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Home My WebLink About2012 Greater Kuparuk Area Greater Kuparuk Area 2012 Annual Reservoir Surveillance Reports Kuparuk, Meltwater, Tabasco, Tarn, & West Sak Oil Pools Reporting Period January 1 to December 31, 2012 2012 GREATER KUPARUK AREA ANNUAL SURVEILLANCE REPORTS Table of Contents KUPARUK RIVER OIL POOL REPORT COVER LETTER SUMMARY OF EOR PROJECT ...................................................................ATTACHMENT 1 Map of EOR Program Status Plot of Incremental EOR Oil Rate PRODUCED FLUID VOLUMES ...................................................................ATTACHMENT 2 INJECTED FLUID VOLUMES ......................................................................ATTACHMENT 3 RESERVOIR PRESSURE SURVEYS ..........................................................ATTACHMENT 4 PROPOSED PRESSURE SURVEY PLAN RESERVOIR PRESSURE SURVEY REPORT PROPOSED INJECTION PROFILE SURVEY PLAN INJECTION SURVEY DATA ........................................................................ATTACHMENT 5 Proposed Injection Profile Survey Plan Injectivity Profiles PRODUCTION SURVEY DATA ...................................................................ATTACHMENT 6 Productivity Profiles MISCIBLE INJECTANT COMPOSITION ......................................................ATTACHMENT 7 CPF1 MI Composition CPF2 MI Composition KUPARUK LSEOR DEVELOPMENT PLAN .................................................ATTACHMENT 8 MELTWATER OIL POOL REPORT COVER LETTER 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 LOGS & SPECIAL SURVEYS .............................................ATTACHMENT 5 WELL ALLOCATION & SHALLOW GAS SPECIAL MONITORING .............ATTACHMENT 6 DEVELOPMENT PLANS & OPERATIONAL REVIEW .................................ATTACHMENT 7 MAP SHOWING RECENT DEVELOPMENT WELLS ..................................ATTACHMENT 8 TABASCO OIL POOL REPORT COVER LETTER SUMMARY OF EOR RECOVERY PROJECT ..............................................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 LOGS & SPECIAL SURVEYS .............................................ATTACHMENT 5 WELL ALLOCATION & TEST EVALUATION SUMMARY ............................ATTACHMENT 6 DEVELOPMENT PLANS & OPERATIONAL REVIEW .................................ATTACHMENT 7 TARN OIL POOL REPORT COVER LETTER 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 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 COVER LETTER SUMMARY OF EOR PROJECT ...................................................................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 INJECTION SURVEY DATA ........................................................................ATTACHMENT 5 Proposed Injection Profile Survey Plan Injectivity Profiles 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 COVER LETTER TABLE OF MONTHLY GAS OFFTAKE ........................................................ATTACHMENT 1 ATTACHMENT 1 Kuparuk River Oil Pool 2012 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. Twenty-six MWAG/IWAG drill sites service the Kuparuk reservoir which includes 209 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 2012, the MWAG project operated in full MI production mode for most of the 26 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 into January of 2012. 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 1G and 1R later in that year, after seeing positive response from drillsites 2U, 2V and 2W. See next page for further discussion on drillsites 1G, 1R, and 2X. During the year 2012, Kuparuk imported an average of 16,054 barrels per day of Prudhoe NGLs. Import NGLs and indigenous NGLs blended with available lean gas generated an average of 167 MMSCFD of MI. The annual average MI injection rate into the Kuparuk Field was 125 MMSCFD. The remainder was utilized for Greater Kuparuk Area satellite fields, including 20 MMSCFD as injection and 17 MMSCFD as lift gas in Tarn and Meltwater and 3 MMSCFD as injection at West Sak. A small amount of MI (~3 MMSCFD) is used as lift gas in drillsite 3S. The estimated incremental oil sales in year 2012 from the ongoing Kuparuk MWAG project is 25 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 2012 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 2012 was 204 MMSCFD, down from 237 MMSCFD during 2011. MWAG Small Scale EOR (SSEOR and SSEORX) Drillsite 2Z continued on MI injection; drillsites 1A, 1Y, and 2X no longer receive MI injection. The 2012 average MI injection rate at Drillsite 2Z was 3 MMSCFD. Large Scale EOR (LSEOR) The original LSEOR Drill Sites include: 1F, 1G, 1Q, 1R, 2A, 2B, 2C, 2D, 2F, 2G, 2H, 2K, 2M, 2T, 2U, 2V, 2W, 2X and 3F. Drill sites 1G, 1R, 2F, 2U, 2V, 2W, and 2X did not receive MI in 2012. The total MI injection rate into the remaining drill sites averaged 37 MMSCFD in 2012. EOR Expansions Expansions to the original LSEOR occurred over multiple phases and now include Drill Sites 1B, 1C, 1D, 1E, 1L, 3B, 3G, 3H, 3O, 3Q and 3S. During 2012, the average MI injection rate into these expansion drill sites was 84 MMSCFD. IWAG During 2012 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. IWAG 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. 2012 EOR Program Status GKA Active EOR Patterns • 209 KRU • 9 Tarn • 7 Meltwater • 3 West Sak 2L, 2N (Tarn) 2P (MW) 2G 3R 3O 3N 3K 3H 3J 3C 1R 1H 1D 3B 1Q 1G 1B 3F 2W 1Y 1A 1F 2T 2U 2X 2Z 2V 2C 2D 1L 2A 2B 2F 2E 2K 2M 2H 3I 3A 3Q 1C 3G 3M 1E 3S W SAK SSEOR and SSEORX LSEOR and LSEORX EORX1 Expansion in 2002 – 4 Wells EORX1 Expansion in 2001 EORX1 Expansion in 2003 1C WSak EOR Pilot 2003 1D EOR Expansion in 2008 GKA Satellites 1998-2002 0 5000 10000 15000 20000 25000 30000 35000 40000 45000 BOPD 2005-2012 Kuparuk EOR+NGL Sales Production DS3S DS3R DS3Q DS3O DS3N DS3J DS3H DS3G DS3F DS3C DS3B DS3A DS2Z DS2X DS2W DS2V DS2U DS2T DS2M DS2K DS2H DS2G DS2F DS2D DS2C DS2B DS2A DS1Y DS1R DS1Q DS1L DS1J DS1H DS1G DS1F DS1E DS1D DS1C DS1B DS1A Attachment 2 Kuparuk River Oil Pool 2012 Annual Reservoir Surveillance Report Produced Fluid Volumes CUM OIL CUM GAS CUM WATER Cumulatives at Dec 31, 2011 2,256,040 3,009,551 3,732,828 OIL GAS WATER CUM OIL CUM GAS CUM WATER MO YR MSTB MMSCF MSTB MSTB MMSCF MSTB 1 2012 2,911 6,280 16,452 2,258,951 3,015,831 3,749,280 2 2012 2,759 5,910 14,843 2,261,709 3,021,741 3,764,123 3 2012 2,914 5,987 16,121 2,264,623 3,027,728 3,780,244 4 2012 2,697 5,372 14,958 2,267,320 3,033,100 3,795,202 5 2012 2,816 5,504 16,520 2,270,136 3,038,604 3,811,722 6 2012 2,088 3,769 11,366 2,272,225 3,042,372 3,823,087 7 2012 2,128 3,509 10,724 2,274,352 3,045,881 3,833,811 8 2012 2,691 4,906 14,422 2,277,043 3,050,787 3,848,233 9 2012 2,678 5,166 15,439 2,279,721 3,055,953 3,863,671 10 2012 2,863 5,845 16,552 2,282,584 3,061,798 3,880,223 11 2012 2,705 5,637 15,905 2,285,289 3,067,436 3,896,128 12 2012 2,817 5,885 16,893 2,288,106 3,073,321 3,913,021 2012 TOTAL 32,066 63,770 180,193 2,288,106 3,073,321 3,913,021 Produced Fluid Volumes (Reservoir Units) CUM OIL CUM GAS CUM WATER Cumulatives at Dec 31, 2011 2,783,954 1,712,904 3,803,752 OIL GAS WATER CUM OIL CUM GAS CUM WATER MO YR MRVB MRVB MRVB MRVB MRVB MRVB 1 2012 3,592 4,341 16,765 2,787,546 1,717,245 3,820,517 2 2012 3,404 4,077 15,125 2,790,950 1,721,322 3,835,642 3 2012 3,596 4,079 16,427 2,794,546 1,725,401 3,852,069 4 2012 3,328 3,625 15,242 2,797,874 1,729,026 3,867,311 5 2012 3,475 3,691 16,834 2,801,349 1,732,717 3,884,145 6 2012 2,577 2,459 11,581 2,803,926 1,735,176 3,895,726 7 2012 2,626 2,211 10,927 2,806,552 1,737,387 3,906,654 8 2012 3,320 3,213 14,696 2,809,872 1,740,600 3,921,349 9 2012 3,304 3,450 15,732 2,813,176 1,744,051 3,937,081 10 2012 3,533 3,975 16,866 2,816,709 1,748,025 3,953,948 11 2012 3,338 3,857 16,207 2,820,047 1,751,883 3,970,155 12 2012 3,476 4,030 17,214 2,823,523 1,755,912 3,987,369 2012 TOTAL 39,569 43,008 183,617 2,823,523 1,755,912 3,987,369 Attachment 3 Kuparuk River Oil Pool 2012 Annual Reservoir Surveillance Report Injected Fluid Volumes CUM WATER CUM GAS CUM MI Cumulatives at Dec 31, 2011 6,062,111 1,180,387 1,205,478 WATER GAS MI CUM WATER CUM GAS CUM MI MO YR MSTB MMSCF MMSCF MSTB MMSCF MMSCF 1 2012 20,838 189 3,942 6,082,949 1,180,576 1,209,420 2 2012 19,213 0 4,139 6,102,161 1,180,576 1,213,559 3 2012 19,371 0 4,174 6,121,532 1,180,576 1,217,733 4 2012 18,127 0 3,880 6,139,659 1,180,576 1,221,613 5 2012 18,882 0 4,314 6,158,541 1,180,576 1,225,927 6 2012 13,547 40 2,814 6,172,088 1,180,617 1,228,741 7 2012 14,696 824 1,512 6,186,784 1,181,440 1,230,253 8 2012 17,013 0 4,011 6,203,797 1,181,440 1,234,264 9 2012 16,280 59 4,157 6,220,078 1,181,499 1,238,421 10 2012 17,760 83 4,530 6,237,838 1,181,582 1,242,951 11 2012 19,558 105 3,873 6,257,396 1,181,687 1,246,824 12 2012 22,904 217 3,999 6,280,300 1,181,904 1,250,823 2012 TOTAL 218,189 1,517 45,345 6,280,300 1,181,904 1,250,823 Injected Fluid Volumes (Reservoir Units) CUM WATER CUM GAS CUM MI Cumulatives at Dec 31, 2011 6,177,290 1,042,971 627,822 WATER GAS MI CUM WATER CUM GAS CUM MI MO YR MRVB MRVB MRVB MRVB MRVB MRVB 1 2012 21,233 168 3 6,198,523 1,043,139 627,825 2 2012 19,578 0 3 6,218,101 1,043,139 627,828 3 2012 19,739 0 3 6,237,840 1,043,139 627,831 4 2012 18,471 0 3 6,256,311 1,043,139 627,834 5 2012 19,241 0 3 6,275,552 1,043,139 627,837 6 2012 13,804 36 2 6,289,357 1,043,175 627,840 7 2012 14,975 732 1 6,304,332 1,043,907 627,841 8 2012 17,336 0 3 6,321,668 1,043,907 627,844 9 2012 16,590 53 3 6,338,258 1,043,960 627,847 10 2012 18,098 74 3 6,356,356 1,044,033 627,850 11 2012 19,929 93 3 6,376,285 1,044,127 627,853 12 2012 23,339 193 3 6,399,625 1,044,320 627,856 2012 TOTAL 222,335 1,349 34 6,399,625 1,044,320 627,856 ATTACHMENT 4 Kuparuk River Oil Pool 2012 Annual Reservoir Surveillance Report Reservoir Pressure Surveys 6. Oil Gravity: 0.91 (water = 1.0) 8. Well Name and Number: 9. API Number 50XXXXXXXXXXXX NO DASHES 10. Type See Instructions 11. AOGCC Pool Code 12. Zone 13. Perforated Intervals Top - Bottom TVDSS 14. Final Test Date 15. Shut-In Time, Hours 16. Press. Surv. Type (see instructions for codes) 17. B.H. Temp. 18. Depth Tool TVDSS 19. Final Observed Pressure at Tool Depth 20. Datum TVDSS (input) 21. Pressure Gradient, psi/ft. 22. Pressure at Datum (cal) 1A-08 50029200000000 OIL 490100 AC (-5885 - -5921), (-5925 - -5930), (-5934 - -5939), (-5957 - -5968), (-6018 - -6020), (-6101 - -6111), (-6117 - -6143) 03/31/12 1777 SBHP 151 5844 2432 6200 0.281 2532 1A-25 50029200000000 OIL 490100 AC (-5981 - -5987), (-5987 - -5996), (-5996 - -6013), (-6016 - -6032), (-6132 - -6138), (-6148 - -6181) 04/24/12 128 SBHP 156 5999 2295 6200 0.336 2362 1A-27 50029200000000 OIL 490100 AC (-5961 - -6002), (-6029 - -6038), (-6162 - -6172), (-6182 - -6216), 04/15/12 25991 SBHP 154 5941 2951 6200 0.306 3030 1B-05 50029200000000 MWAG 490100 A (-6292 - -6332), (-6337 - -6345), (-6351 - -6356), (-6390 - -6410), (-6430 - -6480), (-6582 - -6590), (-6602 - -6615), (-6620 - -6632) 08/24/12 649 SBHP 143 6535 3383 6200 0.433 3238 1B-05 50029200000000 MWAG 490100 C (-6292 - -6332), (-6337 - -6345), (-6351 - -6356), (-6390 - -6410), (-6430 - -6480), (-6582 - -6590), (-6602 - -6615), (-6620 - -6632) 08/03/12 1009 SBHP 137 6324 2439 6200 0.303 2401 1B-05 50029200000000 MWAG 490100 C (-6292 - -6332), (-6337 - -6345), (-6351 - -6356), (-6390 - -6410), (-6430 - -6480), (-6582 - -6590), (-6602 - -6615), (-6620 - -6632) 08/23/12 306 SBHP 143 6400 2452 6200 0.350 2382 1B-07 50029200000000 MWAG 490100 A (-6199 - -6253), (-6267 - -6279), (-6285 - -6290), (-6415 - -6424), (-6431 - -6438), (-6443 - -6455) 08/31/12 907 SBHP 140 6341 3518 6200 0.331 3471 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 7. Gas Gravity: Kuparuk River Unit Kuparuk River Oil Pool -6200' SS 0.71 3. Unit or Lease Name:4. Field and Pool:5. Datum Reference: Form 10-412 Rev. 12/2008 6. Oil Gravity: 0.91 (water = 1.0) 8. Well Name and Number: 9. API Number 50XXXXXXXXXXXX NO DASHES 10. Type See Instructions 11. AOGCC Pool Code 12. Zone 13. Perforated Intervals Top - Bottom TVDSS 14. Final Test Date 15. Shut-In Time, Hours 16. Press. Surv. Type (see instructions for codes) 17. B.H. Temp. 18. Depth Tool TVDSS 19. Final Observed Pressure at Tool Depth 20. Datum TVDSS (input) 21. Pressure Gradient, psi/ft. 22. Pressure at Datum (cal) 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 7. Gas Gravity: Kuparuk River Unit Kuparuk River Oil Pool -6200' SS 0.71 3. Unit or Lease Name:4. Field and Pool:5. Datum Reference: 1B-07 50029200000000 MWAG 490100 C (-6199 - -6253), (-6267 - -6279), (-6285 - -6290), (-6415 - -6424), (-6431 - -6438), (-6443 - -6455) 09/01/12 907 SBHP 140 6239 2741 6200 0.331 2728 1B-18 50029200000000 OIL 490100 AC (-6298 - -6321), (-6324 - -6332), (-6337 - -6346), (-6385 - -6405), (-6393 - -6611), (-6618 - -6639) 09/03/12 7336 SBHP 164 6541 2640 6200 0.445 2488 1B-18 50029200000000 OIL 490100 AC (-6298 - -6321), (-6324 - -6332), (-6337 - -6346), (-6385 - -6405), (-6393 - -6611), (-6618 - -6639) 05/14/12 4104 SBHP 162 6464 2614 6200 0.350 2522 1C-05 50029200000000 MWAG 490100 C (-6308 - -6310), (-6372 - -6432), (-6698 - -6708), (-6718 - -6736) 01/10/12 110 SBHP 139 6350 2834 6200 0.450 2766 1C-16 50029200000000 OIL 490100 C (-6468 - -6489)07/24/12 403 SBHP 160 6479 3332 6200 0.341 3237 1C-28 50029200000000 OIL 490100 A (-6409 - -6425), (-6441 - -6475), (-6475 - -6463) 08/09/12 297 SBHP 153 6250 2406 6200 0.350 2388 1D-04A 50029200000000 OIL 490100 C (-6419 - -6357)04/27/12 1067 SBHP 145 5903 2952 6200 0.380 3065 1D-05 50029200000000 MWAG 490100 C (-6346 - -6429), (-6563 - -6579) 06/25/12 2615 SBHP 137 6372 3008 6200 0.436 2933 1D-12 50029200000000 OIL 490100 C (-6419 - -6439), (-6452 - -6461), (-6461 - -6477), (-6509 - -6510), (-6532 - -6538) 01/09/12 88 SBHP 158 6418 2835 6200 0.430 2741 1D-40A 50029200000000 MWAG 490100 C (-6144 - -6166)07/12/12 24505 SBHP 134 6145 2293 6200 0.350 2312 1E-05A 50029200000000 OIL 490100 A (-6131 - -6255), (-6230 - -6291), (-6229 - -6226), (-6115 - -6219), (-5954 - -6207) 05/29/12 685 SBHP 145 5928 2985 6200 0.496 3120 1E-09 50029200000000 PW 490100 C (-6075 - -6132), (-6246 - -6255), (-6269 - -6288), (-6292 - -6298) 10/28/12 165 SBHP 153 6280 2829 6200 0.442 2793 1E-15A 50029200000000 SW 490100 A (-6083 - -6143), (-6140 - -6143), (-6193 - -6203), (-6286 - -6257) 10/31/12 235 SBHP 128 6022 4233 6200 0.437 4311 Form 10-412 Rev. 12/2008 6. Oil Gravity: 0.91 (water = 1.0) 8. Well Name and Number: 9. API Number 50XXXXXXXXXXXX NO DASHES 10. Type See Instructions 11. AOGCC Pool Code 12. Zone 13. Perforated Intervals Top - Bottom TVDSS 14. Final Test Date 15. Shut-In Time, Hours 16. Press. Surv. Type (see instructions for codes) 17. B.H. Temp. 18. Depth Tool TVDSS 19. Final Observed Pressure at Tool Depth 20. Datum TVDSS (input) 21. Pressure Gradient, psi/ft. 22. Pressure at Datum (cal) 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 7. Gas Gravity: Kuparuk River Unit Kuparuk River Oil Pool -6200' SS 0.71 3. Unit or Lease Name:4. Field and Pool:5. Datum Reference: 1E-23 50029200000000 MWAG 490100 C (-5949 - -6025), (-6143 - -6156), (-6175 - -6184) 03/29/12 3532 SBHP 105 6003 2142 6200 0.350 2211 1E-23 50029200000000 MWAG 490100 A (-5949 - -6025), (-6143 - -6156), (-6175 - -6184) 03/30/12 3532 PBU 130 6068 3317 6200 0.350 3363 1E-24B 50029200000000 OIL 490100 A (-6070 - -6177), (-6177 - -6223), (-6168 - -6153), (-6107 - -6132), (-6192 - -6159) 10/22/12 725 SBHP 143 5748 2595 6200 0.350 2753 1E-24B 50029200000000 OIL 490100 A (-6070 - -6177), (-6177 - -6223), (-6168 - -6153), (-6107 - -6132), (-6192 - -6159) 03/25/12 588 SBHP 140 5748 3074 6200 0.503 3301 1E-27 50029200000000 MWAG 490100 A (-5925 - -5966), (-5975 - -5983), (-6114 - -6123), (-6138 - -6161), (-6168 - -6172) 01/19/12 231 SBHP 133 6005 2128 6200 0.370 2200 1E-28 50029200000000 OIL 490100 A (-6019 - -6102), (-6239 - -6249), (-6265 - -6285) 09/12/12 1176 SBHP 158 6204 2863 6200 0.350 2862 1E-32 50029200000000 MWAG 490100 C (-5981 - -5991), (-6000 - -6015), (-6044 - -6056), (-6055 - -6068) 06/08/12 94 SBHP 110 6050 2415 6200 0.400 2475 1E-34 50029200000000 OIL 490100 C (-5930 - -5945), (-5951 - -5956), (-5959 - -5971), (-5964 - -5960), (-5969 - -5969) 02/22/12 810 SBHP 151 5921 