamount, In compliance with Rule 7, Conservation Order No. 456A, ConocoPhillips Alaska, Inc., operator of the Meltwater Oil Pool, is hereby submitting the proposed pressure survey plan for 2012. There were 6 pressure surveys reported for the Meltwater Oil Pool to the AOGCC in 2011. In 2012, we expect to conduct approximately 6 pressure surveys. If you have any questions concerning this data, please contact Mark Kovar at (907) 265-6097. Sincerely, ames T. Rodgers Manager, GKA Development Greater Kuparuk Area ALASKA OIL AND GAS CONSERVATION COMMISSION RESERVOIR PRESSURE REPORT 1. Operator. ConocoPhilli s Alaska Inc. 2. Address: P. O. Box 100360, Anchora e, AK 99510-0360 3. Unit or Lease Name: Ku aruk River Unit 4. Field and Pool: Meltmter Oil Pool 5. Datum Reference: -5400' SS 6. Oil Gravity: 7. Gas Gravity: 0.85 water = 1.0 0.74 8. Well Name and Number. 9. API Number 10. Type 50� See NO DASHES Instructions 11. AOGCC Pool Code 12. Zone 13. Perforated Intervals Top Bottom TVDSS 14. Final Test Date 15. Shut -In 16. Press. Time, Hours Surv. Type (see instructions for codes) 17. B.H. 18. Depth Tool Temp. TVDSS 19. Final Observed Pressure at Tool Depth 20. Datum 21. Pressure TVDSS (input) Gradient, psilft. 22. Pressure at Datum (cal) 2P-406 50029214250200 PROD 490140 A -5339--5354 10/10111 300 SBHP 138 5346 1088 5,400 0.320 1105 2P -415A 50029214470000 PROD 490140 A -5431 --5441 07/22/11 14600 SBHP 142 5431 1457 5,400 0.320 1447 2P-429 50029214470000 [NJ 490140 -5299 - -5336, -5370--5399, -5420--5448, A -5482--5488 06/07/11 14352 SBHP 131 5109 2655 5,400 0.300 2742 2P-441 50029214620000 PROD 490140 A -5266--5274 08/08/11 140 SBHP 137 5261 1055 5,400 0.320 1099 2P -448A 50029214620000 PROD 490140 A -5184--5196 09/01/11 21788 SBHP 130 4892 2155 5,4001 0.320 2318 I hereby certify that the fo of true and comet Signature Printed Name �1 kn�e. � -J Title J[ .- !V/// Date 3/31// 2 -- Form 10-412 Rev. 12/2008 INSTRUCTIONS ON REVERSE SIDE Submit in Duplicate ATTACHMENT 5 Meltwater Oil Pool 2011 Annual Reservoir Surveillance Report Production & Special Surveys During 2011, no production/injection profile logs or special surveillance logs were run. A four week flowing bottomhole pressure survey (FBHP) was conducted in February 2011 in well 2P-431. This data was gathered to better understand downhole flow charateristics of gas -lifted Meltwater wells. The FBHP of well 2P-431 was between -675 and —725 psi during the survey. The large drop in FBHP at—625hrs is the result of pumping warm diesel down the tubing to remove paraffin buildup. 12P-431 FBHP Data Top Gauge - Bottom Gauge 2p Header Pressure 760 260 725 226 700 200 676 176 660 160 0 100 200 300 400 600 600 700 Elapsed Time (hours) ATTACHMENT 6 Meltwater Oil Pool 2011 Annual Reservoir Surveillance Report Results of Well Allocation, Test Evaluation, and Special Monitoring Well Allocation Meltwater drillsite 2P facilities were fabricated with a conventional test separator. A minimum of two well tests per month are taken on production wells. Test separator backpressure corrections are applied to wells that experienced greater than 100 psi backpressure over header pressure. Correction to stock tank barrel conditions are made by applying Meltwater specific pressure corrections (derived from the PVT analysis of Meltwater North #1 crude oil samples) and API temperature corrections. Miscible gas is used for injection and gas lift at drillsite 2P. For the wells that were on MI lift during a well test, the metered liquid rates are adjusted for NGLs associated with MI lift. Production volumes are tracked through an automated production monitoring SCADA system (SetCIM). The 2011 Meltwater allocation factors by month are listed below. Month Oil Water Gas Jan -11 0.965 1.058 0.990 Feb -11 0.943 1.031 0.998 Mar -11 0.954 1.051 1.002 Apr -11 0.954 1.049 0.959 May -11 0.899 1.001 0.925 Jun -11 0.887 1.021 0.960 Jul -11 0.813 1.019 0.928 Aug -11 0.909 1.088 0.961 Sep -11 0.867 1.039 0.975 Oct -11 0.874 1.075 0.967 Nov -11 0.882 1.070 0.965 Dec -11 0.886 1.063 0.970 Shallow Gas Special Monitoring Wells 2P-406, 2P-431, 2P-432, 2P-434, 2P-438, 2P-441, 2P-447, 2P -448A and 2P-451 have a history of elevated outer annulus (OA) pressures that may rebuild pressure after bleeding. The surface pressures are monitored daily via SetCIM (wells have pressure transducers that transmit real-time OA pressures). Fluid levels are surveyed approximately once per month via echometer measurements. Calculations are then made to determine the approximate pressures in the outer annulus at the C-80 interval in each of the wells that have elevated surface OA pressures. This data is then sent to the AOGCC on a semi-annual basis. (See table on following page). Throughout 2011 all wells under shallow gas special monitoring exhibited relatively stable or decreasing OA pressures. While there appears to be a connection between the cessation of injection in these wells and declining OA pressures, OAP and injection rates do not match up in time. Therefore, there is inconclusive evidence to say there is a relationship between the two. Well 2P -406's outer annulus was cemented to surface in early 2012 and therefore has been since removed from the Metwater OA pressure survey for 2011. The OA pressure of well 2P-434 has declined to less than 150 psig at surface since cessation of injection into this well in August 2007. Meltwater OA pressure survey for 2011 2P-431 2P-417 2P-432 2P-451 2P-434 Date Surface Casin CA FL TVD 2P-438 Surface Casin OA FL TVD From Press @ Equivalen C-80 Ton t Mud Vert Date Surface Casing Pressure CA FL (TVD From Surface) Press @ C-80 To Equivalen t Mud VA Surface Casing Pressure OA FL (TVD From Surface Press @ C-80 Ta Equivalen t Mud Vert Surface Casing Pressure CA FL (TVD From Surfac2L Press @ C- 80 Ta Equivalen t Mud VA Surface Casing Pressure CA FL (TVD From Surface Press @ C-80 Ta Equivalen t Mud VIA 1 f29f2011 1545 2433 1683.34 2161 13.3163 8.86044 1160 1753 1371 10.83 88 BBB 615.5557 4.81987 736 1518 985.994 1411.7797 7.78703 32!2011 1550 2405 1694.48 46f2011 13.4044 1993 853 1770 1057 8.35 88 660 617.24151 4.83307 726 1513 976.517 2167 7.71218 402011 1547 2402 1689.48 1355.59 13.3649 1040 1071 1759 1277 10.09 87 582 638.15709 4.99685 723 1524 969.743 6f20f2011 7.65869 5992011 1442 2417 1570.39 94 12.4228 12.31 997 1608 1227 9.69 88 600 634.09965 4.96507 714 1422 980.995 1272.37 7.74755 6f20f2011 1562 2372 1710.94 1237 13.5347 1333.6416 1160 1664 1386 10.95 87 575 640.12387 5.01225 703 1486 955.63 32 7.54723 7A 5f2011 1501 2507 1624.07 10.3987 12.8474 2187 1181 1632 1414 11.17 89 550 649.14811 5.08291 697 1510 944.663 1207 7.46062 8A 4!2011 1504 2405 1641.38 1386.55 12.9844 10992011 1211 1620 1448 11.44 90 534 654.64362 5.12594 689 1513 936.821 10.1729 7.39868 914!2011 1549 2417 1689.41 1002 13.3643 1176.93 1192 1610 1429 11.29 91 496 666.32046 5.21737 1 684 1522 929.902 1163.93 7.34403 10992011 1544 2410 1685.38 9.2382 13.3324 1 13 1041 1632 1268 10.02 91 970 533.21337 4.17512 675 2487 712.367 952 5.62602 11!4!2011 1543 2426 1682.31 1 1669 13.3081 1153 1 933 1666 1154 9.12 91 541 653.67683 5.11837 BBB 1499 917.828 1 8.56922 1 7.24868 12!3!2011 1550 2409 1693.93 2472 13.4 840 1663 1066 8.42 91 925 545.80952 4.27375 647 1494 900.926 7.1152 12!31 t201 1546 2058 1735.23 13.7268 791 1876 974 7.69 89 377 697.759 5.46354 