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Home My WebLink About2009 Greater Kuparuk AreaConoco Ph i l l i s p Alaska, Inc. Greater Kuparuk Area MAR 11. 2010 2009 Annual Reservoir Surveillance Reports Kuparuk, Meltwater, Tabasco, Tarn, & West Sak Oil Pools Reporting Period January 1 to December 31, 2009 2009 GREATER KUPARUK AREA ANNUAL SURVEILLANCE REPORTS Table of Contents SUMMARY OF EOR PROJECT ............... Map of EOR Program Status Plot of Incremental EOR Oil Rate PRODUCED FLUID VOLUMES .............. ............................................................ ATTACHMENT I INJECTED FLUID VOLUMES .......................... RESERVOIR PRESSURE SURVEYS ............... Proposed Pressure Survey Plan Perforated Intervals and Stratigraphic Zones INJECTION SURVEY DATA ............................ Proposed Injection Profile Survey Plan PRODUCTION SURVEY DATA ....................... MISCIBLE INJECTANT COMPOSITION ........ CPF1 MI Composition CPF2 MI Composition KUPARUK LSEOR DEVELOPMENT PLAN... GKA 2009 SHUT -W WELL REPORT ........................ MELTWATER OIL POOL REPORT ............................. ATTACHMENT 6 ............................. A17ACI-IMENT 7 ............................. ATTACHMENT 8 ............................. ATTACHMENT 9 SUMMARY OF EOR PROJECT & RESERVOIR MANAGEMENT ..................... ATTACHMENT 1 PRODUCED FLUID VOLUMES.............................................................................ATTACHMENT 2 INJECTED FLUID VOLUMES ......................... RESERVOIR PRESSURE SURVEYS .............. Proposed Pressure Survey Plan Perforated Intervals and Stratigraphic Zones PRODUCTION & SPECIAL SURVEYS .......... ...................................................... ATTACHMENT 3 ...................................................... ATTACHMENT 4 ....................................................... ATTACHMENT 5 WELL ALLOCATION & SHALLOW GAS SPECIAL MONITORING ................. ATTACHMENT 6 Meltwater OA Pressure Survey for 2009 MELTWATER DEVELOPMENT PLAN & OPERATIONAL REVIEW ............... ATTACHMENT 7 MAP SHOWING DEVELOPMENT AS OF 12/31/2009 ......................................... ATTACHMENT 8 TABASCO OIL POOL REPORT SUMMARY OF EOR PROJECT........................................................................ PRODUCED FLUID VOLUMES....................................................................... INJECTED FLUID VOLUMES.......................................................................... RESERVOIR PRESSURE SURVEYS............................................................... Proposed Pressure Survey Plan Perforated Intervals and Stratigraphic Zones PRODUCTION LOGS &SPECIAL SURVEYS .................................. WELL ALLOCATION & TEST EVALUATION SUMMARY ........... FUTURE DEVELOPMENT PLANS .................................................... TARN OIL POOL REPORT ATTACHMENT I ...... ATTACHMENT 2 ...... ATTACHMENT 3 ...... ATTACHMENT 4 ... ATTACHMENT 5 ATTACHMENT ........... ATTACHMENT 7 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 Perforated Intervals and Stratigraphic Zones PRODUCTION LOGS & SPECIAL SURVEYS......................................................ATTACHMENT 5 PRODUCTION ALLOCATION FACTORS............................................................ ATTACHMENT 6 TARN DEVELOPMENT PLAN & OPERATIONAL REVIEW ............................. ATTACHMENT 7 MAP SHOWING RECENT DEVELOPMENT WELLS .......................................... ATTACHMENT 8 WEST SAK OIL POOL REPORT SUMMARY OF EOR PROJECT.............................................................................. ATTACHMENT 1 PRODUCED FLUID VOLUMES.............................................................................ATTACHMENT 2 INJECTED FLUID VOLUMES................................................................................ ATTACHMENT 3 RESERVOIR PRESSURE SURVEYS..................................................................... ATTACHMENT 4 Proposed Pressure Survey Plan Perforated Intervals and Stratigraphic Zones INJECTION SURVEY DATA............................................................. PRODUCTION SURVEY DATA ........................................................ GEOCHEMICAL OIL PRODUCTION SPLITS .................................. PRODUCTION ALLOCATION FACTORS ....................................... FUTURE DEVELOPMENT PLANS ................................................ ....... ATTACHMENT 5 ....... ATTACHMENT 6 ....... ATTACHMENT 7 .......ATTACHMENT 8 ........ ATTACHMENT 9 TABLE OF MONTHLY GAS OFFTAKE................................................................ ATTACHMENT 1 ConocoPhillips James T., Rodgers Manager, GKA Development Greater Kuparuk Area ConocoPhillips Alaska, Inc. ATO -1326 PO Box 100360 Anchorage AK 99510-0360 Phone (907)263-4027 Fax: (907)265-6133 March 31. 2010 Mr. Dan Seamount, Commissioner Alaska Oil and Gas Conservation Commission 333 West 7h Ave. Suite 100 Anchorage, Alaska 99501-3539 Re: 2009 Kuparuk Oil Pool Annual Reservoir Surveillance Report Dear Commissioner Seamount, In compliance with Rule 3, Conservation Order No. 198B, ConocoPhillips Alaska, Inc., operator of the Kuparuk River Unit, is hereby submitting the annual surveillance report on the Kuparuk River Oil Pool. This report documents the required information pertinent to the field development and enhanced recovery operations from January through December 2009. The following is an outline of the information provided: a. A summary of the enhanced recovery project (Attachment 1). b. Voidage balance, by month, for produced and injected fluids, including low molecular weight hydrocarbons (Attachments 2 and 3). c. Analysis of reservoir pressure surveys taken in 2009 (Attachment 4). d. A tabulation of both injection (Attachment 5) and production (Attachment 6) logs and surveys analyzed during 2009 from wells in the Kuparuk permit area. e. Composition of enriched gas injected during 2009 and estimate of MMP (Attachment 7). f. Kuparuk LSEOR development plan (Attachment 8). g. 365 days or longer shut in well report for the Greater Kuparuk Area (Attachment 9). If you have any questions concerning this data, please contact Mark Kovar at 265-6097. Sincerely, *A4)A J U3C�� mes T. Rodgers Manager, GKA Development Greater Kuparuk Area Kuparuk River Oil Pool ATTACHMENT 2009 Reservoir Surveillance Report Kuparuk River Oil Pool 2009 Annual Reservoir Surveillance Report Summary of the Enhanced Recovery Project Enhanced Recovery Miscible water -alternating -gas (MWAG) continues to serve as the main enhanced oil recovery process for the Kuparuk field. Thirty-three MWAG/IWAG drill sites service the Kuparuk reservoir which includes 242 available EOR patterns. These are the patterns that have received gas injection in 2009. 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 (CPF's). 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 2009, the MWAG project operated in full MI production mode for most of the 33 MWAG drillsites. Three mature MWAG drillsites (drillsites 2U, 2V and 2W) continued to conduct lean gas chase (LGC) tests. The purpose of this lean gas injection, in the format of immiscible water alternating gas or IWAG, is to collect data to evaluate post-MWAG options. The observations from these three drillsites indicated potential for increasing returning NGL sales. Drillsites 1A, 1Y and 2X were subsequently converted to lean gas chase mid -2009, followed by drillsites 1 G and 1 R later in the year, after seeing positive response from drillsites 2U, 2V and 2W. Drillsite 1D started MI injection in October of 2008 upon completion of an EOR expansion project. Very positive response of the MI injection has been observed in many patterns in drillsite 1D during 2009. The annual average of 1,440 STB/d incremental oil sales in 2009 exceeded expectations. During the year 2009, Kuparuk imported an average of 18,391 barrels per day of Prudhoe NGLs. Import NGLs and indigenous NGLs blended with available lean gas generated an average of 185 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 46 MMSCFD as injection and 11 MMSCFD as lift gas in Tarn and Meltwater. A small amount of MI (-3MMSCFD) is used as lift gas in drillsite 3S. West Sak 1J and 1E started VRWAG (viscosity reduction water alternating gas) testing and used a tiny amount (-0.3 MMSCFD) of MI. The estimated incremental oil sales in calendar year 2009 from the ongoing Kuparuk MWAG project was 35.2 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 2009 was continuing 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 2009 was 278 MMSCFD, down slightly from 294 MMSCFD during 2008. MWAG Small Scale EOR (SSEOR and SSEORX) Drill Sites 1A and 1Y continued MWAG during the first half of 2009 and were converted to LGC from July. Drillsite 2Z continued on MI injection. The 2009 average MI injection rate of the three drillsites was 14 MMSCFD. ConocoPhillips Kuparuk River Oil Pool 2009 Reservoir Surveillance Report Larne Scale EOR (LSEOR) The original LSEOR Drill Sites include: 1F, 1G, 1Q, 1R, 2A, 213, 2C, 2D, 2F, 2G, 2H, 2K, 2M, 2T, 2U, 2V, 2W, 2X and 3F. The total MI injection rate into these drill sites averaged 45 MMSCFD in 2009. EOR Expansions Expansions to the original LSEOR occurred over multiple phases and now include Drill Sites 113, 1C, 1D, 1 E, 1 L, 313, 3G, 3H, 30, 3Q and 3S. During 2009, the average MI injection rate into these expansion drill sites was 67 MMSCFD. IWAG During 2009 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 2U, 2V & 2W, and further expanded to drillsites 1A, 1Y and 2X in July to evaluate post-MWAG options. Drillsites 1G and 1R were also converted to lean gas injection later in the year to take the last opportunity to retrieve trapped NGL before the gas injection line is used for water injection. ConocoPhillips Kuparuk River Oil Pool 2009 Reservoir Surveillance Report 2009 EOR Program Status 3R - 3Q -30 3M 0 SSEOR and SSEORX 3N LSEOR and LSEORX 31-- --- 3K 3H U — EORX1 Expansion in 2001 3A 3C EORX1 Expansion in 2002 - 4 Wells 3S 3g ?IGIH GKA Satellites 1998-2002 3G 3F IQ 2w EORX1 Expansion in 2003 2T 2u 1Y _ _ 1C WSak EOR Pilot 2003 2X 1A 16 1C 2V - 2z 1D EOR Expansion in 2008 2A 2C 1F 1E iD 2B 2D ""GKA Active EOR Patterns 2M 2H 2F iL WSAK 2L, 2N (Tam) 2P (Mw) ConocoPhillips • 242 KRU 2G 2E • 17 Tarn 2K • 6 Meltwater •4 West Sak d O m Kuparuk River Oil Pool 45000 35000 25000 15000 10000 0 C3 v v v l0 t0 L0 t0 CD (0 C0 (0 n r r n W W W W 0 0 0 d) 0 2 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 1 L I 1 1 L I 1 1 ` 1 I 1 1 1 1 1 1 1 1 1 L 1 1 C Q -1 O Q O C Q O Q CU O Q O w Q O ConocoPhillips 2009 Reservoir Surveillance Report 2004-2009 Kuparuk EOR + NGL Sales Production ®DS1A ■DS1B 0DS1C ❑DS10 ■DS1E ®DS1F ■DS1G 8DS1H ■DS1L ■DS10 ODS1R E7DS1Y ■DS2A ■DS2B ■DS2C 0DS2D 0DS2F 0DS2G 0 DS2H 0DS2K ❑ DS2M 8 DS2T ODS2U 0DS2V ■ DS2W 8 DS2X