2278 6200 0.440 2401 1F-02 50029200000000 IWAG 490100 AC (-5786 - -5787), (-5829 - -5863), (-5904 - -5905), (-5954 - -5997), (-5955 - -5997), (-6037 - -6045) 12/30/12 12035 SBHP 129 5914 2656 6200 0.342 2754 1F-03A 50029200000000 OIL 490100 A (-5973 - -5997)11/01/12 11521 SBHP 152 5736 2381 6200 0.488 2607 1F-04 50029200000000 MWAG 490100 AC (-5783 - -5801), (-5859 - -5861), (-5905 - -5915), (-5928 - -5948), (-5954 - -5961) 12/26/12 12042 SBHP 126 5872 3315 6200 0.343 3427 1F-20 50029200000000 OIL 490100 AC (-5782 - -5792), (-5899 - -5920) 09/09/12 5198 SBHP 158 5841 2749 6200 0.235 2833 Form 10-412 Rev. 12/2008 6. Oil Gravity: 0.91 (water = 1.0) 8. Well Name and Number: 9. API Number 50XXXXXXXXXXXX NO DASHES 10. Type See Instructions 11. AOGCC Pool Code 12. Zone 13. Perforated Intervals Top - Bottom TVDSS 14. Final Test Date 15. Shut-In Time, Hours 16. Press. Surv. Type (see instructions for codes) 17. B.H. Temp. 18. Depth Tool TVDSS 19. Final Observed Pressure at Tool Depth 20. Datum TVDSS (input) 21. Pressure Gradient, psi/ft. 22. Pressure at Datum (cal) 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 7. Gas Gravity: Kuparuk River Unit Kuparuk River Oil Pool -6200' SS 0.71 3. Unit or Lease Name:4. Field and Pool:5. Datum Reference: 1G-10A 50029200000000 OIL 490100 AC (-6255 - -6265), (-6265 - -6274), (-6285 - -6290), (-6297 - -6304), (-6514 - -6540) 12/18/12 1592 SBHP 155 6239 2573 6200 0.332 2560 1H-03 50103200000000 PW 490100 C (-6260 - -6291), (-6338 - -6362), (-6504 - -6508), (-6515 - -6534) 10/22/12 168 SBHP 137 6205 2706 6200 0.437 2704 1H-03 50103200000000 PW 490100 A (-6260 - -6291), (-6338 - -6362), (-6504 - -6508), (-6515 - -6534) 10/15/12 168 SBHP 133 6316 3968 6200 0.437 3917 1H-14 50103200000000 OIL 490100 C (-6458 - -6465), (-6489 - -6490), (-6572 - -6587), (-6590 - -6592), (-6591 - -6592), (-6593 - -6595), (-6596 - -6599), (-6600 - -6604), (-6605 - -6616) 04/26/12 180 SBHP 122 6496 3727 6200 0.526 3571 1H-19 50103200000000 PW 490100 C (-6345 - -6392), (-6411 - -6440), (-6455 - -6462), (-6470 - -6477), (-6591 - -6606), (-6616 - -6631) 10/06/12 96 SBHP 135 6393 2896 6200 0.440 2811 1H-19 50103200000000 PW 490100 A (-6345 - -6392), (-6411 - -6440), (-6455 - -6462), (-6470 - -6477), (-6591 - -6606), (-6616 - -6631) 10/07/12 118 SBHP 138 6527 4097 6200 0.440 3953 1H-20 50103200000000 PW 490100 C (-6482 - -6499), (-6483 - -6485), (-6485 - -6497), (-6536 - -6544), (-6562 - -6587) 09/10/12 6017 SBHP 144 6536 2305 6200 0.426 2162 1H-21 50103200000000 OIL 490100 C (-6438 - -6508), (-6555 - -6578) 04/27/12 199 SBHP 162 6564 2175 6200 0.436 2016 1J-03 50103200000000 OIL 490100 C (-6362 - -6368), (-6490 - -6496) 10/13/12 4828 SBHP 152 6330 3131 6200 0.093 3119 1J-09 50103200000000 OIL 490100 C (-6102 - -6106), (-6109 - -6122), (-6117 - -6133), (-6133 - -6146) 07/11/12 96 SBHP 154 6117 2240 6200 0.410 2274 Form 10-412 Rev. 12/2008 6. Oil Gravity: 0.91 (water = 1.0) 8. Well Name and Number: 9. API Number 50XXXXXXXXXXXX NO DASHES 10. Type See Instructions 11. AOGCC Pool Code 12. Zone 13. Perforated Intervals Top - Bottom TVDSS 14. Final Test Date 15. Shut-In Time, Hours 16. Press. Surv. Type (see instructions for codes) 17. B.H. Temp. 18. Depth Tool TVDSS 19. Final Observed Pressure at Tool Depth 20. Datum TVDSS (input) 21. Pressure Gradient, psi/ft. 22. Pressure at Datum (cal) 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 7. Gas Gravity: Kuparuk River Unit Kuparuk River Oil Pool -6200' SS 0.71 3. Unit or Lease Name:4. Field and Pool:5. Datum Reference: 1J-09 50103200000000 OIL 490100 C (-6102 - -6106), (-6109 - -6122), (-6117 - -6133), (-6133 - -6146) 08/13/12 876 SBHP 154 6117 2397 6200 0.350 2426 1J-09A 50103200000000 OIL 490100 C (-6102 - -6106), (-6109 - -6112), (-6113 - -6139) 10/06/12 77 SBHP 148 6056 2477 6200 0.440 2540 1L-03A 50103200000000 PW 490100 A (-5964 - -5980), (-5994 - -6018), (-6012 - -6041) 11/29/12 19107 SBHP 108 4809 2459 6200 0.493 3145 1L-13 50103200000000 OIL 490100 C (-5819 - -5842), (-5822 - -5863), (-5842 - -5866), (-5954 - -5972), (-6028 - -6035) 10/11/12 285 SBHP 158 5927 2788 6200 0.350 2884 1L-21 50029200000000 0 490100 AC (-11653 - - 11713), (-11713 - -11733), (- 11925 - -11957) 10/07/12 7142 SBHP 133 6466 2323 6200 0.350 2230 1L-26A 50029200000000 OIL 490100 C (-5816 - -5817), (-5816 - -5816), (-5817 - -5816), (-5824 - -5825), (-5874 - -5886), (-5983 - -5998), (-5990 - -5993) 01/08/12 22000 SBHP 153 5806 3031 6200 0.368 3176 1L-26A 50029200000000 OIL 490100 A (-5816 - -5817), (-5816 - -5816), (-5817 - -5816), (-5824 - -5825), (-5874 - -5886), (-5983 - -5998), (-5990 - -5993) 06/15/12 38803 SBHP 126 5160 2842 6200 0.350 3206 1Q-01 50029200000000 MWAG 490100 C (-6153 - -6159), (-6241 - -6272), (-6281 - -6284), (-6447 - -6501) 02/23/12 99999 SBHP 148 6283 3737 6200 0.350 3708 1Q-01 50103200000000 MWAG 490100 A (-6153 - -6159), (-6241 - -6272), (-6281 - -6284), (-6447 - -6501) 02/22/12 99999 SBHP 149 6364 3776 6200 0.350 3719 1Q-02B 50103200000000 MWAG 490100 A (-6223 - -6225), (-6329 - -6339), (-6375 - -6376), (-6608 - -6672) 01/29/12 324 SBHP 120 6329 4184 6200 0.450 4126 1Q-06 50029200000000 OIL 490100 AC (-5947 - -5978), (-5995 - -6010), (-6130 - -6166), (-6223 - -6234) 01/20/12 493 SBHP 152 6098 2305 6200 0.350 2341 Form 10-412 Rev. 12/2008 6. Oil Gravity: 0.91 (water = 1.0) 8. Well Name and Number: 9. API Number 50XXXXXXXXXXXX NO DASHES 10. Type See Instructions 11. AOGCC Pool Code 12. Zone 13. Perforated Intervals Top - Bottom TVDSS 14. Final Test Date 15. Shut-In Time, Hours 16. Press. Surv. Type (see instructions for codes) 17. B.H. Temp. 18. Depth Tool TVDSS 19. Final Observed Pressure at Tool Depth 20. Datum TVDSS (input) 21. Pressure Gradient, psi/ft. 22. Pressure at Datum (cal) 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 7. Gas Gravity: Kuparuk River Unit Kuparuk River Oil Pool -6200' SS 0.71 3. Unit or Lease Name:4. Field and Pool:5. Datum Reference: 1Q-11 50029200000000 MWAG 490100 AC (-5786 - -5851), (-5859 - -5865), (-5957 - -6013), (-6052 - -6064) 05/31/12 21052 SBHP 119 5970 2511 6200 0.373 2597 1Q-22 50029200000000 OIL 490100 AC (-6401 - -6407), (-6590 - -6611) 04/02/12 22610 SBHP 168 6502 2824 6200 0.412 2700 1R-09 50029200000000 IWAG 490100 AC (-6306 - -6335), (-6428 - -6433), (-6439 - -6463), (-6485 - -6489) 12/12/12 186 SBHP 114 6452 4041 6200 0.449 3928 1R-09 50029200000000 IWAG 490100 AC (-6306 - -6335), (-6428 - -6433), (-6439 - -6463), (-6485 - -6489) 10/10/12 296 SBHP 124 6397 3938 6200 0.436 3852 1R-09 50029200000000 IWAG 490100 AC (-6306 - -6335), (-6428 - -6433), (-6439 - -6463), (-6485 - -6489) 09/26/12 297 SBHP 124 6397 3938 6200 0.436 3852 1R-10 50029200000000 MWAG 490100 AC (-6297 - -6328), (-6415 - -6431), (-6435 - -6454), (-6471 - -6476), (-6507 - -6512) 12/11/12 2127 SBHP 122 6404 3727 6200 0.423 3641 1R-13 50029200000000 MWAG 490100 AC (-6443 - -6457), (-6570 - -6610), (-6627 - -6634), (-6656 - -6662) 03/12/12 7182 SBHP 125 6552 3179 6200 0.440 3024 1R-14 50029200000000 OIL 490100 AC (-6485 - -6513), (-6642 - -6648), (-6651 - -6678), (-6731 - -6737) 05/11/12 5902 SBHP 158 6690 3096 6200 0.438 2882 1R-29 50029200000000 OIL 490100 C (-6440 - -6461), (-6551 - -6556), (-6582 - -6588), (-6613 - -6627), (-6636 - -6648) 09/20/12 152 SBHP 158 6449 2710 6200 0.245 2649 1R-29 50029200000000 OIL 490100 A (-6440 - -6461), (-6551 - -6556), (-6582 - -6588), (-6613 - -6627), (-6636 - -6648) 09/21/12 169 SBHP 160 6501 3074 6200 0.350 2969 1R-31 50029200000000 OIL 490100 A (-6574 - -6597), (-6616 - -6632) 05/05/12 60 PBU 160 6382 1675 6200 0.350 2443 1Y-04 50029200000000 MWAG 490100 AC (-5926 - -5975), (-6017 - -6042), (-6191 - -6207), (-6193 - -6206), (-6220 - -6237) 09/14/12 27966 SBHP 143 5905 2457 6200 0.182 2511 Form 10-412 Rev. 12/2008 6. Oil Gravity: 0.91 (water = 1.0) 8. Well Name and Number: 9. API Number 50XXXXXXXXXXXX NO DASHES 10. Type See Instructions 11. AOGCC Pool Code 12. Zone 13. Perforated Intervals Top - Bottom TVDSS 14. Final Test Date 15. Shut-In Time, Hours 16. Press. Surv. Type (see instructions for codes) 17. B.H. Temp. 18. Depth Tool TVDSS 19. Final Observed Pressure at Tool Depth 20. Datum TVDSS (input) 21. Pressure Gradient, psi/ft. 22. Pressure at Datum (cal) 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 7. Gas Gravity: Kuparuk River Unit Kuparuk River Oil Pool -6200' SS 0.71 3. Unit or Lease Name:4. Field and Pool:5. Datum Reference: 1Y-21 50029200000000 OIL 490100 A (-5958 - -6017), (-6176 - -6179), (-6188 - -6200), (-6210 - -6228) 01/01/12 5562 SBHP 157 6143 2342 6200 0.350 2362 1Y-29 50103200000000 OIL 490100 AC (-5960 - -5966), (-5970 - -5982), (-5991 - -6026), (-6057 - -6067) 11/15/12 9070 SBHP 156 5982 2452 6200 0.432 2546 2A-08 50103200000000 MWAG 490100 AC (-5721 - -5769), (-5805 - -5828) 10/31/12 13022 SBHP 130 5805 2728 6200 0.477 2916 2A-11 50029200000000 OIL 490100 AC (-5768 - -5793), (-5843 - -5852), (-5863 - -5884) 05/24/12 111 SBHP 157 5852 2259 6200 0.420 2405 2A-19A 50029200000000 OIL 490100 AC (-5741 - -5757), (-5800 - -5818) 09/08/12 864 SBHP 152 5779 2621 6200 0.474 2821 2C-04 50029200000000 MWAG 490100 A (-5575 - -5576), (-5633 - -5674), (-5647 - -5648), (-5649 - -5649), (-5653 - -5653), (-5658 - -5661), (-5664 - -5665), (-5669 - -5672), (-5695 - -5700), (-5697 - -5700), (-5706 - -5711), (-5707 - -5708), (-5708 - -5709), (-5710 - -5711), (-5755 - -5757), (-5795 - -5818), (-5796 - -5816), (-5816 - -5823) 08/19/12 8448 SBHP 128 5810 3080 6200 0.335 3211 2C-09 50029200000000 OIL 490100 AC (-5731 - -5819), (-5905 - -5937), (-5910 - -5910), (-5911 - -5912), (-5915 - -5930), (-5919 - -5921), (-5923 - -5931), (-5955 - -5971), (-5959 - -5961), (-5964 - -5966) 06/26/12 280 SBHP 152 5529 2237 6200 0.350 2472 Form 10-412 Rev. 12/2008 6. Oil Gravity: 0.91 (water = 1.0) 8. Well Name and Number: 9. API Number 50XXXXXXXXXXXX NO DASHES 10. Type See Instructions 11. AOGCC Pool Code 12. Zone 13. Perforated Intervals Top - Bottom TVDSS 14. Final Test Date 15. Shut-In Time, Hours 16. Press. Surv. Type (see instructions for codes) 17. B.H. Temp. 18. Depth Tool TVDSS 19. Final Observed Pressure at Tool Depth 20. Datum TVDSS (input) 21. Pressure Gradient, psi/ft. 22. Pressure at Datum (cal) 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 7. Gas Gravity: Kuparuk River Unit Kuparuk River Oil Pool -6200' SS 0.71 3. Unit or Lease Name:4. Field and Pool:5. Datum Reference: 2C-10 50029200000000 OIL 490100 AC (-5756 - -5761), (-5846 - -5846), (-5846 - -5853), (-5850 - -5850), (-5854 - -5854), (-5863 - -5864), (-5863 - -5888), (-5867 - -5868), (-5871 - -5872), (-5875 - -5875), (-5878 - -5879), (-5881 - -5882), (-5885 - -5885), (-5888 - -5888), (-5916 - -5920), (-5946 - -5954) 07/07/12 558 SBHP 160 5900 2357 6200 0.435 2487 2C-11 50029200000000 OIL 490100 AC (-5770 - -5787), (-5770 - -5787), (-5845 - -5853), (-5845 - -5853), (-5862 - -5891), (-5862 - -5891), (-5738 - -5747), (-5796 - -5805), (-5815 - -5846), (-5890 - -5899) 12/20/12 516 SBHP 160 5870 2343 6200 0.436 2487 2C-12 50103200000000 OIL 490100 AC (-5738 - -5747), (-5796 - -5805), (-5815 - -5846), (-5890 - -5899) 07/01/12 416 SBHP 159 5850 2784 6200 0.417 2930 2C-13 50103200000000 OIL 490100 A (-5782 - -5790), (-5801 - -5829) 06/28/12 312 SBHP 162 5806 3249 6200 0.350 3387 2C-14 50103200000000 OIL 490100 AC (-5690 - -5708), (-5794 - -5802), (-5810 - -5837), (-5862 - -5874) 07/09/12 611 SBHP 160 5834 2604 6200 0.310 2718 2C-15 50103200000000 OIL 490100 AC (-5660 - -5692), (-5773 - -5780), (-5788 - -5811), (-5829 - -5845) 07/08/12 586 SBHP 159 5809 2588 6200 0.434 2758 Form 10-412 Rev. 12/2008 6. Oil Gravity: 0.91 (water = 1.0) 8. Well Name and Number: 9. API Number 50XXXXXXXXXXXX NO DASHES 10. Type See Instructions 11. AOGCC Pool Code 12. Zone 13. Perforated Intervals Top - Bottom TVDSS 14. Final Test Date 15. Shut-In Time, Hours 16. Press. Surv. Type (see instructions for codes) 17. B.H. Temp. 18. Depth Tool TVDSS 19. Final Observed Pressure at Tool Depth 20. Datum TVDSS (input) 21. Pressure Gradient, psi/ft. 22. Pressure at Datum (cal) 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 7. Gas Gravity: Kuparuk River Unit Kuparuk River Oil Pool -6200' SS 0.71 3. Unit or Lease Name:4. Field and Pool:5. Datum Reference: 2C-16 50103200000000 OIL 490100 AC (-5607 - -5609), (-5639 - -5675), (-5681 - -5689), (-5694 - -5707), (-5738 - -5739), (-5790 - -5790), (-5800 - -5815), (-5803 - -5805), (-5809 - -5811), (-5813 - -5814), (-5836 - -5853) 07/08/12 580 SBHP 159 5806 2330 6200 0.394 2485 2D-03 50103200000000 OIL 490100 A (-5812 - -5815), (-5817 - -5819), (-5822 - -5823), (-5826 - -5830), (-5836 - -5838), (-5846 - -5848), (-5853 - -5855), (-5895 - -5896), (-5897 - -5898), (-5912 - -5944), (-5934 - -5934), (-5935 - -5936), (-5936 - -5937) 02/25/12 384 SBHP 159 5920 1762 6200 0.350 1860 2D-04 50103200000000 MWAG 490100 AC (-5847 - -5849), (-5872 - -5874), (-5893 - -5895), (-5906 - -5912), (-5917 - -5919) 05/12/12 5443 SBHP 119 5906 3919 6200 0.445 4050 2D-05 50103200000000 MWAG 490100 A (-5824 - -5864), (-5954 - -5962), (-5973 - -6011), (-5916 - -6021) 08/24/12 15959 SBHP 125 5892 2710 6200 0.289 2799 2D-05 50103200000000 MWAG 490100 A (-5824 - -5864), (-5954 - -5962), (-5973 - -6011), (-5916 - -6021) 06/29/12 14612 SBHP 129 5953 3070 6200 0.496 3193 2D-05 50103200000000 MWAG 490100 AC (-5824 - -5864), (-5954 - -5962), (-5973 - -6011), (-5916 - -6021) 06/06/12 14074 SBHP 156 6110 2991 6200 0.432 3030 2D-06B 50029200000000 OIL 490100 AC (-5916 - -6021)02/17/12 218 SBHP 157 5848 1891 6200 0.341 2011 2D-08 50029200000000 OIL 490100 AC (-5843 - -5866), (-5954 - -5967), (-5955 - -5967), (-5980 - -6012) 06/21/12 187 SBHP 159 5926 2664 6200 0.328 2754 2D-12 50029200000000 OIL 490100 A (-5889 - -5902), (-5922 - -5946) 06/21/12 2086 SBHP 159 5902 3446 6200 0.435 3576 Form 10-412 Rev. 12/2008 6. Oil Gravity: 0.91 (water = 1.0) 8. Well Name and Number: 9. API Number 50XXXXXXXXXXXX NO DASHES 10. Type See Instructions 11. AOGCC Pool Code 12. Zone 13. Perforated Intervals Top - Bottom TVDSS 14. Final Test Date 15. Shut-In Time, Hours 16. Press. Surv. Type (see instructions for codes) 17. B.H. Temp. 18. Depth Tool TVDSS 19. Final Observed Pressure at Tool Depth 20. Datum TVDSS (input) 21. Pressure Gradient, psi/ft. 22. Pressure at Datum (cal) 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 7. Gas Gravity: Kuparuk River Unit Kuparuk River Oil Pool -6200' SS 0.71 3. Unit or Lease Name:4. Field and Pool:5. Datum Reference: 2D-14 50029200000000 IWAG 490100 AC (-5790 - -5802), (-5837 - -5850), (-5862 - -5902) 06/01/12 31717 SBHP 143 5719 3612 6200 0.274 3744 2D-15 50029200000000 OIL 490100 AC (-5785 - -5799), (-5845 - -5861), (-5869 - -5906) 06/21/12 193 SBHP 161 5846 2973 6200 0.430 3125 2E-07 50029200000000 OIL 490100 AC (-5885 - -5918), (-5983 - -6001) 02/23/12 56000 SBHP 157 5962 3404 6200 0.360 3490 2E-09 50029200000000 OIL 490100 AC (-6006 - -6022), (-6047 - -6063), (-6082 - -6088) 03/24/12 99999 SBHP 163 6067 3360 6200 0.446 3419 2E-10 50029200000000 OIL 490100 A (-5907 - -5927), (-5949 - -5957), (-5986 - -5994) 03/23/12 626 SBHP 155 5898 1566 6200 0.350 1672 2E-16 50029200000000 OIL 490100 A (-5894 - -5907), (-5923 - -5946) 06/22/12 202 SBHP 162 5897 3101 6200 0.436 3233 2F-05X 50029200000000 OIL 490100 A (-5830 - -5839), (-5849 - -5873) 08/28/12 14345 SBHP 160 5851 3920 6200 0.435 4072 2F-06 50029200000000 OIL 490100 A (-5770 - -5781), (-5792 - -5829), (-5867 - -5874) 06/24/12 42714 SBHP 157 5640 2948 6200 0.439 3194 2F-09 50029200000000 OIL 490100 A (-5841 - -5853), (-5865 - -5905) 06/24/12 240 SBHP 161 5875 2948 6200 0.433 3089 2F-10 50029200000000 OIL 490100 A (-5813 - -5827), (-5816 - -5830), (-5878 - -5892), (-5905 - -5947) 06/26/12 280 SBHP 160 5821 3436 6200 0.350 3569 2F-11 50029200000000 OIL 490100 AC (-5798 - -5799), (-5847 - -5855), (-5884 - -5885), (-5909 - -5924), (-5939 - -5963), (-5971 - -5978) 06/22/12 201 SBHP 161 5914 2176 6200 0.428 2298 2F-11 50029200000000 OIL 490100 AC (-5798 - -5799), (-5847 - -5855), (-5884 - -5885), (-5909 - -5924), (-5939 - -5963), (-5971 - -5978) 08/30/12 1848 SBHP 160 5914 3124 6200 0.428 3246 2F-11 50029200000000 OIL 490100 AC (-5798 - -5799), (-5847 - -5855), (-5884 - -5885), (-5909 - -5924), (-5939 - -5963), (-5971 - -5978) 03/01/12 144 SBHP 160 5914 2040 6200 0.414 2158 Form 10-412 Rev. 12/2008 6. Oil Gravity: 0.91 (water = 1.0) 8. Well Name and Number: 9. API Number 50XXXXXXXXXXXX NO DASHES 10. Type See Instructions 11. AOGCC Pool Code 12. Zone 13. Perforated Intervals Top - Bottom TVDSS 14. Final Test Date 15. Shut-In Time, Hours 16. Press. Surv. Type (see instructions for codes) 17. B.H. Temp. 18. Depth Tool TVDSS 19. Final Observed Pressure at Tool Depth 20. Datum TVDSS (input) 21. Pressure Gradient, psi/ft. 22. Pressure at Datum (cal) 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 7. Gas Gravity: Kuparuk River Unit Kuparuk River Oil Pool -6200' SS 0.71 3. Unit or Lease Name:4. Field and Pool:5. Datum Reference: 2F-11 50029200000000 OIL 490100 AC (-5798 - -5799), (-5847 - -5855), (-5884 - -5885), (-5909 - -5924), (-5939 - -5963), (-5971 - -5978) 05/17/12 120 SBHP 157 5904 2087 6200 0.350 2191 2F-11A 50029200000000 OIL 490100 A (-5798 - -5799), (-5847 - -5855), (-5964 - -5966), (-5967 - -5929) 11/01/12 3364 SBHP 151 5750 3402 6200 0.556 3652 2F-12 50029200000000 OIL 490100 AC (-5842 - -5853), (-5867 - -5900) 06/20/12 154 SBHP 160 5871 2677 6200 0.424 2817 2F-14 50029200000000 MWAG 490100 AC (-5888 - -5897), (-5916 - -5934) 05/13/12 2016 SBHP 98 4267 4149 6200 0.454 5026 2F-14 50029200000000 MWAG 490100 A (-5888 - -5897), (-5916 - -5934) 10/10/12 5619 SBHP 111 5912 4406 6200 0.356 4509 2F-14 50029200000000 MWAG 490100 AC (-5888 - -5897), (-5916 - -5934) 02/25/12 145 SBHP 106 5912 4933 6200 0.372 5040 2F-17 50029200000000 PW 490100 AC (-5847 - -5854), (-5913 - -5921), (-5942 - -5955) 09/27/12 2500 SBHP 141 5819 4669 6200 0.450 4841 2F-18 50029200000000 OIL 490100 A (-5948 - -5957), (-5979 - -6000) 06/23/12 11410 SBHP 116 4602 3117 6200 0.441 3822 2F-18 50029200000000 OIL 490100 A (-5948 - -5957), (-5979 - -6000) 09/19/12 14400 SBHP 158 5957 4387 6200 0.441 4494 2F-18 50029200000000 OIL 490100 AC (-5948 - -5957), (-5979 - -6000) 11/25/12 15132 SBHP 159 5957 4325 6200 0.378 4417 2F-19 50103200000000 OIL 490100 A (-5856 - -5865), (-5905 - -5923), (-5939 - -5957) 08/23/12 44154 SBHP 154 5735 3745 6200 0.458 3958 2F-19 50103200000000 OIL 490100 AC (-5856 - -5865), (-5905 - -5923), (-5939 - -5957) 06/23/12 42692 SBHP 151 5777 3608 6200 0.453 3799 2F-19A 50029200000000 OIL 490100 A (-5976 - -5980)12/05/12 9999 SBHP 132 5258 3428 6200 0.330 3739 2G-02 50029200000000 OIL 490100 A (-5929 - -5942), (-5954 - -5982) 10/13/12 11552 SBHP 154 5937 4435 6200 0.360 4530 2G-04 50029200000000 OIL 490100 A (-5934 - -5940), (-5951 - -5979), (-6017 - -6025), (-6026 - -6034), (-6035 - -6043) 06/23/12 215 SBHP 159 5956 3800 6200 0.402 3898 2G-08 50029200000000 OIL 490100 A (-5865 - -5875), (-5887 - -5916) 07/01/12 400 SBHP 161 5891 3952 6200 0.439 4088 2G-10 50103200000000 MWAG 490100 A (-5974 - -5987), (-6000 - -6028) 03/19/12 4153 SBHP 118 5914 4710 6200 0.332 4805 2G-12 50103200000000 MWAG 490100 A (-5988 - -6003), (-6015 - -6048) 10/10/12 3636 SBHP 100 6015 4679 6200 0.449 4762 Form 10-412 Rev. 12/2008 6. Oil Gravity: 0.91 (water = 1.0) 8. Well Name and Number: 9. API Number 50XXXXXXXXXXXX NO DASHES 10. Type See Instructions 11. AOGCC Pool Code 12. Zone 13. Perforated Intervals Top - Bottom TVDSS 14. Final Test Date 15. Shut-In Time, Hours 16. Press. Surv. Type (see instructions for codes) 17. B.H. Temp. 18. Depth Tool TVDSS 19. Final Observed Pressure at Tool Depth 20. Datum TVDSS (input) 21. Pressure Gradient, psi/ft. 22. Pressure at Datum (cal) 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 7. Gas Gravity: Kuparuk River Unit Kuparuk River Oil Pool -6200' SS 0.71 3. Unit or Lease Name:4. Field and Pool:5. Datum Reference: 2G-13 50103200000000 OIL 490100 A (-5996 - -6007), (-5996 - -6004), (-5999 - -5999), (-5999 - -6000), (-6006 - -6006), (-6006 - -6007), (-6021 - -6051), (-6023 - -6026), (-6030 - -6030), (-6031 - -6032), (-6032 - -6033), (-6036 - -6037), (-6041 - -6041), (-6046 - -6048) 05/17/12 56000 SBHP 153 5851 4533 6200 0.447 4689 2G-15 50103200000000 OIL 490100 A (-5904 - -5914), (-5967 - -5978), (-5969 - -5970), (-5973 - -5973), (-5974 - -5975), (-5992 - -6023), (-5994 - -5995), (-5996 - -5998), (-6000 - -6001), (-6003 - -6005), (-6007 - -6009), (-6013 - -6014), (-6015 - -6016) 07/10/12 924 SBHP 161 5995 4349 6200 0.430 4437 2H-05 50103200000000 OIL 490100 A (-5877 - -5899), (-5961 - -5965), (-5975 - -5997), (-5978 - -5990), (-6018 - -6038) 10/16/12 1924 SBHP 158 5985 3345 6200 0.430 3438 2H-06 50103200000000 OIL 490100 A (-5843 - -5867), (-5934 - -5938), (-5948 - -5968), (-5985 - -6005) 10/11/12 1550 SBHP 160 5970 3238 6200 0.350 3319 2H-11 50103200000000 OIL 490100 AC (-5908 - -5915), (-5964 - -5980), (-6003 - -6022) 02/03/12 550 SBHP 160 5958 2751 6200 0.350 2836 2H-14 50103200000000 OIL 490100 A (-5947 - -5959), (-5982 - -5990), (-5998 - -6022), (-6040 - -6058) 01/27/12 1128 PBU 165 5982 3329 6200 0.360 3407 2H-15 50103200000000 MWAG 490100 A (-5855 - -5855), (-5887 - -5893), (-5900 - -5915), (-5932 - -5958) 10/03/12 746 SBHP 114 5907 3663 6200 0.386 3776 Form 10-412 Rev. 12/2008 6. Oil Gravity: 0.91 (water = 1.0) 8. Well Name and Number: 9. API Number 50XXXXXXXXXXXX NO DASHES 10. Type See Instructions 11. AOGCC Pool Code 12. Zone 13. Perforated Intervals Top - Bottom TVDSS 14. Final Test Date 15. Shut-In Time, Hours 16. Press. Surv. Type (see instructions for codes) 17. B.H. Temp. 18. Depth Tool TVDSS 19. Final Observed Pressure at Tool Depth 20. Datum TVDSS (input) 21. Pressure Gradient, psi/ft. 22. Pressure at Datum (cal) 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 7. Gas Gravity: Kuparuk River Unit Kuparuk River Oil Pool -6200' SS 0.71 3. Unit or Lease Name:4. Field and Pool:5. Datum Reference: 2H-16 50103200000000 MWAG 490100 AC (-5815 - -5833), (-5859 - -5864), (-5870 - -5885), (-5897 - -5913) 10/04/12 764 SBHP 128 5509 3067 6200 0.350 3309 2K-01 50029200000000 OIL 490100 AC (-5963 - -5990), (-5963 - -5990) 11/07/12 3517 SBHP 156 5963 4199 6200 0.502 4318 2K-01 50029200000000 OIL 490100 A (-5963 - -5990), (-5963 - -5990) 06/27/12 300 SBHP 156 5959 3845 6200 0.433 3949 2K-04 50029200000000 OIL 490100 AC (-5941 - -5951), (-5975 - -5992), (-3807 - -3827) 07/18/12 810 SBHP 156 5983 2960 6200 0.470 3062 2K-06 50103200000000 MWAG 490100 AC (-5978 - -5992), (-6028 - -6044), (-6028 - -6055) 04/19/12 2870 SBHP 128 6003 3768 6200 0.437 3854 2K-07 50103200000000 OIL 490100 A (-5978 - -5984), (-6039 - -6047), (-6062 - -6087) 07/05/12 528 SBHP 156 5979 2909 6200 0.430 3004 2K-14 50103200000000 OIL 490100 AC (-6190 - -6225)04/07/12 180 SBHP 159 6085 2466 6200 0.350 2506 2K-14 50029200000000 OIL 490100 A (-6190 - -6225)02/23/12 113 SBHP 164 8661 2303 6200 0.459 1173 2K-14 50029200000000 OIL 490100 AC (-6190 - -6225)02/24/12 112 SBHP 164 6097 2300 6200 0.350 2336 2K-14A 50029200000000 OIL 490100 A (-6190 - -6225)07/24/12 1660 SBHP 156 6024 3832 6200 0.436 3909 2K-16 50029200000000 OIL 490100 A (-6807 - -6097), (-6807 - -6096), (-6141 - -6147), (-6166 - -6198) 12/13/12 21528 SBHP 163 6142 4318 6200 0.440 4343 2K-26 50029200000000 OIL 490100 A (-5934 - -5938), (-5988 - -6000), (-6019 - -6041) 11/20/12 100 SBHP 159 6065 2081 6200 0.307 2122 2K-27 50029200000000 OIL 490100 AC (-6005 - -6017), (-6027 - -6044), (-6027 - -6044) 09/07/12 764 SBHP 146 5794 3380 6200 0.428 3554 2M-01 50029200000000 OIL 490100 AC (-5897 - -5938)03/14/12 144 SBHP 160 5916 3040 6200 0.400 3154 2M-03 50029200000000 MWAG 490100 AC (-5891 - -5907), (-5916 - -5925), (-5936 - -5953), (-5953 - -5969) 02/23/12 270 SBHP 130 5938 4483 6200 0.450 4601 2M-03 50029200000000 MWAG 490100 AC (-5891 - -5907), (-5916 - -5925), (-5936 - -5953), (-5953 - -5969) 05/25/12 2000 SBHP 134 5914 3921 6200 0.446 4049 2M-03 50029200000000 MWAG 490100 AC (-5891 - -5907), (-5916 - -5925), (-5936 - -5953), (-5953 - -5969) 04/18/12 1277 SBHP 132 5938 4054 6200 0.440 4169 2M-05 50029200000000 MWAG 490100 AC (-5859 - -5880), (-5889 - -5895), (-5895 - -5910) 05/25/12 2112 SBHP 137 5838 3901 6200 0.446 4062 Form 10-412 Rev. 12/2008 6. Oil Gravity: 0.91 (water = 1.0) 8. Well Name and Number: 9. API Number 50XXXXXXXXXXXX NO DASHES 10. Type See Instructions 11. AOGCC Pool Code 12. Zone 13. Perforated Intervals Top - Bottom TVDSS 14. Final Test Date 15. Shut-In Time, Hours 16. Press. Surv. Type (see instructions for codes) 17. B.H. Temp. 18. Depth Tool TVDSS 19. Final Observed Pressure at Tool Depth 20. Datum TVDSS (input) 21. Pressure Gradient, psi/ft. 22. Pressure at Datum (cal) 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 7. Gas Gravity: Kuparuk River Unit Kuparuk River Oil Pool -6200' SS 0.71 3. Unit or Lease Name:4. Field and Pool:5. Datum Reference: 2M-05 50029200000000 MWAG 490100 AC (-5859 - -5880), (-5889 - -5895), (-5895 - -5910) 04/18/12 1547 SBHP 127 5863 3976 6200 0.433 4122 2M-05 50029200000000 MWAG 490100 AC (-5859 - -5880), (-5889 - -5895), (-5895 - -5910) 02/23/12 270 SBHP 135 5863 4237 6200 0.444 4387 2M-06 50029200000000 MWAG 490100 AC (-5820 - -5829), (-5829 - -5857) 03/04/12 213 SBHP 121 5820 4531 6200 0.435 4696 2M-07 50103200000000 OIL 490100 A (-5907 - -5915), (-1919 - -5935), (-5953 - -5959), (-5960 - -5961), (-5961 - -5962), (-5962 - -5961), (-5963 - -5970), (-5975 - -5975), (-5975 - -5976), (-5976 - -5976) 08/02/12 1139 PBU 155 5649 3507 6200 0.360 4398 2M-10 50103200000000 OIL 490100 AC (-5826 - -5834), (-5846 - -5852), (-5856 - -5869), (-5878 - -5892), (-5892 - -5906) 06/29/12 350 SBHP 156 5881 3169 6200 0.433 3307 2M-12 50103200000000 OIL 490100 A (-5870 - -5882), (-5918 - -5937) 06/29/12 350 SBHP 156 5889 3764 6200 0.360 3876 2M-15 50103200000000 OIL 490100 AC (-5865 - -5880), (-5903 - -5912), (-5924 - -5940), (-5940 - -5955) 06/28/12 330 SBHP 158 5937 3126 6200 0.425 3238 2M-20 50029200000000 OIL 490100 AC (-5846 - -5857), (-5858 - -5870), (-5881 - -5885), (-5894 - -5904), (-5916 - -5931), (-5931 - -5939), (-5939 - -5942) 06/25/12 280 SBHP 154 5843 2373 6200 0.421 2523 2M-21 50029200000000 OIL 490100 AC (-5744 - -5751), (-5756 - -5763), (-5801 - -5810), (-5810 - -5819), (-5819 - -5828) 06/25/12 280 SBHP 154 5810 2544 6200 0.417 2707 2M-22 50029200000000 OIL 490100 A (-5960 - -5976), (-6011 - -6021) 06/26/12 280 SBHP 158 5990 2696 6200 0.395 2779 2M-24 50029200000000 OIL 490100 A (-5894 - -5902), (-5922 - -5929), (-5938 - -5950), (-5966 - -5983), (-5983 - -5988) 07/15/12 880 SBHP 160 5934 2816 6200 0.450 2936 2M-25 50029200000000 OIL 490100 A (-5963 - -5975), (-5975 - -5993) 06/26/12 280 SBHP 150 5735 2208 6200 0.430 2408 Form 10-412 Rev. 12/2008 6. Oil Gravity: 0.91 (water = 1.0) 8. Well Name and Number: 9. API Number 50XXXXXXXXXXXX NO DASHES 10. Type See Instructions 11. AOGCC Pool Code 12. Zone 13. Perforated Intervals Top - Bottom TVDSS 14. Final Test Date 15. Shut-In Time, Hours 16. Press. Surv. Type (see instructions for codes) 17. B.H. Temp. 18. Depth Tool TVDSS 19. Final Observed Pressure at Tool Depth 20. Datum TVDSS (input) 21. Pressure Gradient, psi/ft. 22. Pressure at Datum (cal) 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 7. Gas Gravity: Kuparuk River Unit Kuparuk River Oil Pool -6200' SS 0.71 3. Unit or Lease Name:4. Field and Pool:5. Datum Reference: 2M-27 50029200000000 MWAG 490100 A (-5900 - -5911), (-5915 - -5924), (-5938 - -5950), (-5950 - -5965) 04/20/12 1650 SBHP 137 5939 4128 6200 0.361 4222 2M-27 50029200000000 MWAG 490100 C (-5900 - -5911), (-5915 - -5924), (-5938 - -5950), (-5950 - -5965) 02/24/12 284 SBHP 126 5939 4335 6200 0.438 4449 2M-28 50029200000000 OIL 490100 AC (-5900 - -5915), (-5915 - -5930), (-5930 - -5946) 06/27/12 318 SBHP 161 5933 3372 6200 0.436 3489 2M-29 50029200000000 OIL 490100 AC (-5972 - -5990), (-5990 - -5996), (-5997 - -5991), (-5999 - -6001), (-6002 - -5999) 06/27/12 324 SBHP 159 5885 3815 6200 0.360 3929 2M-33 50029200000000 OIL 490100 AC (-5990 - -5993), (-5993 - -5996), (-6013 - -6061), (-6065 - -6070) 06/28/12 343 SBHP 162 5914 3801 6200 0.443 3928 2T-03 50029200000000 OIL 490100 AC (-5665 - -5677), (-5673 - -5695), (-5677 - -5695), (-5719 - -5730), (-5726 - -5727) 04/30/12 112 SBHP 156 5672 2913 6200 0.438 3144 2T-12A 50029200000000 OIL 490100 A (-5720 - -5746), (-5812 - -5843) 03/31/12 260 SBHP 159 5770 3221 6200 0.350 3372 2T-12A 50029200000000 OIL 490100 C (-5720 - -5746), (-5812 - -5843) 04/01/12 260 SBHP 109 4165 2261 6200 0.230 2729 2T-14 50029200000000 OIL 490100 AC (-5727 - -5760), (-5818 - -5844) 03/21/12 386 SBHP 150 5453 2371 6200 0.370 2648 2T-15 50029200000000 MWAG 490100 AC (-5688 - -5719), (-5781 - -5805) 03/22/12 411 SBHP 127 5690 3108 6200 0.369 3296 2T-19 50029200000000 OIL 490100 AC (-5758 - -5772), (-5805 - -5835), (-5805 - -5816), (-5816 - -5830), (-5855 - -5870) 07/17/12 801 SBHP 158 5810 2599 6200 0.419 2763 2T-31 50103200000000 OIL 490100 A (-5695 - -5711), (-5737 - -5747) 07/16/12 1439 SBHP 156 5654 2872 6200 0.419 3101 2T-37 50103200000000 OIL 490100 A (-5689 - -5704), (-5718 - -5730) 07/21/12 896 SBHP 155 5692 2821 6200 0.420 3034 2U-06 50029200000000 OIL 490100 AC (-5648 - -5686), (-5753 - -5763), (-5763 - -5796), (-5841 - -5859) 07/26/12 1019 SBHP 155 5593 2666 6200 0.350 2878 Form 10-412 Rev. 12/2008 6. Oil Gravity: 0.91 (water = 1.0) 8. Well Name and Number: 9. API Number 50XXXXXXXXXXXX NO DASHES 10. Type See Instructions 11. AOGCC Pool Code 12. Zone 13. Perforated Intervals Top - Bottom TVDSS 14. Final Test Date 15. Shut-In Time, Hours 16. Press. Surv. Type (see instructions for codes) 17. B.H. Temp. 18. Depth Tool TVDSS 19. Final Observed Pressure at Tool Depth 20. Datum TVDSS (input) 21. Pressure Gradient, psi/ft. 22. Pressure at Datum (cal) 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 7. Gas Gravity: Kuparuk River Unit Kuparuk River Oil Pool -6200' SS 0.71 3. Unit or Lease Name:4. Field and Pool:5. Datum Reference: 2U-10 50029200000000 OIL 490100 AC (-5675 - -5700), (-5777 - -5815), (-5844 - -5846), (-5850 - -5852), (-5869 - -5871) 06/25/12 271 SBHP 158 5761 2571 6200 0.396 2745 2U-15 50029200000000 OIL 490100 AC (-5667 - -5750), (-5770 - -5774), (-5780 - -5785), (-5876 - -5921) 07/21/12 873 SBHP 156 5876 2017 6200 0.350 2130 2V-10 50029200000000 OIL 490100 AC (-5665 - -5681), (-5681 - -5691), (-5691 - -5702), (-5708 - -5714), (-5719 - -5724), (-5811 - -5816), (-5822 - -5835), (-5845 - -5878), (-5882 - -5885) 10/05/12 1340 SBHP 161 5848 2451 6200 0.423 2600 2V-11 50029200000000 OIL 490100 AC (-5651 - -5667), (-5668 - -5686), (-5693 - -5696), (-5701 - -5706), (-5790 - -5804), (-5817 - -5844) 06/28/12 295 SBHP 161 5808 2416 6200 0.420 2581 2W-01 50029200000000 OIL 490100 AC (-5784 - -5842), (-5933 - -5937), (-5950 - -5981), (-6029 - -6040) 06/25/12 297 SBHP 151 5946 2267 6200 0.409 2371 2W-03 50029200000000 OIL 490100 AC (-5689 - -5750), (-5836 - -5892), (-5935 - -5943) 06/26/12 315 SBHP 150 5813 2144 6200 0.375 2289 2W-07 50029200000000 OIL 490100 AC (-5702 - -5763), (-5863 - -5905), (-5864 - -5906) 06/26/12 319 SBHP 154 5862 2507 6200 0.433 2653 2W-11 50029200000000 OIL 490100 AC (-5769 - -5848), (-5855 - -5859), (-5953 - -5957), (-5960 - -5985), (-5988 - -5996), (-5998 - -6001), (-6006 - -6010) 06/27/12 337 SBHP 156 5955 2656 6200 0.430 2762 2W-12 50029200000000 OIL 490100 AC (-5793 - -5795), (-5795 - -5816), (-5943 - -5945), (-5945 - -5977), (-5977 - -5984), (-5999 - -6003), (-6010 - -6017), (-6036 - -6041) 06/23/12 290 SBHP 154 6010 2670 6200 0.396 2745 Form 10-412 Rev. 12/2008 6. Oil Gravity: 0.91 (water = 1.0) 8. Well Name and Number: 9. API Number 50XXXXXXXXXXXX NO DASHES 10. Type See Instructions 11. AOGCC Pool Code 12. Zone 13. Perforated Intervals Top - Bottom TVDSS 14. Final Test Date 15. Shut-In Time, Hours 16. Press. Surv. Type (see instructions for codes) 17. B.H. Temp. 18. Depth Tool TVDSS 19. Final Observed Pressure at Tool Depth 20. Datum TVDSS (input) 21. Pressure Gradient, psi/ft. 22. Pressure at Datum (cal) 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 7. Gas Gravity: Kuparuk River Unit Kuparuk River Oil Pool -6200' SS 0.71 3. Unit or Lease Name:4. Field and Pool:5. Datum Reference: 2W-13 50029200000000 OIL 490100 AC (-5787 - -5815), (-5845 - -5849), (-5960 - -6006), (-6020 - -6024), (-6050 - -6055) 06/25/12 838 SBHP 154 6019 2800 6200 0.433 2878 2W-15 50029200000000 OIL 490100 