643 1421 912.826 7.20918 2!8!2012 1552 2417 11694.81 13.4071 1 697 1659 912 1 7.21 87 480 666.816 5.22125 638 1502 889.989 7.02882 2P-411 2P-417 2P -418A 2P-451 Date Surface Casin CA FL TVD Press @ Equivalen C-80 Ton t Mud Wt Surface Casin OA FL TVD From Press @ Equivalen C-80 Ton t Mud Vert Surface Casin OA FL TVD Press @ C- 80 Top Equivalen t Mud Wt Surface Casin OA FL TVD Press @ Equivalen C-80 Ton t Mud Wt 1 f29f2011 978 1953 1144.84 9.01197 1041 10 1573 12.36 1315 2405 1431 .3608 11.3138 994 2161 1116.38 8.86044 3!3!2011 976 1978 1138.05 8.95852 1109 10 1633 12.84 1306 2456 1411.7797 11.1589 1002 2207 1115.77 8.85561 46f2011 974 1993 1133.23 8.92054 938 10 1482 11.64 1294 2482 1395.6399 11.0313 1012 2167 1135.22 9.00993 59 2011 1167 1893 1355.59 10.6709 1040 10 1572 12.35 1272 2456 1375.3003 10.8706 1025 2207 1140.76 9.05396 6f20f2011 1128 1891 1314.21 10.3452 1050 94 1566 12.31 1247 2465 1343.91 10.6225 1053 2201 11173.79 9.31605 7f15f2011 1089 1892 1272.37 10.0159 970 36 1506 11.84 1237 2466 1333.6416 10.5413 1069 2192 1191.52 9.45682 M 4!2011 1016 1923 1189.48 9.3633 1111 32 1629 12.80 1223 2476 1315.6024 10.3987 1066 2187 1189.39 9.43991 914!2011 1104 1907 1285.95 10.1227 940 10 1484 11.66 1207 2462 1299.4667 10.2712 1063 1099 1386.55 11.0047 10992011 1054 1894 1235.72 9.72732 1000 33 1532 12.04 1190 2435 1287.0289 10.1729 1052 2200 1172.96 9.30949 11 !4!2011 1002 1908 1176.93 9.26456 1150 2766 1187 9.33 1181 2466 1270.1422 10.0394 1046 2206 1163.93 9.23782 12!3!2011 992 1873 1173.58 9.2382 1156 1 13 1673 13.14 1166 1 2466 11252.6424 19.90106 1 1046 2200 1164.98 9.24618 12!31(2011 952 1686 11170.61 1 9.21481 1 1150 1 10 1 1669 13.12 1153 1 2321 11264.8661 19.99768 1 1046 1 1602 11276.19 10.1288 2!8!2012 901 1857 1 1088.6 1 8.56922 1 1100 1 2183 1 1233 9.69 1134 1 2472 11217.0991 19.62012 1 970 1 2224 1108094 8.57916 ATTACHMENT 7 Meltwater Oil Pool 2011 Annual Reservoir Surveillance Report Meltwater Development Plans and Operational Review Following are summaries of key activities in 2011. Development Drilling Development opportunities are being analyzed in light of the new seismic data, recent surveillance findings and the absence of injection water supply. Digital processing of the 2007-2008 winter seismic survey is complete and the data is being analyzed. This data will help in evaluating the potential of the peripheral edges of the Meltwater pool, analyzing producer -injector patterns, and identifying infill drilling potential. Well 2P-432 began flowback operations in February 2009 to decrease the elevated reservoir pressures in this portion of the reservoir. This flowback ended in May 2011. The flowback decreased pressure around this well to less than 3300 psig and will make potential sidetrack operations safer. Further flowbacks are not planned at this time. Pipeline Operations Due to low flow rates through the water injection line, there has been awareness of increased risk for microbial -induced under -deposit corrosion and increased diagnostic work was being conducted. Frequent pigging of the production and water injection lines was conducted to minimize effects of under -deposit corrosion. Despite these efforts, the water injection line had to be taken out of service on October 15, 2009, due to operational constraints caused by areas of excessive under -deposit corrosion pitting. A proactive maintenance pigging and inspection operation continues on the produced oil pipeline from the Meltwater drillsite. Exploration/Delineation No further exploration work is currently planned for the Bermuda interval. However, the overlying Cairn sand, believed to be gas bearing, had been targeted for 2009 development in order to supply fuel gas to the Kuparuk facilities. Pre -drill engineering and geologic assessments determined that probable volumes accessible from the 2P pad were insufficient for economic development. ATTACHMENT 8 Meltwater Oil Pool 2011 Annual Reservoir Surveillance Report Map showing Development as of December 31, 2011 Meltwater Participating Area / Kuparuk River Unit Le"rid • IXl P d - 1d INJ, MWAG 4- P -A Meltwater sand pq 25 ft W Oft ConocoPhillips Alaska; Inc. Meltwater Oil Pool Development through December 2011 NCONFIDENTIAL At o,n a,, o, h�twPwW—d CSR YSUN TABASCO James T. Rodgers ConocoPhillips Manager, Development Greater Kuparuk Area ConocoPhillips Alaska, Inc. ATO -1326 PO Box 100360 Anchorage AK 99510-0360 Phone (907) 263-4027 Fax: (907) 265-6133 March 31, 2012 Mr. Dan Seamount, Commissioner Alaska Oil and Gas Conservation Commission 333 West 7th Ave. Suite 100 Anchorage, Alaska 99501-3539 Re: 2011 Tabasco Oil Pool Annual Reservoir Surveillance Report Dear Commissioner Seamount, In compliance with Rule 11, Conservation Order No. 435, ConocoPhillips Alaska, Inc., operator of the Kuparuk River Field, is hereby submitting the annual surveillance report on the Tabasco Oil Pool. This report documents the required information pertinent to the field development and enhanced recovery operations from January through December 2011. The following is an outline of the information provided: a. A summary of the enhanced recovery project (Attachment 1). b. Voidage balance, by month, for produced and injected fluids (Attachments 2 and 3). c. Analysis of reservoir pressure surveys taken in 2011 (Attachment 4). d. Results of production surveys, and any special surveys, taken on the Tabasco Oil Pool in 2011 (Attachment 5). e. Results of well allocation and test evaluation for Rule 7, and any other special monitoring (Attachment 6). f. Development plans and operational review (Attachment 7). If you have any questions concerning this data, please contact Mark Kovar at (907) 265-6097. Sincerely, -James T. Rodgers Manager, GKA Development Greater Kuparuk Area ATTACHMENT 1 Tabasco Oil Pool 2011 Annual Reservoir Surveillance Report Summary of the Enhanced Recovery Project Tabasco produced 587 MBO of crude, 92 MMSCF of gas, and 5197 MBW during 2011. Water injection was 5615 MBW over the same period. Cumulative oil, gas, water production, and water injection through year-end 2011 were 16.95 MMBO, 2.8 BCF, 70.52 MMBW, and 81.48 MMBWI, respectively. The cumulative year-end 2011 INV ratio, based on current formation volume factors, is estimated at 0.92 for Tabasco. Year-end 2011 Tabasco well count (all at Kuparuk River Unit Drill Site 2T) was: Producers: 9 completed 6 on-line Injectors: 3 completed 1 on-line The water oil ratio (WOR) was 10.05 at the end of 2011 compared to 7.48 at the end of 2010. Water breakthrough has occurred at all producers. Production and injection logs, coupled with the structural positions and water breakthrough histories of the producers, suggest that the water production mechanism is dominated by gravity -induced slumping. Attachment 2 Tabasco Oil Pool 2011 Annual Reservoir Surveillance Report Produced Fluid Volumes Cumulatives at Dec 31, 2010 16,364,504 2,705,366 65,326,843 Produced Fluid Volumes (Reservoir Units) OIL GAS WATER CUM OIL CUM GAS CUM WATER MO YR STB MSCF STB STB MSCF STB 1 2011 49,459 5,847 365,757 16,413,963 2,711,213 65,692,600 2 2011 52,773 7,574 370,031 16,466,736 2,718,787 66,062,631 3 2011 52,324 8,289 435,563 16,519,060 2,727,076 66,498,194 4 2011 53,704 9,196 550,226 16,572,764 2,736,272 67,048,420 5 2011 50,992 8,205 461,689 16,623,756 2,744,477 67,510,109 6 2011 