B DS2Z ODS3A E3 DS3B 0DS3C ■DS3F ODS3G ■DS3H 9DS3J ■ DS3K ■ DS30 0DS3Q ■DS3R MOM Kuparuk River Oil Pool 2009 Reservoir Surveillance Report ATTACHMENT Kuparuk River Oil Pool 2009 Annual Reservoir Surveillance Report Produced Fluid Volumes Produced Fluid Volumes (Reservoir Units) OIL GAS WATER CUM OIL CUM GAS CUM WATER MO YR MSTB MMSCF MSTB MSTB MMSCF MSTB 1 2009 3,381 7,178 14,231 2,114,189 1,560,569 3,062,918 2 2009 3,207 7,104 13,628 2,117,396 1,567,673 3,076,545 3 2009 3,513 7,931 15,021 2,120,909 1,575,604 3,091,566 4 2009 3,232 7,073 13,483 2,124,141 1,582,677 3,105,049 5 2009 3,235 6,848 14,016 2,127,376 1,589,525 3,119,065 6 2009 2,992 6,906 13,005 2,130,367 1,596,431 3,132,071 7 2009 3,051 6,644 12,960 2,133,419 1,603,076 3,145,030 8 2009 3,110 7,079 14,343 2,136,529 1,610,155 3,159,373 9 2009 3,031 7,031 13,887 2,139,560 1,617,186 -3;173;260 10 2009 3,080 7,365 14,309 2,142,640 1,624,551 3,187,569 11 2009 2,997 7,014 14,296 2,145,637 1,631,565 3,201,864 12 2009 3,189 7,820 15,594 2,148,826 1,639,385 3,217,458 2009 TOTAL 38,018 85,994 168,771 Cumulatives at Dec 31, 2008 2,110,808 1,553,391 3,048,687 Produced Fluid Volumes (Reservoir Units) ConocoPhillips OIL GAS WATER CUM OIL CUM GAS CUM WATER MO YR MRVB MRVB MRVB MRVB MRVB MRVB 1 2009 4,173 4,938 14,515 2,600,809 1,686,471 3,117,640 2 2009 3,958 4,947 13,900 2,604,766 1,691,418 3,131,540 3 2009 4,335 5,552 15,322 2,609,101 1,696,970 3,146,862 4 2009 3,988 4,909 13,752 2,613,089 1,701,878 3,160,614 5 2009 3,992 4,707 14,296 2,617,081 1,706,586 3,174,911 6 2009 3,692 4,863 13,266 2,620,773 1,711,449 3,188,176 7 2009 3,765 4,605 13,219 2,624,538 1,716,054 3,201,395 8 2009 3,838 4,966 14,630 2,628,376 1,721,020 3,216,025 9 2009 3,740 4,957 14,164 2,632,116 1,725,977 3,230,189 10 2009 3,801 5,233 14,595 2,635,917 1,731,210 3,244,784 11 2009 3,698 4,957 14,581 2,639,615 1,736,167 3,259,366 12 2009 3,936 5,591 15,905 2,643,550 1,741,758 3,275,271 2009 TOTAL 46,914 60,225 172,146 Cumulatives at Dec 31, 2008 2,596,636 1,681,532 3,103,125 ConocoPhillips Kuparuk River Oil Pool 2009 Reservoir Surveillance Report ATTACHMENT 3 Kuparuk River Oil Pool 2009 Annual Reservoir Surveillance Report Injected Fluid Volumes Injected Fluid Volumes (Reservoir Units) WATER GAS MI CUM WATER CUM GAS CUM MI MO YR MSTB MMSCF MMSCF MSTB MMSCF MMSCF 1 2009 17,701 682 4,411 5,286,390 1,107,309 1,021,721 2 2009 16,179 608 4,685 5,302,569 1,107,917 1,026,406 3 2009 17,486 775 5,176 5,320,055 1,108,692 1,031,582 4 2009 15,498 434 4,613 5,335,553 1,109,126 1,036,195 5 2009 15,870 1,554 3,033 5,351,422 1,110,680 1,039,228 6 2009 13,835 636 4,747 5,365,258 1,111,316 1,043,975 7 2009 15,787 1,731 3,148 5,381,045 1,113,047 1,047,123 8 2009 15,423 4,092 761 5,396,467 1,117,138 1,047,884 9 2009 14,790 1,735 3,670 5,411,258 1,118,873 1,051,554 10 2009 15,359 2,413 3,662 5,426,617 1,121,287 1,055,216 11 2009 15,851 1,547 3,672 5,442,468 1,122,834 1,058,889 12 2009 16,856 2,108 3,931 5,459,324 1,124,943 1,062,819 2009 TOTAL 190,635 18,316 45,510 Cumulatives at Dec 31, 2008 5,268,689 1,106,627 1,017,310 Injected Fluid Volumes (Reservoir Units) ConocoPhillips WATER GAS MI CUM WATER CUM GAS CUM MI MO YR MRVB MRVB MRVB MRVB MRVB MRVB 1 2009 18,055 607 3,339 5,379,894 972,870 767,216 2 2009 16,502 540 3,546 5,396,396 973,410 770,763 3 2009 17,836 689 3,918 5,414,232 974,099 774,681 4 2009 15,808 386 3,492 5,430,040 974,485 778,173 5 2009 16,187 1,382 2,296 5,446,227 975,866 780,469 6 2009 14,112 566 3,593 5,460,339 976,432 784,062 7 2009 16,103 1,539 2,383 5,476,442 977,970 786,446 8 2009 15,731 3,637 576 5,492,173 981,608 787,022 9 2009 15,086 1,542 2,778 5,507,259 983,150 789,800 10 2009 15,666 2,146 2,773 5,522,925 985,296 792,572 11 2009 16,168 1,376 2,780 5,539,093 986,672 795,352 12 2009 17,193 1,874 2,976 5,556,287 988,546 798,328 2009 TOTAL 194,448 16,283 34,451 Cumulatives at Dec 31, 2008 5,361,839 972,263 763,877 ConocoPhillips Kuparuk River Oil Pool ATTACHMENT 4 2009 Reservoir Surveillance Report Kuparuk River Oil Pool 2009 Annual Reservoir Surveillance Report Reservoir Pressure Surveys ConocoPhillips ConocoPhillips March 31, 2010 Mr. Dan Seamount, Commissioner Alaska Oil and Gas Conservation Commission 333 West 7h Ave. Suite 100 Anchorage, Alaska 99501-3539 Re: Kuparuk River Oil Pool — Proposed Pressure Survey Plan for 2010 Dear Commissioner Seamount, James T. Rodgers Manager, GKA Development Greater Kuparuk Area ConocoPhillips Alaska, Inc. ATO -1326 PO Box 100360 Anchorage AK 99510-0360 Phone(907)263-4027 Fax: (907)265-6133 In compliance with Rule 8, Conservation Order No. 432, ConocoPhillips Alaska, Inc., operator of the Kuparuk River Oil Pool, is hereby submitting the proposed pressure survey plan for 2010. There were 382 pressure surveys reported for the Kuparuk River Oil Pool to the AOGCC in 2009. In 2010, we expect to conduct approximately 150 pressure surveys, including initial surveys for new wells prior to initial sustained production. If you have any questions concerning this data, please contact Mark Kovar at 265-6097. Sincerely, James T. Rodgers Manager, GKA Development Greater Kuparuk Area ConocoPhillips Kuparuk River Oil Pool 2009 Reservoir Surveillance Report Form 10-412 Rev. 12/2008 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION RESERVOIR PRESSURE REPORT 1. Operator ConowPhilifilps Alaska Inc. 2. Morass: P. O. Box 100360. Anchor e, AK 99510-0360 3. Unit or Lease Name: K.daruk RNar Unit 4. Field and Pool: Ku ruk Rlw Oil Pool 5. Datum Reference: G SS 6. Oil Gal 7. Gas GaWty: 0.91 water= 1.0 0.71 8. Well Name and Number 9. API Number 50� NO DASHES 10. Type Sae Instructions 11. AOGCC Pool Code 12. Zona 13. perforated 14. Final Test Interva6 Data Top - Bottom TVOSS 15. Shut -In 16. Press, Time, Hour Sm. Type (see InelNdionsfor codes) 17. B.H. Temp. 18. Depth Tool TVDSS 19, Final Observed Pressure at Tool Depth 20. Datum WOES(Inpuq 21. Pressure Gradient, psi/ft. 22. Pressure at Datum(oa0 1A43 M9205150000 OIL 490100 AC 01/15=9 76 SBHP 159 6230 1727 6200 0.36 1716 1A-13 029207000000 MWAG 490100 AC 03/182009 17064 SBHP 149 16231 2692 6200 0,35 2681 1A-17 029221020000 OIL 490100 A 0122/2009 104 SBHP 158 6178 2287 6200 0.45 2297 IA -18 029221030000 OIL 1401M A 1 04!07/2009 1 87 SBHP 161 6292 3190 6200 0.43 3150 1A-19 029241110000 OIL 490100 AC 0122/2009 99 SBHP 153 5995 2310 6200 0.35 2382 14-22 029221270000 OIL 490100 A 0124/2009 105 SBHP-A 161 6232 2322 6200 0.35 2311 1A-22 029221270000 OIL 490100 C 01/24/2009 S9 SBHP 156 6056 1625 6200 0.35 1675 1A-23 029221310000 OIL 490100 A 09/172009 528 SBHP 157 6122 3181 6200 0.35 3208 14-25 029221160000 OIL 490100 AC 04/072009 B2 SBHP 158 16130 2376 6200 0.45 2407 14-27 029221240000 OIL 490100 AC 11/03.2009 87 SBHP 159 6092 2444 6200 0.35 2482 1A-28 029221260000 OIL 49D100 AC 04/0612009 1 76 SBHP 161 6099 2619 6200 0.43 2663 1M4 029205950000 PW 490100 A 11/1512009 2009 SBHP 140 6283 2403 6200 10.35 2374 18-04 029205950000 PW 490100 C 1166/2009 2009 SBHP 133 6213 2165 6200 0.36 2160 1B-05 029202370000 MWAG 490100 C 11/19/2009 2081 SBHP 135 6223 2337 6200 0.35 2329 1605 029202370000 MWAG 490100 C 1121/2000 2135 SBHP 143 6400 2327 6200 0.44 2239 1&05 029202370000 MWAG 490100 A 11222009 2145 SBHP 156 1653S 3247 6200 0.44 3100 1607 029206160000 MWAG 490100 C 11282009 2320 SBHP 141 6238 2674 6200 0.30 2662 1e-07 029205160000 MWAG 490100 A 112912009 1 2320 ISBHP 148 6342 3024 6200 0.43 12963 1617 029224610000 OIL 490100 C 04/07/2009 86 SBHP 161 6449 2112 6200 0.58 1968 IB -19 029224750000 OIL 490100 AC 0422!2009 9262 SBHP 160 6247 3044 6200 0.41 3025 1604 029205470000 OIL 490100 C 01121/2009 45 SBHP 162 6381 2417 6200 0.23 2375 1C -07A 029205690100 OIL 490100 C 061282009 2520 SSHP 147 6364 3105 6200 0.44 3034 1611 029227140000 OIL 490100 C 04/102009 166 SBHP 160 sW7 2915 6200 0.35 2832 1611 029227140000 OIL 490100 C 04/30/2009 638 SBHP 161 6500 3210 6200 0.40 3091 1611 029227140000 OIL 490100 C 10/102009 0 PBU 158 6110 2900 6200 0,35 2932 1611 02922714WDD OIL 490100 C 0]27/2009 2760 SBHP 148 6109 3336 6200 0.53 3384 71 Form 10-412 Rev. 12/2008 Kuparuk River Oil Pool 2009 Reservoir Surveillance Report Form 10.412 Rev. 12/2008 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION RESERVOIR PRESSURE REPORT 1. Operator. OonocoPhilli s Alaska Inc. 2. Address: P. O. Box 100360, Anchors i AK 99510-0350 3. Unll or Lease Name: Ku aruk River unit 4. Field and Pool: Kugshn,k River Oil Pool 5. Datum Reference: .6200' SS 6. Oil Gravity: Z Gas Gravity: 0.91 (water= 1.o 0.71 8. Well Name and Number: S. API Number NO DASHES 10. Type See Instructions 11. AOGOC Pad Code 12. Zone 13. Perforated 14. Find Test Intervals Date Top - Bottom TVDSS 15, Shut -In 16. Press. Time, Hours Surv. Type (see instructionsfor codes) 17. B.H. Temp. 18. Depth Tool 19. Final TVOSS Observed Pressure at Tool Depth 20. DaNm TVDSS (input) 21. Pressure Gradient, psi/ft. 22. Pressure at Datum (cal) 1G16 029229340000 OIL 490100 C 0824/2009 360 SBHP 158 6472 3083 6200 0.43 2966 1C-19 029231490000 OIL 490100 C 04/072009 78 SBHP 161 IU64 2732 6200 0.42 2622 1C.23 029229420000 OIL 490100 C 04/182009 5088 SBHP 155 6444 MIS Wee 0.40 3229 1024 1029221063ODDO OIL 1490100 C 11/022009 1 79 ISSHP 155 6267 2115 162M 0.26 2098 10-03 029204080000 OIL 490100 C 0122/2009 97 SBHP 159 6259 2724 6200 0.14 2716 1D -04A 029204160100 OIL 490100 C 04/072009 60 SBHP 147 5902 2748 6200 0.40 2865 1D-11 029229460000 MWAG 490100 C 09/062009 384 SBHP 144 6.410 2849 6200 0.43 2758 1D-14 029229500000 MWAG 49010D C 11/10/21109 3696 SBHP 143 6061 3251 6200 0.44 3312 1E414 029204780000 MWAG 490100 AC OIMG12009 1656 SBHP 140 5785 2518 62M 0.10 2560 IE -05 0292047WDDO OIL 490100 A 05/17/2009 20520 SBHP 149 6013 2734 6200 0.28 2787 1E-06 029204930000 OIL 490100 C 06242009 576 SBHP 157 6044 2539 6200 0.29 2585 1E-011 029204960000 PW 1490100 A 101072009 1 384 SBHP 142 6199 3746 6200 0.35 3746 1 E4y3 02920720DOW PW 490100 AC 0526/2009 18720 SBHP 151 5104 2542 6200 0.37 2578 1E-11 79207870000 MWAG 490100 C 06/01/2009 17640 SBHP 137 6070 2629 6200 0.32 2571 1E-11 029207870000 MWAG 490100 A 052612009 70000 PSU 146 6190 3075 6200 0.49 3080 IE -12 029207360000 OIL 490100 A 04/7/2009 72 SBHP 158 6231 2439 6200 0.40 2427 1E.12 029207360000 OIL 490100 A 111302009 144 SBHP 159 6153 2508 6200 0.44 2529 1E-05 02927690000 PW 490100 A 11272009 57 SBHP 128 6205 4894 6200 0.44 4892 1E-15 02927690000 PW 490100 AC 07/062009 1152 SBHP 137 5180 3677 6200 0.35 3684 1E-18 029209040000 OIL 490100 AC 0121/2009 53 SBHP 159 6345 2546 6200 0.36 2494 1E-33 029227970000 OIL 490100 C 725/2009 624 SBHP 156 6088 2713 6200 0.30 2747 IF -01A 029208890100 OIL 490100 AC 02/06/2009 2016 SBHP 153 5800 2375 6200 0.06 2399 1F-14 029210220000 OIL 4901DO AC 04/112009 46 SBHP 159 6160 2126 6200 0.18 2133 1F-17 029226570000 OIL 490100 AC 012012009 75 SBHP 161 6090 2601 6200 Opt 2647 113-01 029208050000 MWAG 490100 AC 0412512009 853 SBHP 148 6379 2667 6200 0.35 2604 IC -04 029208350WO MWAG 490100 AC 04232009 816 SBHP 138 6610 3250 6200 0.35 3106 Form 10.412 Rev. 12/2008 Kuparuk River Oil Pool 2009 Reservoir Surveillance Report Form 10-412 Rev. 12/2008 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION RESERVOIR PRESSURE REPORT 1. Operator. C0nocoPhilli s Alaska Inc 2. AOdress: P.O. Boz 100360 Arclto e. AK 99510-0360 3. Unit or Lease Name: Kupanuk Rimr Unit 8. Well Name and 9. API Number Number. 