AC (-5747 - -5801), (-5811 - -5815), (-5907 - -5959) 06/27/12 389 SBHP 153 5847 2510 6200 0.426 2660 2W-17 50029200000000 OIL 490100 A (-5872 - -5877), (-5889 - -5912), (-5948 - -5980) 06/25/12 288 SBHP 156 5898 2359 6200 0.435 2490 2X-13 50029200000000 OIL 490100 AC (-5667 - -5699), (-5699 - -5733), (-5844 - -5864), (-5869 - -5897) 07/04/12 487 SBHP 152 5834 2198 6200 0.425 2353 2X-14 50029200000000 OIL 490100 AC (-5716 - -5807), (-5955 - -5972), (-5957 - -5965), (-5981 - -6006), (-5981 - -5997) 07/05/12 621 SBHP 153 5844 2295 6200 0.235 2379 2X-15 50029200000000 OIL 490100 AC (-5729 - -5774), (-5789 - -5804), (-5939 - -5942), (-5950 - -5970), (-5982 - -6002), (-5982 - -6002) 07/05/12 605 SBHP 159 5971 2412 6200 0.415 2507 2Z-08 50029200000000 MWAG 490100 C (-5821 - -5901), (-5980 - -5989), (-5998 - -6023) 03/05/12 621 SBHP 134 5918 2757 6200 0.460 2887 2Z-13A 50029200000000 OIL 490100 AC (-5920 - -5924), (-5967 - -5987), (-5988 - -5996), (-6000 - -5992) 09/20/12 33173 SBHP 154 5718 2999 6200 0.340 3163 2Z-18 50029200000000 OIL 490100 AC (-5779 - -5794), (-5800 - -5841), (-5845 - -5846), (-5953 - -5961), (-5969 - -5993), (-6014 - -6027) 07/03/12 450 SBHP 155 5863 2652 6200 0.350 2770 2Z-29 50029200000000 OIL 490100 AC (-5808 - -5843), (-5936 - -5949), (-5956 - -5985), (-5956 - -5967), (-5967 - -5988), (-5985 - -5991), (-6019 - -6026), (-6031 - -6039) 07/07/12 570 SBHP 158 5935 2608 6200 0.350 2701 Form 10-412 Rev. 12/2008 6. Oil Gravity: 0.91 (water = 1.0) 8. Well Name and Number: 9. API Number 50XXXXXXXXXXXX NO DASHES 10. Type See Instructions 11. AOGCC Pool Code 12. Zone 13. Perforated Intervals Top - Bottom TVDSS 14. Final Test Date 15. Shut-In Time, Hours 16. Press. Surv. Type (see instructions for codes) 17. B.H. Temp. 18. Depth Tool TVDSS 19. Final Observed Pressure at Tool Depth 20. Datum TVDSS (input) 21. Pressure Gradient, psi/ft. 22. Pressure at Datum (cal) 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 7. Gas Gravity: Kuparuk River Unit Kuparuk River Oil Pool -6200' SS 0.71 3. Unit or Lease Name:4. Field and Pool:5. Datum Reference: 3A-06 50103200000000 SW 490100 AC (-5866 - -5924), (-6016 - -6033), (-6017 - -6032), (-6041 - -6078), (-6096 - -6101) 06/01/12 11757 SBHP 134 5669 3222 6200 0.460 3466 3A-09 50103200000000 OIL 490100 A (-2252 - -2272), (-5921 - -5934), (-6011 - -6029), (-6013 - -6029), (-6036 - -6076), (-6101 - -6107) 09/08/12 8304 SBHP 158 6010 3317 6200 0.350 3383 3A-12 50103200000000 OIL 490100 A (-5938 - -5966), (-5974 - -5999), (-6034 - -6040) 12/05/12 2462 SBHP 152 6011 2411 6200 0.340 2475 3A-12 50103200000000 OIL 490100 A (-5938 - -5966), (-5974 - -5999), (-6034 - -6040) 09/05/12 280 SBHP 152 5981 2148 6200 0.350 2225 3A-17A 50103200000000 OIL 490100 A (-6018 - -6011)11/12/12 109 SBHP 155 5951 3186 6200 0.350 3273 3B-08 50103200000000 OIL 490100 C (-5921 - -5927), (-5949 - -5960), (-5980 - -5994), (-6014 - -6023), (-6106 - -6139), (-6152 - -6167), (-6171 - -6175) 10/27/12 831 SBHP 151 6003 3165 6200 0.440 3252 3B-08 50103200000000 OIL 490100 A (-5921 - -5927), (-5949 - -5960), (-5980 - -5994), (-6014 - -6023), (-6106 - -6139), (-6152 - -6167), (-6171 - -6175) 10/26/12 837 SBHP 151 6067 3570 6200 0.440 3629 3C-09 50103200000000 PW 490100 A (-6310 - -6320), (-6355 - -6363), (-6433 - -6467), (-6483 - -6499) 08/05/12 216 SBHP 113 6402 4969 6200 0.430 4882 3C-09 50103200000000 PW 490100 C (-6310 - -6320), (-6355 - -6363), (-6433 - -6467), (-6483 - -6499) 08/06/12 216 SBHP 126 6282 4325 6200 0.430 4290 3C-10 50103200000000 OIL 490100 A (-6337 - -6346), (-6452 - -6484), (-6500 - -6519) 01/19/12 839 SBHP 156 6489 2788 6200 0.386 2676 Form 10-412 Rev. 12/2008 6. Oil Gravity: 0.91 (water = 1.0) 8. Well Name and Number: 9. API Number 50XXXXXXXXXXXX NO DASHES 10. Type See Instructions 11. AOGCC Pool Code 12. Zone 13. Perforated Intervals Top - Bottom TVDSS 14. Final Test Date 15. Shut-In Time, Hours 16. Press. Surv. Type (see instructions for codes) 17. B.H. Temp. 18. Depth Tool TVDSS 19. Final Observed Pressure at Tool Depth 20. Datum TVDSS (input) 21. Pressure Gradient, psi/ft. 22. Pressure at Datum (cal) 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 7. Gas Gravity: Kuparuk River Unit Kuparuk River Oil Pool -6200' SS 0.71 3. Unit or Lease Name:4. Field and Pool:5. Datum Reference: 3C-11 50103200000000 OIL 490100 A (-6320 - -6323), (-6335 - -6344), (-6371 - -6376), (-6382 - -6387), (-6384 - -6386), (-6464 - -6470), (-6473 - -6503) 10/18/12 72 SBHP 156 6377 3202 6200 0.360 3138 3C-11 50103200000000 OIL 490100 A (-6320 - -6323), (-6335 - -6344), (-6371 - -6376), (-6382 - -6387), (-6384 - -6386), (-6464 - -6470), (-6473 - -6503) 08/05/12 108 SBHP 156 6485 1828 6200 0.360 1726 3F-02 50103200000000 OIL 490100 A (-5748 - -5842), (-5974 - -6006), (-5981 - -6004), (-6023 - -6056) 12/08/12 9585 SBHP 155 5938 2879 6200 0.410 2987 3F-13A 50103200000000 OIL 490100 AC (-5781 - -5787), (-5991 - -6003) 06/12/12 59040 SBHP 158 5927 4440 6200 0.419 4555 3F-19A 50103200000000 OIL 490100 AC (-5808 - -5822), (-5860 - -5868), (-5981 - -5997), (-6012 - -6028) 04/28/12 16200 SBHP 158 5917 4107 6200 0.350 4206 3G-13 50103200000000 MWAG 490100 AC (-5751 - -5771), (-5751 - -5771), (-5771 - -5789), (-5771 - -5789), (-5800 - -5825), (-5800 - -5825) 02/26/12 432 SBHP 120 5771 3886 6200 0.440 4075 3G-13 50103200000000 MWAG 490100 AC (-5751 - -5771), (-5751 - -5771), (-5771 - -5789), (-5771 - -5789), (-5800 - -5825), (-5800 - -5825) 03/05/12 456 SBHP 134 5771 3881 6200 0.350 4031 3G-16 50103200000000 MWAG 490100 A (-5699 - -5711), (-5760 - -5784), (-5798 - -5822) 02/05/12 2808 SBHP 129 5765 3422 6200 0.350 3574 3G-20 50029200000000 MWAG 490100 AC (-5765 - -5772), (-5783 - -5804), (-5815 - -5836) 02/27/12 1416 SBHP 131 5794 3840 6200 0.350 3982 3G-20 50029200000000 MWAG 490100 AC (-5765 - -5772), (-5783 - -5804), (-5815 - -5836) 01/02/12 72 SBHP 124 5794 4225 6200 0.170 4294 3G-22 50103200000000 OIL 490100 AC (-5774 - -5802), (-5802 - -5822), (-5812 - -5776) 06/21/12 4968 SBHP 156 5787 3779 6200 0.460 3969 3G-23 50103200000000 PW 490100 A (-5741 - -5752), (-5765 - -5797), 04/21/12 80352 SBHP 140 5769 3893 6200 0.390 4061 Form 10-412 Rev. 12/2008 6. Oil Gravity: 0.91 (water = 1.0) 8. Well Name and Number: 9. API Number 50XXXXXXXXXXXX NO DASHES 10. Type See Instructions 11. AOGCC Pool Code 12. Zone 13. Perforated Intervals Top - Bottom TVDSS 14. Final Test Date 15. Shut-In Time, Hours 16. Press. Surv. Type (see instructions for codes) 17. B.H. Temp. 18. Depth Tool TVDSS 19. Final Observed Pressure at Tool Depth 20. Datum TVDSS (input) 21. Pressure Gradient, psi/ft. 22. Pressure at Datum (cal) 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 7. Gas Gravity: Kuparuk River Unit Kuparuk River Oil Pool -6200' SS 0.71 3. Unit or Lease Name:4. Field and Pool:5. Datum Reference: 3G-23 50103200000000 PW 490100 A (-5741 - -5752), (-5765 - -5797), 03/28/12 79776 SBHP 142 5769 3914 6200 0.360 4069 3G-23 50103200000000 PW 490100 AC (-5741 - -5752), (-5765 - -5797), 01/01/12 65232 SBHP 139 5769 4020 6200 0.380 4184 3H-11 50103200000000 OIL 490100 AC (-6115 - -6132), (-5983 - -6009), (-6082 - -6099), (-6065 - -6075) 06/03/12 20625 SBHP 157 6053 3551 6200 0.430 3614 3H-11A 50103200000000 OIL 490100 AC (-6015 - -6030), (-5939 - -5991) 12/09/12 25176 SBHP 152 5971 3212 6200 0.440 3313 3H-34 50103200000000 OIL 490100 A (-6025 - -6040), (-6040 - -6040), (-6023 - -6022), (-6022 - -6052), (-5983 - -6040), (-6041 - -6080) 06/20/12 20 SBHP 155 5986 2958 6200 0.405 3045 3I-01 50103200000000 OIL 490100 A (-6255 - -6270), (-6259 - -6274), (-6270 - -6274), (-6281 - -6302) 03/28/12 9720 SBHP 149 6007 4033 6200 0.350 4101 3J-13 50029200000000 PW 490100 AC (-6185 - -6193), (-6193 - -6206), (-6211 - -6221), (-6277 - -6295), (-6281 - -6281), (-6307 - -6331), (-6320 - -6321), (-6377 - -6380) 01/05/12 15936 SBHP 121 6288 3629 6200 0.350 3598 3K-05 50029200000000 PW 490100 A (-6608 - -6629), (-6622 - -6623), (-6638 - -6660), (-6640 - -6641), (-6650 - -6654), (-6650 - -6651), (-6657 - -6658), (-6661 - -6662), (-6665 - -6671), (-6706 - -6709), (-6712 - -6719) 02/04/12 1827 SBHP 135 6663 4384 6200 0.333 4230 Form 10-412 Rev. 12/2008 6. Oil Gravity: 0.91 (water = 1.0) 8. Well Name and Number: 9. API Number 50XXXXXXXXXXXX NO DASHES 10. Type See Instructions 11. AOGCC Pool Code 12. Zone 13. Perforated Intervals Top - Bottom TVDSS 14. Final Test Date 15. Shut-In Time, Hours 16. Press. Surv. Type (see instructions for codes) 17. B.H. Temp. 18. Depth Tool TVDSS 19. Final Observed Pressure at Tool Depth 20. Datum TVDSS (input) 21. Pressure Gradient, psi/ft. 22. Pressure at Datum (cal) 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 7. Gas Gravity: Kuparuk River Unit Kuparuk River Oil Pool -6200' SS 0.71 3. Unit or Lease Name:4. Field and Pool:5. Datum Reference: 3K-10 50029200000000 OIL 490100 A (-6643 - -6659), (-6645 - -6646), (-6647 - -6647), (-6653 - -6654), (-6657 - -6657), (-6671 - -6693), (-6675 - -6676), (-6681 - -6682), (-6686 - -6687), (-6689 - -6690), (-6697 - -6697), (-6700 - -6701), (-6703 - -6704), (-6706 - -6707), (-6709 - -6712) 02/03/12 3560 SBHP 160 6658 2284 6200 0.449 2078 3K-10A 50029200000000 OIL 490100 A (-6655 - -6623)04/18/12 5359 SBHP 153 6572 3989 6200 0.466 3816 3K-10A 50029200000000 OIL 490100 A (-6655 - -6623)09/19/12 359 SBHP 160 6572 1786 6200 0.350 1656 3K-11 50029200000000 SW 490100 A (-6584 - -6603), (-6594 - -6595), (-6596 - -6598), (-6601 - -6602), (-6614 - -6626), (-6617 - -6618), (-6623 - -6624), (-6626 - -6639), (-6627 - -6628), (-6632 - -6633), (-6636 - -6636), (-6637 - -6638), (-6643 - -6643), (-6644 - -6645), (-6647 - -6648), (-6652 - -6653), (-6657 - -6661) 01/02/12 112 SBHP 106 6622 5438 6200 0.455 5246 Form 10-412 Rev. 12/2008 6. Oil Gravity: 0.91 (water = 1.0) 8. Well Name and Number: 9. API Number 50XXXXXXXXXXXX NO DASHES 10. Type See Instructions 11. AOGCC Pool Code 12. Zone 13. Perforated Intervals Top - Bottom TVDSS 14. Final Test Date 15. Shut-In Time, Hours 16. Press. Surv. Type (see instructions for codes) 17. B.H. Temp. 18. Depth Tool TVDSS 19. Final Observed Pressure at Tool Depth 20. Datum TVDSS (input) 21. Pressure Gradient, psi/ft. 22. Pressure at Datum (cal) 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 7. Gas Gravity: Kuparuk River Unit Kuparuk River Oil Pool -6200' SS 0.71 3. Unit or Lease Name:4. Field and Pool:5. Datum Reference: 3K-11 50029200000000 SW 490100 A (-6584 - -6603), (-6594 - -6595), (-6596 - -6598), (-6601 - -6602), (-6614 - -6626), (-6617 - -6618), (-6623 - -6624), (-6626 - -6639), (-6627 - -6628), (-6632 - -6633), (-6636 - -6636), (-6637 - -6638), (-6643 - -6643), (-6644 - -6645), (-6647 - -6648), (-6652 - -6653), (-6657 - -6661) 03/04/12 313 SBHP 101 6523 5871 6200 0.450 5726 3K-15 50029200000000 PW 490100 AC (-6438 - -6451), (-6588 - -6606), (-6596 - -6597), (-6599 - -6600), (-6602 - -6602), (-6603 - -6604), (-6623 - -6623), (-6624 - -6637), (-6626 - -6627), (-6632 - -6633), (-6634 - -6635), (-6639 - -6639), (-6644 - -6653) 01/21/12 204 SBHP 135 6601 4961 6200 0.453 4779 3K-17 50029200000000 OIL 490100 A (-6435 - -6451), (-6586 - -6601), (-6594 - -6594), (-6596 - -6597), (-6598 - -6599), (-6599 - -6600), (-6615 - -6628), (-6617 - -6617), (-6626 - -6627), (-6633 - -6633), (-6636 - -6637), (-6640 - -6641), (-6649 - -6653), (-6687 - -6693) 02/04/12 19464 SBHP 163 4861 3757 6200 0.423 4323 Form 10-412 Rev. 12/2008 6. Oil Gravity: 0.91 (water = 1.0) 8. Well Name and Number: 9. API Number 50XXXXXXXXXXXX NO DASHES 10. Type See Instructions 11. AOGCC Pool Code 12. Zone 13. Perforated Intervals Top - Bottom TVDSS 14. Final Test Date 15. Shut-In Time, Hours 16. Press. Surv. Type (see instructions for codes) 17. B.H. Temp. 18. Depth Tool TVDSS 19. Final Observed Pressure at Tool Depth 20. Datum TVDSS (input) 21. Pressure Gradient, psi/ft. 22. Pressure at Datum (cal) 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 7. Gas Gravity: Kuparuk River Unit Kuparuk River Oil Pool -6200' SS 0.71 3. Unit or Lease Name:4. Field and Pool:5. Datum Reference: 3K-18 50029200000000 PW 490100 A (-6599 - -6619), (-6607 - -6608), (-6611 - -6612), (-6613 - -6614), (-6614 - -6615), (-6632 - -6649), (-6632 - -6633), (-6634 - -6634), (-6638 - -6638), (-6641 - -6642), (-6643 - -6644), (-6645 - -6645), (-6649 - -6656) 03/02/12 36552 SBHP 120 6627 2968 6200 0.473 2766 3K-35 50029200000000 OIL 490100 A (-6370 - -6386), (-6399 - -6417) 09/04/12 5071 SBHP 139 5866 4362 6200 0.350 4479 3M-04 50029200000000 OIL 490100 A (-6183 - -6196), (-6201 - -6213), (-6229 - -6253), (-6229 - -6263) 01/13/12 2952 SBHP 156 6218 4531 6200 0.420 4523 3M-13 50103200000000 OIL 490100 AC (-6140 - -6150), (-6150 - -6164), (-6168 - -6185), (-6176 - -6179), (-6189 - -6220), (-6191 - -6219) 07/13/12 11448 SBHP 157 6020 4386 6200 0.450 4467 3M-13 50103200000000 OIL 490100 AC (-6140 - -6150), (-6150 - -6164), (-6168 - -6185), (-6176 - -6179), (-6189 - -6220), (-6191 - -6219) 12/28/12 15476 SBHP 149 5990 4566 6200 0.440 4658 3M-14 50103200000000 OIL 490100 A (-6177 - -6178), (-6180 - -6181), (-6184 - -6184), (-6189 - -6221) 07/06/12 51701 SBHP 157 6178 4843 6200 0.340 4850 3M-15 50103200000000 SW 490100 AC (-6180 - -6211)04/17/12 18480 SBHP 117 6196 4133 6200 0.450 4135 3M-26 50103200000000 SW 490100 AC (-6231 - -6257)02/07/12 3266 SBHP 127 6244 4954 6200 0.440 4935 3M-26 50103200000000 SW 490100 A (-6231 - -6257)10/19/12 9381 SBHP 146 6321 4938 6200 0.490 4879 3M-29A 50029200000000 OIL 490100 AC (-5769 - -5971), (-5968 - -5983) 09/07/12 60501 SBHP 140 5691 3968 6200 0.487 4216 3N-01 50029200000000 OIL 490100 AC (-6259 - -6264), (-6263 - -6264), (-6264 - -6267), (-6267 - -6268), (-6267 - -6271), (-6277 - -6286), (-6286 - -6287), (-6286 - -6291), (-6291 - -6304) 09/03/12 7152 PBU 155 6098 3413 6200 0.440 3458 Form 10-412 Rev. 12/2008 6. Oil Gravity: 0.91 (water = 1.0) 8. Well Name and Number: 9. API Number 50XXXXXXXXXXXX NO DASHES 10. Type See Instructions 11. AOGCC Pool Code 12. Zone 13. Perforated Intervals Top - Bottom TVDSS 14. Final Test Date 15. Shut-In Time, Hours 16. Press. Surv. Type (see instructions for codes) 17. B.H. Temp. 18. Depth Tool TVDSS 19. Final Observed Pressure at Tool Depth 20. Datum TVDSS (input) 21. Pressure Gradient, psi/ft. 22. Pressure at Datum (cal) 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 7. Gas Gravity: Kuparuk River Unit Kuparuk River Oil Pool -6200' SS 0.71 3. Unit or Lease Name:4. Field and Pool:5. Datum Reference: 3N-04 50029200000000 SW 490100 AC (-6207 - -6215), (-6240 - -6242), (-6242 - -6243), (-6242 - -6245), (-6244 - -6245), (-6245 - -6249), (-6251 - -6257), (-6263 - -6269) 04/28/12 8040 SBHP 121 6256 3715 6200 0.450 3690 3N-07 50029200000000 OIL 490100 AC (-6335 - -6340), (-6378 - -6393), (-6388 - -6389), (-6390 - -6390), (-6405 - -6422) 03/01/12 12504 SBHP 160 6298 3638 6200 0.350 3604 3N-07A 50029200000000 OIL 490100 A (-6344 - -6343), (-6344 - -6330), (-6372 - -6327), (-6324 - -6241), (-6374 - -6372), (-6372 - -6358), (-6386 - -6386), (-6425 - -6381), (-6379 - -6368), (-6331 - -6423), (-6423 - -6438), (-6394 - -6392), (-6392 - -6376), (-6375 - -6387) 09/24/12 27077 SBHP 144 6067 3925 6200 0.448 3984 3N-08A 50029200000000 SW 490100 AC (-6225 - -6234), (-6290 - -6309), (-6297 - -6298), (-6299 - -6300), (-6310 - -6336), (-6345 - -6351) 02/26/12 3531 SBHP 118 6288 4520 6200 0.449 4480 3N-08A 50029200000000 SW 490100 A (-6225 - -6234), (-6290 - -6309), (-6297 - -6298), (-6299 - -6300), (-6310 - -6336), (-6345 - -6351) 10/17/12 483 SBHP 106 6319 4040 6200 0.450 3986 3N-11A 50029200000000 MWAG 490100 A (-6305 - -6316), (-6322 - -6319) 10/08/12 218 SBHP 99 6327 3254 6200 0.446 3198 3N-11A 50029200000000 MWAG 490100 A (-6305 - -6316), (-6322 - -6319) 08/23/12 5836 SBHP 94 6327 3663 6200 0.437 3608 Form 10-412 Rev. 12/2008 6. Oil Gravity: 0.91 (water = 1.0) 8. Well Name and Number: 9. API Number 50XXXXXXXXXXXX NO DASHES 10. Type See Instructions 11. AOGCC Pool Code 12. Zone 13. Perforated Intervals Top - Bottom TVDSS 14. Final Test Date 15. Shut-In Time, Hours 16. Press. Surv. Type (see instructions for codes) 17. B.H. Temp. 18. Depth Tool TVDSS 19. Final Observed Pressure at Tool Depth 20. Datum TVDSS (input) 21. Pressure Gradient, psi/ft. 22. Pressure at