51,462 8,088 414,045 16,675,218 2,752,565 67,924,154 7 2011 42,565 6,536 367,478 16,717,783 2,759,101 68,291,632 8 2011 49,888 8,767 494,839 16,767,671 2,767,868 68,786,471 9 2011 47,302 7,785 458,449 16,814,973 2,775,653 69,244,920 10 2011 49,319 8,067 489,017 16,864,292 2,783,720 69,733,937 11 2011 46,828 7,855 470,852 16,911,120 2,791,575 70,204,789 12 2011 40,448 6,310 318,998 2011 TOTAL 587,064 92,519 5,196,944 Cumulatives at Dec 31, 2010 16,364,504 2,705,366 65,326,843 Produced Fluid Volumes (Reservoir Units) Cumulatives at Dec 31, 2010 17,320,068 76,215 65,326,843 OIL GAS WATER CUM OIL CUM GAS CUM WATER MO YR RVB RVB RVB RVB RVB RVB 1 2011 52,427 0 365,757 17,372,495 76,215 65,692,600 2 2011 55,939 19 370,031 17,428,434 76,234 66,062,631 3 2011 55,463 96 435,563 17,483,898 76,330 66,498,194 4 2011 56,926 168 550,226 17,540,824 76,498 67,048,420 5 2011 54,052 107 461,689 17,594,875 76,605 67,510,109 6 2011 54,550 88 414,045 17,649,425 76,693 67,924,154 7 2011 45,119 58 367,478 17,694,544 76,751 68,291,632 8 2011 52,881 178 494,839 17,747,425 76,929 68,786,471 9 2011 50,140 116 458,449 17,797,565 77,045 69,244,920 10 2011 52,278 116 489,017 17,849,843 77,161 69,733,937 11 2011 49,638 130 470,852 17,899,481 77,291 70,204,789 12 2011 42,875 65 318,998 2011 TOTAL 622,288 1,141 5,196,944 Cumulatives at Dec 31, 2010 17,320,068 76,215 65,326,843 Attachment 3 Tabasco Oil Pool 2011 Annual Reservoir Surveillance Report Injected Fluid Volumes Cumulatives at Dec 31, 2010 75,867,045 0 0 Injected Fluid Volumes (Reservoir Units) WATER GAS MI CUM WATER CUM GAS CUM MI MO YR STB MSCF MSCF STB MSCF MSCF 1 2011 313,810 0 0 76,180,855 0 0 2 2011 453,773 0 0 76,634,628 0 0 3 2011 497,392 0 0 77,132,020 0 0 4 2011 616,017 0 0 77,748,037 0 0 5 2011 478,087 0 0 78,226,124 0 0 6 2011 473,403 0 0 78,699,527 0 0 7 2011 447,981 0 0 79,147,508 0 0 8 2011 488,673 0 0 79,636,181 0 0 9 2011 488,440 0 0 80,124,621 0 0 10 2011 481,586 0 0 80,606,207 0 0 11 2011 454,465 0 0 81,060,672 0 0 12 2011 422,181 0 0 2011 TOTAL 5,615,808 0 0 Cumulatives at Dec 31, 2010 75,867,045 0 0 Injected Fluid Volumes (Reservoir Units) Cumulatives at Dec 31, 2010 75,867,052 0 0 WATER GAS MI CUM WATER CUM GAS CUM MI MO YR RVB RVB RVB RVB RVB RVB 1 2011 313,810 0 0 76,180,862 0 0 2 2011 453,773 0 0 76,634,635 0 0 3 2011 497,392 0 0 77,132,027 0 0 4 2011 616,017 0 0 77,748,044 0 0 5 2011 478,087 0 0 78,226,131 0 0 6 2011 473,403 0 0 78,699,534 0 0 7 2011 447,981 0 0 79,147,515 0 0 8 2011 488,673 0 0 79,636,188 0 0 9 2011 488,440 0 0 80,124,628 0 0 10 2011 481,586 0 0 80,606,214 0 0 11 2011 454,465 0 0 81,060,679 0 0 12 2011 422,181 0 0 2011 TOTAL 5,615,808 0 0 Cumulatives at Dec 31, 2010 75,867,052 0 0 ATTACHMENT 4 Tabasco Oil Pool 2011 Annual Reservoir Surveillance Report Reservoir Pressure Surveys ConocoPhillips March 31, 2012 Mr. Dan Seamount, Commissioner Alaska Oil and Gas Conservation Commission 333 West 7'h Ave. Suite 100 Anchorage, Alaska 99501-3539 Re: Tabasco Oil Pool — Proposed Pressure Survey Plan for 2012 James T. Rodgers Manager, GKA Development Greater Kuparuk Area ConocoPhillips Alaska, Inc. ATO -1326 PO Box 100360 Anchorage AK 99510-0360 Phone (907) 263-4027 Fax: (907) 265-6133 Dear Commissioner Seamount, In compliance with Rule 8, Conservation Order No. 435A, ConocoPhillips Alaska, Inc., operator of the Tabasco Oil Pool, is hereby submitting the proposed pressure survey plan for 2012. One pressure survey was reported for the Tabasco Oil Pool to the AOGCC in 2011. A static bottom hole pressure was obtained on well 2T-202 as part of preparations for its upcoming rig workover. Our plan is to acquire six BHPS. If you have any questions concerning this data, please contact Mark Kovar at (907) 265-6097. Sincerely, J rhes T. Rodgers Manager, GKA Development Greater Kuparuk Area STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION RESERVOIR PRESSURE REPORT 1. Operator: ConocoPhilli s Alaska Inc. 2. Address: I P. O. Box 100360, Anchora e, AK 99510-0360 3. Unit or Lease Name: Ku aruk River Unit 4. Field and Pool: Tabasco Oil Pool 5. Datum Reference: -3000' SS 6. Oil Gravity: 0.96 (water= 1.0) 7. Gas Gravity: 0.572 8. Well Name and Number: 9. API Number 50xxxxxxxxxxxx NO DASHES 10. Type 11. AOGCC See Pool Code Instructions 12. Zone 13. Perforated Intervals Top Bottom TVDSS 14. Final Test Date 15. Shut -In 16. Press. 17. B.H. Time, Hours Surv. Type Temp. (see instructions for codes) 18. Depth Tool 19. Final TVDSS Observed Pressure at Tool Depth 20. Datum TVDSS (input) 21. Pressure 22. Pressure at Gradient, psi/ft. Datum (cal) 2T-202 490160 PROD 490160 A -2918 - -3194 12/21/11 388 SBHP 76 2590 1204 5,400 0.400 1368 23. All tests reported herein were made in accordance with th pplica rules, regulations and instructions of the Alaska Oil and Gas Conservation Commission. I hereby certify that the foreg is true and co ct to o my owledge. �� ) Signature [✓ v _D Title J d^ , y l Printed Name ' Ur � Date 1; l Form 10-412 Rev. 12/2008 INSTRUCTIONS ON REVERSE SIDE Submit in Duplicate ATTACHMENT 5 Tabasco Oil Pool 2011 Annual Reservoir Surveillance Report Production Logs and Special Surveys Only one special survey was run during 2011. This log was run on well 2T-220 to inspect the production casing during rig work over operations. Data was collected from 2200' TVD to surface as the tool was unable to get below this depth. Inspection of the results showed the production casing was in good condition and did not warrant replacement. There are rig workovers planned for 2012 where this same log will be run during each. Since production wells are completed with gravel pack screens and electrical submersible pumps, no production logs are planned for 2012 ATTACHMENT 6 Tabasco Oil Pool 2011 Annual Reservoir Surveillance Report Results of Well Allocation A minimum of two well tests per month are conducted on production wells. Fluid samples are obtained on a regular basis, and water cut corrections are applied to well tests as required based on subsequent lab analysis. Generally, good agreement was observed for water cuts comparing phase dynamics and shakeout analysis. Production volumes are tracked through the Setcim production monitoring SCADA system. In 2002, Tabasco switched from an allocation factor of 1.0 to floating production allocation factors. Tabasco 2011 production allocation factors were as follows: Month Oil Gas Water Jan -1 1 0.9898 0.9651 1.0582 Feb -1 1 0.9981 0.9428 1.0309 Mar -11 1 1.0019 0.9635 1.0510 A. 1 • °+ 0.9534 1.0488 May -1 1 0.9656 1 ' 1: 1.0349 Jun -1 1 0.9605 1 :: ! 1.0213 Jul -1 1 0.9279 0.8124 1.0152 Aug -1 0.9612 1 '1'. 