50%%%XxxxxxK)0( NO DASHES 10, Type See Instructions 11. AOGCC Pool Code 12. Zone 13. Perforated 14. Final Test Inerts Date Top -Bottom TVOSS 4. Field and Pcal: Kuparuk River 01 Pool 15. Shut -In 16. Press. 17. B.H. Time, Hours Surv. Type Temp. (see Instructionsfor codes) S. Datum Reference: -62W SS 18. Depth Tool 19. Final TVOSS Observed Pressure at Tool Depth 6. Oil Gravity: 7. Gas Gravity: 0.91 water=1.0 0.71 20. Datum 21. Pressure TVDSS (input) Gradient, psi/8, 22. Pressure at Datum (cal) 1G46 029208900000 MWAG 490100 AC 04232009 816 SBHP 122 6132 2937 6200 0.35 2961 1G-09 029210010000 MWAG 490100 AC 0621/2009 2232 SBHP 137 16499 2886 6200 0.43 2757 16.11 029210080000 OIL 490100 AC W7 2009 289 SBHP 164 6595 2316 6200 0.36 2174 1Cs12 029210090000 OIL 490100 AC 10/122009 1320 SBHP 164 6513 2380 6200 0.35 2270 iG-16 029210310000 MWAG 490100 AC 04262009 858 SBHP 140 6501 2642 6200 0.35 2537 11401 029223300000 OIL 490100 A 0674/2009 482 SBHP 161 6469 2808 6200 0.35 2714 1X-01 029223300000 OIL 490100 C 06115/20D9 381 SBHP 157 6327 2500 6200 0.42 2447 iH-04 029207700000 PW 490100 AC 06232009 883 SBHP 140 6522 3597 6200 0.43 3458 11+10 029223460000 OIL 490100 AC 12102/2009 15882 SBHP 154 6310 2570 6200 0.05 2565 lH43 029223560000 OIL 490100 C 04/07/2009 8p SBHP 161 6579 2688 6200 0.21 2608 1J-03 029230020000 OIL 490100 C 01282009 264 SBHP 152 6301 2991 6200 0.35 2956 13-10 029230100000 OIL 490100 C 04/072009 71 SBHP 151 5885 2397 6200 0.42 2530 11415 02921150000 MWAG 490100 C 122312009 168 SBHP 131 5780 3100 62W 0.28 3216 TL -08 029211750000 OIL 490100 A 10125/2009 240 SBHP 158 5880 2785 6200 0.33 2891 1L-08 029211750000 OIL 490100 C 10242009 240 SBHP 151 5814 12487 IU00 0.33 2615 IL-12 029220330000 OIL 49D10D AC 04/072009 75 SBHP 155 5817 2623 6200 0.25 2720 1L-15 029212040000 OIL 490100 A 11/06/2009 648 SBHP 158 5882 2485 6200 0.37 2603 IL-15 029212040000 OIL 490100 C 10/252003 360 SBHP 153 5820 3187 6200 0.37 3328 11--18 029221450000 MWAG 490100 C 10/192009 336 SBHP 150 59n 3449 6200 0.43 3545 1L-19 029220090000 OIL 49010D AC 11/022009 20 SBHP 155 5920 2083 6200 0.38 21W 1L-22 029221140000 MWAG 490100 AC 03iOB1P069 1776 SBHP 129 5901 2676 6200 0.44 2808 i1-24 029221700000 OIL 490100 AC 04/072003 65 SBHP 151 5836 2362 6200 0.10 2399 10.01 029212470000 MWAG 490100 A 06212009 34080 SBHP 150 6364 3964 6200 0.35 3907 10-01 029212470000 MWAG 490100 C 06212009 34080 SBHP-C 148 6279 3951 6200 0.28 3929 10-02B 10-03 029212480200 029212490000 MWAG OIL 490100 490100 A C 10/13200922295 101112009 SBHP 99 SBHP 151 161 6329 6443 2131 1963 6200 6200 0.31 0.37 2091 1873 Form 10-412 Rev. 12/2008 Kuparuk River Oil Pool 2009 Reservoir Surveillance Report Form 10-412 Rev. 1212008 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION RESERVOIR PRESSURE REPORT 1. Operator. conowPhillips Alaska Inc. 2. Address: P. O. Bon 100360. Anchored, AK 99510-0360 3. UNt or Lease Name: K amk River Unit 4. Field and Pool: Ku wk River Oil Pool 5. Daum Reference: .6200 SS 6. Oil Gr4Mty: 7. Gas Gr4Wly: 0.91 water= 1.0 0.71 8. Well Name and Number. 9. API Number 50� NO DASHES 10. Type Sae Instructions 11. AOGCC Pool Code 12. Zone 13, Pedoreted 14. Final Test Intervals Date Top -Bottom TVDSS 15. Shut -In 16. Press. Time, HoursSum. Type (see instructions for Codes) 17. B.H. Temp. 18. Depth Tool 19. Final TVOSS Observed Pressure at Tool Depth 20. Dam u TVDSS (input) 21. Pressure Gresham, Palm. 22. Pressure at Datum (cal) 10-03 029212490000 OIL 490100 A 10/17/2009 240 SBHP 163 6543 2517 6200 0.35 2397 1047 029212340000 IWAG 490100 A 08/192009 11472 SBHP 141 161M 3217 6200 0.43 3246 10.07A 029212340100 MWAG 490100 A 08/192009 11472 SBHP 141 6128 3217 6200 0.43 3248 10-08 1029212250000 IWAG 490100 A 1 05/142009 99999 SBHP 144 6353 2945 62W 0.35 128M 10-OBA 029212250100 MWAG 490100 AC 05H4/2009 18548 SBHP 144 6176 2945 6200 0.35 2953 10-09 029212090000 MWAG 490100 C 06/01/2009 17208 SBHP 143 5953 2336 6200 0.35 2422 10-09 029212090000 MWAG 490100 A 06/012009 1 383 IPBLI 142 6052 2232 6200 0.35 2284 10-11 029212160000 MWAG 490100 AC 05/162009 18672 SBHP 137 5977 2374 6200 0.35 2452 10-12 029212100000 MWAG 490100 AC 05272009 18960 SBHP 140 6138 2637 6200 0.45 2665 10.13 029213050000 MWAG 490100 C 071=2009 19344 SSHP 137 5933 2865 6200 0.31 2948 10-13 029213060000 MWAG 490100 A 06/132009 19368 SBHP 133 6010 2824 6200 0.35 2891 10-15 029213030000 OIL 490100 A 11232003 124 SBHP 153 6200 1765 6200 0.37 1766 10-15 029213080000 OIL 490100 A 0522/2009 19800 SBHP 153 6265 3587 62000.35 3564 10-15 029213080000 OIL 490100 A 082512009 35 SBHP 147 6200 3688 62M 0,47 3688 10-22 029225950000 OIL 490100 AC 10/19/2009 1097 ISSHIP 160 6503 2356 6200 0.39 2238 10-24 029225840000 MWAG 490100 A 10/142009 11472 SBHP 143 6093 1936 6200 0.37 1976 10-26 029225900000 OIL 490100 AC 04/06/2003 72 SBHP 150 161M 1617 6200 0.35 1630 1R42 029214050000 OIL 490100 A 09/112009 216 SBHP 160 6491 11870 6200 0.35 1768 1R-02 029214050000 OIL 490100 C 09/1012009 216 SBHP 154 6329 2228 62M 0.35 2183 1R-02 029214050000 OIL 490100 A 05127/2009 264 SBHP 156 6537 1715 6200 0.28 1621 1R -03A 029214060100 MWAG 490100 AC 0423%2009 792 SBHP 129 6532 2750 6200 0.39 2620 1R-07 029213320000 OIL 490100 A 031072009 17 SBHP 160 6572 1983 6200 0.35 1853 1R-07 029213320000 OIL 490100 A 03/1312009 192 SBHP 158 6572 2166 6200 0.35 2036 1R-08 029213330000 MWAG 490100 AC 09/122009 5088 SBHP 124 6490 3115 6200 OAd 2987 1R-10 029213510000 MWAG 490100 A 04202009 720 SBHP 128 6415 3877 6200 0.35 3802 1R-12 029213530000 OIL 1490100 IAC 01202009 72 SBHP 140 5750 1771 6200 007 1803 Form 10-412 Rev. 1212008 Kuparuk River Oil Pool 2009 Reservoir Surveillance Report Form 10412 Rev. 12/2008 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION RESERVOIR PRESSURE REPORT 1. Operator. ConocoPhilli s Alaska Inc. 2. Address: P. 0. Boz 1D0360. Ancfto e, AK 99510-0360 3. Unit or Lease Name: Ku ruk River Unit 4. Field and Pod: Ku aruk River Oil Pool 5. Datum Reference: -6206 SS 6. Oil Gravity: 7. Gas Gravity: 0.91 imter a 1.0 0.71 8. Wall Name and Number. 9. API Number 50� NO DASHES 10, Type Sae Instructions 11. AOGCC Pool Code 12. Zone 13. Perforated 14. Final Test IntBrvaB Data Top - Bottom TVDSS 15. Shut -In 16. Press. 17. B.H. Time, Hours Suv. Type Temp. (see Indnrpionsfor =des) 18. Depth Tool 19. Final TVDSS Observed Pressure at Tod Depth 20. DatMn 11%S(inpul) 21. Pressure Gradient psi/0. 22. Pressure al Datum(cal) 1R-05 029213870000 MWAG 490100 A 0420/2009 720 SBHP 123 6458 3290 6200 0.45 3174 1R-17 029222120000 MWAG 490100 A WM42009 9350 SBHP 134 6535 3180 6200 0.35 3063 1R -19A 029221950100 MWAG 490100 A 04232009 792 SBHP 129 6641 3506 6200 0.45 3307 1RASA 029221850100 MWAG 1490100 A 05/27MMS 1608 SBHP 133 6641 3415 6200 0.42 3230 1R-23 029222000000 MWAG 490100 C 0&152009 15072 SBHP 147 6686 2833 6200 0.37 2653 1R-25 029221530000 OIL 490100 AC 0&0512009 7104 SWHP NA 6200 2351 6200 0.36 2351 1R-32 029225230000 MWAG 490100 A 0425/2009 840 SBHP 137 6677 3607 6200 0.43 3402 1Y-02 029209410000 MWAG 490100 AC 08/2612009 104 SBHP 147 6205 2758 6200 0.44 2756 1Y-05 029209660000 MWAG 490100 AC 082712009 120 SBHP 140 5937 2439 6200 0.45 2530 1Y-07 029209500000 MWAG 490100 AC 082812009 153 SBHP 141 5911 2641 6200 0.35 2742 1Y-12 009209130000 MWAG 490100 AC 1 082512009 72 SBHP 140 5911 2838 6200 0.43 2962 1Y-04 029209100000 MWAG 1490100 AC 1 08126/2009 33672 SBHP 146 5878 2667 6200 0.26 2741 1Y-16 029209270000 MWAG 490100 AC 08272009 124 SBHP 139 6000 2529 6200 0.35 2599 1Y-21 029223870000 OIL 490100 A 04/1612009 1 333 SBHP-A 165 6143 2247 6200 035 2267 tY-21 029223870000 OIL 490100 C 04/16/2009 331 SSHPC 154 6317 2477 6200 0.31 2534 1Y-30 029218510000 OIL 490100 A 1023/2003 138 SBHP 151 6053 2119 6200 0.35 2170 2A4)2 103200240000 MWAG 490100 AC 02262009 336 SBHP 134 5829 3455 6200 0.35 3585 2A-05 103200300000 OIL 490100 AC 08103/2009 120 PBU 151 5709 2442 6200 0.35 W14 2A-10 103200560000 OIL 490100 AC 10/26/2009 220 SBHP 157 5869 2534 6200 0.35 2650 2A-11 103200570000 OIL 490100 AC 07212003 92 SBHP 147 5355 2389 6200 0.35 2685 2A-11 103200570000 OIL 490100 AC 072012009 92 SBHP 147 5355 2387 6200 0.34 2674 2A-12 103200580000 IOIL l4ohlOn AC 102312009 % SBHP 158 5814 2492 6200 0.35 2627 2A-13 103200390000 OIL 490100 AC 07/202009 1012 SBHP 151 5493 2613 6200 0.38 2882 ZA-14 1032DD400000 OIL 490100 AC 08/272009 2466 SBHP 160 5868 2934 620) 0.43 3077 2A-15 2A-18 103200410000 103202200000 OIL OIL 490100 490100 AC A 0722/2009 06252009 1177 SBHP 120 SBHP 143 154 15780 5358 2721 2672 6200 6200 0.34 0.35 3007 2819 Form 10412 Rev. 12/2008 Kuparuk River Oil Pool 2009 Reservoir Surveillance Report Folin 10-412 Rev. 12/2008 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION RESERVOIR PRESSURE REPORT 1. operator. ConocoPhilli s Alaska Inc. 2. AOdress: P.O. Box 100360, Ancho,sme, AK 99510-0360 3. Unit or Lease Name: K amk River Unit 4. Field and Pool: K ruk Riw Oil Pool S. Datum Reference: -MISS S. Oil Grapy: 0.91 wator= 1.0 7. Gas Gran ty: 0.71 S. Well Name and Number. 9. API Number NO DASHES 10. Type See Instructors 11. AOGCC Pool Cade 12. Zone 13. Perforated 14. Final Test Intervals Date Top -Bottom TVDSS 15, Shut -In 16. Press. 