Datum (cal) 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 7. Gas Gravity: Kuparuk River Unit Kuparuk River Oil Pool -6200' SS 0.71 3. Unit or Lease Name:4. Field and Pool:5. Datum Reference: 3N-12 50103200000000 SW 490100 AC (-6289 - -6303), (-6391 - -6392), (-6391 - -6393), (-6393 - -6395), (-6395 - -6396), (-6395 - -6399), (-6406 - -6416), (-6416 - -6417), (-6417 - -6421), (-6421 - -6424), (-6424 - -6425), (-6425 - -6427), (-6427 - -6431), (-6431 - -6437) 05/31/12 5802 SBHP 127 6188 4182 6200 0.442 4187 3N-13 50103200000000 OIL 490100 AC (-6302 - -6318), (-6357 - -6368), (-6362 - -6363), (-6364 - -6365), (-6366 - -6366), (-6367 - -6368), (-6375 - -6392), (-6383 - -6384), (-6386 - -6387), (-6389 - -6390), (-6391 - -6392), (-6395 - -6396), (-6406 - -6431) 02/26/12 912 SBHP 115 6394 3755 6200 0.350 3687 3N-13 50103200000000 OIL 490100 AC (-6302 - -6318), (-6357 - -6368), (-6362 - -6363), (-6364 - -6365), (-6366 - -6366), (-6367 - -6368), (-6375 - -6392), (-6383 - -6384), (-6386 - -6387), (-6389 - -6390), (-6391 - -6392), (-6395 - -6396), (-6406 - -6431) 02/03/12 406 SBHP 108 6394 3711 6200 0.430 3628 3O-04 50103200000000 OIL 490100 C (-6461 - -6474), (-6483 - -6495), (-6499 - -6516), (-6525 - -6540) 09/09/12 29368 SBHP 160 6445 4177 6200 0.440 4069 3O-10 50103200000000 MWAG 490100 AC (-6451 - -6460), (-6467 - -6485), (-6493 - -6507) 08/09/12 253 SBHP 110 6479 5300 6200 0.442 5177 Form 10-412 Rev. 12/2008 ATTACHMENT 5 Kuparuk Oil Pool 2012 Annual Reservoir Surveillance Report Injectivity Profiles KUPARUK RIVER UNIT KUPARUK RIVER OIL POOL CONSERVATION ORDER 198B RULE 4 - INJECTIVITY PROFILES 2012 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-09 0292066900 - 00 02/83 11/24/12 SPINNER CLOSE C SANDS Single Selective A 3800 1A-10 0292067300 - 00 02/94 05/24/12 SZT CLOSE C SANDS Single Selective A 200 1A-15 0292071100 - 00 02/83 11/24/12 SZT CLOSE C SANDS Single Selective A 1250 1E-01 0292046400 - 00 05/83 03/27/12 SPINNER A/C SPLITS Single Selective AC 8076 A 0 1E-21 0292089200 - 00 05/83 05/03/12 SPINNER A/C SPLITS Single Selective AC 4820 A 0 1G-01 0292080500 - 00 11/93 02/22/12 SPINNER A/C SPLITS Single Selective AC 3000 A 60 1G-04 0292083500 - 00 10/85 11/08/12 SPINNER A/C SPLITS Triple AC 3240 A 356 1G-09 0292100100 - 00 08/84 07/17/12 SPINNER A/C SPLITS Triple AC 3000 A 330 1G-09 0292100100 - 00 08/84 11/14/12 SPINNER A/C SPLITS Triple AC 2420 A 242 1L-14 0292213200 - 00 09/91 03/26/12 SPINNER A/C SPLITS Single AC 3606 A 0 1L-17 0292215100 - 00 09/91 04/26/12 SPINNER A/C SPLITS Single AC 2685 A 15 1L-22 0292211400 - 00 08/91 07/18/12 SPINNER A/C SPLITS Single AC 2030 A 0 1Q-09 0292120900 - 00 07/96 01/01/12 SPINNER A/C SPLITS Single Selective A 2912 A 2912 ATTACHMENT 5 KUPARUK RIVER UNIT KUPARUK RIVER OIL POOL CONSERVATION ORDER 198B RULE 4 - INJECTIVITY PROFILES 2012 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 ATTACHMENT 5 1Q-24 0292258400 - 00 04/96 01/03/12 SPINNER A/C SPLITS Single AC 4434 A 2015 1R-08 0292133300 - 00 09/85 05/17/12 SPINNER A/C SPLITS Single Selective AC 508 A 508 1R-19A 0292218501 - 00 11/92 11/21/12 SPINNER A/C SPLITS Single Selective AC 2010 A 327 2B-11 0292108900 - 00 11/85 09/26/12 SPINNER A/C SPLITS Single AC 5394 A 1672 2C-04 0292097300 - 00 11/85 09/05/12 SPINNER A/C SPLITS Single Selective AC 1230 A 12 2K-03 1032010000 - 00 05/92 08/31/12 SPINNER A/C SPLITS Single A 6000 2K-05 1032009800 - 00 04/91 12/26/12 SPINNER A/C SPLITS Single AC 227 A 1288 2U-05 0292128100 - 00 11/86 05/04/12 SPINNER FOLLOW-UP Single Selective AC 2765 A 1465 2W-02 0292127900 - 00 11/85 12/03/12 SPINNER A/C SPLITS Single Selective AC 5500 A 1210 2W-04 0292127500 - 00 11/85 05/14/12 SPINNER A/C SPLITS Single Selective AC 5043 A 3429 2W-05 0292120800 - 00 11/85 05/14/12 SPINNER A/C SPLITS Single Selective AC 4285 A 2 2W-09 0292123500 - 00 01/86 02/19/12 SPINNER FOLLOW-UP Single Selective AC 3279 A 492 KUPARUK RIVER UNIT KUPARUK RIVER OIL POOL CONSERVATION ORDER 198B RULE 4 - INJECTIVITY PROFILES 2012 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 ATTACHMENT 5 2W-16 0292125500 - 00 11/85 03/13/12 SPINNER A/C SPLITS Single Selective AC 5000 A 500 2Z-22 0292252400 - 00 05/95 01/09/12 SPINNER A/C SPLITS Single Selective AC 7000 A 0 3F-04 0292144900 - 00 05/86 11/27/12 SPINNER A/C SPLITS Single Selective AC 1507 A 194 3F-07 0292146300 - 00 05/86 10/24/12 SPINNER CLOSE C SANDS Single Selective AC 2600 A 390 3F-08 0292146400 - 00 10/87 06/14/12 SPINNER A/C SPLITS Single Selective AC 8349 A 884 3F-20 0292294700 - 00 02/00 05/05/12 SZT A/C SPLITS Monobore AC 2148 A 333 3F-12 0292148300 - 00 07/86 05/05/12 SPINNER A/C SPLITS Single Selective AC 1546 A 257 32 >>Total IPROF Count for 2012 ATTACHMENT 6 Kuparuk Oil Pool 2012 Annual Reservoir Surveillance Report Productivity Profiles KUPARUK RIVER UNIT KUPARUK RIVER OIL POOL CONSERVATION ORDER 432 RULE 9 - PRODUCTIVITY PROFILES ANNUAL 2012 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-18 0292210300 - 00 09/91 09/02/12 SZT CLOSE C SANDS Triple A 120 800 900 1A-20 0292211200 - 00 10/91 12/05/12 SPINNER CLOSE C SANDS Triple AC 240 17 116 A 210 17 89 1D-28 0292323700 - 00 02/05 11/06/12 SPINNER A/C SPLITS Single C 292 2533 1150 1E-03 0292047700 - 00 12/81 11/26/12 SPINNER A/C SPLITS Single Selective AC 304 736 260 A 0 0 0 1F-06 0292082000 - 00 10/82 02/10/12 SPINNER A/C SPLITS Single Selective AC 307 642 516 A 0 0 0 1F-14 0292102200 - 00 02/84 04/12/12 SPINNER A/C SPLITS Single Selective AC 366 1038 306 A 250 148 141 1Q-16 0292130900 - 00 06/85 01/02/12 SPINNER A/C SPLITS Single Selective AC 379 2326 453 A 340 2237 241 1R-05 0292133000 - 00 07/85 01/07/12 SPINNER A/C SPLITS Single Selective A 304 2946 183 1R-20 0292220700 - 00 04/92 11/11/12 SPINNER A/C SPLITS Single Selective AC 0 1164 0 A 0 216 0 1Y-06A 0292095801 - 00 05/99 07/25/12 SPINNER A/C SPLITS Monobore AC 138 820 289 A 84 10 107 1Y-15A 0292091901 - 00 12/98 11/10/12 SPINNER A/C SPLITS Monobore AC 117 1735 1355 A 104 34 84 1Y-22 0292236900 - 00 11/93 07/18/12 SPINNER A/C SPLITS Single AC 163 620 473 A 163 408 473 2B-01 0292114700 - 00 10/84 05/07/12 SPINNER A/C SPLITS Single Selective AC 450 2500 1420 A 68 375 213 ATTACMENT 6 KUPARUK RIVER UNIT KUPARUK RIVER OIL POOL CONSERVATION ORDER 432 RULE 9 - PRODUCTIVITY PROFILES ANNUAL 2012 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 ATTACMENT 6 2B-03A 0292115101 - 00 03/03 04/15/12 SPINNER A/C SPLITS Single Selective AC 92 415 239 A 71 320 184 2D-03 0292117800 - 00 12/84 02/19/12 SZT CLOSE C SANDS Single Selective A 150 190 600 2H-11 1032005200 - 00 12/85 03/28/12 SPINNER A/C SPLITS Single Selective AC 143 945 182 A 137 415 141 2W-01 0292127300 - 00 03/85 04/18/12 SPINNER A/C SPLITS Single Selective AC 18 2605 20 A 225 90 450 2W-06 0292121100 - 00 02/85 07/21/12 SPINNER OPEN C SANDS Single Selective AC 164 3605 564 A 0 0 0 2W-11 0292123800 - 00 02/85 05/06/12 SPINNER A/C SPLITS Single Selective AC 128 3287 298 A 65 249 46 2W-12 0292124000 - 00 02/85 04/17/12 SPINNER A/C SPLITS Single Selective AC 255 5444 3572 A 238 867 186 2W-15 0292125400 - 00 03/85 09/07/12 SPINNER A/C SPLITS Single Selective AC 216 2446 627 A 104 1174 101 2X-18 0292260800 - 00 05/96 11/16/12 SPINNER A/C SPLITS Single AC 167 780 656 A 17 78 66 3B-03 0292132200 - 00 06/85 10/09/12 SPINNER OPEN C SANDS Single Selective AC 0 0 0 A 260 0 0 3B-06 0292133600 - 00 07/85 01/05/12 SPINNER A/C SPLITS Single AC 152 896 101 A 121 815 46 3C-06 0292109600 - 00 09/85 01/01/12 SPINNER A/C SPLITS Single Selective AC 148 264 115 A 70 103 64 KUPARUK RIVER UNIT KUPARUK RIVER OIL POOL CONSERVATION ORDER 432 RULE 9 - PRODUCTIVITY PROFILES ANNUAL 2012 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 ATTACMENT 6 3C-06 0292109600 - 00 09/85 08/23/12 SPINNER A/C SPLITS Single Selective AC 84 269 60 A 66 141 34 3N-19 0292305600 - 00 03/02 07/02/12 SPINNER A/C SPLITS Single A 491 150 199 27 >> Total PPROF Count for 2012 Attachment 7 Kuparuk River Oil Pool 2012 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. Date Facility CO2 N2 C1 C2 C3 iC4 nC4 iC5 nC5 C6 C7 C8+MMP (Calc), psia 1/6/2012 CPF-1 1.096 0.264 68.395 6.300 4.996 3.145 7.731 2.495 2.056 2.000 1.734 1.148 2,900 1/19/2012 CPF-1 1.091 0.276 69.078 6.175 4.653 3.212 7.621 2.459 2.005 1.983 1.730 1.085 2,989 2/4/2012 CPF-1 1.121 0.297 69.682 6.448 4.856 3.012 7.246 2.281 1.882 1.860 1.651 1.083 3,126 2/20/2012 CPF-1 1.228 0.301 72.063 6.723 4.955 2.654 6.275 1.903 1.585 1.526 1.346 0.968 3,572 3/1/2012 CPF-1 1.099 0.273 67.515 6.537 5.182 3.348 7.991 2.502 2.062 1.998 1.741 1.124 2,805 3/24/2012 CPF-1 1.209 0.275 70.115 6.541 4.942 3.222 7.394 2.340 1.934 1.879 1.624 0.008 3,336 4/12/2012 CPF-1 1.191 0.273 68.681 6.652 5.215 3.102 7.509 2.379 1.975 1.899 1.620 0.968 3,019 7/1/2012 CPF-1 1.129 0.310 68.133 6.308 4.313 2.826 7.913 2.733 2.166 2.637 1.607 1.364 2,758 8/2/2012 CPF-1 1.233 0.340 70.272 6.907 5.199 2.871 7.059 2.252 1.881 1.949 1.001 0.610 3,371 8/17/2012 CPF-1 1.247 0.315 69.288 6.663 5.330 2.686 6.942 2.421 1.995 2.276 1.350 1.048 3,089 9/2/2012 CPF-1 1.338 0.395 70.598 6.855 5.625 2.574 6.485 2.110 1.745 1.923 1.134 0.951 3,369 9/13/2012 CPF-1 1.289 0.331 69.378 6.610 4.849 2.861 7.323 2.415 1.943 2.238 1.301 1.081 3,081 9/29/2012 CPF-1 1.115 0.280 68.857 6.614 4.763 2.924 7.412 2.463 1.961 2.373 1.426 1.206 2,980 10/15/2012 CPF-1 1.156 0.273 69.856 6.612 4.573 2.863 7.237 2.352 1.882 2.199 1.312 1.113 3,153 10/26/2012 CPF-1 1.129 0.335 70.448 6.501 4.430 2.914 7.158 2.300 1.832 2.128 1.255 1.034 3,249 11/9/2012 CPF-1 1.103 0.293 69.882 6.451 4.535 3.113 7.261 2.346 1.891 2.192 1.273 1.056 3,161 12/2/2012 CPF-1 1.204 0.304 67.735 7.077 5.418 3.119 7.788 2.464 2.092 2.150 1.223 0.935 2,942 12/11/2012 CPF-1 1.085 0.284 66.661 6.554 5.010 3.408 8.431 2.686 2.201 2.546 1.416 1.087 2,666 AVG 3,087 MMP Target 3,300 KUPARUK RIVER UNIT MI COMPOSITION : CPF-1 Date Facility CO2 N2 C1 C2 C3 iC4 nC4 iC5 nC5 C6 C7 C8+MMP (Calc), psia 1/6/2012 CPF-2 0.921 0.215 69.377 7.707 5.489 2.521 6.963 2.179 1.739 1.633 1.447 0.943 3,284 1/19/2012 CPF-2 0.910 0.209 68.919 7.645 5.565 2.917 7.267 2.127 1.702 1.585 1.382 0.890 3,242 2/4/2012 CPF-2 0.941 0.208 68.992 7.739 5.446 2.894 7.149 2.064 1.640 1.585 1.462 1.029 3,230 2/20/2012 CPF-2 0.989 0.204 70.417 7.526 5.000 2.753 7.023 2.003 1.601 1.500 1.330 0.847 3,441 3/1/2012 CPF-2 0.903 0.196 67.416 7.148 4.914 3.265 7.905 2.446 1.914 1.959 1.807 1.226 2,836 3/24/2012 CPF-2 0.975 0.270 70.150 7.634 5.214 3.055 6.992 1.944 1.552 1.435 1.274 0.749 3,449 4/12/2012 CPF-2 0.912 0.218 67.731 7.576 5.479 3.217 8.028 2.277 1.845 1.636 1.380 0.833 3,060 7/27/2012 CPF-2 1.056 0.297 75.607 8.760 6.263 1.724 4.189 1.115 0.958 0.761 0.380 0.243 4,590 8/2/2012 CPF-2 0.896 0.311 68.417 8.454 6.901 2.463 6.414 2.158 1.715 1.829 0.961 0.689 3,330 8/17/2012 CPF-2 0.933 0.247 68.054 7.609 5.358 3.085 7.769 2.357 1.872 2.029 1.106 0.761 3,106 9/2/2012 CPF-2 0.990 0.278 70.249 7.482 4.898 2.536 6.809 2.169 1.691 2.015 1.196 0.955 3,360 9/13/2012 CPF-2 1.019 0.289 68.620 7.843 5.522 2.608 7.086 2.292 1.803 2.056 1.203 0.967 3,165 9/29/2012 CPF-2 0.907 0.261 68.731 7.698 5.353 2.839 7.418 2.249 1.780 1.946 1.109 0.879 3,205 10/15/2012 CPF-2 0.045 0.231 69.263 7.767 5.282 2.810 6.915 2.142 1.681 1.958 1.177 1.004 3,338 10/26/2012 CPF-2 0.925 0.239 69.124 7.752 5.171 2.617 7.193 2.248 1.778 1.968 1.159 0.990 3,235 11/9/2012 CPF-2 0.908 0.228 70.131 7.530 4.893 2.804 6.655 2.185 1.710 1.956 1.161 0.976 3,362 12/2/2012 CPF-2 0.927 0.268 68.289 7.672 5.246 3.181 7.463 2.274 1.815 1.979 1.122 0.958 3,122 12/11/2012 CPF-2 0.906 0.224 69.365 7.551 5.012 2.983 7.242 2.190 1.741 1.904 1.103 0.909 3,277 AVG 3,313 MMP Target 3,300 KUPARUK RIVER UNIT MI COMPOSITION : CPF-2 Attachment 8 Kuparuk River Unit Kuparuk River Oil Pool 2012 Annual Reservoir Surveillance Report LSEOR Development Plan During 2012, the Greater Kuparuk Area (GKA) averaged 16,054 BPD of PBU NGL imports and 8,311 BPD of indigenous NGLs for an annual average of 167 MMSCFD of Miscible Injectant (MI) manufactured. Of the total MI production in 2012, 125 MMSCFD was injected into the Kuparuk Field. Within the main Kuparuk Field, the 125 MMSCFD was allocated as: 3 MMSCFD for the SSEOR and SSEORX drillsites, 37 MMSCFD to the LSEOR drillsites and 84 MMSCFD to the LSEOR expansion drillsites. LSEOR expansion drillsites include drillsites: 1B, 1C, 1D, 1E, 1L, 3B, 3G, 3H, 3O, 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. Positive responses from the MI injection have been observed since implementation. ATTACHMENT 1 Meltwater Oil Pool 2012 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. The Area Injection Order was modified on January 29, 2013. Injection of MI began in January 2002 and the MWAG (miscible water alternating gas) process was implemented in May 2003. The Meltwater MWAG process uses Kuparuk spec MI which is injected above the minimum miscibility pressure. In 2009 the water injection line to Meltwater was proactively shut in due to internal corrosion and the field is currently on MI flood only. For compositional analysis of the Kuparuk spec MI, refer to Attachment 7 of 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 2012 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 2012: 1. 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, injection 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 areas to less than 3,300 psi. Well 2P-432, with a bottom hole pressure of 4,366 psi began flowback in February 2009. Shut-in bottom hole 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. In December 2012 well 2P-432 was brought back online to increase throughput in the 2P produced oil (PO) line and is expected to remain online through the winter months of 2013. This 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. Oil production from 2P-432 is currently at 500 bopd but the well is expected to be shut in by the spring of 2013 to optimize the Meltwater MI flood due to a direct connection between 2P-432 and its offset injectors 2P-434 and 2P-429. The 2P-432 well test GORs are currently relatively low. As the GOR increases the well will be shut in. 3. A total of eight wells, including six producers, are currently shut-in. Well 2P-406 is temporarily shut-in after a leak was detected in the surface casing. It is undergoing repairs and should be back online by May 2013. Wells 2P-415A 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-443 has a history of severe paraffin deposition and freezing problems and it will be an intermittent producer for the foreseeable future. Well 2P-448A is currently shut in for tubing by inner annulus communication but is expected to be returned to service in March 2013. 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 continued through 2012. 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. In late 2011 and throughout the winter and spring of 2012 well 2P-417’s oil rate again increased to approximately 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. In the summer of 2012 production from 2P-417 began declining and has stabilized at approximately 450 bopd. Well 2P-441 resumed production in April 2011 at an initial rate in excess of 2,000 bopd that is likely due to offset injection support. Since then well 2P-441’s production has stabilized at approximately 750 bopd. Significant Studies in Progress 1. 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 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 2P-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 the hydraulic connection and these three wells effectively act as one line-drive injector when on water injection service. The last pressure survey (September 4, 2010) showed that the pressure decreased approximately 1,200 psi to 3,021 psi after water injection in well 2P-429 was discontinued. 