1.0857 Sep -1 1 0.9754 0.6674 141 ATTACHMENT 7 Tabasco Oil Pool 2011 Annual Reservoir Surveillance Report Development Plans and Operational Review Tabasco injection withdrawal ratios (INV ratio) are monitored to maintain an instantaneous value of 1.0 or greater. Adjustments to injection and/or production rates are made to maintain an instantaneous INV ratio of 1.0 or greater so that gas will remain in solution and pressure support maintained for the Tabasco reservoir. There are rig workovers scheduled during 2012 for some Tabasco producers. These rig workovers will consist of pulling and replacing the current ESP completions with new ESP under packer completions TARN ConocoPhillips March 31, 2012 Mr. Dan Seamount, Commissioner Alaska Oil and Gas Conservation Commission 333 West 7th Ave. Suite 100 Anchorage, Alaska 99501-3539 Re: 2011 Tarn Oil Pool Annual Reservoir Surveillance Report Dear Commissioner Seamount, James T. Rodgers Manager, GKA Development Greater Kuparuk Area ConocoPhillips Alaska, Inc. ATO -1326 PO Box 100360 Anchorage AK 99510-0360 Phone (907) 263-4027 Fax: (907) 265-6133 In compliance with Rule 11, Conservation Order No. 430, ConocoPhillips Alaska, operator of the Kuparuk River Field, is hereby submitting the annual surveillance report on the Tarn Oil Pool. This report documents the required information pertinent to the field development and enhanced recovery operations from January through December 2011. The following is an outline of the information provided: a. A summary of the enhanced recovery project (Attachment 1). b. Voidage balance, by month, for produced and injected fluids (Attachments 2 and 3). c. Analysis of reservoir pressure surveys taken in 2011 (Attachment 4). d. Results of production surveys, and any special surveys, taken on the Tarn Oil Pool in 2011 (Attachment 5). e. Results of well allocation and test evaluation for Rule 7, and any other special monitoring (Attachment 6). f. Development Plan and Operational Review (Attachments 7 and 8). If you have any questions concerning this data, please contact Mark Kovar at (907) 265-6097. Sincerely, l James T. Rodgers Manager, GKA Development Greater Kuparuk Area ATTACHMENT 1 Tarn Oil Pool 2011 Annual Reservoir Surveillance Report Summary of EOR Project and Reservoir Management Summary Background In 1998 Arco Alaska, Inc. received approvals for formation of the Tarn Oil Pool in the Kuparuk River Unit, an Area Injection Order for Tarn, expansion of the Kuparuk River Unit, and formation of the Tarn Participating Area. The Tarn Pool Rules and Area Injection Order were approved on July 21St and July 20th, 1998 respectively. The Unit Expansion and Participating area were approved effective July 1, 1998. Construction of the Tarn road, pads, powerlines, and pipelines took place in the 1998/1999 winter construction season. Tarn development drilling commenced in April of 1998. Tarn production began on July 8, 1998. Injection of miscible injectant (MI) began in November 1998. Tarn switched to a miscible water alternating gas (MWAG) recovery process in July 2001. Progress of EOR Project The permanent 12" water injection line was completed and brought on-line in July 2001. This allowed Tarn to switch from strictly an MI flood to an MWAG recovery process which increases ultimate recovery from the Tarn reservoir. Water injection capacity has been good, and total fluid injection has been able to match reservoir voidage. The Tarn MWAG process uses Kuparuk spec MI which is injected above the minimum miscibility pressure. For compositional analysis of the Kuparuk spec MI, refer to the Kuparuk section of the annual surveillance report. Reservoir Management Summary In 2011, Tarn produced 3.82 MMBO, 6.48 MMBW, and 4.98 BSCF gas. The injection totals for 2011 were 0.47 BSCF Lean Gas, 3.7 BSCF of MI and 13.33 MMBW. The 2011 IM ratio is 1.15 for Drill Site 2N, and 1.09 for Drill Site 2L. Plans are to continue maintaining reservoir pressure by balancing monthly injection and production rates. ATTACHMENT 2 Tarn River Oil Pool 2011 Annual Reservoir Surveillance Report Produced Fluid Volumes 2011 TOTAL 3,819,434 4,981,813 6,478,596 Cumulatives at Dec 31, 2010 100,991,586 160,061,310 50,215,216 Produced Fluid Volumes (Reservoir Units) OIL GAS WATER CUM OIL CUM GAS CUM WATER MO YR STB MSCF STB STB MSCF STB 1 2011 281,185 387,446 597,832 101,272,771 160,448,756 50,813,048 2 2011 310,635 382,553 643,815 101,583,406 160,831,309 51,456,863 3 2011 349,901 424,729 584,861 101,933,307 161,256,038 52,041,724 4 2011 330,051 517,940 582,164 102,263,358 161,773,978 52,623,888 5 2011 3633298 598,115 523,672 102,626,656 162,372,093 53,147,560 6 2011 3853733 512,626 541,770 103,012,389 162,884,719 53,689,330 7 2011 349,211 445,035 531,550 103,361,600 163,329,754 54,220,880 8 2011 3203741 421,948 521,843 103,682,341 163,751,702 54,742,723 9 2011 283,636 318,337 466,617 103,965,977 164,070,039 55,209,340 10 2011 282,188 355,236 510,943 104,248,165 164,425,275 55,720,283 11 2011 277,763 318,708 477,195 104,525,928 164,743,983 56,197,478 12 2011 285,092 299,140 496,334 5 2011 TOTAL 3,819,434 4,981,813 6,478,596 Cumulatives at Dec 31, 2010 100,991,586 160,061,310 50,215,216 Produced Fluid Volumes (Reservoir Units) 2011 TOTAL 5,153,721 2,908,141 6,569,296 Cumulatives at Dec 31, 2010 135,364,094 111,240,281 50,918,229 OIL GAS WATER CUM OIL CUM GAS CUM WATER MO YR RVB RVB RVB RVB RVB RVB 1 2011 378,401 240,308 606,202 135,742,495 111,480,589 51,524,431 2 2011 418,539 211,515 652,828 136,161,034 111,692,103 52,177,259 3 2011 471,164 232,011 593,049 136,632,198 111,924,114 52,770,308 4 2011 444023 354,388 590,314 137,076,321 112,278,502 53,360,622 5 2011 4891113 423,124 531,003 137,565,434 112,701,626 53,891,626 6 2011 5203394 304,069 549,355 138,085,828 113,005,694 54,440,981 7 2011 472,246 252,889 538,992 138,558,074 113,258,583 54,979,972 8 2011 433,594 248,492 529,149 138,991,668 113,507,075 55,509,121 9 2011 383,162 155,804 473,150 139,374,829 113,662,879 55,982,271 10 2011 381,467 198,150 518,096 139,756,297 113,861,029 56,500,367 11 2011 375,917 157,013 483,876 140,132,214 114,018,043 56,984,243 12 2011 385,601 130,379 503,283 0 2011 TOTAL 5,153,721 2,908,141 6,569,296 Cumulatives at Dec 31, 2010 135,364,094 111,240,281 50,918,229 ATTACHMENT 3 Tarn River Oil Pool 2011 Annual Reservoir Surveillance Report Injected Fluid Volumes Cumulatives at Dec 31, 2010 151,585,758 15,718,281 173,557,417 Injected Fluid Volumes (Reservoir Units) WATER GAS MI CUM WATER CUM GAS CUM MI MO YR STB MSCF MSCF STB MSCF MSCF 1 2011 1,004,661 0 73,130 152,590,419 15,718,281 173,630,547 2 2011 1,301,705 0 197,132 153,892,124 15,718,281 173,827,679 3 2011 1,370,551 0 532,888 155,262,675 15,718,281 174,360,567 4 2011 1,074,430 0 576,022 156,337,105 15,718,281 174,936,589 5 2011 1,180,444 71,519 212,241 157,517,549 15,789,800 175,148,830 6 2011 1,254,532 0 169,898 158,772,081 15,789,800 175,318,728 7 2011 958,088 64,287 81,902 159,730,169 15,854,087 175,400,630 8 2011 882,990 0 440,094 160,613,159 15,854,087 175,840,724 9 2011 1,048,668 0 318,532 161,661,827 15,854,087 176,159,256 10 2011 1,046,278 86,294 194,182 162,708,105 15,940,381 176,353,438 11 2011 1,020,702 0 461,347 163,728,807 15,940,381 176,814,785 12 2011 1,183,459 0 434,482 15156,- 8 6 2011 TOTAL 13,326,508 222,100 3,691,850 Cumulatives at Dec 31, 2010 151,585,758 15,718,281 173,557,417 Injected Fluid Volumes (Reservoir Units) Cumulatives at Dec 31, 2010 153,707,959 17,852,110 142,053,317 WATER GAS MI CUM WATER CUM GAS CUM MI MO YR RVB RVB RVB RVB RVB RVB 1 2011 1,018,726 0 59,406 154,726,685 17,852,110 142,112,723 2 2011 1,319,929 0 161,584 156,046,614 17,852,110 142,274,307 3 2011 1,389,739 0 439,100 157,436,352 17,852,110 142,713,407 4 2011 1,089,472 0 472,750 158,525,824 17,852,110 143,186,157 5 2011 1,196,970 82,461 171,199 159,722,795 17,934,571 143,357,357 6 2011 1,272,095 0 129,292 160,994,890 17,934,571 143,486,649 7 2011 971,501 66,408 65,617 161,966,391 18,000,980 143,552,266 8 2011 895,352 0 342,525 162,861,743 18,000,980 143,894,791 9 2011 1,063,349 0 245,660 163,925,093 