17. B.H. Time. Hours Surv. TYPe Temp. (see Instmgionsfor Codes) 18. Depth Tool 19. Final TVDSS Observetl Presat T001%pth 20. Datum TVDSS tinPup 21. Pressure Gradient, psi/ft. 22. Pressure at Datum (MI) 2A-22 103202210000 OIL 490100 AC 0828/2003 1 7171 SBHP 151 5649 2676 6200 0.41 2902 2A-25 103202390000 OIL 490100 AC 12/132009 1 984 SBHP 151 1573 2963 6200 0.35 3113 2A-26 103205750000 OIL 490100 A 02/162009 1 10000 SBHP 160 5962 3941 6200 0.35 4024 28.01 029211470000 OIL 1490100 AC 1 07/01/2009 1 216 SBHP 158 5893 2087 6200 0.35 2194 213-02 029211540000 OIL 490100 AC 09106/2009 108 SBHP 158 5926 2744 6200 0.35 2840 28-08 029210790000 MWAG 490100 A 12/152003 240 SBHP 127 5676 3801 6200 0.35 3984 2&09 029210820000 MWAG 490100 C 1=02009 140 SBHP 127 5765 2653 6200 0.34 2811 2809 029210820000 MWAG 490100 A 1220/2009 140 PBU 167 5831 4760 6200 0.35 4889 MAD 029210840000 MWAG 490100 A 1729/2009 90 SBHP 120 5844 4402 6200 0.35 4526 29-14 029211430000 OIL 490100 AC 07/072009 360 SBHP 159 5827 12702 6200 0.36 2836 2&16 029211460000 OIL 490100 A 08232009 4140 SBHP 155 5849 3351 6200 0.35 3474 2C-02 029209720000 MWAG 490100 AC 11/1012009 4320 SBHP 117 5780 3258 Ism 0.35 3405 2C45 029209780000 MWAG 490100 A W17/2009 1 4344 SBHP 119 5821 2888 6200 0.35 3021 2= 029209790000 MWAG 490100 AC 4424 SBHP 130 5907 3497 6200 0.44 3626 2C-07 029209750000 IWAG 490100 A 4464 SBHP 117 5832 3563 6200 0.47 3837 2C-08 029209740000 MWAG 490100 AC E03,r03,2.g 4434 SBHP 116 5854 3485 6200 0.45 3641 2C-16 029212180000 OIL 490100 AC 130 SBHP 152 5569 2347 6200 0.35 2568 2002 029211770000 MWAG 490100 A 768 SBHP 130 5867 3824 6200 0.45 3972 20-05 029211570000 MWAG 490100 A 90 SBHP 124 5980 5238 6200 0.35 5315 213-05 029211570000 MWAG 490100 AC 0521/2009 984 SBHP NA 5882 2917 6200 0.35 3028 20-068 029211680200 OIL 490100 A 112212009 88 SBHP 156 5848 2047 6200 0.30 2153 20.07 029211690000 MWAG 490100 AC 11/1612009 1147 SBHP 114 5849 3688 6200 0.35 3811 20-10 029211350000 MWAG 490100 A 11/172009 2811 SBHP 121 5893 3769 6200 0.45 3907 20-11 029211340000 MWAG 490100 A 11/172009 4368 SBHP 121 5902 3649 6200 0.45 3783 20-14 029211830000 IWAG 490100 AC WV2009 4176 SBHP 139 5846 3605 6200 0.33 3722 2E-12 029212270000 PW 490100 A 0421/2009 23875 SBHP 130 5920 3025 6200 0.38 3131 Folin 10-412 Rev. 12/2008 Kuparuk River Oil Pool 2009 Reservoir Surveillance Report Form 10-412 Rev. 12/2008 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION RESERVOIR PRESSURE REPORT 1. Operator. con0coPhillips Alaska Inc. 2. Address: P. O. Be. 100360, Anchera . AK W5104360 3. UNI orLease Name: Ku nM River Unit 8. Well Name and 9. API Number Number. 50XRXXRXX)(XXXX NO DASHES 10. Type Sea Instructions 11, AOGCC Pool Code 12. Zone 13. Perforated 14. Final Test Intervas Date Top - Bottom NDSB 4. Re)d and Pod: Ku aruk River Oil Pool 15. Shut -In Morass. 17. B.H. Time, Hours S.V. Type Temp. (see Inslrud er,for codes) 5. Datum Reference: -6200 SS 18. DepthTool 19. Final TVDSS Observed Pressure at Teel Depth 6. Oil Gravity: Z Gas Gravity: 0.91 water =1A 0.71 20. Datum 21. Pressure TVDSS (input) Gradient, psi/e. 22. Pressure al Datum (rat) 2E-13 029212130000 PW 490100 AC 04/21/2009 23880 SBHP 138 5986 3387 6200 0.40 3473 2E-14 029212140000 PW 490100 A 04/23pOD9 23904 SSHP 135 5930 3458 6200 0.34 3560 2F-06 029210750000 OIL 490100 A 08/07/2009 53 SBHP 159 5640 3089 6200 0.43 3330 2F-09 029210300000 OIL 490100 A 0628/2009 170 SBHP 160 5875 3154 6200 0.41 3287 2F-10 029210940000 OIL 490100 A D8108/20W 75 SBHP 160 5921 3212 6200 0.42 3371 2F-11 029210950000 OIL 490100 AC 08/082009 % SBHP 120 4141 1622 6200 0.05 1715 2F-19 029227280000 OIL 490100 AC 08282009 17980 SBHP 150 5787 3631 6200 0.47 3825 2F-20 029227390000 OIL 490100 A 082912009 99576 SBHP 165 6146 3362 6200 0.32 3379 2&06 029211210000 OIL 490100 A 07/02/2009 288 SBHP 152 5725 3909 6200 0.48 4137 22:10 029211400000 MWAG 490100 A Wiliam 1385 SBHP 103 6001 4964 6200 0.35 5034 MAI 029211600000 OIL 490100 A 09/11/2009 34350 SBHP 156 5965 4596 6200 0.42 4695 2G-14 029211610000 MWAG 490100 A 1120/2009 138 SBHP 123 5940 5018 6200 0.45 5135 2G15 029211620000 OIL 490100 A 031%/2009 171 SBHP 161 5995 3925 6200 0.40 4007 2H-04 103200270000 MWAG 490100 A 02/122009 144 SBHP 114 5973 4558 6200 0.39 4647 2H-05 103200430000 OIL 490100 A 1229/2009 144 SBHP 157 5985 2602 6200 0.36 2684 21-1-12 103200530000 OIL 490100 AC 07/17/2003 600 SBHP 158 5951 3001 6200 0.39 30% 21<4)8 103201110000 OIL 490100 AC 05/182009 27000 SBHP 161 6047 4372 6200 0.35 4425 2K-22 103201190000 OIL 40100 q 0122/2009 24312 SBHP 159 4882 3729 6200 0.35 4190 2K-22 103201190000 OIL 490100 A D4/182009 24696 SBHP 164 6184 3800 6200 0.35 3806 2K-27 103203880000 OIL 4901DD A 11/04=9 880 SBHP 123 4742 3092 6200 0.35 3602 2M-08 103201840000 OIL 40100 A 0712312009 168 SBHP 159 5971 3149 6200 0.35 3229 21441 103201590000 OIL 490100 AC 0628/2000 140 SBHP 152 5839 3226 6200 0.35 3352 2T42 103200720000 MWAG 490100 A 0&1412009 % SBHP 114 5708 4324 6200 0.32 4481 ZT-05 103200750000 MWAG 490100 A 05/19/2009 2 SBHP 117 5653 4703 6200 0.35 4895 2T41 103200650000 MWAG 490100 AC 0424/2009 1 144 SBHP 132 5756 3027 6200 1044 3222 2T -12A 1032006601011 OIL 490100 A 0927/2009 1 15304 SBHP 160 5]74 3550 6200 0.35 3699 Form 10-412 Rev. 12/2008 Kuparuk River Oil Pool 2009 Reservoir Surveillance Report t-orm 10-412 REV. 1212008 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION RESERVOIR PRESSURE REPORT 1. Operator.2. Address: conoeoPhillips Alaska Inc. P.O. Bax 100380. AnFro e. AK 99510.0360 3. Udt or Lease mne: Ku aruk River. Unit 8. Well Name and 9. API Number Number: 50XI0KX)D000W(X NO DASHES 10. Type See Insvuctlons 11. AOGCC Pod Coda 12. Zone 13. Perforated 14. Rnal Test Intervals Date Top - Bottom TVDSS 4. Field and Pool: Ku wk River Oil Pool 15. Shut -In 16. Press. 17. B.H. Time, Hours Sur' Type Temp. (see instrudlonsfor 5. Datum Reference: .6200 SS 18. DepthTool 19. Firm TVDSS Observed Pressure at Tod Depth B. 011 Gnanty. 7. Gas GraNty', 0.91 water= 1.0 0.71 20. Datum 21. Pressure MOSS (input) Gradient, psittt. 22. Pressure at Datum (cal) wiles) 2T-124 103200650100 OIL 490100 C 09202009 15304 PBU 109 4136 2502 6200 0.35 3224 2r-19 103202140000 OIL 490100 AC 111142009 3000 SBHP 3252 6200 0.35 3367 2T-19 103202140000 OIL 490100 AC 09/30.2009 1900 SBHP 3240 woo 0.35 3381 2T-21 103202120000 OIL 490100 A 09292009 44804 SBHP 3154 6200 0.43 3348 27-27 103202170000 OIL 490100 A 07=009 432 SBHP t1605733 2579 6200 0.35 27422T -27A 103202170100 OIL 490100 A 12/072009 40 SBHP 3086 6200 0.60 3443 ZT29 103202220000 MWAG 490100 A 0&2812009 4531 SWHP 1825 6200 0.35 4038 27-29 103202220000 MWAG 490100 A 09/092009 4075 SBHP 139 5722 3928 6200 0.35 4095 2T-29 103202220000 MWAG 490100 A 022721109 144 SBHP 126 5708 47W 6200 0.35 4908 2T-29 103202220000 MWAG 490100 A 09130/2009 5300 SBHP 142 5722 3822 6200 0.35 3989 27-29 103202220000 MWAG 490100 A 07/082003 3288 SBHP 137 5722 4005 6200 0.35 4172 Tr -32 103202180000 MWAG 490100 A 05202009 192 1SBHP 146 5701 3659 6200 0.45 3883 2r36 103202280000 MWAG 490100 AC 122&2009 13860 SBHP 141 5745 2868 6200 0.39 3045 2T-37 103202270000 OIL 490100 A 101162009 19900 SBHP 155 5690 3149 6200 0.35 3327 2T38A 103202290100 OIL 1490100 AC 10202009 12600 SBHP 152 5699 2826 6200 0.35 3001 2739 103203920000 OIL 490100 AC 0212012009 300 SBHP 156 5787 2093 6200 0.35 2237 2T40 103205280000 OIL 490100 A 10/152009 144 SBHP 154 5722 1657 6200 0.35 1830 21.1-07A 029212830100 MWAG 490100 A 12/0312009 19694 SBHP 121 5869 3627 6200 0.45 3776 2V-0850 029211280000 MWAG 490100 A 05242009 27480 SBHP 118 5858 3606 6200 0.44 3756 2V.69 029213000000 OIL 490100 AC 06242009 122 SBHP 158 5837 2093 6200 0.35 2730 2V-10 029213100000 OIL 490100 AC 06242009 78 SBHP 161 5848 2606 6200 0.35 2769 2V-13 029212930000 OIL 490100 AC 06252009 76 SBHP 157 5740 2724 6200 0.35 2885 2V-15 029212950000 OIL 490100 AC 052512009 78 SBHP 157 5820 2612 6200 0.35 2745 2W-01 029212730000 OIL 490100 A 07/092009 432 SBHP 153 5913 20`50 woo 0.21 2110 209-05 029212080000 MWAG 490100 AC 02272009 Sul SBHP 141 5870 3150 6200 0.35 3266 2W-11 029212380090 OIL 490100 AC 0512&2009 192 SBHP 140 5668 2474 6200 0.35 2660 t-orm 10-412 REV. 1212008 Kuparuk River Oil Pool 2009 Reservoir Surveillance Report Form 10-412 Rev. 12/2008 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION RESERVOIR PRESSURE REPORT 1. Operator. 2. Address: ConacoPNlli s Alaska Inc. P. O. Boz 100360, Ancha , AK 99510.0360 3. Unit or Lease Name: Unit S. and 9. API Number SOXX%Xl(XXXXXX% NO DASHES 10. Type Sea InsWctlons 11. AOGCC Pool Code 12. Zone 13. penetrated 14. Final Test Intervals Date Top -Bottom TVDSS 4. Field and Pod: Ku k River Oil Pool 15. Shut -In 16. Press. 17. B.H. Tins Hours Sum. Type Temp. (see instnn:lionsfor 5. Datum Reference: -0200 SS 18. Depen Tool 19. Flnal NDSS Obserred Fred, we at Tool Depth 6. Oil Gravity: 7. Gas Gravity: 0.91 water=l.0 071 20. Datum 21. Pressure TVDSS (input) Grediont. Psittl. 22. pressure al Datum (cal) codes) F2W.17 029212550000 MWAG 490100 AC 08/15/2009 111]4 SBHP 125 5928 3093 6200 0.35 3188 029233700000 OIL 490100 A 05/05/2009 480 SBHP 153 5868 2714 6200 0.35 2830 029209820000 MWAG 490100 AC 0822/2009 6600 SBHP 133 5871 2872 6200 0.35 2987 2X-04 029209950000 MWAG 1490100 A 1SBHP 113 5882 4798 6200 0.46 4944 2X-05 W9209850000 MWAG 490100 AC 04/1012009 1 672 SBHP 120 5848 3250 6200 0.45 3409 2X-06 029209880000 MWAG 490100 AC 1223/2000 16890 SBHP 126 W93 2613 6200 0.44 2836 2X-07 029209910000 MWAG 490100 AC 04/10/2009 678 SBHP 114 5904 2756 6200 0.45 2889 2X-08 029209920000 MWAG 490100 AC 04/11/2009 1512 SBHP it0 5852 3146 6200 0.38 3278 2X-08 029209920000 MWAG 490100 AC 02/212003 330 SBHP 100 5852 3455 6200 0.35 3577 2X-16 029211950000 OIL 490100 AC 07/042009 336 SBHP 152 5594 2259 6200 0.06 2295 2X-19 029226160000 OIL 490100 C 064Y2/2009 14135 SBHP 145 5629 2671 6200 am 2871 2X -19A 029226180100 OIL 490100 C 06/032003 10000 SBHP 146 W29 2669 6200 0.44 2920 2Z-01 029209530000 OIL 490100 A 041292009 80 SBHP 143 5758 1761 6200 0.35 1916 22-03 029209640000 MWAG 490100 A 0/1118/2009 64200 SBHP 157 6006 3935 6200 0.35 4003 2Z45 029209560000 OIL 490100 AC 021=009 15000 SBHP 153 5954 2453 6200 0.35 2539 22-06 029209570000 MWAG 490100 AC 03/10/2009 15000 SBHP 124 5856 2911 6200 0.35 3032 22-07 029209460000 OIL 490100 AC 04292003 360 SBHP 154 5909 2299 6200 0.35 2401 2Z-08 029200280000 MWAG 490100 C 09/0812009 2376 SBHP 141 5-/10 2412 6200 0.35 2584 22-08 029209240000 MWAG 490100 A 09/092009 2376 SBHP 135 5951 3125 6200 0.35 3212 2Z-13 029213600000 OIL 490100 A 09/17/2009 6700 SBHP 153 5703 3104 6200 0.35 3278 2Z-19 029218820000 OIL 490100 AC 051022009 18200 SBHP 152 578D 2716 6200 0.35 2863 2Z-21 029218770000 OIL 490100 AC 10/172009 1600 SBHP 155 5999 2404 6200 0.35 2478 22-23 029225440000 MWAG 490100 AC OB27/2009 25790 SBHP 130 5821 2718 6200 0.44 2885 3A-02 029214310000 SW 490100 A 03242009 1054 SBHP 90 5936 4296 6200 0.44 4412 3A-02 029214310000 SW 490100 C 0322/2009 9999 SBHP 101 5828 2989 6200 0.38 3123 3A -03B 029214320200 OIL 490100 A 12/132009 68 SBHP 158 6101 2724 6200 0.42 2766 Form 10-412 Rev. 12/2008 Kuparuk River Oil Pool 2009 Reservoir Surveillance Report Form 10-412 Rev. 12/2008 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION RESERVOIR PRESSURE REPORT 1. Operator: ConbcoPhilll s Alaska Inc 2. Address: P.O. Box 100360. Anrhora e. AK 99510-0360 3. Unit or Lease Name: Kupaiuk River Unit 4. Field and Pcal : IlKuparuk River 011 Pool 5. Datum Rareronoe: -6200' SS 6. Oil Gravity: 7. Gas Gravity: 0.91 (water= 1.0 0.71 8. Well Name and 9. API Number 5� OASHFS 10. Type See Instructions 11. AOGOC Pod Code 12, Zone 13. PerforatbFinW IntervalsTime. Tap-Botto TVDSSinstructions 15. Shut -In 16. Press. 