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. As part of reservoir surveillance, as well as to further our understanding of these linear features, pressure transient testing was initiated in June of 2011. At the time all Meltwater injectors were in MI injection service with the exception of 2P-432 and 2P-434 that were shut in. A down hole pressure gauge was installed in 2P-434 to monitor pressure effects from step changes in injection rate that were applied to well 2P-429. Multiple step rate changes and one full injection shut in event were performed on 2P-429. Analysis of the results indicated a pressure response time of less than two days. 3. A new Meltwater reservoir management plan was put in place. This reservoir strategy included reducing the injection/withdrawal ratio to reduce the average reservoir pressure to original pressure and imposing a well head injection pressure limit on Meltwater injectors. The well head injection pressure limit of 2600 psi imposed on Meltwater injectors is predicated upon FIT/LOT (Formation Integrity Test / Leak-off Test) data obtained from Meltwater wells wherein production casing was set at the top of the Bermuda interval. Upon implementing the reservoir management strategy changes, production and reservoir data continued to be collected and shared with AOGCC. Seven of the ten wells with historically high OA pressure wells were bled during the CPF2 shutdown in June and July of 2012. Of these ten wells, three were not bled. Wells 2P-406 and 2P-447 have cemented outer annuli and well 2P-434 was not bled as the pressure was not significant. The duration of these bleeds were limited to four hours, or, if the pressure of the outer annulus dropped below 50 psi the bleed was discontinued. A number of wells were bled more than once. The volumes of gas bled were less than 80 MSCF in a four hour period and the recharge rates of the pressures in these outer annuli were slow. Six of the seven wells bled showed a significant step change decrease in their outer annuli pressures. The one anomaly, well 2P-448A, initially indicated a step change decrease in its OA pressure; however, the well was returned to service at the end of August, and a rise in OA pressure was noted that coincides exactly with the timing of the well being returned to service. The results of this bleed campaign are significant. Historically, bleeds performed on the outer annuli of Meltwater wells were never able to initiate and maintain a step change decrease in the outer annulus pressures. Another indicator that the changes in reservoir management strategy are having an effect is the change in composition of the outer annulus gas. Currently, OA gas is now less similar to MI and more similar to native gas from shallow intervals. Native gas is primarily characterized by methane as well as a small presence of C2’s and C3’s. MI on the other hand has measurable amounts of C4’s through C7’s that are not typical of native gas. CPAI has initiated studies with our ConocoPhillips Houston technical experts to better describe the geologic components of the overburden, the geologic elements such as faults and fracture systems, and how these elements respond to subsurface dynamic processes. Reservoir Management Summary Meltwater came on-line in November of 2001 and has cumulatively produced 17.1 MMBO, 3.2 MMBW, and 43.0 BCF of gas by year-end 2012. Miscible gas injection began in 2002 with water injection beginning in 2003 (MWAG cycles). Cumulative injection through year-end 2012 at Meltwater has been 25.1 MMBW and 58.4 BCF of gas (52.4 BCF of MI gas and 6.0 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 (I/W) for the field was approximately 0.75. I/W rates for subsequent years were approximately 1.5 to restore adequate voidage replacement. In late 2004, cumulative I/W reached 1.0 and climbed to a peak of 1.3 by 2009. Despite three injectors being taken off-line in 2008, instantaneous I/W 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 remain on MI injection and reduce the reservoir pressure to near original pressure. The cumulative year-end 2012 I/W ratio is 1.19 from year-end 2011 of 1.25 due to staying below I/W Monthly Rate of 0.5 since July 2012. Attachment 2 Meltwater Oil Pool 2012 Annual Reservoir Surveillance Report Produced Fluid Volumes CUM OIL CUM GAS CUM WATER Cumulatives at Dec 31, 2011 16,080,624 *39,215,239 3,172,842 OIL GAS WATER CUM OIL CUM GAS CUM WATER MO YR STB MSCF STB STB MSCF STB 1 2012 102,022 310,170 3,985 16,182,646 39,525,409 3,176,827 2 2012 98,651 319,328 3,814 16,281,297 39,844,737 3,180,641 3 2012 102,202 325,983 4,182 16,383,499 40,170,720 3,184,823 4 2012 100,453 375,548 2,653 16,483,952 40,546,268 3,187,476 5 2012 99,116 391,576 2,243 16,583,068 40,937,844 3,189,719 6 2012 40,517 179,954 514 16,623,585 41,117,798 3,190,233 7 2012 50,756 140,313 1,665 16,674,341 41,258,111 3,191,898 8 2012 103,638 353,583 4,511 16,777,979 41,611,694 3,196,409 9 2012 91,842 365,070 6,466 16,869,821 41,976,764 3,202,875 10 2012 76,184 316,700 2,904 16,946,005 42,293,464 3,205,779 11 2012 53,772 275,086 4,108 16,999,777 42,568,550 3,209,887 12 2012 75,634 401,869 26,174 17,075,411 42,970,419 3,236,061 2012 TOTAL 994,787 3,755,180 63,219 17,075,411 42,970,419 3,236,061 Produced Fluid Volumes (Reservoir Units) Cumulatives at Dec 31, 2011 21,467,632 32,471,517 3,217,262 ** OIL GAS WATER CUM OIL CUM GAS CUM WATER MO YR RVB RVB RVB RVB RVB RVB 1 2012 136,199 274,057 4,041 21,603,831 32,745,573 3,221,303 2 2012 131,699 286,523 3,867 21,735,530 33,032,096 3,225,170 3 2012 136,440 291,470 4,241 21,871,970 33,323,566 3,229,411 4 2012 134,105 347,636 2,690 22,006,075 33,671,202 3,232,101 5 2012 132,320 366,327 2,274 22,138,394 34,037,530 3,234,375 6 2012 54,090 171,800 521 22,192,485 34,209,330 3,234,896 7 2012 67,759 120,821 1,688 22,260,244 34,330,151 3,236,585 8 2012 138,357 321,094 4,574 22,398,601 34,651,245 3,241,159 9 2012 122,609 341,918 6,557 22,521,210 34,993,162 3,247,715 10 2012 101,706 299,007 2,945 22,622,915 35,292,169 3,250,660 11 2012 71,786 268,217 4,166 22,694,701 35,560,386 3,254,825 12 2012 100,971 393,836 26,540 22,795,672 35,954,222 3,281,366 2012 TOTAL 1,328,041 3,482,705 64,104 22,795,672 35,954,222 3,281,366 *2011 Cum Gas volume includes corrections made after 2011 Surveillance Report was issued. **2011 Cumulatives changed to reflect corrections to RVB Calculations. Attachment 3 Meltwater Oil Pool 2012 Annual Reservoir Surveillance Report Injected Fluid Volumes CUM WATER CUM GAS CUM MI Cumulatives at Dec 31, 2011 25,136,450 5,918,787 48,947,902 WATER GAS MI CUM WATER CUM GAS CUM MI MO YR STB MSCF MSCF STB MSCF MSCF 1 2012 0 0 672,154 25,136,450 5,918,787 49,620,056 2 2012 0 0 521,459 25,136,450 5,918,787 50,141,515 3 2012 0 0 507,293 25,136,450 5,918,787 50,648,808 4 2012 0 0 393,135 25,136,450 5,918,787 51,041,943 5 2012 0 0 227,140 25,136,450 5,918,787 51,269,083 6 2012 0 6,413 67,173 25,136,450 5,925,200 51,336,256 7 2012 0 56,133 24,973 25,136,450 5,981,333 51,361,229 8 2012 0 3 201,870 25,136,450 5,981,336 51,563,099 9 2012 0 0 191,274 25,136,450 5,981,336 51,754,373 10 2012 0 0 165,572 25,136,450 5,981,336 51,919,945 11 2012 0 19,409 182,165 25,136,450 6,000,745 52,102,110 12 2012 0 0 268,582 25,136,450 6,000,745 52,370,692 2012 TOTAL 0 81,958 3,422,790 25,136,450 6,000,745 52,370,692 Injected Fluid Volumes (Reservoir Units) Cumulatives at Dec 31, 2011 25,488,360 5,034,721 37,053,563 * WATER GAS MI CUM WATER CUM GAS CUM MI MO YR RVB RVB RVB RVB RVB RVB 1 2012 0 0 508,821 25,488,360 5,034,721 37,562,383 2 2012 0 0 394,744 25,488,360 5,034,721 37,957,128 3 2012 0 0 384,021 25,488,360 5,034,721 38,341,148 4 2012 0 0 297,603 25,488,360 5,034,721 38,638,752 5 2012 0 0 171,945 25,488,360 5,034,721 38,810,697 6 2012 0 5,663 50,850 25,488,360 5,040,384 38,861,547 7 2012 0 49,565 18,905 25,488,360 5,089,949 38,880,451 8 2012 0 3 152,816 25,488,360 5,089,952 39,033,267 9 2012 0 0 144,794 25,488,360 5,089,952 39,178,061 10 2012 0 0 125,338 25,488,360 5,089,952 39,303,399 11 2012 0 17,138 137,899 25,488,360 5,107,090 39,441,298 12 2012 0 0 203,317 25,488,360 5,107,090 39,644,615 2012 TOTAL 0 72,369 2,591,052 25,488,360 5,107,090 39,644,615 *2011 Cumulatives changed to reflect corrections to RVB Calculations. ATTACHMENT 4 Meltwater Oil Pool 2012 Annual Reservoir Surveillance Report Reservoir Pressure Surveys ATTACHMENT 5 Meltwater Oil Pool 2012 Annual Reservoir Surveillance Report Production Logs and Special Surveys During the fall of 2012 acoustic logging surveys were run in six wells at Meltwater to determine if there was near wellbore fluid movement evident between various stratigraphic layers from the top of the Bermuda formation to the surface casing shoe. The wells in which acoustic logs were run were 2P-417, 2P-419, 2P-431, 2P-441, 2P-448, and 2P-447. Five of these six wells have experienced an elevated outer annulus pressure at some time in their well life. The one exception, 2P-419, was run as a baseline for comparison. The wells were shut in and allowed to stabilize at least 24 hours prior to logging. The production string was filled with water to enhance acoustic coupling. Within safe control limits the annulus was allowed to build to maximum shut in pressure. Logging sensors were deployed on third-party slick line. The bottom hole assembly included natural gamma sensors, casing collar locator, quartz pressure transducer, high resolution temperature sensor, and two independent ultrasonic acoustic sensors. Each survey comprised two logging runs. Run 1 was logged under shut in and presumed no flow condition to establish a geothermal gradient and acoustic baseline. Run 2 was logged while venting the production casing – surface casing annulus to detect current flow in the near wellbore area. ATTACHMENT 6 Meltwater Oil Pool 2012 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 were taken on production wells. Test separator backpressure corrections were applied to wells that experienced greater than 100 psi backpressure over header pressure. Correction to stock tank barrel conditions were 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 were adjusted for NGLs associated with MI lift. Production volumes were tracked through an automated production monitoring SCADA system (SetCIM). The 2012 Meltwater allocation factors by month are listed below. Month Oil Gas Water Jan-2012 0.9537 0.9162 1.0483 Feb-2012 0.9537 0.9210 1.0222 Mar-2012 0.9470 0.9065 1.0374 Apr-2012 0.9757 0.9081 0.9885 May-2012 0.9642 0.8937 1.0694 Jun-2012 0.4565 0.4396 0.4820 Jul-2012 0.4559 0.4949 0.4251 Aug-2012 0.9888 1.0106 1.0005 Sep-2012 0.9838 0.9387 1.0402 Oct-2012 0.9723 0.9159 1.0494 Nov-2012 0.9605 0.9176 1.0438 Dec-2012 0.9684 0.9107 1.0641 Shallow Gas Special Monitoring Wells 2P-406, 2P-417, 2P-431, 2P-432, 2P-434, 2P-438, 2P-441, 2P-447, 2P-448A, and 2P-451 have historically experienced at some point in time during their well lives elevated outer annulus (OA) pressures that may rebuild pressure after bleeding. The surface pressures are monitored continuously via SetCIM (wells have pressure transducers that transmit real-time OA pressures) and fluid levels are surveyed approximately once per month via echometer measurements. Upon implementation of the reservoir management strategy to reduce the reservoir pressure as well as the sandface injection pressure a significant decrease in the average outer annulus pressures of the wells with historically high outer annulus pressures has been realized. ATTACHMENT 7 Meltwater Oil Pool 2012 Annual Reservoir Surveillance Report Meltwater Development Plan and Operational Review Following are summaries of key activities that are planned for 2013 and subsequent years. Development Drilling No future development drilling, well conversions to injection or injector flowbacks are planned at this time. However, development opportunities are being analyzed taking into account seismic and surveillance findings. Pipeline Operations Due to low flow rates through the water injection line, there was awareness of the 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. ATTACHMENT 1 Tabasco Oil Pool 2012 Annual Reservoir Surveillance Report Summary of the Enhanced Recovery Project Tabasco produced 394 MBO of crude, 69 MMSCF of gas, and 3,597 MBW during 2012. Water injection was 3,952 MBW over the same period. Cumulative oil, gas, water production, and water injection through year-end 2012 were 17.35 MMBO, 2.87 BCF, 74.12 MMBW, and 85.44 MMBWI, respectively. The cumulative year-end 2012 I/W ratio, based on current formation volume factors, is estimated at 0.92 for Tabasco. Year-end 2012 Tabasco well count (all at Kuparuk River Unit Drill Site 2T) was: Producers: 9 completed 6 on-line Injectors: 3 completed 2 on-line The pool average water oil ratio (WOR) was 8.36 at the end of 2012 compared to 7.89 at the end of 2011. 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 2012 Annual Reservoir Surveillance Report Produced Fluid Volumes CUM OIL CUM GAS CUM WATER Cumulatives at Dec 31, 2011 16,951,568 2,797,885 70,523,787 OIL GAS WATER CUM OIL CUM GAS CUM WATER MO YR STB MSCF STB STB MSCF STB 1 2012 42,484 7,124 330,364 16,994,052 2,805,009 70,854,151 2 2012 35,206 6,437 311,003 17,029,258 2,811,446 71,165,154 3 2012 39,011 7,355 360,407 17,068,269 2,818,801 71,525,561 4 2012 36,910 7,124 348,902 17,105,179 2,825,925 71,874,463 5 2012 42,057 8,068 505,475 17,147,236 2,833,993 72,379,938 6 2012 2,853 1,349 141,633 17,150,089 2,835,342 72,521,571 7 2012 497 109 4,013 17,150,586 2,835,451 72,525,584 8 2012 11,363 2,331 91,641 17,161,949 2,837,782 72,617,225 9 2012 32,038 5,122 240,146 17,193,987 2,842,904 72,857,371 10 2012 54,438 8,020 385,508 17,248,425 2,850,924 73,242,879 11 2012 40,896 7,287 410,716 17,289,321 2,858,211 73,653,595 12 2012 55,857 8,631 467,094 17,345,178 2,866,842 74,120,689 2012 TOTAL 393,610 68,957 3,596,902 17,345,178 2,866,842 74,120,689 Produced Fluid Volumes (Reservoir Units) CUM OIL CUM GAS CUM WATER Cumulatives at Dec 31, 2011 17,942,356 77,356 70,523,787 OIL GAS WATER CUM OIL CUM GAS CUM WATER MO YR RVB RVB RVB RVB RVB RVB 1 2012 45,033 118 330,364 17,987,389 77,474 70,854,151 2 2012 37,318 151 311,003 18,024,707 77,625 71,165,154 3 2012 41,352 189 360,407 18,066,059 77,814 71,525,561 4 2012 39,125 196 348,902 18,105,184 78,010 71,874,463 5 2012 44,580 218 505,475 18,149,764 78,228 72,379,938 6 2012 3,024 95 141,633 18,152,788 78,323 72,521,571 7 2012 527 4 4,013 18,153,315 78,326 72,525,584 8 2012 12,045 74 91,641 18,165,360 78,400 72,617,225 9 2012 33,960 64 240,146 18,199,320 78,464 72,857,371 10 2012 57,704 40 385,508 18,257,024 78,504 73,242,879 11 2012 43,350 156 410,716 18,300,374 78,660 73,653,595 12 2012 59,208 81 467,094 18,359,583 78,741 74,120,689 2012 TOTAL 417,227 1,385 3,596,902 18,359,583 78,741 74,120,689 Attachment 3 Tabasco Oil Pool 2012 Annual Reservoir Surveillance Report Injected Fluid Volumes CUM WATER CUM GAS CUM MI Cumulatives at Dec 31, 2011 81,482,853 0 0 WATER GAS MI CUM WATER CUM GAS CUM MI MO YR STB MSCF MSCF STB MSCF MSCF 1 2012 360,506 0 0 81,843,359 0 0 2 2012 417,527 0 0 82,260,886 0 0 3 2012 467,684 0 0 82,728,570 0 0 4 2012 382,304 0 0 83,110,874 0 0 5 2012 434,921 0 0 83,545,795 0 0 6 2012 152,424 0 0 83,698,219 0 0 7 2012 10,285 0 0 83,708,504 0 0 8 2012 2,044 0 0 83,710,548 0 0 9 2012 211,991 0 0 83,922,539 0 0 10 2012 439,255 0 0 84,361,794 0 0 11 2012 479,010 0 0 84,840,804 0 0 12 2012 594,378 0 0 85,435,182 0 0 2012 TOTAL 3,952,329 0 0 85,435,182 0 0 Injected Fluid Volumes (Reservoir Units) CUM WATER CUM GAS CUM MI Cumulatives at Dec 31, 2011 81,482,860 0 0 . WATER GAS MI CUM WATER CUM GAS CUM MI MO YR RVB RVB RVB RVB RVB RVB 1 2012 360,506 0 0 81,843,366 0 0 2 2012 417,527 0 0 82,260,893 0 0 3 2012 467,684 0 0 82,728,577 0 0 4 2012 382,304 0 0 83,110,881 0 0 5 2012 434,921 0 0 83,545,802 0 0 6 2012 152,424 0 0 83,698,226 0 0 7 2012 10,285 0 0 83,708,511 0 0 8 2012 2,044 0 0 83,710,555 0 0 9 2012 211,991 0 0 83,922,546 0 0 10 2012 439,255 0 0 84,361,801 0 0 11 2012 479,010 0 0 84,840,811 0 0 12 2012 594,378 0 0 85,435,189 0 0 2012 TOTAL 3,952,329 0 0 85,435,189 0 0 ATTACHMENT 4 Tabasco Oil Pool 2012 Annual Reservoir Surveillance Report Reservoir Pressure Surveys ATTACHMENT 5 Tabasco Oil Pool 2012 Annual Reservoir Surveillance Report Production Logs and Special Surveys Since production wells are completed with gravel pack screens and electrical submersible pumps, no production logs are planned for 2013. There were 6 rig workovers executed in 2012 which utilized the caliper log. The logs suggested minor