18,000,980 144,140,451 10 2011 1,060,926 99,497 148,839 164,986,018 18,100,477 144,289,290 11 2011 1,034,992 0 363,243 166,021,010 18,100,477 144,652,533 12 2011 1,200,027 0 338,737 6 2011 TOTAL 13,513,079 248,367 2,937,952 Cumulatives at Dec 31, 2010 153,707,959 17,852,110 142,053,317 ATTACHMENT 4 Tarn Oil Pool 2011 Annual Reservoir Surveillance Report Reservoir Pressure Surveys ConocoPhillips March 31, 2012 Mr. Dan Seamount, Commissioner Alaska Oil and Gas Conservation Commission 333 West 7th Ave. Suite 100 Anchorage, Alaska 99501-3539 Re: Tarn Oil Pool — Proposed Pressure Survey Plan for 2012 James T. Rodgers Manager, GKA Development Greater Kuparuk Area ConocoPhillips Alaska, Inc. ATO -1326 PO Box 100360 Anchorage AK 99510-0360 Phone (907) 263-4027 Fax: (907) 265-6133 Dear Commissioner Seamount, In compliance with Rule 8, Conservation Order No. 430A, ConocoPhillips Alaska, Inc., operator of the Tarn Oil Pool, is hereby submitting the proposed pressure survey plan for 2012. There were 20 pressure surveys reported for the Tarn Oil Pool to the AOGCC in 2011. In 2012, we expect to conduct approximately 20 pressure surveys, including initial surveys for new wells prior to initial sustained production or injection. If you have any questions concerning this data, please contact Mark Kovar at (907) 265-6097. Sincerely, (t U J�(nes T. 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(`� Z Z Q d m U o U D ri Y m J J N N J N J J N N J N J J N N J Z N N Z Z N N Z N Z Z N N N Z N N Z N Z N N L ATTACHMENT 5 Tarn Oil Pool 2011 Annual Reservoir Surveillance Report Production Logs and Special Surveys Well Date Comment 2L-330 6/24/2011 Gas lift survey 2L-320 10/5/2011 P B U 2L-312 4/3/2011 Expro video log to identify chemical inj mandrel leak 2L-307 10/22/2011 hole finder to 2L-307 8/9/2011 Caliper log.in tubing 2L-307 7/22/2011 Leak detect to 2N-319 8/31/2011 borehole imaging tool 2N-303 9/5/2011 EMIT/PMIT 2N-304 9/10/2011 leak detect to 2N-304 8/12/2011 microvertilo , caliper 2N-342 1 7/27/2011 Caliper, vertilo 2N-341 1 4/25/2011 Caliper ATTACHMENT 6 Tarn Oil Pool 2011 Annual Reservoir Surveillance Report Allocation Factors Month Oil Water Gas 01/31/11 0.9898 1.0582 0.9650 02/28/11 0.9981 1.0309 0.9429 03/31/11 1.0018 1.0511 0.9538 04/30/11 0.9593 1.0488 0.9535 05/31/11 0.9557 1.0349 0.9308 06/30/11 0.9605 1.0213 0.8868 07/31/11 0.9573 1.0481 0.8414 08/31/11 0.9613 1.0857 0.9094 09/30/11 0.9754 1.0401 0.8670 10/31/11 0.9667 1.0754 0.8737 11/30/11 0.9649 1.0700 0.8820 12/31/11 0.9697 1.0641 0.8857 ATTACHMENT 7 Tarn Oil Pool 2011 Annual Reservoir Surveillance Report Tarn Development Plans and Tarn Operational Review Development Drilling Well 2L-312, a grassroots producer, was put on production June 2011. This well targeted distal turbidite sands on the northern side of the 2L accumulation. Well 2L-320 a grassroots producer, was put on production May 2011. This well targeted an un -drained infill location within the 2L accumulation. Well 2L-306, a grassroots horizontal producer was put on production June 2011. This well, the first horizontal multi -stage fracture stimulated well in Tarn, targeted distal sands on the northern flank of the 2L accumulation. Well 2L-322 was spud in April 2011. This well was intended to be a grassroots horizontal producer, however the well was not completed prior to the end of the Tarn drilling campaign, and is suspended. Artificial Lift Tarn was originally designed to use miscible gas (MI) as a means of gas lifting the production wells. However, paraffin deposition in the tubing string occurs when the production fluid temperature falls below the cloud point of 92°F. This is the case of longer reach wells and lower liquid rate production wells. Excessive paraffin build-up and the high frequency of required paraffin scrapes in some wells led to a change in artificial lift methodology towards surface -powered downhole jet pumps. In 2001, after successful pilot tests in 1999 and 2000, 13 of the gas lifted wells were converted to jet pump using hot produced water as power fluid. This technique has proven to be very successful in mitigating paraffin deposits. Slickline scrapes and hot oil treatments have been virtually eliminated leading to production increases of about 10%. Unfortunately the untreated saline produced water injected down the inner annuli (power fluid) has accelerated tubing and casing corrosion. Three well integrity failures occurred on jet -pumped wells due to both tubing and well casing corrosion in 2006-2007: 2L-321, 2N-318 and 2N-305. These wells were shut-in and secured. Wells 2N-305 and 2N- 318 were both sidetracked in 2009. A workover to install an additional casing string was successfully completed for 2L-321 during 2008. In 2009 and 2010, three additional wells were shut in after failing mechanical integrity tests: 2N-319, 2N- 303, and 2L-313. Each of these wells was in jet pump service when the failure occurred. These wells will likely remain secured and shut in until a rotary sidetrack targeting more prolific reservoir is executed. In 2011, well 2N-304 failed a mechanical integrity test, and was secured until a rotary sidetrack can be performed. As of the end of 2011, only two wells at Tarn remain on jet pump: 2L-311 and 2N-342. After water breakthrough occurs in producing wells, paraffin deposition is less likely due to increased well flowing temperatures (the heat capacity of water is greater than that of oil). Completion designs and alternatives to jet pumps are being considered for new and existing wells. Capillary chemical injection tubes are being installed in new production wells. The capillary injection lines enable paraffin inhibition chemicals to be injected into the tubing, treating the oil prior to paraffin deposition. In 2011, a paraffin inhibition pilot test was conducted. The results of the pilot test were inconclusive; therefore, another pilot test may be performed to determine the effectiveness of continuous downhole chemical injection. Depending on the pilot test results, the continuous chemical injection could be expanded to other wells that have been completed with capillary injection lines. ATTACHMENT 8 Tarn Oil Pool 2011 Annual Reservoir Surveillance Report Map showing recent development wells - "";�N 1-2 E ConocoPhillips March 31, 2012 Mr. Dan Seamount, Commissioner Alaska Oil and Gas Conservation Commission 333 West 7th Ave. Suite #100 Anchorage, Alaska 99501-3539 James T. Rodgers Manager — GKA Development Greater Kuparuk Area ConocoPhillips Alaska Inc. ATO -1326 PO Box 100360 Anchorage AK 99510-0360 Phone (907)263-4027 Fax: (907)265-6133 Re: 2011 West Sak Oil Pool Annual Reservoir Surveillance Report Dear Mr. Seamount, In compliance with Rule 11, Conservation Order No. 406A, ConocoPhillips Alaska, Inc., operator of the Kuparuk River Unit, is hereby submitting the annual surveillance report on the West Sak Oil Pool. This report documents information pertinent to field development and enhanced recovery operations from January 2011 through December 2011. The following is an outline of the information provided: a. A summary of the current enhanced oil recovery in the West Sak Oil Pool (Attachment 1). b. Voidage balance, by month, for produced and injected fluid (Attachment 2 & 3). c. Analysis of reservoir pressure surveys taken in 2011 and pressure survey plans