17. B.H. Hours Surv. TYPe Temp. (see for codes) 18. Depth Tool 19. Final TVOSSObsorved Pressure at Tool Depth 20. Datum TVOSS(mbut) 21Pressure22PressureatNumber. Gradient. PsiRf. Datum (capNO 3A-04 029214330000 SW 490100 A 1064 SBHP 80 5925 3391 6200 0.44 3512 3A-04 029214330000 SW 490100 C 1098 SBHP 106 5797 3078 6200 0.40 3239 3A-10 029214570000 SW 490100 A 807 SBHP 106 5995 4978 62W 0.38 5056 3A.11 029214680000 SW 14901CO C 1 09/16/2009 1 117 SBHP 98 15918 3178 6200 0.47 13311 3A-11 029214580000 SW 490100 A 1 0911]12009 134 SBHP 89 8192 3977 6200 0.45 3080 3A-14 029214900000 SW 490100 A 03104/2009 812 SBHP 103 6093 4265 6200 0.42 4310 3A-15 029214910000 SW 490100 C 09/1512009 377 SBHP 110 5965 3471 6200 0.43 3572 3A-15 029214910000 SW 490100 A 07/1212009 377 SBHP 88 6013 4448 6200 0.45 4532 3A-15 029214910000 SW 490100 C 01252003 6096 SBHP 124 5932 3581 6200 0.34 3672 3A-15 029214910000 SW 490100 A 01/192009 5945 SBHP 115 6087 4127 6200 0.46 4179 3803 029213220000 OIL 490100 C 11/072009 90 SBHP 152 5957 2256 6200 0.42 2358 3803 029213220070 OIL 490100 A 11103/2009 92 PBU 155 6043 2232 6200 0.42 2298 3814 02921287OWD OIL 490100 AC 09/10/2009 9905 SBHP 145 5684 2792 6200 0.35 293 3C-02 MW14140000 PW 490100 A ilNmm9 4080 SBHP 120 6149 391 6200 0.50 3897 3602 029214140000 PW 1490100 A 0&2812009 3936 SBHP 115 W% 3784 6200 0.46 3758 3C42 029214140000 PW 490100 A 04/08/2009 120 SBHP 105 6185 4569 6200 0.35 4574 3C-02 029214140000 PW 490100 C 04/072009 120 SBHP 108 6101 4289 6200 0.50 4339 3G02 029214140000 PW 490100 A 07/07/2009 1944 SBHP 112 6206 3954 6200 0.44 3951 3C-02 029214140007 PW 490100 A 051032009 528 SBHP 120 6095 4246 6200 0.35 4283 3C4)7 029213910000 PW 490100 A 08232009 144 SBHP 103 6359 5065 6200 0.41 5000 3607 029213910000 PW 490100 C 0822/2009 144 SBHP 117 6303 4356 340 3C-09 029213550000 PW 490100 A 0922/2009 120 SBHP 114 6403 5094 6200 3C-09 029213550000 PW 490100 C 08212079 120 SBHP 114 6319 3989 6200 3611 029213570000 OIL 490107 C 08/08/2009 42480 SBHP 157 6405 4017 6200 K0.43M' 3C.11 3C -14A 029213570070 029214250100 OIL 490100 490100 A C 08/062009 06/222009 72 SBHP 96 SBHP 155 154 6484 6189 1549 2258 6200 6200 Form 10-412 Rev. 12/2008 Kuparuk River Oil Pool 2009 Reservoir Surveillance Report Form 10-412 Rev. 12/2008 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION RESERVOIR PRESSURE REPORT 1. Operator: corrocoPhillips Alaska Inc. 2. Address: P. O. Bar 100360, Anclwr4 , AK 99510-0360 3. Unit or Lease Name: Ku River Unit 4. Field and Pod: Ku amk River Oil Pod 5. Datum Reference: 6200 SS 6, Oil Gravity: 7, Gas Gravity: 0.91 nvater= 1.0 0.71 8. Well Namand Waneer: 9. API Number 50%%%%KXWOO' X NO DASHES 10. Type Bee Insbuctlans 11. AOGCC Pool Code 12. Zona 13. Perforated 14. Find Test Intervals Date Top -Bottom TVDSS 15. Shut -In 16. Press. Time, Hours Sm. Type (see instructions for won) 17. B.H. Temp. 18. Depth Tool 19. Final NDSS Obsenred Pressure at Tod Depth 20. Datum TVDS$ (rpul) 21. Pressure Gradient. psb11. 22. Pressure al Datum (rat) 3C-148 029214250200 SW 490100 A 09/162009 168 SBHP 156 6389 3572 6200 0.38 3500 3CA40 029214250200 SW 490100 A 11/15/2009 240 SBHP 142 5677 2131 6200 0.35 2314 3015A 029214260100 OIL 490100 A 0727/2009 96 SBHP 157 6271 2680 5200 0.41 2651 30-16 102921427DOOD OIL 1490100 A 08I0220D9 1 72 ISBHP 153 6241 1475 16200 0.04 1473 3C-17 029233890000 OIL 49010D A 11/0912009 96 SBHP 158 6453 3630 6200 0.44 3519 3F42 029214470000 OIL 490100 C 11/152009 237 SBHP 152 57% 2484 6200 0.34 2622 3F-02 029214470000 OIL 490100 A 11/162009 253 PBU 156 5883 2540 6200 0.34 2648 3F-05 029214600000 OIL 490100 AC 01/0912009 166 SBHP 157 5994 2774 6200 0.42 2861 3F46 029214620000 OIL 490100 AC 01/0412009 80 SBHP 152 5919 2662 6200 0.36 2763 3F-0] 029214630000 MWAG 4%100 AC 0424/2009 95 SBHP 127 5998 3285 6200 0.44 3374 3F-08 029214640000 MWAG 490100 A 04124/2009 93 SBHP 119 5937 4255 6200 0.44 4371 3F-70 029214810000 OIL 490100 A 11/102009 119 SBHP 156 5908 1978 6200 0.36 2%3 3F-11 029214820000 MWAG 4%100 AC 042412009 91 SBHP 129 %61 29% 6200 0.44 3203 3F-14 029215000000 OIL 4%100 AC 01/0912009 172 SBHP 154 5%0 2%9 6200 0.35 3046 36-02 103201460000 OIL 4%100 A 01/232009 712 SBHP 153 5733 3248 6200 0.28 3379 3G-04 103201430000 OIL 490100 AC 01212003 481 SBHP 161 5733 2802 6200 0.33 2956 3G-05 103201320000 OIL 4%100 AC 042412009 94 SBHP 159 5840 2%1 fi200 O.d4 3118 3G% 103201300000 OIL 490100 A 11/14/2009 72 PBU 155 5704 2385 6200 0.35 3009 3G08 103201280000 OIL 490100 A 12212009 72 PBU 155 5701 2490 6200 0.35V4289 3G-09 103201290000 OIL 490100 A 09202009 134 PBU 156 5708 2691 6200 0.42 3G-09 103201290000 OIL 490100 C 09/1912009 230 SBHP 152 %85 3092 6200 0.42 36-71 103201330000 OIL 490100 AC 12/W2009 % SBHP 155 5745 2004 6200 0.32 3G-12 103201310000 MWAG 490100 AC 04242009 93 SBHP 128 5744 4578 6200 0.45 3G-13 103201370000 MWAG 4%100 AC 04242009 % SBHP 123 5802 4118 6200 0.43103201350ODD MWAG 490100 A 0925/2009 701 PBU 120 5738 3%5 6200 0.46 3G16 103201350000 MWAG 490100 C 09/25/2003 97 SBHP 128 5706 32% 6200 0.46 3483 Form 10-412 Rev. 12/2008 Kuparuk River Oil Pool 2009 Reservoir Surveillance Report Form 10-412 Rev. 1212008 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION RESERVOIR PRESSURE REPORT 1. operator. ConocoPhilifilps Alaska Inc. 2. Address: P. O. Box 100360, Anchaa AK 99510-0360 3. Unit w Lease Name: Ku aruk River Unit 8. Well Name ana 9. API Number Numaer. 50XXYXXXXXXXXX NO DASHES 10. Type See Instructions 11. AOGCC P001 Code 12. Zone 13. Performed 14. Final Test Intervals Date Top -Bottom TVOSS 4. Field am Pool: K aruk River Oil Pool 15. Shut4n 16. press. 17. B.H. Time, Hours Swv. Type Temp. (am Instructions for codes) 5. Datum RWwohw: .620V SS 18, Depth Tool 19. Final TVDSS ObMwd Pressure at Tool Depth 6. Oil Gravity: 7. Gas Gravity: 0.91 fwatar= 1.0 0.71 20. Datum 21. Pressure TVDSS (Input) Gradient, Psitlt. 22. Preswre at Dahm (w0 313-16 103201350000 MWAG 490100 AC 0424/2009 98 SBHP 125 5761 3991 6200 0.44 4184 3618 103201420000 OIL 490100 AC 11/10/2009 108 SBHP 159 5794 2603 5200 0.42 2773 3G -21A 103201480100 OIL 490100 A 10/15/2009 1310 SBHP 143 5274 3273 6200 0.11 3375 311.02 103200830000 MWAG 4MIX) AC 04/0412009 154 SBHP 90 5876 3201 62DD 0.33 3308 31.03 103200850000 OIL 490100 A 10104/2009 1 356 SBHP 154 5931 1984 6200 0. 4 2102 3X-06 103200780000 MWAG 490100 AC 0328/2003 1 5155 SBHP 94 5882 3448 6200 0.28 3537 3H49 103200860000 MWAG 490100 AC 032&2039 1 1141 SBHP 80 5949 3271 6200 0.47 3389 311-11 103200310606 OIL 49D1W AC 01/192009 70 SBHP 156 5995 3291 6200 0.43 3379 31+13A 103200890100 OIL 490100 AC 12/19/2009 83 SBHP 154 5894 2060 6200 0.43 2200 31+15 103200820000 MWAG 490100 AC 03130/2003 1176 SBHP 79 5904 3534 6200 0.44 3664 3H-17 103200810000 SW 1490100 A 04212009 1722 SBHP 99 6022 4503 6200 0.40 4574 3H-18 103200350000 MWAG 490100 AC 04212009 2397 SBHP 80 5894 3606 162M 0.41 3732 31+20 103200930000 OIL 490100 A 12/19/2009 88 SSHP 155 6022 2783 6200 0.41 2856 31-22 103200970000 SW 490100 A 03111/2003 973 SBHP 96 5998 4828 6200 0.44 4917 31144 103202350000 MWAG 490100 AC MIS= 177 SBHP 99 4826 3996 6200 0.26 4353 311-31 103202050000 MWAG 490100 AC 041052009 183 SBHP 101 5949 4459 6200 0.30 4534 31+33 103205780000 OIL 490100 A 0227/2009 99999 SBHP 156 IW73 4079 6200 0.50 4142 31-33 103205780000 OIL 490100 A 09242009 2413 SBHP 155 5807 4012 6200 0.41 4173 3H-33 1032057801100 OIL 490100 A 051182009 161 SBHP 146 5807 3288 6200 0.35 3426 3H33A 103205760100 OIL 490100 A 11103/2009 99999 SBHP 147 5930 3995 6200 0.62 4163 31-01 029215140000 OIL 490100 A 1211812009 83 SBHP 154 5981 2997 6200 0.333069 31-02 029215150000 SW 490100 A 031062009 622 SBHP 92 6285 3738 6200 0.42 3702 31-04 029215170000 OIL 490100 A 11/092009 88 SBHP 159 6212 3499 6200 0.37 3494 3146 0292193500 00 SW 490100 AC Oi312039 1222 SBHP 84 6180 4700 620 0 0.47 4719 31-07 029215490000 SW 490100 A 031312003 1228 SBHP 83 6191 4542 5200 0.45 4546 M-12 029215550000 SW 490100 A 041042009 1319 SBHP 97 5014 3809 6200 0.42 4307 Form 10-412 Rev. 1212008 Kuparuk River Oil Pool 2009 Reservoir Surveillance Report Form 10-412 Rev. 12/2008 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION RESERVOIR PRESSURE REPORT 1, operator. ConocoPhilli s Alaska Inc. 2. Aderess: P. O. Bax 100360, Anchorage, AK 995109360 3. Udt or Lease Name: Kup" River Unit 4. Field and Pool: Ku nk River Oil Pool 5. Datum Referenm: -6200' SS 6. Oil Gravity: 7. Gas Gnwty: 0.91 water=l.0 0.71 8. Well Nano and Number. 9. API Number 5� NO DASHES 10. Type See Instructions 11. AOGCC Pod Cada 12. Zane 13. Pert0noad 14. Final Test Intervals Date Top - Batton, TVDSS 15, Shu41n 16. Press. Time, Hours Sum Type (see instructionsfoi meas) 17. B.H. Temp. 18. Depth Tool 19. Mnal TVDSS Observed Pressumw Tad Depth 20. Datum TVDSS (Input) 21. Pressure Gredled. psiB. 22. Pressure at Datum (rel) 31-13 029219230000 SW 490100 A 10/05I2D09 W87 SBHP 105 6168 4378 6200 0.41 4391 31-13 029219230000 SW 490100 A 12/29/2009 5735 SBHP 124 6168 4.221 6200 0.43 4265 31-13 029219230000 SW 490100 A 04104/2003 2245 SBHP 103 6168 4535 6200 0.41 4548 31-13 029219230000 SW 490100 A 08107/2009 2273 SBHP 105 6168 4452 6200 0.45 4466 31-13 029219230000 SW 490100 A 11122/2009 4838 SOHP 122 6168 4308 6200 0.43 4322 31-17 029219220000 OIL 490100 A 11/09/2009 82 SBHP 158 6141 3037 6200 0.46 3121 3J-02 029213980000 PW 490100 A 04/11/2009 119 Pau 118 5956 4805 6200 0.45 4915 3J-02 029213980000 PW 490100 C 04/1012009 141 SBHP 119 5030 5128 6200 0.45 5205 3J-03 029213990000 OIL 490100 A 08112/2009 114 SBHP 156 6128 2524 6200 0.43 2555 W46 029214370000 OIL 490100 AC 01/15/2000 28 SBHP 155 6371 1951 6200 0.29 1901 3J-09 029214MOD00 PW 490100 A 03106/2009 9352 SBHP 126 62M 3782 6200 0.44 3745 3J-11 029214680000 OIL 490100 C 11/1112009 133 ISSHP 152 6166 2123 6200 0.43 2138 3.1 029214680000 OIL 490100 A 11/11/2009 136 PBU 155 6241 2137 6200 0.43 2520 3J-13 0292149MOOD PW 4901W AC 1229/2009 115 SBHP 118 6288 4565 6200 0.44 4526 3J-15 029214970000 OIL 490100 C 11/082009 475 SBHP 152 6236 2318 6200 0.45 2302 3K-02 02921W10000 PW 490100 A 0820/2009 72 SBHP 112 6518 4797 6200 1.45 4654 3K-07 02921620WO PW 490100 A 0&2312009 168 SBHP 115 6591 5059 6200 0.46 4879 3K48 029216210000 PW 490100 A 0425/2009 888 SBHP 120 6519 4898 620 0.48 4745 3K-08 029216210000 PW 490100 C 08118/2009 12840 SBHP 134 6465 3757 6200 0.45 3638 3K-08 029216210000 PW 490100 C 10/09/2009 336 SBHP 134 6411 4151 5200 0.46 4054 3K-08 029216210000 PW 490101 A 1320 SBHP 126 6597 4356 6200 0.46 4173 3K-08 029216210000 PW 49D100 A 2083 SWHP 132 6529 4575 6201 0.35 4460 3K-08 029216210000 PW 490100 A E11/22120M 3600 SBHP 132 6519 4436 6200 0.45 4293 3K -09A 029216560100 OIL 490100 A 888 SBHP 162 6]06 2065 6200 0.34 13K -09A 029216560100 OIL 490100 A 120 SBHP 164 6706 1515 6200 0.363K -09A 029216 5 00100 OIL 490100 A 192 SBHP 162 6706 1489 6200 0.33 1322 Form 10-412 Rev. 12/2008 Kuparuk River Oil Pool 2009 Reservoir Surveillance Report Form 10-412 Rev. 1212008 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION RESERVOIR PRESSURE REPORT 1. Operates CW=Philll s Alaska Inc 2. Address: P.O. S9K 100360. Anchora e, AK 99510-0360 3. Unit or lease Name: aruk River Unit 4. Field and Pool : Ku ruk River Oil Pool 5. Datum Reference: 6200' SS 6. Oil Gravity: 7. Gas Gravity: 0.91 water=1.0 0.71 B. Well Name and Number. 