corrosion; however, inspection of results suggested that the overall conditions were acceptable and operational. ATTACHMENT 6 Tabasco Oil Pool 2012 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 2012 production allocation factors were as follows: Month Oil Gas Water Jan-12 0.9538 0.9165 1.0480 Feb-12 0.9537 0.9207 1.0217 Mar-12 0.9470 0.9063 1.0368 Apr-12 0.9760 0.9083 1.0239 May-12 0.9641 0.8939 1.0685 Jun-12 0.4578 0.4417 0.4827 Jul-12 0.0746 0.0735 0.0669 Aug-12 0.9889 1.0112 1.0008 Sep-12 0.9837 0.9389 1.0409 Dec-12 0.9410 0.8869 1.0153 Nov-12 0.9604 0.9175 1.0429 Dec-12 0.9684 0.9108 1.0642 ATTACHMENT 7 Tabasco Oil Pool 2012 Annual Reservoir Surveillance Report Development Plans and Operational Review Tabasco Injection/W ithdrawal Ratios (I/W Ratio) are monitored to maintain an instantaneous value of approximately 1.0. Adjustments to injection and/or production rates are made to achieve this in order to maintain pressure support for the Tabasco Reservoir and keep gas in solution. The 2013 injection strategy is to replace voidage by splitting water injection between 2T-201 and 2T-217A. In 2012, five rig workovers (RWOs) were completed on wells 2T-202, 2T-207, 2T-215, 2T-218, and 2T-220 to install a production packer as a second barrier in the well. The packer that was installed on well 2T-202 has been determined to have a two-way leak and therefore the well remains shut-in. Planning is underway to execute a packer leak repair on producer 2T-202. This will include placing a polymer agent in the inner annulus on top of the packer to seal the slow leak that has been identified and thus allow for this well to be returned to production. The sixth RWO in 2012 was performed on well 2T-209. The decision was made to preserve the wellbore of well 2T-209 but not return the well to production. Due to an apparent direct connection with injector 2T-201, it was determined that continued production of well 2T-209 negatively impacts peripheral producers. The wellbore was preserved for future development and reservoir surveillance opportunities. In 2012 the decision was made to plug and abandon well 2T-204 as it had no future utility. Development planning is currently underway. In January of 2013 a team was assembled to evaluate the Tabasco formation for future development opportunities. The goals of this group are to: • Redevelop the Tabasco Full Field reservoir model • Complete water conformance modeling and an investigation into polymer flooding options • Perform carbon-oxygen logging to determine if efficient waterflood sweep has been realized in the top of the Tabasco formation • Evaluate rotary sidetrack options to develop the top of the Tabasco formation and areas that may be isolated from efficient injection support. ATTACHMENT 1 Tarn Oil Pool 2012 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 MW AG 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 2012, Tarn produced 2.60 MMBO, 5.99 MMBW, and 3.58 BSCF gas. The injection totals for 2012 were 0.17 BSCF Lean Gas, 3.99 BSCF of MI and 9.90 MMBW. At the end of 2012, the cum I/W ratio was 1.04 for Drill Site 2N, and 1.22 for Drill Site 2L. Plans are to continue maintaining reservoir pressure by balancing monthly injection and production rates. ATTACHMENT 2 Tarn River Oil Pool 2012 Annual Reservoir Surveillance Report Produced Fluid Volumes CUM OIL CUM GAS CUM WATER Cumulatives at Dec 31, 2011 104,811,020 *165,043,148 56,693,812 OIL GAS WATER CUM OIL CUM GAS CUM WATER MO YR STB MSCF STB STB MSCF STB 1 2011 280,165 299,079 496,297 105,091,185 165,342,227 57,190,109 2 2011 252,083 295,408 474,429 105,343,268 165,637,635 57,664,538 3 2011 264,533 274,675 538,663 105,607,801 165,912,310 58,203,201 4 2011 240,944 355,495 509,679 105,848,745 166,267,805 58,712,880 5 2011 247,233 372,897 610,824 106,095,978 166,640,702 59,323,704 6 2011 118,044 192,294 240,428 106,214,022 166,832,996 59,564,132 7 2011 119,468 163,163 248,600 106,333,490 166,996,159 59,812,732 8 2011 262,851 363,348 575,633 106,596,341 167,359,507 60,388,365 9 2011 220,094 322,702 594,836 106,816,435 167,682,209 60,983,201 10 2011 207,905 304,003 577,216 107,024,340 167,986,212 61,560,417 11 2011 194,679 304,102 542,005 107,219,019 168,290,314 62,102,422 12 2011 194,737 336,956 577,732 107,413,756 168,627,270 62,680,154 2012 TOTAL 2,602,736 3,584,122 5,986,342 107,413,756 168,627,270 62,680,154 2 Produced Fluid Volumes (Reservoir Units) CUM OIL CUM GAS CUM WATER Cumulatives at Dec 31, 2011 140,517,815 *114,148,450 57,487,525 OIL GAS WATER CUM OIL CUM GAS CUM WATER MO YR RVB RVB RVB RVB RVB RVB 1 2011 379,026 133,877 503,245 140,896,841 114,282,327 57,990,771 2 2011 341,028 147,946 481,071 141,237,869 114,430,274 58,471,842 3 2011 357,787 119,111 546,204 141,595,655 114,549,384 59,018,046 4 2011 325,922 215,411 516,815 141,921,577 114,764,796 59,534,860 5 2011 334,404 233,828 619,376 142,255,981 114,998,623 60,154,236 6 2011 159,535 128,966 243,794 142,415,516 115,127,589 60,398,030 7 2011 162,033 94,143 252,080 142,577,549 115,221,733 60,650,110 8 2011 355,842 213,956 583,692 142,933,391 115,435,688 61,233,802 9 2011 297,712 201,878 603,164 143,231,103 115,637,566 61,836,966 10 2011 281,097 189,438 585,297 143,512,200 115,827,005 62,422,263 11 2011 263,368 198,259 549,593 143,775,568 116,025,264 62,971,856 12 2011 263,226 236,979 585,820 144,038,793 116,262,242 63,557,676 2012 TOTAL 3,520,978 2,113,792 6,070,151 144,038,793 116,262,242 63,557,676 2 *2011 Cum Gas differs from last year's report due to reallocation of September 2011 gas volumes after report was issued ATTACHMENT 3 Tarn River Oil Pool 2012 Annual Reservoir Surveillance Report Injected Fluid Volumes CUM WATER CUM GAS CUM MI Cumulatives at Dec 31, 2011 164,912,266 15,940,381 177,249,267 WATER GAS MI CUM WATER CUM GAS CUM MI MO YR STB MSCF MSCF STB MSCF MSCF 1 2012 1,245,781 0 440,559 166,158,047 15,940,381 177,689,826 2 2012 1,028,312 0 445,802 167,186,359 15,940,381 178,135,628 3 2012 1,101,542 0 325,623 168,287,901 15,940,381 178,461,251 4 2012 986,264 0 369,840 169,274,165 15,940,381 178,831,091 5 2012 818,750 0 321,242 170,092,915 15,940,381 179,152,333 6 2012 386,940 22,048 117,712 170,479,855 15,962,429 179,270,045 7 2012 276,483 116,126 55,793 170,756,338 16,078,555 179,325,838 8 2012 857,658 0 294,135 171,613,996 16,078,555 179,619,973 9 2012 884,759 0 191,649 172,498,755 16,078,555 179,811,622 10 2012 859,312 0 272,831 173,358,067 16,078,555 180,084,453 11 2012 763,224 71,051 500,389 174,121,291 16,149,606 180,584,842 12 2012 694,672 0 617,849 174,815,963 16,149,606 181,202,691 2012 TOTAL 9,903,697 209,225 3,953,424 174,815,963 16,149,606 181,202,691 Injected Fluid Volumes (Reservoir Units) CUM WATER CUM GAS CUM MI Cumulatives at Dec 31, 2011 167,221,038 18,100,477 144,991,269 WATER GAS MI CUM WATER CUM GAS CUM MI MO YR RVB RVB RVB RVB RVB RVB 1 2012 1,263,222 0 343,154 168,484,260 18,100,477 145,334,423 2 2012 1,042,708 0 345,555 169,526,968 18,100,477 145,679,978 3 2012 1,116,964 0 247,799 170,643,932 18,100,477 145,927,777 4 2012 1,000,072 0 281,448 171,644,003 18,100,477 146,209,225 5 2012 830,213 0 245,659 172,474,216 18,100,477 146,454,885 6 2012 392,357 23,957 91,466 172,866,573 18,124,434 146,546,351 7 2012 280,354 122,718 43,112 173,146,927 18,247,152 146,589,463 8 2012 869,665 0 227,999 174,016,592 18,247,152 146,817,462 9 2012 897,146 0 148,270 174,913,738 18,247,152 146,965,732 10 2012 871,342 0 218,088 175,785,080 18,247,152 147,183,820 11 2012 773,909 79,973 405,674 176,558,989 18,327,125 147,589,494 12 2012 704,397 0 499,430 177,263,386 18,327,125 148,088,924 2012 TOTAL 10,042,349 226,649 3,097,655 177,263,386 18,327,125 148,088,924 ATTACHMENT 4 Tarn Oil Pool 2012 Annual Reservoir Surveillance Report Reservoir Pressure Surveys 1. Operator:2. Address:ConocoPhillips Alaska Inc.P. O. Box 100360, Anchorage, AK 99510-03603. Unit or Lease Name:4. Field and Pool: 5. Datum Reference: 6. Oil Gravity: 7. Gas Gravity:Kuparuk River UnitTarn Oil Pool -5200' SS 0.83 (water = 1.0) 0.748. Well Name and Number:9. API Number 50XXXXXXXXXXXX NO DASHES10. Type See Instructions11. AOGCC Pool Code12. Zone 13. Perforated Intervals Top - Bottom TVDSS14. Final Test Date15. Shut-In Time, Hours16. Press. Surv. Type (see instructions for codes)17. B.H. Temp.18. Depth Tool TVDSS19. Final Observed Pressure at Tool Depth20. Datum TVDSS (input)21. Pressure Gradient, psi/ft.22. Pressure at Datum (cal)2L-306 50029216770000 PROD 490165 A (-5265 - -5266), (-5287 - -5287), (-5289 - -5288), (-5291 - -5291), (-5231 - -5253)10/24/12 95 SBHP 139 5274 1156 5200 0.043 11532L-315 50029216770000 PROD 490165 A (-5231 - -5253) 06/30/12 395 SBHP 137 5242 1103 5200 0.350 10882L-326 50029222580000 PROD 490165 A (-4960 - -4968) 06/30/12 401 SBHP 131 4937 1113 5200 0.440 12292L-330 50029222580000 PROD 490165 A (-5257 - -5268), (-5637 - -5653)07/13/12 690 SBHP 137 5263 1576 5200 0.040 15732N-304 50029229210000 PROD 490165 A (-5353 - -5361) 12/04/12 11700 SBHP 142 5357 2016 5200 0.320 19662N-304 50029228420000 PROD 490165 A (-5353 - -5361) 01/10/12 3861 SBHP 141 5356 1649 5200 0.430 15822N-306 50029228420000 INJ 490165 A (-5238 - -5243), (-5246 - -5257), (-5261 - -5273), (-5308 - -5320), (-5327 - -5357)03/30/12 1648 SBHP 117 5255 3762 5200 0.449 37372N-308 50029229110000 PROD 490165 A (-5073 - -5082), (-5073 - -5096)06/22/12 200 SBHP 138 5084 2387 5200 0.430 24372N-310 50029228440000 INJ 490165 A (-5283 - -5300), (-5358 - -5425), (-5434 - -5482), (-5507 - -5516), (-5727 - -5746)01/12/12 2364 SBHP 130 5464 3931 5200 0.420 38202N-311A 50029228440000 PROD 490165 A (-5162 - -5174) 06/20/12 144 SBHP 138 5168 966 5200 0.300 9762N-313 50029228350000 PROD 490165 A (-5050 - -5064), (-5064 - -5078), (-5003 - -5014), (-5014 - -5019), (-5101 - -5129), (-4956 - -4962), (-4970 - -4992), (-4998 - -5012), (-5012 - -5033)06/20/12 160 SBHP 134 5057 2268 5200 0.418 23282N-315 50029228140000 PROD 490165 A (-5003 - -5014), (-5014 - -5019)06/21/12 176 SBHP 134 5011 1969 5200 0.284 20232N-317 50029229050000 PROD 490165 A (-5101 - -5129) 06/22/12 205 SBHP 141 5115 2653 5200 0.424 26892N-320 50029229040100 PROD 490165 A (-4956 - -4962), (-4970 - -4992)06/22/12 182 SBHP 134 4964 2356 5200 0.144 23902N-329 50029229040100 PROD 490165 A (-4998 - -5012), (-5012 - -5033)06/24/12 228 SBHP 134 5016 1960 5200 0.220 20012N-333 50029229000000 PROD 490165 A (-4986 - -4997) 09/25/12 105 SBHP 137 4987 2439 5200 0.428 25302N-335 50029228300000 INJ 490165 A (-4935 - -4959), (-4964 - -4968), (-4982 - -4991), (-4994 - -4999), (-4999 - -5007)09/19/12 19890 SBHP 130 4963 2643 5200 0.280 27092N-337B 50029228300000 PROD 490165 A (-5090 - -5101) 09/19/12 20400 SBHP 131 5101 3546 5200 0.340 3580STATE OF ALASKAALASKA OIL AND GAS CONSERVATION COMMISSIONRESERVOIR PRESSURE REPORTForm 10-412 Rev. 12/2008 ATTACHMENT 5 Tarn Oil Pool 2012 Annual Reservoir Surveillance Report Production Logs and Special Surveys Well Date Comment 2L-307 3/7/2012 Perforate whipstock tray 2L-306 10/28/2012 Mill out ball seats of frac sleeves in horizontal 2L-306 10/29/2012 Fill clean out horizontal ATTACHMENT 6 Tarn Oil Pool 2012 Annual Reservoir Surveillance Report Allocation Factors Month Oil Gas Water 01/31/12 0.9537 0.9162 1.0479 02/29/12 0.9538 0.9210 1.0217 03/31/12 0.9471 0.9065 1.0368 04/30/12 0.9758 0.9081 1.0239 05/31/12 0.9642 0.8936 1.0685 06/30/12 0.4566 0.4396 0.4827 07/31/12 0.4560 0.4949 0.4546 08/31/12 0.9889 1.0106 1.0008 09/30/12 0.9838 0.9387 1.0409 10/31/12 0.9724 0.9159 1.0491 11/30/12 0.9604 0.9177 1.0429 12/31/12 0.9683 0.9107 1.0642 ATTACHMENT 7 Tarn Oil Pool 2012 Annual Reservoir Surveillance Report Tarn Development Plan and Operational Review Development Drilling No Tarn development drilling occurred in 2012. Development opportunities exist at Tarn and are being evaluated. Producer to Injector Conversions Conversion plans for 2013 include converting the pre-produced well 2L-310 and producing well 2N-308 to MWAG injection. Well 2L-310 will provide pressure support and EOR benefit to 2011 offset producers 2L-312 and 2L-306, while well 2N-308 will provide MWAG injection support to 2N-315 and 2L-326 producing wells. 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 occur s when the production fluid temperature falls below the cloud point of 92ºF. 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 2012, 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). Consequently, completion designs and alternatives to jet pumps are being considered for new and existing wells. Capillary chemical injection tubes were installed in new production wells drilled in 2010 and 2011. 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, additional paraffin inhibition pilot testing is being considered. ATTACHMENT 8 Tarn Oil Pool 2012 Annual Reservoir Surveillance Report Map showing recent development wells ATTACHMENT 1 West Sak Oil Pool 2012 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 2012. At the end of 2012 there were fifty-two active water injectors and forty-eight active producers in the West Sak Oil Pool. This represents a decrease of two active producers and an increase of twenty-five active injectors in West Sak from January 2012 to December 2012. 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. Injection wells have been returned to service following rig work that was completed to implement two barriers in the surrounding producers. 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 ~60% of 2012 with the remaining time on produced water injection. Waterflood performance was good in the majority of the West Sak patterns. During 2012 the West Sak oil pool experienced one new confirmed rapid water breakthrough event, termed matrix bypass event (MBE), resulting 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 has been implemented in seven wells since 2011 with sustained success in four of the wells. 