for 2012 (Attachment 4). d. Results of injection surveys, production surveys, and any special surveys, conducted in the West Sak Oil Pool in 2011 (Attachments 5-7). e. Results of pool production allocation factors (Attachment 8). f. Development plans and operational review (Attachment 9). If you have any questions concerning this data, please contact Mark Kovar at (907) 265-6097. Sincerely, James T. Rodgers Manager- GKA Development Greater Kuparuk Area ATTACHMENT I West Sak Oil Pool 2011 Annual Reservoir Surveillance Report Summary of the Enhanced Oil Recovery Project There were no new wells placed in service in the West Sak Oil Pool in 2011. At the end of 2011 there were twenty-seven active water injectors and fifty active producers in the West Sak Oil Pool. This represents a decrease of two active producers and five active injectors in West Sak from January 2011 to December 2011. Well 1D-126 was suspended due to a casing leak to surface in April 2010. As a result of this casing leak, all twenty-seven injectors surrounding single casing producers were shut-in in June 2010 pending remediation work. Rig work is in progress to implement two barriers in the surrounding producers. Once all surrounding producers have two barriers, the wells will be returned to injection. Waterflooding the reservoir for pressure maintenance and improved sweep continues to be the main enhanced oil recovery mechanism in the West Sak oil pool. Drill Sites 1B, 1C, 1D and 1J inject CPF-1 produced water while Drill Site 3K injects seawater. The injectors on Drill Site 1E were on seawater service for —70% of 2011 with the remaining time on produced water injection. Waterflood performance was good in the majority of the West Sak patterns. During 2011 the West Sak oil pool did not experience rapid water breakthrough events, termed matrix bypass events (MBEs), that result in highly conductive pathways between an injector and a producer. Analysis and review of the matrix bypass events is an ongoing activity. Measures to mitigate future MBEs were implemented in 2005 and 2007 resulting in reduced frequency of occurrence. In addition, remediation repairs were implemented in 2009 and 2010 that successfully isolated four MBEs. A new technology to isolate MBEs was implemented in three wells in 2011 with preliminary indications of success. During 2003, ConocoPhillips Alaska, Inc. received approval to commence a West Sak Small Scale EOR (SSEOR) Pilot Project using Kuparuk MI in a water -alternating gas (WAG) pilot. The SSEOR Pilot Project is completed. In 2009, a West Sak Viscosity Reducing Water Alternating Gas Pilot project was approved for four West Sak injectors at 1E & 1J. Initial VRWAG gas injection began in November 2009 in two injectors, 1 E-102 and 1 E-117. Two additional injectors, 1 J-170 and 1 J-122, began gas injection in April 2010. Well 1 E-102 was shut-in following a matrix bypass event with 1E-121. Well 1E-102 has been removed from the VRWAG pilot project. No breakthroughs have been detected in the three remaining patterns. The gas injection volumes in 2011 were — 540 mmscf for well IE -117, — 310 mmscf for well 1J-122, and — 400 mmscf for well 1J-170. The VRWAG cycles and data analysis for these three patterns are ongoing and surveillance efforts will continue to evaluate the impact of the viscosity reducing gas injection. ATTACHMENT 2 West Sak Oil Pool 2011 Annual Reservoir Surveillance Report Produced Fluid Volumes Cumulatives at Dec 31, 2010 50,894,359 24,121,232 13,496,276 Produced Fluid Volumes (Reservoir Units) OIL GAS WATER CUM OIL CUM GAS CUM WATER MO YR STB MSCF STB STB MSCF STB 1 2011 363,640 177,166 123,364 51,257,999 24,298,398 13,619,640 2 2011 467,134 254,993 145,161 51,725,133 24,553,391 13,764,801 3 2011 507,549 270,792 174,834 52,232,682 24,824,183 13,939,635 4 2011 471,739 341,781 166,835 52,704,421 25,165,964 14,106,470 5 2011 522,493 335,604 182,196 53,226,914 25,501,568 14,288,666 6 2011 496,486 307,379 155,108 53,723,400 25,808,947 14,443,774 7 2011 546,073 313,635 148,540 54,269,473 26,122,582 14,592,314 8 2011 489,224 330,539 118,133 54,758,697 26,453,121 14,710,447 9 2011 462,404 309,861 100,865 55,221,101 26,762,982 14,811,312 10 2011 474,762 304,649 113,068 55,695,863 27,067,631 14,924,380 11 2011 472,719 290,023 136,472 56,168,582 27,357,654 15,060,852 12 2011 463,006 299,939 141,204 8 2011 TOTAL 5,737,229 3,536,361 1,705,780 Cumulatives at Dec 31, 2010 50,894,359 24,121,232 13,496,276 Produced Fluid Volumes (Reservoir Units) 2011 TOTAL 6,382,826 3,971,590 1,808,878 Cumulatives at Dec 31, 2010 52,473,023 20,849,253 13,361,467 OIL GAS WATER CUM OIL CUM GAS CUM WATER MO YR RVB RVB RVB RVB RVB RVB 1 2011 390,727 173,230 125,477 52,863,750 21,022,483 13,486,944 2 2011 496,535 269,417 146,661 53,360,284 21,291,900 13,633,605 3 2011 539,959 282,033 175,050 53,900,244 21,573,933 13,808,655 4 2011 507,155 407,578 167,333 54,407,399 21,981,511 13,975,988 5 2011 559,197 378,586 183,484 54,966,596 22,360,097 14,159,472 6 2011 525,412 341,523 155,233 55,492,008 22,701,620 14,314,705 7 2011 584,264 342,109 150,318 56,076,273 23,043,729 14,465,023 8 2011 525,365 388,188 120,314 56,601,638 23,431,917 14,585,337 9 2011 489,603 365,051 100,388 57,091,241 23,796,969 14,685,725 10 2011 505,862 353,952 114,740 57,597,103 24,150,920 14,800,465 11 2011 788,202 325,129 241,725 58,385,306 24,476,049 15,042,190 12 2011 470,544 344,794 128,155 8 2011 TOTAL 6,382,826 3,971,590 1,808,878 Cumulatives at Dec 31, 2010 52,473,023 20,849,253 13,361,467 MO 1 2 3 4 5 6 7 8 9 10 11 12 MO 1 2 3 4 5 6 7 8 9 10 11 12 ATTACHMENT 3 West Sak Oil Pool 2011 Annual Reservoir Surveillance Report Injected Fluid Volumes 2011 TOTAL 4,769,390 0 1,251,933 Cumulatives at Dec 31, 2010 73,958,195 0 1,242,169 Injected Fluid Volumes (Reservoir Units) WATER GAS MI CUM WATER CUM GAS CUM MI YR STB MSCF MSCF STB MSCF MSCF 2011 341,249 0 30,568 74,299,444 0 1,272,737 2011 330,704 0 106,099 74,630,148 0 1,378,836 2011 351,288 0 234,144 74,981,436 0 1,612,980 2011 318,857 0 239,245 75,300,293 0 1,852,225 2011 356,915 0 94,373 75,657,208 0 1,946,598 2011 374,896 0 69,758 76,032,104 0 2,016,356 2011 401,751 0 7,012 76,433,855 0 2,023,368 2011 327,902 0 30,420 76,761,757 0 2,053,788 2011 309,787 0 140,644 77,071,544 0 2,194,432 2011 540,997 0 115,917 77,612,541 0 2,310,349 2011 534,243 0 86,243 78,146,784 0 2,396,592 2011 580,801 0 97,510 2011 TOTAL 4,769,390 0 1,251,933 Cumulatives at Dec 31, 2010 73,958,195 0 1,242,169 Injected Fluid Volumes (Reservoir Units) 2011 TOTAL 5,115,289 0 937,698 Cumulatives at Dec 31, 2010 72,195,351 0 930,385 WATER GAS MI CUM WATER CUM GAS CUM MI YR RVB RVB RVB RVB RVB RVB 2011 335,607 0 22,895 72,530,958 0 953,280 2011 333,707 0 79,468 72,864,665 0 1,032,748 2011 356,782 0 175,374 73,221,447 0 1,208,122 2011 318,846 0 179,195 73,540,293 0 1,387,317 2011 356,523 0 70,685 73,896,816 0 1,458,002 2011 370,436 0 52,249 74,267,252 0 1,510,251 2011 401,237 0 5,252 74,668,489 0 1,515,503 2011 336,681 0 22,785 75,005,170 0 1,538,287 2011 313,022 0 105,342 75,318,192 0 1,643,630 2011 540,200 0 86,822 75,858,392 0 1,730,451 2011 909,319 0 64,596 76,767,711 0 1,795,047 2011 542,929 0 73,035 2011 TOTAL 5,115,289 0 937,698 Cumulatives at Dec 31, 2010 72,195,351 0 930,385 ATTACHMENT 4 West Sak Oil Pool 2011 Annual Reservoir Surveillance Report Reservoir Pressure