9. API Number W)U(%YJ(%K%X0(K NO DASHES 10. Type See Instructions 11, AOGCC Pool Code 12. Zone 13. Perforated 14. Final Test Intervals Dale Top - Bottom TVDSS 15. Shut -In i6. Press. 17. B.H. Time, Hours & Type Temp. (see Instluctionsfor codes) 18. Depth Tool 19. Final TVDSS Obsenretl Pressure at Tool Depth 20. Datum TVDSS (input) 21. Pressure Gradient. psi/8. 22. Pressure al Datum Iraq 3K-10 029216530000 OIL 490100 A 06121/2009 96 SBHP 162 6658 1349 6200 0.37 1179 3K-12 029216550000 OIL 490100 A 0427/2009 1776 SBHP 129 6700 5255 6200 0.40 5055 3K-12 029216550000 OIL 490100 A 10N92009 5735 SBHP 131 6700 4834 6200 0.48 4594 3K-12 029216550000 OIL 14901M A 06/142009 1 2927 ISWHP 131 16700 5295 162DO 0.43 $078 3K-15 029216320WO PW 490100 AC 03/272003 144 SBHP 114 6546 4933 6200 0.45 4T 3K-ifi 029216330000 OIL 490100 A 03292009 192 SBHP 160 6533 2651 6200 0.42 2511 3K-17 029216420000 OIL 490100 A 07/1612009 4400 SBHP 161 6,132 3260 6200 0.34 3181 3K-19 029230220000 PW 490100 AC 0820/2009 72 SBHP 117 6536 5384 6200 0.40 5250 3K -22A 029227590100 PW 490100 A 03272009 37.2 SWHP NA 6589 4912 6200 0.43 4743 3K-26 029227640000 PW 490100 A 08202009 72 SBHP 116 W67 4253 6200 0.41 4051 3K-27 029227510000 OIL 490100 A 11/112009 1032 SBHP 163 6627 4401 6200 0.44 4213 3K30 029227770000 PW 490100 A 0027/2000 37.2 SWHP NA 6636 5332 6200 0.43 5143 3K-31 029228820000 PW 490100 A 08242009 168 SBHP 121 6W4 4637 6200 0.46 4442 3K34 029220790000 PW 490100 A 03272W9 144 SBHP 125 6590 4371 6200 0.46 4191 3M-01 029216600000 SW 4901W A 03/0612009 BGS SBHP 86 6274 4359 6200 0.41 4329 3M-02 029216950000 SW 490100 A 03108/2000 665 SBHP 108 6255 4708 6200 0.38 4687 3M -03A 029216960100 OIL 490100 A 01/132009 99999 SBHP 153 6196 4305 6200 0.35 4307 3M-04 029216970000 OIL 490100 A 12/092009 83 SBHP 156 6228 3624 6200 0.35 3614 3MA0 029217150000 SW 490100 AC 031=2009 664 SBHP 114 6182 4634 6200 0.47 4642 3M-12 029217190000 SW 490100 AC 03129/2009 1 1161 SBHP 121 6039 3743 6200 0.43 3812 3M-17 029217290000 OIL 490100 A 12I092W9 90 SBHP 160 6241 4090 6200 0.35 4076 3M-19 029217370000 OIL 490100 A 12/112009 83 SBHP 158 6151 3169 6200 0.35 3186 3M-23 029224260000 OIL 490100 AC 11(10/2009 117 SBHP 157 6124 3513 6200 0.35 3540 3M-24 029224320000 OIL 490100 A 12/122009 110 SBHP 159 6090 3483 6200 0.35 3522 3M -25A 3M -25A 029224330100 029224330100 600 SW 400700 490100 A A 0423/2000 031302000 2012 SBHP 1433 SBHP 115 112 6069 6071 4360 4656 6200 6200 0.44 0.43 4417 4711 Form 10-412 Rev. 1212008 Kuparuk River Oil Pool 2009 Reservoir Surveillance Report Form 10-412 Rev. 12/2008 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION RESERVOIR PRESSURE REPORT 1. Damneder. Conclailabillips Alaska Inc. 2. Address: P. 0. Box 100360, Arrchmna o. AK 9951MMO 3. Unit or Looso Nam¢ Ku aruk River Unit 4. Fldtl and Pod: 11(uparalk River Oil Pod 5. Datum Reference: 5200' SS 6. Oil Gravity: 0.91 fwaII 1.01 7. Gas Grata y: 0.71 8. Wall Name and Nummn: b 9. API Number10. SOXXXUXXXXXM NO DASHES Typo Seo Instructions 11, AOGCC 12. Zeno Pool Cade 13. Parlorated 14, Final Test Intervals Date Tap - Bottom TVDSS 15. Shut -In Time, Hours 16. Press. Sm.. Type (sea Instructions for codes) 17, B.N. Temp. 18. Depth Tool 19. Final TVDSS Observed pressure at Tool Depth 20. Datura TVDSS(input) 21. Pressure Gradient, psl41. M. Pressure at Datum last) 3M-28 029224420WO OIL 490100 A 11109/2009 795 SBHP 155 6003 2671 6200 0.35 2746 3N -02A 029215270100 OIL 490103 C 102012009 9999 SBHP 155 6260 3860 6200 0.35 3839 3N.03 029215280000 SW 490100 A OSM2009 2760 SBHP 114 Im 4347 162M 0.45 4320 31447 102921539= OIL 1490100 A I 0527/2009 1 72 lS5HP 166 6339 2226 6200 10.27 2188 3W11 029215800000 SW 490100 A 09272000 37.2 SWHP 155 6355 5316 Woo 0.% 5280 3N-13 029215840000 SW 490100 A 09/2717.009 1d10 SWHP 155 6357 5163 6200 0.35 5104 3N -14A 029215890100 OIL 490100 A 05,182003 168 SBHP 156 6319 3417 6200 0.45 3353 3N-17 029215940000 OIL 490100 A 121172009 185.4 SBHP 157 6431 1635 6200 0.35 1554 30.01 0292111360000 OIL 490100 A 01282009 4680 SBHP 115 4205 2745 6200 0.49 3722 30.03 029218380000 OIL 490100 A 11/162009 181 SBHP 160 161606 3177 16200 0.35 130M 30.08 029218280000 OIL 490100 A I 12/152009 91.6 SBHP 165 6629 2742 6200 0.35 2592 30.19 029227530000 MWAG 490100 A 0820/21109 75048 SBHP ISO 6526 4306 6200 0.44 4162 30.08A 029216810100 PW 490100 A 07/12/2f109 4914 SBHP 118 5357 3191 6200 0.45 3570 3S-07 103204300000 OIL 490100 C 04,032009 90 SBHP 163 5803 2857 6200 0.45 3035 3S -WC 103204500300 OIL 490100 C 04/07/2009 91 SBHP 155 VIP! 1436 6200 0.31 1571 3540 103204400000 OIL 490100 C 10/172009 109 SBHP 153 5817 2932 6200 0.43 3097 3S-19 103204600000 OIL 1490100 C 04102209 98 SBHP 163 5849 2245 6200 0.49 2415 3S -23A 103204530100 OIL 490100 1 C 04/03/2009 96 ISSHP 1147 5127 2238 6200 0.44 2710 23. All tests reported herein were made In accordance with the apps a rules, regulations and Instructions of the Alaska Oil and Gas Conservation Commission. I hereby certify met me foregoingi and correct to best o m nevi 0. Signature Title Pnmod Name Dale 3/S//0,/L> Form 10-412 Rev. 12/2008 Kuparuk River Oil Pool Kuparuk Perforated Intervals and Stratigraphic Zones WELL NAME PERF TOP ss PERF BTM SS ZONE 1A-03 -6387.53 -6390.89 A-4 10-03 -6362.39 -6387.53 A-4 1A-03 -6360.71 -6362.39 A-4 1A-03 -6360.71 -6362.39 A-5 10-03 -6350.69 -6355.7 A-5 1A-03 -6171.12 -6190.68 C-1 1A-03 -6067.77 -6122.47 C-3 1A-03 -6067.77 -6122.47 C-4 1A-13 -6206.76 -6230.6 A-4 IA -13 -6190.87 -6197.82 A-5 to -13 -6190.87 -6197.82 A-6 1AA3 -6040.96 -6056.84 C-1 1A-13 -5940.72 -6017.14 C-2 1A-13 -5940.72 -6017.14 C-3 1A-13 -5940.72 -6017.14 C-4 1A-17 -6191.62 -6202.51 A-3 1A-17 -6150.79 -6171.57 A4 1A-17 -5978.02 -5991.79 C-1 1A-17 -5899.2 -5946.49 C-3 1A-17 -5899.2 -5946.49 C4 10-18 -6302.17 -6326.98 A-4 1A-18 -6288.42 -6292.09 A-5 10-18 -6141.77 -6157.18 C-1 1A-18 -6082.96 -6101.03 C-3 1A-18 -6082.96 -6101.03 C-0 1A-18 -6057.69 -6082.96 C-4 1A-19 -6180.41 -6203.72 A4 1A-19 -6167.6 -6170.8 A-5 1A-19 -6007.17 -6025.8 C-1 1A-19 -5941.45 -5974.65 C-2 1A-19 -5941.45 -5974.65 C-3 1A-19 -5941.45 -5974.65 C4 1A-19 -5932.97 -5941.45 C-4 1A-19 -5909.88 -5932.97 C-4 1A-22 -6262.64 -6292.07 A4 1A-22 -6248.54 -6252.39 A-5 1A-22 -6107.55 -6124.41 C-1 10-22 -6073.04 -6076.96 C-2 10-22 -6062.58 -6066.51 C-3 1A-22 -6062.58 -6066.51 C-4 1A-22 -6036.34 -6062.58 C4 1A-23 -6114.23 -6137.86 A-4 1A-23 -6098.49 -6102.42 A-5 10-23 -5960.94 -5972.71 C-1 1A-23 -5900.12 -5919.73 C-3 ConocoPhillips 2009 Reservoir Surveillance Report WELL NAME PERFTOP ss PERF BTM SS ZONE 1A-23 -5900.12 -5919.73 C-4 1A-23 -5894.23 -5900.12 C-0 1A-23 -5856.97 -5894.23 C-4 1A-25 -6147.87 -6180.69 A-4 10-25 -6132.41 -6137.58 A-5 1A-25 -6016.28 -6032.4 UNIT B IA -25 -5996.19 -6013.2 C-2 1A-25 -5996.19 -6013.2 C-3 1A-25 -5986.87 -5996.19 C-3 1A-25 -5986.87 -5996.19 C-4 TA -25 -5980.63 -5986.87 C4 1A-27 -6186.66 -6219.92 A-4 1A-27 -6166.44 -6176.22 A-5 1A-27 -6033.68 -6042.85 C-1 1A-27 -5965.24 -6005.98 C4 1A-28 -6180.3 -6216.03 A-4 1A-28 -6163.29 -6171.23 A-5 1A-28 -6024.27 -6035.52 C-1 1A-28 -6024.27 -6035.52 C-2 1A-28 -6001.56 -6024.27 C-2 IA -28 -6001.56 -6024.27 C-3 1A-28 -6001.56 -6024.27 C4 1B-04 -6373.56 -6404.45 A4 1B-04 -6356.03 -6366.83 A-5 1 B-04 -6192.07 -6234.5 C-1 1B•04 -6192.07 -6234.5 C-2 1 B-04 -6192.07 •6234.5 C-3 1B-04 -6192.07 -6234.5 C-4 1 B-05 -6619.88 -6631.88 A-4 1 B-05 -6601.9 -6614.89 A-4 1 B-05 -6581.91 -6589.91 A-5 1B-05 -6429.95 -6479.94 UNIT B 1 B-05 -6389.95 -6409.95 C-1 1 B-05 -6350.96 -6355.96 C-2 1 B-05 -6336.96 -6344.96 C-2 TB -05 -6291.96 -6331.96 C-3 18-05 -6291.96 -6331.96 C4 TB -07 -6442.93 -6454.8 A4 1 B-07 -6430.89 -6437.6 A4 TB -07 -6414.63 -6424.13 A-5 1B-07 -6285.25 -6290.22 UNIT 1 B-07 -6267.45 -6278.85 C-1 1B-07 -6199.3 -6253.17 C-2 1 B•07 -6199.3 6253.17 C-3 1 B-07 -6199.3 -6253.17 C4 Kuparuk River Oil Pool 2009 Reservoir Surveillance Report WELL NAME PERF TOP ss PERF BTM ss ZONE WELL NAME PERF TOP ss PERF BTM ss ZONE 1B-17 -6433.75 -6451.36 C-1 1E-04 -6057.28 -6060.15 A-0 1B-17 -6416.17 -6433.75 C-1 ---1E-04 -6042.19 -6044.34 A-0 1B-17 -6323.06 -6375.74 C-2 1 E-04 -6027.84 -6042.19 A-4 IB -17 -0323.06 -6375.74 C-3 1 E-04 .6026.4 -6027.84 A-4 1B-17 -6323.06 -6375.74 C-0 1E-04 5932.5 -5946.82 UNIT 1B-19 -6337.77 5353.87 A-4 t E-04 -5858.2 -5915.32 C-1 1B-19 5322.53 5337.77 A-4 1 E-04 -5858.2 -5915.32 C-3 IB -19 5147.91 5181.74 C-1 1 E-04 -5858.2 -5915.32 C-4 IB -19 -6147.91 5181.74 C-2 1 E-05 5213.37 5227.36 A-4 1B -i9 5147.91 -6181.74 C-3 ---TE-05 -6189.38 -6207.37 A-5 1C-04 -6435.89 -6445.87 C-1 1E-05 .5979.52 5115.43 C-1 1 C-04 5316.12 5376.01 C-2 --7E-05 -5979.52 -6115.43 C-2 1C-04 5316.12 5376.01 C-3 1E-05 -5979.52 -6115.43 C-3 1C-04 5316.12 5376.01 C4 1E-05 -5979.52 5115.43 C-0 1C-07AL1 5463.56 -6450.04 C4 1E-06 5280.72 5318.69 A4 1c -ii 5422.3 -6456.69 C-3 t E-06 5256.74 -6272.72 A-5 1C-11 5422.3 5456.69 C4 1E-06 -6066.97 5128.88 C-1 1C-16 -6468.14 -6489.19 C-4 1E-06 5066.97 5128.88 C-2 1C-19 -6463.63 5488.91 C4 1E-06 5066.97 5128.88 C-3 1C-23 -6434.47 5455.76 C4 1E-06 5066.97 5128.88 C4 1C-24 5370.25 -6372.36 C-2 1E-08 5256.28 5292.76 A4 1C-24 5359.41 5365.95 C-2 tE-08 -6234.95 5249.2 A-5 1C-24 5339.81 5353.44 C-2 iE-08 -6037.55 5109.34 C-1 1C-24 5339.81 5353.44 C-3 1E-08 5037.55 5109.34 C-2 1C-24 5328.79 1 5338.08 C-3 1E-08 5037.55 -6109.34 C-3 1C-24 5328.79 5338.08 C4 1E-08 -0037.55 5109.34 C4 1C-24 -6322 -6325.8 C-4 1E-09 5291.88 5297.61 A4 1 D-03 -6513.48 5533.29 A4 1 E-09 5268.96 -6288.06 A4 1 D-03 5488.75 -6505.23 A-5 1 E-09 -6246.08 5254.66 A-5 I D-03 -6308.33 -6317.2 C-2 --TE-09 -6075.02 5131.93 C-1 1D-03 -6294.6 5299.45 C-2 1E-09 5075.02 -6131.93 C-2 1 D-03 5283.29 5288.14 C-3 1 E-09 5075.02 5131.93 C-3 1 D-03 -6230.59 5278.45 C4 ---TE-09 -8075.02 -6131.93 C4 113-03 5218.32 5230.59 C4 1E-11 -6260.24 5269.56 A4 1D-03 5199.43 5218.32 C4 1E-11 -6239.83 5257.14 A4 1D-04AL1 5418.72 -6457.7 C-2 1E-11 -6220.17 5227.53 A-5 1D-04AL1 -6418.72 5457.7 C-3 1E-11 -6044.17 -6096.56 C-1 1D-04AL1- O1 .6453.08 -6440.63 C-3 1E-11 -6044.17 -6096.56 C-2 1D-04AL1- 02 .6457.7 -6461.76 C-2 1E-11 -6044.17 5096.56 C-3 1D-11 -6527.59 -6538.65 C-1 1E-11 -6044.17 5096.56 C4 1D-11 5508.81 -6514.33 C-2 1E-12 5253.97 -6258.94 A4 113-11 -6469.78 -6480.74 C4 tE-12 5244.03 5247.34 A4 1D-11 5440.88 -6451.76 C4 1E-12 5239.07 5244.03 A4 10-14 -6306.29 5318.98 C4 1E-12 5230.81 -6239.07 A4 1 E-04 5060.15 -6071.67 A4 1E-12 -6228.33 -6230.81 A-4 ConocoPhillips Kuparuk River Oil Pool 2009 Reservoir Surveillance Report WELL NAME PERF TOP SS PERFBTM SS ZONE WELL NAME PERF TOP SS PERF BTM SS ZONE 1E-12 -6216.77 -6217.6 A5 1G-01 -6390.39 -6404.74 A-4 IE -12 5210.18 -6216.77 A-5 1G-01 -6379.24 5382.43 A-5 