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, 1E-102 and 1E-117. Two additional injectors, 1J-170 and 1J-122, began gas injection in April 2010. Well 1E-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 2012 were ~ 610 mmscf for well 1E-117, ~ 310 mmscf for well 1J-122, and ~ 350 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 2012 Annual Reservoir Surveillance Report Produced Fluid Volumes Cumulatives at Dec 31, 2011 56,631,588 *27,657,615 15,202,056 OIL GAS WATER CUM OIL CUM GAS CUM WATER MO YR STB MSCF STB STB MSCF STB 1 2012 469,945 297,659 135,561 57,101,533 27,955,274 15,337,617 2 2012 401,187 289,646 131,272 57,502,720 28,244,920 15,468,889 3 2012 412,302 285,131 143,958 57,915,022 28,530,051 15,612,847 4 2012 366,803 231,492 191,380 58,281,825 28,761,543 15,804,227 5 2012 402,675 320,288 179,795 58,684,500 29,081,831 15,984,022 6 2012 395,588 325,565 140,951 59,080,088 29,407,396 16,124,973 7 2012 437,289 330,279 150,988 59,517,377 29,737,675 16,275,961 8 2012 446,674 319,006 163,626 59,964,051 30,056,681 16,439,587 9 2012 414,531 278,755 239,265 60,378,582 30,335,436 16,678,852 10 2012 462,305 272,338 229,466 60,840,887 30,607,774 16,908,318 11 2012 495,067 278,960 257,825 61,335,954 30,886,734 17,166,143 12 2012 501,830 272,244 215,400 61,837,784 31,158,978 17,381,543 2012 TOTAL 5,206,196 3,501,363 2,179,487 61,837,784 31,158,978 17,381,543 Produced Fluid Volumes (Reservoir Units) Cumulatives at Dec 31, 2011 58,855,849 *24,820,876 15,170,345 OIL GAS WATER CUM OIL CUM GAS CUM WATER MO YR RVB RVB RVB RVB RVB RVB 1 2012 501,901 343,673 135,517 59,357,750 25,164,549 15,305,862 2 2012 425,833 353,536 131,007 59,783,583 25,518,085 15,436,869 3 2012 437,393 343,711 144,354 60,220,976 25,861,796 15,581,223 4 2012 391,041 269,381 192,104 60,612,017 26,131,177 15,773,327 5 2012 429,597 401,281 179,273 61,041,614 26,532,458 15,952,600 6 2012 422,621 406,610 141,155 61,464,235 26,939,069 16,093,755 7 2012 465,838 409,418 152,208 61,930,073 27,348,487 16,245,963 8 2012 476,135 385,986 163,969 62,406,208 27,734,472 16,409,932 9 2012 440,656 334,104 237,232 62,846,864 28,068,576 16,647,164 10 2012 492,172 307,107 229,606 63,339,035 28,375,683 16,876,770 11 2012 760,231 312,526 406,784 64,099,267 28,688,210 17,283,554 12 2012 518,402 285,920 201,532 64,617,668 28,974,130 17,485,086 2012 TOTAL 5,761,819 4,153,254 2,314,741 64,617,668 28,974,130 17,485,086 *2011 Cum Gas volume includes corrections made after 2011 Surveillance Report was issued. ATTACHMENT 3 West Sak Oil Pool 2012 Annual Reservoir Surveillance Report Injected Fluid Volumes CUM WATER CUM GAS CUM MI Cumulatives at Dec 31, 2011 78,727,585 *21,732 * 2,360,521 WATER GAS MI CUM WATER CUM GAS CUM MI MO YR STB MSCF MSCF STB MSCF MSCF 1 2012 596,280 0 101,676 79,323,865 21,732 2,462,197 2 2012 542,318 0 92,867 79,866,183 21,732 2,555,064 3 2012 553,136 0 79,175 80,419,319 21,732 2,634,239 4 2012 537,098 0 87,195 80,956,417 21,732 2,721,434 5 2012 529,364 0 203,779 81,485,781 21,732 2,925,213 6 2012 417,004 0 181,105 81,902,785 21,732 3,106,318 7 2012 373,133 0 151,452 82,275,918 21,732 3,257,770 8 2012 425,234 0 65,817 82,701,152 21,732 3,323,587 9 2012 407,552 0 100,864 83,108,704 21,732 3,424,451 10 2012 417,901 0 123,781 83,526,605 21,732 3,548,232 11 2012 454,475 0 83,850 83,981,080 21,732 3,632,082 12 2012 447,922 0 0 84,429,002 21,732 3,632,082 2012 TOTAL 5,701,417 0 1,271,561 84,429,002 21,732 3,632,082 Injected Fluid Volumes (Reservoir Units) CUM WATER CUM GAS CUM MI Cumulatives at Dec 31, 2011 77,310,640 34,916 1,768,030 WATER GAS MI CUM WATER * CUM GAS * CUM MI MO YR RVB RVB RVB RVB RVB RVB 1 2012 596,375 0 76,155 77,907,015 34,916 1,844,185 2 2012 536,845 0 69,557 78,443,860 34,916 1,913,743 3 2012 551,861 0 59,302 78,995,721 34,916 1,973,045 4 2012 542,811 0 65,309 79,538,532 34,916 2,038,354 5 2012 530,254 0 152,630 80,068,786 34,916 2,190,984 6 2012 407,421 0 135,648 80,476,207 34,916 2,326,632 7 2012 370,394 0 113,438 80,846,601 34,916 2,440,070 8 2012 436,213 0 49,297 81,282,814 34,916 2,489,367 9 2012 409,073 0 75,547 81,691,887 34,916 2,564,914 10 2012 407,702 0 92,712 82,099,589 34,916 2,657,626 11 2012 836,686 0 62,804 82,936,275 34,916 2,720,429 12 2012 420,042 0 0 83,356,317 34,916 2,720,429 2012 TOTAL 6,045,677 0 952,399 83,356,317 34,916 2,720,429 * gas and MI after 2011 report was issued 2011 Cum Water and Cum Gas totals differ from last year's report due to correction of allocation between ATTACHMENT 4 West Sak Oil Pool 2012 Annual Reservoir Surveillance Report Reservoir Pressure Surveys Form 10-412 Rev. 12/2008 INSTRUCTIONS ON REVERSE SIDE Submit in Duplicate 6. Oil Gravity: 0.94 (water = 1.0) 8. Well Name and Number: 9. API Number 50XXXXXXXXXXXX NO DASHES 10. Type See Instructions 11. AOGCC Pool Code 12. Zone 13. Perforated Intervals Top - Bottom TVDSS 14. Final Test Date 15. Shut-In Time, Hours 16. Press. Surv. Type (see instructions for codes) 17. B.H. Temp. 18. Depth Tool TVDSS 19. Final Observed Pressure at Tool Depth 20. Datum TVDSS (input) 21. Pressure Gradient, psi/ft. 22. Pressure at Datum (cal) 1C-117 50029214590000 INJ 490150 A (-3630 - -3666), (-3692 - -3711), (-3739 - -3758), (-3774 - -3790), (-3796 - -3825), (-3807 - -3827), (-3835 - -3866), (-3847 - -3866) 02/13/12 14880 SBHP 79 3737 1656 3500 0.500 1538 1C-119 50029226910000 INJ 490150 ABD (-3595 - -3609), (-3609 - -3627), (-3655 - -3671), (-3671 - -3689), (-3700 - -3723), (-3782 - -3789), (-3834 - -3842) 02/14/12 18624 SBHP 75 3690 1772 3500 0.490 1679 1C-121 50029226910100 INJ 490150 ABD (-3548 - -3589), (-3613 - -3648), (-3657 - -3682), (-3702 - -3713), (-3721 - -3747), (-3784 - -3811) 02/15/12 18648 SBHP 48 2296 1195 3500 0.450 1737 1C-123 50029213430000 INJ 490150 A (-3611 - -3642), (-3674 - -3685), (-3721 - -3727), (-3735 - -3740), (-3760 - -3774), (-3780 - -3809), (-3855 - -3874) 02/12/12 14856 SBHP 69 3444 1462 3500 0.390 1484 1C-125 50029216320000 INJ 490150 ABD (-3526 - -3546), (-3546 - -3556), (-3584 - -3607), (-3631 - -3639), (-3649 - -3653), (-3674 - -3682), (-3691 - -3721), (-3755 - -3779) 02/12/12 13752 SBHP 75 3633 1441 3500 0.390 1389 1C-127 50029215390000 INJ 490150 A (-3598 - -3636), (-3663 - -3730), (-3664 - -3698), (-3748 - -3764), (-3773 - -3795), (-3836 - -3857) 02/17/12 15024 SBHP 75 3722 1661 3500 0.440 1563 1C-131 50029215390100 INJ 490150 BD (-3661 - -3700), (-3723 - -3758) 04/27/12 16656 SBHP 88 3649 1733 3500 0.378 1677 -3500' SS 0.57 3. Unit or Lease Name:4. Field and Pool:5. Datum Reference: ConocoPhillips Alaska Inc.P. O. Box 100360, Anchorage, AK 99510-0360 7. Gas Gravity: Kuparuk River Unit West Sak Oil Pool STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION RESERVOIR PRESSURE REPORT 1. Operator:2. Address: Form 10-412 Rev. 12/2008 INSTRUCTIONS ON REVERSE SIDE Submit in Duplicate 6. Oil Gravity: 0.94 (water = 1.0) 8. Well Name and Number: 9. API Number 50XXXXXXXXXXXX NO DASHES 10. Type See Instructions 11. AOGCC Pool Code 12. Zone 13. Perforated Intervals Top - Bottom TVDSS 14. Final Test Date 15. Shut-In Time, Hours 16. Press. Surv. Type (see instructions for codes) 17. B.H. Temp. 18. Depth Tool TVDSS 19. Final Observed Pressure at Tool Depth 20. Datum TVDSS (input) 21. Pressure Gradient, psi/ft. 22. Pressure at Datum (cal) -3500' SS 0.57 3. Unit or Lease Name:4. Field and Pool:5. Datum Reference: ConocoPhillips Alaska Inc.P. O. Box 100360, Anchorage, AK 99510-0360 7. Gas Gravity: Kuparuk River Unit West Sak Oil Pool STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION RESERVOIR PRESSURE REPORT 1. Operator:2. Address: 1C-133 50029215400100 INJ 490150 BD (-3665 - -3695), (-3725 - -3755), (-3769 - -3791), (-3811 - -3821), (-3827 - -3841), (-3845 - -3857), (-3875 - -3945) 04/28/12 16896 SBHP 75 3710 1773 3500 0.340 1702 1C-135 50029215400100 PROD 490150 D (-3675 - -3663)01/20/12 3888 SBHP 74 3664 1200 3500 0.350 1143 1D-101 50029217960100 INJ 490150 ABD (-3593 - -3630), (-3658 - -3676), (-3676 - -3695), (-3702 - -3728), (-3745 - -3760), (-3768 - -3801), (-3822 - -3869) 02/20/12 15020 SBHP 76 3621 2251 3500 0.410 2201 1D-108 50029222200000 PROD 490150 ABD (-3572 - -3599), (-3632 - -3660), (-3694 - -3722), (-3750 - -3767), (-3805 - -3837) 05/07/12 240 SBHP 53 2503 1000 3500 0.420 1419 1D-109 50029222200000 INJ 490150 BD (-3550 - -3581), (-3613 - -3645), (-3655 - -3674), (-3696 - -3704), (-3713 - -3747), (-3768 - -3779), (-3788 - -3823), (-3842 - -3855) 10/08/12 2832 SBHP 34 1594 1705 3500 0.410 2486 1D-117 50029222210000 INJ 490150 ABD (-3600 - -3971), (-3616 - -3646), (-3616 - -3639), (-3639 - -3646), (-3680 - -3700), (-3727 - -3742), (-3732 - -3742), (-3784 - -3814), (-3838 - -3868), (-3912 - -3920), (-3954 - -3962) 06/15/12 17784 SBHP 79 3748 1773 3500 0.440 1664 Form 10-412 Rev. 12/2008 INSTRUCTIONS ON REVERSE SIDE Submit in Duplicate 6. Oil Gravity: 0.94 (water = 1.0) 8. Well Name and Number: 9. API Number 50XXXXXXXXXXXX NO DASHES 10. Type See Instructions 11. AOGCC Pool Code 12. Zone 13. Perforated Intervals Top - Bottom TVDSS 14. Final Test Date 15. Shut-In Time, Hours 16. Press. Surv. Type (see instructions for codes) 17. B.H. Temp. 18. Depth Tool TVDSS 19. Final Observed Pressure at Tool Depth 20. Datum TVDSS (input) 21. Pressure Gradient, psi/ft. 22. Pressure at Datum (cal) -3500' SS 0.57 3. Unit or Lease Name:4. Field and Pool:5. Datum Reference: ConocoPhillips Alaska Inc.P. O. Box 100360, Anchorage, AK 99510-0360 7. Gas Gravity: Kuparuk River Unit West Sak Oil Pool STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION RESERVOIR PRESSURE REPORT 1. Operator:2. Address: 1D-125A 50029216840000 INJ 490150 ABD (-3452 - -3484), (-3511 - -3543), (-3557 - -3579), (-3596 - -3603), (-3612 - -3629), (-3638 - -3644), (-3662 - -3675), (-3686 - -3700), (-3709 - -3717), (-3728 - -3741) 12/17/12 840 SBHP 80 3556 2170 3500 0.420 2147 1D-129 50029216830000 PROD 490150 ABD (-3444 - -3459), (-3469 - -3484), (-3470 - -3498), (-3499 - -3509), (-3530 - -3550), (-3539 - -3549), (-3576 - -3593), (-3579 - -3589), (-3616 - -3626), (-3619 - -3629), (-3643 - -3653), (-3659 - -3669), (-3699 - -3709), (-3712 - -3742), (-3739 - -3749) 04/05/12 36 SBHP 74 3225 1108 3500 0.370 1210 1D-129 50029216810100 PROD 490150 ABD (-3444 - -3459), (-3469 - -3484), (-3470 - -3498), (-3499 - -3509), (-3530 - -3550), (-3539 - -3549), (-3576 - -3593), (-3579 - -3589), (-3616 - -3626), (-3619 - -3629), (-3643 - -3653), (-3659 - -3669), (-3699 - -3709), (-3712 - -3742), (-3739 - -3749) 11/27/12 5688 SBHP 65 3173 1503 3500 0.393 1632 Form 10-412 Rev. 12/2008 INSTRUCTIONS ON REVERSE SIDE Submit in Duplicate 6. Oil Gravity: 0.94 (water = 1.0) 8. Well Name and Number: 9. API Number 50XXXXXXXXXXXX NO DASHES 10. Type See Instructions 11. AOGCC Pool Code 12. Zone 13. Perforated Intervals Top - Bottom TVDSS 14. Final Test Date 15. Shut-In Time, Hours 16. Press. Surv. Type (see instructions for codes) 17. B.H. Temp. 18. Depth Tool TVDSS 19. Final Observed Pressure at Tool Depth 20. Datum TVDSS (input) 21. Pressure Gradient, psi/ft. 22. Pressure at Datum (cal) -3500' SS 0.57 3. Unit or Lease Name:4. Field and Pool:5. Datum Reference: ConocoPhillips Alaska Inc.P. O. Box 100360, Anchorage, AK 99510-0360 7. Gas Gravity: Kuparuk River Unit West Sak Oil Pool STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION RESERVOIR PRESSURE REPORT 1. Operator:2. Address: 1D-130 50029222660000 INJ 490150 ABD (-3478 - -3480), (-3497 - -3499), (-3521 - -3523), (-3533 - -3549), (-3561 - -3563), (-3576 - -3610), (-3579 - -3581), (-3581 - -3610), (-3615 - -3617), (-3620 - -3625), (-3625 - -3645), (-3631 - -3633), (-3647 - -3649), (-3664 - -3670), (-3667 - -3669), (-3669 - -3670), (-3679 - -3711), (-3723 - -3725), (-3734 - -3739), (-3749 - -3788), (-3761 - -3763), (-3771 - -3772), (-3798 - -3800), (-3808 - -3820), (-3830 - -3832), (-3858 - -3860), (-3962 - -3964) 01/02/12 960 SBHP 95 3569 3680 3500 0.420 3651 1D-139 50103204300000 INJ 490150 ABD (-3551 - -3586), (-3615 - -3652), (-3661 - -3680), (-3704 - -3711), (-3720 - -3729), (-3734 - -3742), (-3748 - -3759), (-3775 - -3816), (-3852 - -3861) 09/23/12 20184 SBHP 81 3608 1167 3500 0.360 1128 3K-103 50029211530000 INJ 490150 B (-3483 - -3482), (-3484 - -3484), (-3493 - -3494), (-3500 - -3501), (-3506 - -3505), (-3509 - -3509), (-3509 - -3508), (-3510 - -3510), (-3512 - -3512), (-3515 - -3516), (-3523 - -3523), (-3569 - -3569) 04/22/12 177 SBHP 64 4382 1710 6200 0.428 2488 ATTACHMENT 5 West Sak Oil Pool 2012 Annual Reservoir Surveillance Report Injectivity Profiles KUPARUK RIVER UNIT WEST SAK OIL POOL CONSERVATION ORDER 406B RULE 11d - INJECTIVITY PROFILES 2012 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-160 292334400-00 07/12 12/06/12 SPINNER A/C SPLITS Single BD 450 1C-119 292303400-00 10/12 11/08/12 SPINNER A/C SPLITS Single ABD 220 1C-133 292301300-00 11/12 11/12/12 SPINNER A/C SPLITS Single BD 130 3 >>Total IPROF Count for 2011 ATTACHMENT 5 ATTACHMENT 6 Kuparuk River Unit West Sak Oil Pool 2012 Annual Reservoir Surveillance Report Production Survey Data During 2012, no production profile survey was attempted for the West Sak Oil Pool. ATTACHMENT 7 West Sak Oil Pool 2012 Annual Reservoir Surveillance Report Special Survey Date Geochemical Oil Production Splits Well Name Sample Date A Sand B Sand D Sand 1B-101 04/08/12 0%47%53% 1B-101 09/07/12 0%47%53% 1C-102 01/30/12 0%6%94% 1C-102 06/10/12 0%40%60% 1C-102 07/19/12 0%29%71% 1C-109 06/10/12 0%65%35% 1C-109 07/19/12 0%55%45% 1C-109 08/16/12 0%44%56% 1C-119 10/29/12 21%29%50% 1C-133 11/11/12 0%75%25% 1C-170 01/30/12 0%0%100% 1C-170 05/08/12 0%0%100% 1C-172A 01/30/12 100%0%0% 1C-172A 07/03/12 100%0%0% 1C-178 05/08/12 0%53%48% 1C-178 07/03/12 0%32%68% 1C-184 01/30/12 0%0%100% 1C-184 05/08/12 0%0%100% 1C-184 07/03/12 0%0%100% 1C-184 08/16/12 0%0%100% 1D-102 02/05/12 0%56%44% 1D-102 06/15/12 0%93%7% 1D-102 09/07/12 0%60%40% 1D-105A 06/21/12 0%0%100% 1D-105A 07/11/12 0%0%100% 1D-105A 08/16/12 0%0%100% 1D-108 02/05/12 70%1%29% 1D-108 08/16/12 70%1%29% 1D-110A 02/05/12 39%16%45% 1D-112 02/05/12 40%34%25% 1D-115 02/05/12 53%31%16% 1D-115 08/14/12 54%0%46% 1D-118 02/06/12 69%0%31% 1D-121 06/15/12 51%14%35% 1D-121 07/11/12 41%29%30% 1D-123 09/09/12 63%12%25% 1D-124 06/21/12 68%1%31% 1D-124 07/11/12 61%13%26% 1D-127 06/15/12 30%52%18% 1D-127 08/03/12 30%52%18% 1D-129 02/05/12 68%16%16% 1D-133 02/05/12 74%22%4% 1D-133 09/09/12 85%2%13% 1D-134 02/05/12 64%23%13% 1D-135 02/05/12 13%19%68% 1D-141A 02/24/12 0%0%100% 1D-141A 06/15/12 0%0%100% 1D-141A 09/01/12 0%0%100% 1E-170 02/03/12 0%68%32% 1E-170 02/27/12 0%56%44% 1E-170 03/22/12 0%69%31% 1E-170 05/18/12 0%69%31% ATTACHMENT 7 West Sak Oil Pool 2012 Annual Reservoir Surveillance Report Special Survey Date Geochemical Oil Production Splits Well Name Sample Date A Sand B Sand D Sand 1E-170 06/15/12 0%48%52% 1E-170 08/08/12 0%46%54% 1E-170 09/05/12 0%37%64% 1E-168 02/03/12 15%26%59% 1E-168 04/08/12 0%0%100% 1E-168 07/03/12 0%0%100% 1E-166 02/03/12 11%24%65% 1E-166 04/08/12 5%36%59% 1E-166 07/02/12 7%0%94% 1E-166 07/03/12 7%26%67% 1E-126 02/03/12 54%0%46% 1E-126 05/19/12 25%53%22% 1E-126 06/09/12 25%57%18% 1E-126 08/12/12 7%52%42% 1E-126 09/06/12 7%52%42% 1E-123 07/19/12 0%41%59% 1E-121 02/03/12 0%20%80% 1E-121 05/18/12 0%14%86% 1E-121 08/12/12 0%16%84% 1E-121 09/05/12 0%23%77% 1J-101 01/30/12 46%9%45% 1J-101 06/14/12 50%1%49% 1J-101 07/15/12 16%38%46% 1J-103 01/30/12 0%53%47% 1J-103 06/09/12 21%22%57% 1J-103 07/15/12 10%30%60% 1J-107 01/30/12 0%2%98% 1J-107 06/14/12 0%0%100% 1J-107 07/19/12 0%0%100% 1J-115 01/30/12 30%23%48% 1J-115 06/09/12 30%23%47% 1J-115 07/15/12 15%28%57% 1J-120 01/30/12 20%12%68% 1J-120 02/14/12 7%13%80% 1J-120 03/12/12 8%11%81% 1J-120 05/18/12 9%14%77% 1J-120 06/19/12 9%14%77% 1J-120 08/03/12 5%13%83% 1J-120 09/07/12 6%14%80% 1J-135 07/15/12 0%79%21% 1J-137 01/30/12 0%54%46% 1J-152 01/30/12 69%7%25% 1J-152 05/19/12 58%0%42% 1J-152 07/15/12 31%14%55% 1J-156 07/09/12 32%26%42% 1J-158 01/30/12 0%79%21% 1J-158 05/18/12 0%89%11% 1J-158 07/19/12 0%80%20% 1J-159 01/30/12 23%4%73% 1J-159 05/19/12 27%0%73% 1J-159 07/19/12 32%4%64% 1J-160 07/08/12 0%69%31% ATTACHMENT 7 West Sak Oil Pool 2012 Annual Reservoir Surveillance Report Special Survey Date Geochemical Oil Production Splits Well Name Sample Date A Sand B Sand D Sand 1J-162 05/19/12 0%46%54% 1J-166 01/30/12 18%0%82% 1J-166 02/14/12 19%0%81% 1J-166 03/12/12 47%0%53% 1J-166 05/18/12 33%4%62% 1J-166 06/14/12 38%7%56% 1J-166 08/03/12 21%11%68% 1J-168 01/30/12 0%39%62% 1J-168 02/24/12 0%45%55% 1J-168 03/22/12 0%39%61% 1J-168 05/18/12 59%37%5% 1J-168 06/14/12 71%19%10% 1J-168 08/08/12 46%38%16% 1J-174 07/13/12 0%47%53% 1J-178 01/30/12 0%63%37% 1J-178 06/14/12 0%65%35% 1J-178 08/12/12 0%65%35% 1J-182 01/30/12 0%76%24% 1J-182 05/19/12 0%74%26% 1J-182 07/15/12 0%78%22% 3K-102 03/18/08 0%50%50% 3K-102 04/02/08 0%43%57% 3K-102 05/09/08 0%50%50% 3K-102 07/03/09 0%34%66% 3K-102 11/05/09 0%27%73% 3K-102 05/07/10 0%35%65% 3K-102 08/29/10 0%46%55% 3K-102 10/06/10 0%51%49% 3K-102 01/27/11 0%50%50% 3K-102 04/09/11 0%42%58% 3K-102 07/26/11 0%17%83% 3K-102 01/30/12 0%42%58% 3K-102 05/19/12 0%66%34% 3K-102 07/22/12 0%41%60% 3K-102 08/23/12 0%38%62% 3K-103 08/20/12 0%100%0% 3K-103L1 08/20/12 0%0%100% 3K-108 08/20/12 0%100%0% 3K-108L1 08/20/12 0%0%100% Month Oil Gas Water 01/31/12 0.9537 0.9161 1.0480 02/29/12 0.9537 0.9211 1.0218 03/31/12 0.9470 0.9065 1.0368 04/30/12 0.9758 0.9081 1.0238 05/31/12 0.9641 0.8937 1.0685 06/30/12 0.9522 0.9555 1.0177 07/31/12 0.9815 1.0100 0.9945 08/31/12 0.9889 1.0106 1.0009 09/30/12 0.9838 0.9387 1.0409 10/31/12 0.9724 0.9160 1.0492 11/30/12 0.9604 0.9177 1.0430 12/31/12 0.9684 0.9107 1.0642 West Sak Oil Pool 2012 Annual Reservoir Surveillance Report Allocation Factors ATTACHMENT 8 Attachment 9 Kuparuk River Unit West Sak Oil Pool 2012 Annual Reservoir Surveillance Report Development Plans and Operational Review • WEST SAK DEVELOPMENT There was no new development in 2012. • 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 advanced to install a down hole heater and attempt an oil sample collection from an existing well. Attachment 1 Kuparuk River Oil Pool 2012 Annual Reservoir Surveillance Report Gas Offtake Data 2012 Monthly Gas Offtake MSCFD SCFD RB/D January 633 632968 559 February 614 613621 542 March 575 575065 508 April 588 588267 519 May 551 550935 486 June 329 329033 291 July 332 331581 293 August 470 469613 415 September 525 525300 464 October 524 524258 463 November 576 576367 509 December 407 407226 360 Average 510 510,353 451 Kuparuk Gas Offtake-2012 0 100 200 300 400 500 600 700 January March May July September November MCFD