Surveys ConocoPhillips March 31, 2012 Mr. Dan Seamount, Commissioner Alaska Oil and Gas Conservation Commission 333 West 7th Ave. Suite 100 Anchorage, Alaska 99501-3539 Re: West Sak Oil Pool — Proposed Pressure Survey Plan for 2012 Dear Commissioner Seamount, James T. Rodgers Manager, GKA Development Greater Kuparuk Area ConocoPhillips Alaska, Inc. ATO -1326 PO Box 100360 Anchorage AK 99510-0360 Phone (907) 263-4027 Fax: (907) 265-6133 In compliance with Rule 8, Conservation Order No. 406A, ConocoPhillips Alaska, Inc., operator of the West Sak Oil Pool, is hereby submitting the proposed pressure survey plan for 2012. There were 20 pressure surveys reported for the West Sak Oil Pool to the AOGCC in 2011. In 2012, we expect to conduct approximately 20 pressure surveys, including initial surveys for new wells prior to initial sustained production. If you have any questions concerning this data, please contact Mark Kovar at 265-6097. Sincerely, es T. Rodgers Manager, GKA Development Greater Kuparuk Area STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION RESERVOIR PRESSURE REPORT 1. Operator: 2. Address: ConocoPhilli s Alaska Inc. P. O. Box 100360, Anchorage, AK 99510-0360 3. Unit or Lease Name: 4. Field and Pool: 5. Datum Reference: 6. Oil Gravity: 7. Gas Gravity: Ku aruk River Unit West Sak Oil Pool -3500' SS 0.94 (water= 1. 0.57 8. Well Name and 9. API Number 10. Type 11. AOGCC 12. Zone 13. Perforated 14. Final Test 15. Shut -In 16. Press. 17. B.H. 18. Depth Tool 19. Final 20. Datum 21. Pressure 22. Pressure at Number: 50xxxxxxxxxxxx See Pool Code Intervals Top Date Time, Hours Surv. Type Temp. TVDSS Observed TVDSS (input) Gradient, psi/ft. Datum (cal) NO DASHES Instructions Bottom TVDSS (see Pressure at instructions for Tool Depth codes) 1 B-101 50029228750000 PROD 490150 BD -3646 - -3625 06/04/11 48 SBHP 72 3456 721 5,400 0.780 755 1C-104 50029229000000 PROD 490150 BD -3644--3590 06/29/11 8000 SBHP 69 3303 1288 5,400 0.370 1361 -3527 - -3556, -3585 - -3607, -3632 - -3654, -3674 - -3682, -3692 - -3722, 1C-125 50029229000000 ]NJ 490150 AD -3756--3779 04/26/11 3000 SBHP 761 3651 1458 5,400 0.440 1392 1C-170 50029229500000 PROD 490150 BD -3702--3711 04/09/11 4377 SBHP 74 3654 1250 5,400 0.3401 1198 -3661 - -3778, 1C-174 50029229650000 INJ 49015o ABD -3740--3740 04/05/11 4300 SBHP 72 3608 1535 5,400 0.390 1493 113-178 50029229820000 PROD 490150 BD -3681--3723 04/20/11 4300 SBHP 72 3501 1232 5,400 0.393 1231 1C-184 50029229750000 PROD 490150 D -3752--3732 05/17/11 3000 SBHP 72 3732 1295 5,400 0.330 1219 113-190 50029229970000 [NJ 490150 D -3744--3674 04/09/11 1440 SBHP 75 16391 1821 5,400 0.044 1903 1D -105A 50029207690000 PROD 490150 D -3690--3729 09/02/11 72 SBHP 70 3310 700 5,400 0.370 770 -3521 --3551, -3581 - -3596, -3599 - -3615, -3625 - -3648, -3669 - -3677, -3691 --3714, -3738 - -3769, 1D-111 50029207690100 [NJ 490150 ABD -3806--3822 04/20/11 4500 SBHP 84 36711 1679 5,400 0.480 1597 -3454 - -3473, -3454--3484, -3515 - -3578, -3603--3647, 1D-116 50029207690100 PROD 490150 ABD -3669--3708 08/16/11 3000 SBHP 68 3175 1452 5,400 0.3661 1571 -3541--3571, -3601 - -3631, -3693 - -3723, 1D-121 50029208950000 PROD 490150 ABD -3771 --3801 06/15/11 2880 SBHP 711 3416 1562 5,400 0.410 1597 -3416 - -3446, -3476 - -3508, -3509 - -3539, -3563 - -3582, -3591 - -3610, ID -123 1 50029208920000 PROD 490150 ABD -3629--3678 06116/111 48 SBHP 73 3215 10641 5,400 0.470 1198 -3373 - -3397, -3427 - -3445, -3517 - -3521, -3546 - -3556, 1 D-127 50029208920000 1 PROD 1 490150 JAD 1 -3577 - -3605 08/12/11 3000 SBHP 691 3279 1683 5,400 0.270 1743 Form 10-412 Rev. 12/2008 INSTRUCTIONS ON REVERSE SIDE Submit in Duplicate STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION RESERVOIR PRESSURE REPORT 1. Operator: 2. Address: ConocoPhilli s Alaska Inc. P. O. Box 100360, Anchorage, AK 99510-0360 3. Unit or Lease Name: 4. Field and Pool: 5. Datum Reference: 6. Oil Gravity: 7. Gas Gravity: Ku aruk River Unit West Sak Oil Pool -3500' SS 0.94 water= 1.0 0,57 8. Well Name and 9. API Number 10. Type 11. AOGCC 12. Zone 13. Perforated 14. Final Test 15. Shut -In 16. Press. 17. B.H. 18. Depth Tool 19. Final 20. Datum 21. Pressure 22. Pressure at Number. 50xxxxxxxxxxxx See Pool Code Intervals Top Date Time, Hours Surv. Type Temp. TVDSS Observed TVDSS (input) Gradient, psi/ft. Datum (cal) NO DASHES Instructions Bottom TVDSS (see Pressure at instructions for Tool Depth codes) -3410 - -3437, -3469 - -3489, -3511 --3518, -3553 - -3561, -3570 - -3587, -3593 - -3600, -3620--3631, 1 D-128 50029208840000 INJ 1 490150 ABD -3644 - -3662 02/23/11 3000 PBU 74 3299 1688 5,400 0.393 1767 -3410--3437, -3469 - -3489, -3511 - -3518, -3553--3561, -3570 - -3587, -3593 - -3600, -3620 - -3631, ID -128 50029208840000 INJ 490150 ABD -3644 - -3662 07102/111 3000 PBU 1 0 3299 1678 5,400 0.393 1757 -3410--3437, -3469 - -3489, -3511 - -3518, -3553--3561, -3570--3587, -3593 - -3600, -3620--3631, 1D-128 50029208580000 INJ 490150 ABD 13644 - -3662 04/30/11 3000 PBU 741 3299 1682 5,400 0.3931 1761 -3478 - -3480, -3497 - -3499, -3521 - -3523, -3533 - -3549, -3561 - -3563, -3576 - -3610, -3615 - -3617, -3621 - -3645, -3647 - -3649, -3664 - -3670, -3679 - -3711, -3723 - -3725, -3734 - -3739, -3749 - -3788, 1D-130 1 50029208580000 JINJ 1 490150 JABD -3798--3800, 1 05/151111 3000 PBU 1 771 34231 17111 5,400 1 0.3931 1741 Form 10-412 Rev. 12/2008 INSTRUCTIONS ON REVERSE SIDE Submit in Duplicate STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION RESERVOIR PRESSURE REPORT 1. Operator: 2. Address: I ConocoPhilli s Alaska Inc. P. O. Box 100360, Anchora e, AK 99510-0360 S. Unit or Lease Name: 4. Field and Pool: 5. Datum Reference: 6. Oil Gravity: 7. Gas Gravity: Ku aruk River Unit West Salk Oil Pool -3500' SS 0.94 (water = 1.0 0.57 8. Well Name and 9. API Number 10. Type 11. AOGCC 12. Zone 13, Perforated 14. Final Test 15. Shut -In 16. Press. 17. B.H. 18. Depth Tool 19. Final 20. Datum 21. Pressure 22. Pressure at Number: 50XXXXXXXXXXXX See Pool Code Intervals Top Date Time, Hours Surv. Type Temp. TVDSS Observed TVDSS (input) Gradient, psi/ft. Datum (cal) NO DASHES Instructions Bottom TVDSS (see Pressure at instructions for Tool Depth codes) -3478 - -3480, -3497 - -3499, -3521 --3523, -3533 - -3549, -3561 --3563, -3576 - -3610, -3615 - -3617, -3621 - -3645, -3647 - -3649, -3664 - -3670, -3679 - -3711, -3723 - -3725, -3734 - -3739, -3749 - -3788, 1D-130 50029208440000 INJ 490150 ABD -3798--3800, 07/10/11 3000 PBU 771 3423 1706 5,400 0.393 1736 -3478 - -3480, -3497 - -3499, -3521 - -3523, -3533 - -3549, -3561 - -3563, -3576 - -3610, -3615 - -3617, -3621 --3645, -3647 - -3649, -3664 - -3670, -3679 - -3711, -3723 - -3725, -3734 - -3739, -3749 - -3788, 1D-130 50029208370000 [NJ 490150 ABD -3798--3800, 03/04/11 3000 PBU 771 3423 1715 5,400 0.393 1745 23. All tests reported herein were a in accordance with applirules, fegulations and instructions of the Alaska Oil and Gas Conservation Commission. I hereby certify that the foregoing i d correct to th best o y Howled Signature Title 7" Printed Name it Date I Form 10-412 Rev. 12/2008 INSTRUCTIONS ON REVERSE SIDE Submit in Duplicate ATTACHMENT KUPARUK RIVER UNIT WEST SAK OIL POOL CONSERVATION ORDER 406B RULE 11d - INJECTIVITY PROFILES 2011 ANNUAL SUBMITTAL WELL API DATE OF DATE OF DATA TYPE REASON FOR WELL ZONES INJECTION NUMBER NUMBER INITIAL