1E-12 5166.5 5168.15 UNIT B 1 G-01 5192.81 5225.46 C-1 iE-12 5053.62 5119.52 C-1 1G-01 5118.16 5157.59 C-3 1E-12 5053.62 5119.52 C-2 1G-01 5118.16 5157.59 C-4 1E-12 5053.62 5119.52 C-3 1G-04 5637.56 5651.25 A-3 1E-12 5053.62 5119.52 C-4 1G-04 5610.2 5623.88 A-4 1 E-15 5326.51 5331.99 A-4 1G-04 5387.77 5424.79 C-1 1E -1i 5321.82 5326.51 A4 1 G-04 5333.27 5339.1 C-3 IE -15 -6321.04 -6321.82 A4 ---1G-04 5298.27 5325.49 C-4 1E-15 5316.35 5321.04 A4 1G-04 5290.49 5294.38 C-4 1E-15 5315.57 5316.35 A-0 1G-06 5171.65 5194.4 A-3 1E-15 5310.88 5315.57 A-0 1G-06 5144.35 5161.9 A-4 1E-15 5300.72 5310.88 A4 1G -O6 5131.99 5134.59 A-5 1E-15 5295.25 5300.72 A4 1G-06 5050.32 5051.65 UNITB 1E-15 5289.79 5295.25 A-4 1G-06 5007.89 5029.11 C-1 1E-15 5281.98 5287.44 A4 i G-06 -5932.23 -5977.24 C-3 1E-15 5281.98 5287.44 A-5 1G-06 -5932.23 -5977.24 C-4 iE-15 5280.41 5281.98 A-5 IG -09 5651.33 5665.53 A-3 1E-15 5276.51 5280.41 A-5 1G-09 5629.15 5639.79 A4 1E-15 5274.95 5276.51 A-5 1G-09 5415.72 5459.95 C-1 1E-15 5269.49 5274.95 A-5 1G-09 5332.09 5371.31 C4 1E-15 -6192.92 5208.57 UNIT B FG -1 5624.18 5625.88 A-0 1E-15 5139.65 5142.78 UNIT 5607.2 5624.18 A-4 1E-15 5083.24 5139.65 C-1 5594.5 5598.73 A-5 1E-15 5083.24 5139.65 C-3 5369.5 5407.69 C-1 1E-15 5063.24 5139.65 C4 -6256.22 5297.9 C-0 1E-18 5392.32 5396.77 A4 5541.22 5551.49 A4 1E-18 -6364.72 5386.97 A-0 -6526.54 5541.22 A4 1E-18 5340.72 5349.61 A-5 - 5513.33 5526.54 A4 1E-18 5147.86 5164.6 C-2 1G-12 5513.33 5526.54 A-5 1E-18 5068.69 5142.58 C-2 1G-12 5310.95 5349.35 C-1 1E-18 5068.69 5142.58 C-3 1G-12 -6198.1 5252.31 C-3 1E-18 5068.69 5142.58 C-0 1G-12 5198.1 -6252.31 C4 1F -01A -5982.19 5051.81 A-4 1G-16 5501.28 5549.78 A-3 1F -01A -5982.19 5051.81 A-5 1G-16 5501.28 5549.78 A4 1F-14 5210.7 5217.51 A-4 1G-16 5272.58 5330.09 C-1 1F-14 5185.2 5210.7 A-4 1G-16 -6218.51 5221.68 C4 1F-14 5159.75 5171.62 A-5 1G-16 5202.64 5207.39 C4 1F-14 -5998.75 5054.8 C4 1G-16 5192.34 5197.88 C4 IF -17 5075.03 5102.83 A4 1G-16 5182.83 5187.58 C4 1F-17 5053.78 5061.16 A-5 -TH-01 5573.87 5584.23 A4 1F-17 -5927.48 -5945.65 C4 111-01 5553.19 5573.87 A4 1F- 17-5922.94 -5927.48 C4 1 H-01 5553.19 5573.87 A-5 i G -O7 5418.3 1 5431.08 A-3 111-01 5372.33 5396.46 C-1 ConocoPhillips Kuparuk River Oil Pool WELL NAME PERF TOP SS PERF BTM SS ZONE 1 H-01 -6256.77 -6334.39 C-3 1H-01 -6256.77 -6334.39 C4 1H-04 -6501.98 -6522.11 A-4 1 H-04 -6490.23 -6493.59 A-5 1 H-04 -6329.39 -6357.22 C-1 1 H-04 -6235.26 -6287.94 C-3 1H-04 -6235.26 -6287.94 C-0 1H-10 -6590.77 -6619.37 A4 1H-10 -6418.12 -6439.28 C-1 1H-10 -6418.12 -6439.28 C-2 1H-10 -6365.96 -6377.38 C-3 11-1-10 -6330.05 -6358.62 C4 IH -10 -6325.16 -6330.05 C-4 11-1-10 -6317 -6325.16 C4 1H-10 -6313.73 -6317 C4 1H-13 -6624.35 -6657.11 C-1 IH -13 -6560.17 -6586.42 C-2 1H-13 -6560.17 -6586.42 C-3 1H-13 -6503.4 -6553.68 C-3 1H-13 -6503.4 -6553.68 C-0 1J-03 -6490.34 -6495.88 A-5 1J-03 -6362.4 -6368.14 C4 1J-10 -6090.74 -6103.54 A-5 1J-10 -6090.74 -6103.54 A-6 1J-10 -5958.42 -5970.62 C-3 1J-10 -5958.42 -5970.62 C-4 1 L-05 -5986.3 -6010.41 A-4 iL-05 -5955.99 -5969.2 A-5 1L-05 -5829.43 -5862.81 C-0 1L-08 -5942.21 -5958.61 A-5 1L-08 -5783.01 -5833.53 C-0 IL-12 -6025.39 -6032.52 A-4 1L-12 -5949.94 -5972.71 A-5 1L-12 -5838.32 -5846.13 UNIT B 1L-12 5795.82 5838.32 C4 1L-15 -5930.47 5947.51 A-5 1L-15 -5819.69 -5835.31 C-0 1L-15 -5809.47 -5819.69 C-4 1L-18 -6039.17 5046.5 A4 1L-18 5967.2 -5983.36 A-5 1L-18 -5821.95 -5861.49 C4 1L-19 -6014.58 -6029.25 A4 1L-19 -5947.71 -5966.5 A-5 1L-19 -5832.4 -5839.44 UNIT B 1L-19 -5825.36 -5828.17 UNIT B ConocoPhillips 2009 Reservoir Surveillance Report WELL NAME PERF TOP SS PERF BTM SS ZONE 1L-19 -5798.68 -5822.55 C-4 1 L-22 -6097.29 -6106.63 A-4 1 L-22 -6037.15 -6055.2 A-5 1L-22 -5953.5 -5965.12 UNIT B 1L-22 -5948.63 -5949.85 UNIT B 1L-22 -5909 -5915.54 UNIT B 1 L-22 -5873.46 -5905.45 C-4 1 L-24 -6010.96 -6023.02 A-4 1 L-24 -5953.8 -5972.22 A-5 1 L-24 -5835.96 -5865.98 C-4 1Q-01 -6448.81 -6507.42 A-3 1Q-01 -6448.81 -6507.42 A-4 1Q-01 -6276.93 -6280.27 UNITB 1Q-01 -6236.6 -6267.56 C-1 1Q-01 -6148.08 -6154.93 C-4 1Q-02BL1 -6534.88 -6678.81 A-3 1Q-03 -6731.51 -6735.83 A-2 1 Q-03 -6696.77 -6707.68 A-2 1 Q-03 -6633.51 -6679.2 A-3 1 Q-03 -6633.51 -6679.2 A-4 IQ -03 -6456.23 -6466.32 UNIT 1Q-03 -6408.4 -6431.2 C-1 1Q -07A -6219.9 -6221.07 A-4 1Q -07A -6214.29 -6220.95 A-4 1 Q -07A -6214.29 -6220.95 A-5 1 Q -08A -6330.36 -6335.81 A-2 1Q -08A -6272.75 -6274.63 A-3 1Q -08A -6269.92 -6270.39 A-3 1Q -08A -6260.85 -6269.92 A-3 1Q -08A -6250.68 -6260.85 A-3 1Q -08A -6250.19 -6250.68 A-3 1Q -08A -6233.36 -6238.35 A-4 10-08A -6061.98 -6063.8 C-3 1Q -08A -6061.37 -6061.98 C-3 1Q -08A -6042.92 -6061.37 C-3 1Q -08A -6042.92 -6061.37 C-4 1 Q-09 -6226.02 -6241.96 A-2 1Q-09 -6134.41 -6188.18 A-3 1 Q-09 -6134.41 -6188.18 A4 1Q-09 -5989.09 -6001.03 C-1 10-09 -5911.51 -5953.28 C-3 10-09 -5911.51 -5953.28 C4 10-11 -6052.18 -6063.94 A-2 1Q-11 -5956.55 -6012.71 A-3 1Q-11 -5956.55 -6012.71 A4 Kuparuk River Oil Pool WELL NAME PERF TOP SS PERF BTM SS ZONE 1Q-11 -5859.19 -5864.75 UNIT B 1Q-11 -5786.01 -5850.84 C-1 1Q-11 -5786.01 -5850.84 C-2 1Q-11 -5786.01 -5850.84 C-3 14-11 -5786.01 -5850.84 C-4 10-12 -0178.09 -6184.99 A-2 1Q-12 -6138.42 -6155.67 A-3 1Q-12 -6112.54 -6129.8 A-3 1Q-12 -6112.54 -6129.8 A4 1Q-12 -6015.77 -6021.81 UNIT IQ -12 -5969.12 -5984.67 C-1 1Q-12 5891.45 -5944.95 C-2 1Q-12 -5891.45 -5944.95 C-3 10-112 -5891.45 -5944.95 C4 1Q-13 -6143.15 5149.76 A-2 10-13 5105.89 -6110.58 A-2 1Q-13 5042.18 -6089.09 A-3 1Q-13 -6042.18 -6089.09 A4 10-13 -5977.03 1 -5983.33 UNIT 1Q-13 -5969.32 1 -5972.83 UNIT B 1Q-13 -5936.11 -5946.75 C-1 10-13 -5881.67 -5913.3 C-3 1Q-13 -5881.67 -5913.3 C4 1Q-15 5204.58 -6205.24 UNIT 1Q-15 5159.54 5166.3 UNIT 1Q-15 -6067.76 5085.04 C-3 1Q-15 5067.76 -6085.04 C4 1 Q-22 1 5589.83 5610.79 A4 10-22 5400.78 -6406.79 C-1 10-24 -6121.88 5133.77 A-3 1 Q-24 5087.92 -6103.2 A-3 10-24 5087.92 5103.2 A4 10-26 5168.44 5195.68 A-3 iQ-26 -5997.15 -6010.76 C-1 10-26 -5940.83 -5960.82 C3 1Q-26 -5940.83 -5960.82 C4 1Q-26 -5915.37 -5929.01 C4 1R-02 -6543.74 -6564.69 A-3 1R-02 5441.86 5443.25 UNIT 1R-02 -6349.43 5370.05 C-1 1 R-02 5310.97 5312.34 C4 1R -03A -6579.61 1 -6582.29 A-3 1R -03A 5557.88 5578.87 A-3 ConocoPhillips 2009 Reservoir Surveillance Report WELL NAME PERFTOP SS PERF BTM SS ZONE 1 R -03A -6536.81 -6550.23 A-4 1 R -03A -6536.81 -6550.23 A-5 1 R -03A -6375.91 -6384.27 C-1 1 R-07 -6616.99 -6623.92 A-2 1 R-07 -6538.82 -6565.53 A-3 1 R-07 -6522.98 -6531.89 A-4 1R-07 -6355.75 -6361.48 C-1 1 R-08 -6640.24 -6653.95 A-2 1 R-08 -6568.97 -6597.72 A3 1R-08 -6556.13 -6562.17 A-4 1R-08 -6465.23 -6469.71 UNITB 1R-08 -6381.86 -6404.14 C-1 1R-10 -6506.71 -6512.18 A-2 1R-10 -6470.89 -6475.55 A-2 1R -i0 -6435.22 -6453.82 A-3 1R -i0 -6415.09 -6430.57 A-3 1R-10 -6415.09 -6430.57 A4 IR -10 -6297.22 -6327.93 C-1 1R-12 -6512.68 -6517.68 A-2 1R-12 -6474.85 -6497.68 A-2 1R-12 -6420.72 -6459.88 A-3 1R-12 -6420.72 -6459.88 A-4 1R-12 -6338.32 -6346.84 UNIT B 1R-12 -6326.27 5331.94 UNIT 1R-12 5312.08 5320.59 C-1 1R-15 5549.97 5557.01 A-2 IR -15 5467.32 5498.44 A-3 1R-15 -6467.32 5498.44 A4 1R-15 5458 5463.44 A4 1R-15 5458 5463.44 A-5 1R-15 -6314.92 5333.44 C-1 1 R-17 5586.31 5588.17 A-2 1R-17 -6534.5 5570.25 A-3 1R-17 5534.5 5570.25 A4 1R-17 -6534.5 5570.25 A-5 1R-17 5428.74 5438.3 C-1 1R -19A 5733.18 5735.24 A-2 1R -19A 5692.7 5698.19 A-2 IR -19A 5641.17 5674.85 A-3 1R -19A -6641.17 5674.85 A4 1 R-1 9A 5504.79 5521.27 C-1 1R-23 5686.04 5715.05 C-1 1R-23 -6686.04 -6715.05 C-2 1R-25 5791.23 5798.05 A4 1R-25 5613.6 -6641.13 C-1 Kuparuk River Oil Pool WELL NAME PERF TOP SS PERF BTM SS ZONE 1R-32 -6705.88 -6725.94 A-2 1 R-32 -6662.76 -6690.62 A-3 1Y-02 -6226.08 -6253.48 A-3 1Y-02 -6205.08 -6216.39 A-4 1Y-02 -6050.26 -6066.64 C-1 1Y-02 -6006.75 -6011.69 C-3 1Y-02 -5948.39 -6002.64 C-3 1Y-02 -5948.39 -6002.64 C-4 1Y-05 -6106.72 -6117.48 A-3 1Y-05 -6074.27 -6090.94 A4 1Y-05 -6061.72 -6065.07 A-5 1Y-05 -5872.04 -5950.68 C-1 1Y-05 -5872.04 -5950.68 C-2 1Y-05 -5872.04 -5950.68 C-3 1Y-05 -5872.04 -5950.68 CA 1Y-07 -6049.81 -6060.93 A-3 1 Y-07 -6011.74 -6036.37 A4 1Y-07 -5999.92 -6004.05 A-5 1Y-07 -5908.14 -5920.37 UNITB 1Y-07 -5812.76 -5893.35 C-1 1Y-07 -5812.76 -5893.35 C-2 1Y-07 -5812.76 -5893.35 C-3 tY-07 5812.76 1 -5893.35 C-4 1Y-12 -5879.01 -6911.29 A-3 1Y-12 5853.46 5868.29 A-0 1Y-12 -5842.77 -5846.88 A-5 1Y-12 -5756.96 -5768.35 UNIT B 1Y-12 -5747.2 -5750.45 UNIT B 1Y-12 -5674.02 -5740.7 C-1 1Y-12 -5674.02 -5740.7 C-2 1Y-12 -5674.02 5740.7 C-4 tY-14 -6100.47 -6121.3 A-3 1Y-14 -6077.67 -6089.57 A4 1Y-14 -5881.66 -5935.04 C-2 1Y-14 -5881.66 -5935.04 C-3 1Y-14 -5881.66 -5935.04 C-0 1Y-16 -6075.27 -6112.37 A-3 1Y-16 -6056.29 -6067.82 A4 1Y-16 -5947.01 -5964.8 UNIT B 1Y-16 -5938.42 -5942.72 C-1 tY-16 -5882.58 -5926.19 C-3 1Y-16 -5882.58 -5926.19 C-4 1Y-21 -6210.32 -6228.1 A-3 1Y-21 -6210.32 -6228.1 A4 1Y-21 -6187.72 -6199.82 A-4 ConocoPhillips 2009 Reservoir Surveillance Report WELL NAME PERF TOP Ss PERF BTM SS ZONE 1Y-21 -5958.24 -6016.6 C-3 1Y-21 -5958.24 -6016.6 C-4 1Y-30 -6093.44 -6105.46 A-2 1Y-30 -6053.38 -6068.12 A-3 1Y-30 -6005.41 -6053.38 A-3 1Y-30 -6005.41 -6053.38 A-4 1Y-30 -6005.41 -6053.38 A-5 1Y-30 -6001.1 -6005.41 A-5 tY-30 -5883.03 -5903.74 C-1 1Y-30 -5818.01 -5876.14 C-3 1Y30 -5818.01 -5876.14 C-4 9-02 -5931.77 -5956.01 A-3 2A-02 -5911.43 -5920.15 A-4 2A-02 -5811.63 -5856.2 C-4 2A-05 -5869.38 -5883.49 A-3 2A-05 -5845.25 -5869.38 A-3 2A-05 5643.91 -5845.25 A-3 2A-05 -5843.91 -5845.25 A-4 ZA-05 -5830.53 -5835.88 A-4 2A-05 -5822.51 -5830.53 A-4 2A-06 -5821.17 -5822.51 A-4 2A-05 -5774.44 -5799.79 C-4 2A-10 -5859.36 -5884.38 A-3 2A-10 -5838.97 -5846.83 A-0 ZA-10 -5751.75 -5795.32 C-4 2A-11 -5862.62 -5883.72 A-3 2A-11 -5843.16 -5851.62 A-4 2A-11 -5768.46 -5793.1 C-4 2A-12 -5826.74 -5847.27 A-3 2A-12 -5813.8 -5821.41 A-4 2A-12 -5748.05 -5788.66 C-4 2A-13 -5927.31 5934.27 A-2 2A-13 -5846.4 -5888.32 A-3 2A-13 -5846.4 -5888.32 A-4 2A-13 -5739.06 -5778.74 C-4 2A-14 -5871.66 -5902.29 A-3 2A-14 -5746.65 -5799.25 C-4 2A-15 -5907.17 -5944.72 A-3 2A-15 -5779.97 -5820.67 C-0 2A-18 -5943.51 -5962.48 A-3 2A-18 -5821.85 -5859.43 C-4 2A-22 -5731.08 -5747.23 A-3 2A-22 -5731.08 -5747.23 C-4 2A-22 -5717.42 -5728.6 C-4 2A-22 -5700.03 -5709.35 C4 Kuparuk River Oil Pool 2009 Reservoir Surveillance Report WELL NAME PERF TOP ss PERF BTM ss ZONE WELL NAME PERF TOP ss PERF BTM as ZONE 2A-25 -5766.22 -5779.27 A-3 2C-05 -5792.47 -5795.94 A-5 2A-25 -5760.35 -5765.56 A-3 2C-05 -5705.34 -5710.5 UNIT B 2A-25 •5741.52 -5754.5 C4 2C-05 -5696.74 -5701.9 UNIT B 2A-26 -5969.34 •5983.5 A-3 2C-05 -5683.01 -5691.59 C-4 2A-26 -5955.18 -5969.34 A-3 2C-05 -5655.58 -5683.01 C-4 ZA-26 -5923.09 5938.19 A-0 2C-06 -5873.3 -5880.78 A-3 2A-26 -5911.77 -5917.43 A-5 2C-06 -5830.19 5850.08 A-4 2A-26 -5911.77 -5917.43 A-0 2C-06 -5812.75 -5821.06 A-5 213-01 -5927.62 -5928.44 A-3 2C-06 -5721.39 -5728.12 C-4 26-01 -5907.95 -5927.62 A-3 26-06 -5707.92 -5721.39 