PROFILE/ PROFILE/ PROFILE/ COMPLETION TAKING BWPD / 50- INJECTION SURVEY SURVEY SURVEY INJECTION MSCFD 1J-105 0292334600-00 07/07 04/19/11 SPINNER FOLLOW-UP Single ABD 710 1J-156 0292331100-00 10/06 05/16/11 SPINNER A/C SPLITS Single ABD 1357 1J-164 0292327800-00 04/06 03/16/11 SPINNER A/C SPLITS Single ABD 938 3 —Total IPROF Count for 2011 ATTACHMENT 6 Kuparuk River Unit West Sak Oil Pool 2011 Annual Reservoir Surveillance Report Production Survey Data During 2011, no production profile survey was attempted for the West Sak Oil Pool. ATTACHMENT 7 West Sak Oil Pool 2011 Annual Reservoir Surveillance Report% Special Survey Date Geochemical Oil Production Splits Well Name Sample Date A Sand B Sand D Sand 1B-101 04/12/11 0% 70% 30% 1B-101 07/28/11 0% 41% 59% 1C-102 02/10/11 0% 6% 94% 1C-102 04/12/11 0% 5% 95% 1C-102 08/15/11 0% 3% 97% 1C-109 02/10/11 0% 29% 71% 1 C-109 04/12/11 0% 32% 68% 1 C-135 02/10/11 0% 0% 100% 1 C-135 04/12/11 0% 0% 100% 1 C-135 06/10/11 0% 0% 100% 1C-170 06/10/11 0% 0% 100% 1C-170 08/15/11 0% 0% 100% 1 C -1 72A 06/10/11 100% 0% 0% 1C-178 06/10/11 0% 36% 64% 1 C-178 08/15/11 0% 36% 64% 1 C-184 06/10/11 0% 0% 100% 1 C-184 08/15/11 0% 0% 100% 1 D-1 05A 02/08/11 0% 0% 100% 1 D-1 05A 05/01/11 0% 0% 100% 1 D-108 02/08/11 44% 18% 38% 1D -110A 02/08/11 47% 6% 47% 1D -110A 04/13/11 38% 13% 50% 1 D-112 02/17/11 48% 28% 24% 1 D-112 04/13/11 46% 22% 32% 1 D-112 07/24/11 39% 33% 28% 1 D-113 02/08/11 50% 19% 32% 1 D-113 07/24/11 51% 15% 33% 1 D-115 03/23/11 55% 13% 32% 1 D-115 04/13/11 41% 35% 24% 1 D-115 07/24/11 47% 25% 28% 1 D-118 02/08/11 80% 0% 20% 1 D-118 05/03/11 72% 0% 28% 1 D-118 07/24/11 68% 0% 32% 1 D-123 02/08/11 65% 11% 25% 1 D-123 02/10/11 68% 0% 32% 1D-123 05/01/11 64% 12% 25% 1 D-124 02/08/11 67% 1 % 32% 1 D-124 04/13/11 58% 7% 35% 1D-129 02/08/11 73% 10% 18% 1 D-129 04/13/11 51% 31% 18% 1 D-129 07/24/11 56% 28% 16% 1 D-131 02/08/11 74% 26% 0% 1 D-131 03/08/11 93% 7% 0% 1 D-131 04/13/11 74% 27% 0% 1 D-131 07/24/11 72% 28% 00 1 D-133 02/08/11 82% 3% 15% 1 D-133 04/13/11 62% 20% 19% 1 D-133 07/24/11 65% 15% 20% 1 D-134 02/08/11 83% 3% 14% 1 D-134 04/13/11 63% 21% 16% 1 D-134 07/24/11 67% 15% 18% 1 D-135 04/13/11 10% 24% 66% ATTACHMENT 7 West Sak Oil Pool 2011 Annual Reservoir Surveillance Report% Special Survey Date Geochemical Oil Production Splits Well Name Sample Date A Sand B Sand D Sand 1 D-135 07/24/11 10% 24% 66% 1D -141A 02/08/11 0% 0% 100% 1D -141A 04/13/11 0% 0% 100% 1D -141A 07/24/11 0% 0% 100% 1D -141A 09/15/11 0% 0% 100% 1 E-170 02/17/11 0% 78% 22% 1 E-170 04/06/11 0% 41% 59% 1 E-170 07/28/11 0% 59% 41% 1E-168 04/06/11 22% 26% 52% 1E-168 07/28/11 34% 0% 66% 1 E-166 02/17/11 23% 75% 2% 1 E-166 05/03/11 12% 74% 14% IE -166 07/28/11 12% 76% 12% 1E-126 02/17/11 18% 50% 32% 1E-126 04/06/11 2% 51% 47% 1E-121 02/17/11 0% 23% 77% IE -121 05/03/11 0% 37% 63% 1 J-101 01/27/11 22% 35% 44% U-101 04/14/11 28% 34% 38% U-101 07/26/11 45% 9% 46% U-103 02/17/11 0% 64% 36% 1 J-103 04/14/11 0% 38% 62% 1 J-103 07/26/11 0% 54% 46% U-105 04/19/11 33% 17% 50% U-107 02/17/11 0% 99% 1 % U-107 04/14/11 0% 4% 96% U-107 07/26/11 0% 0% 100% IJ -115 02/17/11 12% 37% 51% U-115, 04/14/11 17% 32% 51% 1J-115 07/26/11 46% 12% 42% U-120 02/10/11 6% 15% 79% U-120 04/10/11 6% 21% 74% U-120 07/26/11 4% 17% 79% U-120 08/23/11 7% 16% 77% U-120 09/15/11 3% 27% 71% U-137 04/05/11 0% 78% 22% U-137 04/14/11 0% 61% 39% U-137 07/26/11 0% 60% 40% U-152 02/17/11 13% 51% 37% U-152 04/14/11 46% 23% 31% U-152 07/26/11 65% 0% 35% U-156 05/16/11 37% 15% 48% IJ -158 03/28/11 0% 72% 28% 1 J-158 04/14/11 0% 70% 30% U-158 07/26/11 0% 100% 0% U-159 02/17/11 29% 0% 71% U-159 04/14/11 39% 1 % 61% U-159 07/26/11 49% 0% 51% IJ -164 03/16/11 5% 48% 48% 1 J-166 02/17/11 17% 39% 45% 1 J-166 04/14/11 22% 36% 43% 1 J-166 07/26/11 28% 27% 46% ATTACHMENT 7 West Sak Oil Pool 2011 Annual Reservoir Surveillance Report% Special Survey Date Geochemical Oil Production Splits Well Name Sample Date A Sand B Sand D Sand U-166 08/23/11 21% 22% 58% 1,1-166 09/15/11 18% 26% 56% IJ -168 04/14/11 31% 45% 24% 1J-168 07/26/11 36% 39% 26% 1J-168 08/23/11 19% 57% 24% 1J-168 09/15/11 4% 24% 72% 1J-174 02/17/11 0% 42% 58% 1J-174 04/14/11 0% 56% 4406 1J-174 07/26/11 0% 50% 50% 1J-178 02/17/11 0% 61% 39% U-178 04/14/11 0% 61% 39% 1J-178 07/26/11 0% 60% 40% 1J-182 02/17/11 0% 68% 32% 1J-182 04/14/11 0% 79% 21% 1J-182 07/26/11 0% 71% 29% 3K-102 01/27/11 0% 50% 50% 3K-102 04/09/11 0% 42% 58% 3K-102 07/26/11 0% 17% 83% ATTACHMENT 8 West Sak Oil Pool 2011 Annual Reservoir Surveillance Report Allocation Factors Month Oil Gas Water January -11 0.8956 0.9781 0.9550 February -11 0.9429 1.0309 0.9981 March -11 0.9539 1.0511 1.0019 April -11 0.9535 1.0489 0.9593 May -11 0.9308 1.0349 0.9557 June -11 0.8868 1.0213 0.9605 July -11 0.8413 1.0481 0.9573 August -11 0.9094 1.0858 0.9613 September -11 0.8671 1.0402 0.9754 October -11 0.8737 1.0754 0.9667 November -11 0.8820 1.0700 0.9649 December -11 0.8660 1.0760 0.9730 Attachment 9 Kuparuk River Unit West Sak Oil Pool 2011 Annual Reservoir Surveillance Report Development Plans and Operational Review • WEST SAK DEVELOPMENT There was no new development in 2011. • EASTERN NORTH EAST WEST SAK (EASTERN NEWS) DEVELOPMENT The Kuparuk River Unit working interest owners have re -started the Eastern NEWS development planning work that was suspended in 2008. The final project scope and timing is dependent upon project competitiveness and the economic business climate. • UGNU PILOTS/ STUDIES The Kuparuk River Unit working interest owners have re -started the Ugnu Heavy Oil pilot planning work that was suspended in 2008. During the year, an evaluation was initiated to install a down hole heater and attempt an oil sample collection from an existing well. GAS OFFTAKE ConocoPhillips March 31, 2012 Mr. Dan Seamount, Commissioner Alaska Oil and Gas Conservation Commission 333 West 7th Ave. Suite 100 Anchorage, Alaska 99501-3539 Re: 2011 Allowable Gas Offtake from Kuparuk River Oil Pool Dear Commissioner Seamount, James T. Rodgers Manager, GKA Development Greater Kuparuk Area ConocoPhillips Alaska, Inc. ATO -1326 PO Box 100360 Anchorage AK 99510-0360 Phone (907) 263-4027 Fax: (907) 265-6133 In compliance with Rule 13, Conservation Order No. 432D, ConocoPhillips Alaska, Inc., operator of the Kuparuk River Oil Pool, is hereby submitting the gas offtake volume information for 2011 (Attachment 1). During 2011, the annualized average gas offtake was 562 MSCFD, considerably less than the maximum allowable annual average gas offtake rate of 5 MMSCFD as stated in Rule 13 for Kuparuk River Oil Pool. If you have any questions concerning this data, please contact Mark Kovar at (907) 265-6097. Sincerely, nn �X-- V James T. Rodgers Manager, GKA Development Greater Kuparuk Area ConocoPhillips Attachment 1 Kuparuk River Oil Pool 2011 Annual Reservoir Surveillance Report Gas Offtake Data 2011 Monthly Gas Offtake Kuparuk Gas Offtake -2011 800 700 600 500 MCFD 400 300 200 100 0 �oeot � CoQ O �o Oo MSCFD SCFD RB/D January 522 521774 464 February 535 534893 476 March 619 618935 550 April 544 543633 483 May 555 555032 493 June 532 531633 473 July 513 512903 456 August 526 526355 468 September 507 507000 451 October 575 575097 511 November 736 735567 654 December 587 587000 522 Average 562 562,485 500 Kuparuk Gas Offtake -2011 800 700 600 500 MCFD 400 300 200 100 0 �oeot � CoQ O �o Oo