C-0 26-01 -5907.13 -5907.95 A-3 2C-07 -5828.55 -5856.24 A-4 213.01 -5887.46 -5886.28 A4 2C-07 -5811.82 -5818.8 A-5 28.01 -5870.23 -5887.46 A4 2C-07 •5727.81 •5742.76 C-4 2B-01 -5869.41 -5870.23 A4 2C-08 -5851.8 -5871.33 A-3 28-01 -5857.09 -5860.38 A-5 2C-08 -5851.8 -5871.33 A-0 213-01 -5773 5797.77 C4 2C-08 5834.06 -5846.47 A-5 28-02 -5896.14 -5972.14 A-3 2C-08 -5765 -5782.69 C4 213.02 -5896.14 -5972.14 A4 2C-16 -5835.78 -5853.16 A-3 213.02 -5896.14 -5972.14 A-5 2C-16 -5813.82 •5815.33 A4 2B-02 -5867.4 -5869.09 UNIT B 2C-16 -5813.06 -5813.82 A4 213-02 -5816.76 -5852.19 C4 2C-16 -5810.78 -5813.06 A -4- 42B-08 2B -08-5982.71 -6000.93 A-3 2C-16 -5809.27 -5810.78 A4 28-08 -5944.65 -5964.53 A4 2C-16 -5804.71 -5809.27 A4 28-08 -5929.98 -5935.16 A-5 2C-16 -5803.19 -5804.71 A4 213.08 -5830.53 -5860.42 C4 2C-16 -5800.15 -5803.19 A4 213-09 -5910.72 -5934.15 A-3 2C-16 -5737.79 -5739.31 UNIT B 28-09 -5878.41 -5896.99 A4 2C-16 -5693.5 -5707.27 UNIT B 28.09 -5865.49 -5869.53 A-5 20-16 -5681.24 -5688.9 UNIT B 2B-09 -5785.59 -5801.71 C4 2C-16 -5638.95 -5675.1 C-1 28-10 -5882.25 -5899.92 A-3 2C-16 -5638.95 -5675.1 C-3 26-10 5842.58 -5861.07 A4 2C-16 -5638.95 -5675.1 C4 213-10 -5627.62 •5832.9 A-5 2D-02 -5890.63 -5892.32 A4 213-10 -5743.51 -5774.99 C-4 2D-02 -5883.86 -5887.24 A4 213-14 -5842.21 -5863.02 A-3 2D-02 -5879.64 -5881.33 A4 28-14 -5805.11 -5827.36 A4 213-02 -5875.42 -5876.26 A4 28.14 -5791.77 -5796.21 A-5 2D-02 -5866.99 -5868.67 A4 28-14 -5698.86 -5724.18 C4 213-02 -5863.62 -5864.46 A4 26-16 -5647.79 -5872.56 A-4 2D•02 -5844.27 -5845.95 A-5 213-16 -5830.42 -5837.65 A-5 2D-05 -5971.45 5009.48 A4 2C-02 -5865.86 -5873.14 A-3 2D-05 -5951.62 •5960.63 A-5 2C-02 -5822.28 -5842.23 A-4 2D-05 -5823.07 -5862.14 C4 2C-02 -5807.8 -5811.41 A-5 2D -06B -5916.07 5022.52 A4 20.02 -5703.38 -5721.32 C-4 2D-066 -5916.07 -6022.52 A-5 2C-05 -5839.3 -5854.07 A-3 2D -06B -5916.07 5022.52 A5 2C-05 -5806.33 -5820.2 A4 2D-07 -5882.09 -5918.19 A4 ConocoPhillips Kuparuk River Oil Pool WELL NAME PERF TOP ss PERF BTM ss ZONE 213-07 -5862.67 -5871.92 A-5 213-07 -5774.08 -5803.57 C-4 2D-10 -5905.12 -5907.57 A-0 2D-10 -5889.6 -5892.87 A-4 213-10 -5861.81 -5865.08 A-5 2D-11 -5933.82 -5935.52 A-4 213-11 -5920.19 -5921.04 A-4 2D-11 -5880.29 -5881.14 A-5 2D-11 -5876.91 -5877.75 A-5 2D-14 -5861 -5902.43 A-0 213-14 -5836.62 -5850.32 A-5 213-14 -5789.75 -5801.8 C-4 2E-12 -5957.57 -5963.49 A-4 2E-12 -5920.49 -5946.46 A-4 2E-12 -5887.75 -5902.64 A-5 2E-13 5003.89 -6028.31 A-0 2E-13 -5974.9 -5993.21 A-5 2E-13 -5924.54 -5936.75 C4 2E-14 -5953.77 -5962.6 A-4 2E-14 -5924.35 -5945.68 A-4 2E-14 -5897.87 -5914.05 A5 2F-06 -5867.34 -5874.11 A-3 2F-06 -5791.53 -5828.97 A4 2F-06 -5770.14 -5780.86 A-5 2F-09 -5865.39 -5905.47 A4 2F-09 -5841.34 -5852.92 A-5 2F-10 -5904.5 -5946.92 A4 2F-10 -5878.06 -5891.63 A-5 2F-10 -5826.91 -5829.74 UNIT B 2F-10 -5815.58 -5826.91 C4 2F-10 -5812.74 -5815.58 C4 2F-11 -5961.04 -5968.27 A4 2F-11 -5928.85 5952.4 A4 2F-11 -5899.23 -5913.99 A-5 2F-11 -5873.46 -5874.84 UNIT B 2F-11 -5835.84 -5844.64 C4 2F-19 -5996.95 5014.77 A4 2F-19 -5963.39 -5980.98 A-5 2F-19 -5914.79 -5923.43 C4 2G-06 -5895.73 -5919.88 A4 2G-06 -5873.26 -5881.27 A-5 2G-10 -5999.6 5028.06 A4 2G-10 -5974.17 -5986.88 A-5 2G-13 5048.38 5050.72 A4 2G-13 5046.03 5048.38 A4 ConocoPhillips 2009 Reservoir Surveillance Report WELL NAME PERF TOP 8s PERF BTM ss ZONE 2G-13 -6041.35 -6046.03 A-4 2G-13 -6040.57 -6041.35 A-4 2G-13 -6036.67 -8040.57 -A4 2G-13 -6035.89 -6036.67 A4 2G-13 -6031.99 -6035.89 A4 2G-13 -6031.21 -6031.99 A-4 2G-13 -6025.76 -6031.21 A-4 2G-13 -6023.42 -6025.76 A-4 2G-13 -6021.09 -6023.42 A4 2G-13 -6006.34 -6007.11 A-5 2G-13 5005.56 -6006.34 A-5 2G-13 -6000.13 -6004.01 A-5 2G-13 -5999.36 -6000.13 A-5 2G-13 -5998.59 -5999.36 A-5 2G-13 -5996.26 -5998.59 A-5 2G-14 5997.66 -5999.12 A4 2G-14 -5994.76 -5997.66 A-4 2G-14 -5987.5 -5994.76 A-4 2G-14 -5983.87 -5987.5 A-4 2G-14 -5981.69 -5983.87 A4 2G-14 -5978.06 -5981.69 A-4 2G-14 -5975.15 -5978.06 A-4 2G-14 -5974.42 -5975.15 A4 2G-14 -5972.25 -5974.42 A-4 2G-14 -5968.61 -5972.25 A4 2G-14 -5951.91 -5954.09 A-5 2G-14 -5951.19 -5951.91 A-5 2G-14 -5946.1 -5951.19 A-5 2G-14 -5945.38 -5946.1 A-5 2G-14 -5941.02 -5945.36 A-5 2G-15 5015.15 -6022.83 A4 2G-15 -6013.06 5015.15 A4 2G-15 5008.88 -6013.06 A4 2G-15 -6007.49 5008.88 A4 2G-15 5004.7 5007.49 A4 2G-15 5003.31 5004.7 A4 2G-15 -5999.83 5003.31 A4 2G-15 -5997.75 -5999.83 A4 2G-15 -5996.36 -5997.75 A4 2G-15 -5994.27 -5996.36 A4 2G-15 -5992.19 -5994.27 A4 2G-15 -5974.17 -5978.32 A-5 2G-15 -5972.79 -5974.17 A-5 2G-15 -5970.02 -5972.79 A-5 2G-15 -5968.64 -5970.02 A-5 Kuparuk River Oil Pool WELL PERFTOP PERF BTM A-5 NAME SS I Ss ZONE 2G-15 5967.26 -5968.64 A-5 2G-15 -5904.02 -5913.62 C-0 2H-04 -6003.14 -6011.5 A-3 2H-04 -5993.94 -5999.79 A-3 2H-04 -5946.26 -5973.03 A-4 21-1-04 5931.19 -5937.89 A-5 21-1-04 -5917.79 -5919.47 UNIT B 2H-04 -5879.26 -5889.31 C-0 2H-05 5018.18 -6038.16 A-3 21-1-05 5989.85 -5996.73 A-4 2H-05 -5978.42 -5989.85 A4 2H-05 -5975.37 -5978.42 A4 2H-05 -5980.94 -5964.73 A-5 2H-05 -5876.82 -5899.17 C-4 2H-12 -5975.27 -5996.71 A-3 2H-12 -5946.51 -5954.44 A-4 21-1-12 -5874.31 -5889.03 C4 2K-08 5101.17 5121.99 A4 2K-08 5064.84 -6071.33 C4 2K-08 -6059.4 -6064.84 C4 2K-08 5053.94 5059.4 C4 2K-22 -6208.73 1 5225.3 A4 2K-22 -6189.13 5190.91 A-5 2K-22 -6174.65 -6183.75 A-5 2K-22 5134.55 -6140.47 C4 2K-27 -6026.93 -6043.69 A4 2K-27 -6005.26 5016.91 C4 2M-08 -6006 -6027.88 A4 2M-08 -6006 -6027.88 A-5 2M-11 -5837.9 -5866.5 A-3 2M-11 -5821.65 -5829.4 A4 2M-11 -5802.04 5809.02 C4 2T-02 -5756.33 -5759.21 A-2 2T-02 -5734.79 -5744.12 A-2 2T-02 -5698.98 -5715.44 A-3 2T-05 -5686.42 -5703.35 A-2 2T-05 -5644.83 -5662.45 A-3 2T-05 -5634.26 -5644.83 A-3 ZT-05 -5634.26 -5644.83 A4 2T-11 -5760.52 1 -5789.48 A-3 2T-11 -5747.53 -5752.12 A4 2T-11 -5672.31 -5688.48 C4 2T -12A -5811.71 -5642.86 A-3 2T -12A -5811.71 -5842.86 A4 2T -12A -5719.63 -5745.63 C4 ConocoPhillips 2009 Reservoir Surveillance Report WELL PERF TOP PERF BTM A-3 NAME SS SS ZONE 2T-19 -5854.81 -5869.71 A-2 2T-19 -5630.3 -5835.49 A-3 2T-19 -5815.55 -5830.3 A-3 2T-19 -5804.56 -5815.55 A-3 2T-19 -5804.56 -5815.55 A-4 2T-19 -5757.68 -5771.98 C-0 2T-21 -5772.38 -5773.03 A-3 2T-21 -5759.37 -5772.38 A-3 2T-21 -5752.22 -5759.37 A-3 2T-21 -5752.22 -5759.37 A-4 2T-21 -5732.77 -5741.84 C-4 2T-21 -5730.18 5732.77 C-4 2T-21 -5719.83 -5730.18 C-4 2T -27A -5683.31 -5752.3 A-2 2T -27A -5683.31 -5752.3 A-3 2T-29 -5738.5 -5748.52 A-2 2T-29 -5723.85 -5733.88 A-2 2T-29 -5694.51 -5706.87 A-3 2T -29A -5747.68 -5714.28 A-2 2T-32 -5688.82 -5712.78 A-2 2T-36 -5805.17 -5813.53 A-2 2T-36 -5789.74 -5798.74 A-2 2T-36 -5722.52 -5758.32 A-3 2T-36 -5722.52 -5758.32 C-4 2T-37 -5714.73 -5727.37 A-3 2T-37 -5686.38 -5700.85 C4 2T -38A -5759.84 -5765.61 A-2 2T -38A -5729.15 -5738.43 A-3 2T -38A -5727.99 -5729.15 A-3 2T -38A -5726.83 -5727.99 A-3 2T -38A -5728.83 -5727.99 C4 2T -38A -5721.02 -5726.83 C-0 2T-39 -5838.62 -5843.8 A-2 2T-39 -5814.97 -5823.18 A-2 2T-39 -5783.32 -5790.45 A-3 2T-39 -5766.02 -5772.14 C-4 2T40 -5726.33 -5734.46 A-2 2T40 -5711.73 -5719.84 A-2 2U-01 -5682.94 -5737.05 C-3 2U -07A -5831.18 -5834.73 A-2 2U -07A -5814.04 -5816.99 A-2 2U -07A -5806.38 -5809.91 A-2 2U -07A -5796.96 -5799.31 A-2 2U -07A -5791.06 -5794.6 A-2 2U -07A -5730.27 -5773.3 A-3 Kuparuk River Oil Pool WELL NAME PERF TOP Ss PERF BTM SS ZONE 2U -07A -5730.27 -5773.3 A-4 2V -08A -5855.06 -5891.7 A-3 2V -08A -5824.28 -5843.33 A-4 2V -08A -5723.44 -5753.31 C-4 2V-09 -5833.85 -5860.47 A-3 2V-09 -5813.31 -5823.96 A-4 2V-09 -5740.28 -5743.33 UNIT B 2V-09 -5729.6 -5734.94 UNIT B 2V-09 -5671.37 -5718.91 C-1 2V-09 -5671.37 -5718.91 C-3 2V-09 -5671.37 -5718.91 C-4 2V-10 -5881.52 -5884.84 A-3 2V-10 -5844.91 5878.19 A-3 2V-10 5822.39 -5834.91 A-4 2V-10 -5810.7 -5815.71 A-5 2V-10 -5719.29 -5724.33 UNIT B 2V-10 -5707.52 -5714.24 UNIT B 2V-10 -5690.69 -5701.62 C-1 2V-10 -5690.69 -5701.62 C-3 2V-10 -5690.69 -5701.62 C-4 2V-10 5681.42 -5690.69 C-4 2V-10 -5665.4 -5681.42 C-0 2V-13 -5860.12 -5898.84 A-3 2V-13 -5832.57 -5849.96 A4 2V-13 -5821.01 5826.07 A-5 2V-13 -5729.86 -5745.61 C-4 2V-15 -5894.91 -5903.63 A-2 2V-15 -5794.49 -5803.96 A-0 2V-15 -5664.5 -5687.52 C-4 2W-01 -6029.14 5040.23 A-2 2W-01 -5950.18 -5981.08 A-3 2W-01 -5950.18 -5981.08 A4 2W-01 -5933.25 -5937.49 A4 2W-01 -5784.31 -5842.25 C-1 2W-01 -5784.31 -5842.25 C-2 2W-01 -5784.31 -5842.25 C-3 2W-01 -5784.31 -5842.25 C4 2W-05 5058.24 5061.45 A-2 2W-05 5033.35 -6034.95 A-2 2W-05 -5995.89 5003.03 A-3 2W-05 -5972.95 -5995.89 A-3 2W-05 -5972.16 -5972.95 A-3 2W-05 -5966.64 -5967.43 A4 2W-05 -5961.14 -5966.64 A4 2W-05 -5959.56 -5961.14 AA ConocoPhillips 2009 Reservoir Surveillance Report WELL NAME PERFTOP SS PERF BTM SS ZONE 2W-05 -5959.56 -5961.14 A-5 2W-05 -5868.8 -5871.86 UNIT B 2W-05 -5710.61 -5821.52 C-1 2W-05 -5710.61 -5821.52 C-3 2W-05 -5710.61 -5821.52 C-0 2W-11 -5855.37 -5858.67 UNIT B 2W-11 -5769.01 -5847.62 C-1 2W-11 -5769.01 -5847.62 C-3 2W-11 -5769.01 -5847.62 C-4 2W-16 -5936.03 -5971.43 A-3 2W-16 -5927.65 -5932.67 A4 2W-16 -5830.87 -5834.97 UNIT B 2W-16 -5779.33 -5823.49 C-1 2W-16 -5779.33 -5823.49 C3 2W-16 -5779.33 -5823.49 C-4 2W-17 -5948.39 -5979.68 A-2 2W-17 -5888.92 -5911.76 A-3 2W-17 -5871.6 -5877.07 A4 2X-02 -5978.59 -6001.11 A-3 2X-02 -5955.08 -5964.88 A4 2X-02 -5721.84 -5814.01 C-1 2X-02 -5721.84 -5814.01 C-2 2X-02 -5721.84 -5814.01 C-3 2X-02 -5721.84 -5814.01 C4 2X-04 -5900.18 -5917.95 A-3 2X-04 -5868.3 -5882.45 A4 2X-04 -5755.68 -5760.95 UNIT B 2X-04 -5680.23 -5746.91 C-1 2X-04 -5680.23 -5746.91 C-2 2X-04 -5680.23 -5746.91 C4 2X-05 -5837.24 -5871.11 A-3 2X-05 -5812.54 -5825.25 A4 2X-05 -5709.5 -5723.16 UNIT B 2X-05 -5634.87 -5703.76 C-1 2X-05 -5634.87 -5703.76 C-3 2X-05 -5634.87 -5703.76 C4 2X-06 -5813.41 -5839.35 A-3 2X-06 -5789.27 -5801.78 A4 2X-06 -5641.06 -5685.67 C-1 2X-06 -5641.06 -5685.67 C-3 2X-06 -5641.06 -5685.67 C4 2X-07 -5908.42 -5934.45 A-3 2X-07 -5889.24 -5897.97 A4 2X-07 -5701.83 -5772.63 C4 2X-08 -5964.48 -5985.29 A-3 Kuparuk River Oil Pool 2009 Reservoir Surveillance Report WELL NAME PERF TOP ss PERFBTM ss ZONE WELL NAME PERF TOP as PERF BTM as ZONE 2X-08 -5963.57 -5964.48 A-3 2Z-05 -5845.65 -5887.89 C-2 2X-08 -5932.79 -5963.57 A-3 2Z-05 -5845.65 -5887.89 C-3 2X-08 -5932.79 -5963.57 A-4 2Z-05 -5845.65 -5887.89 C-4 2X-08 -5776.71 -5794.9 C-1 2Z-05 -5844.19 -5845.65 C-4 2X-08 -5776.71 -5794.9 C-3 2Z-05 -5802.03 -5844.19 C-0 2X-08 -5740.34 -5767.61 C-0 2Z-06 -5909.33 -5932.13 A-4 2X-08 -5713.08 -5740.34 C-4 2Z-06 -5893.83 -5898.39 A-5 2X-16 -5935.73 -5950.64 A-3 2Z-06 -5724.26 -5782.68 C-1 2X-16 -5910.15 -5915.52 A-4 2Z-06 -5724.26 -5782.68 C-2 2X-16 -5896.76 -59D3.45 A-4 2Z-06 -5724.26 -5782.68 C-3 2X-16 -5884.76 -5891.42 A-5 2Z-06 -5724.26 -5782.68 C-4 2X-16 -5708.23 -5770.8 C-1 2Z-07 -5920.22 -5950.3 A-4 2X-16 -5708.23 -5770.8 C-2 2Z-07 -5903.08 -5909.93 A-5 ZX -16 -5708.23 -5770.8 C-3 2Z-07 -5816.51 5817.35 UNIT B 2X-16 -5708.23 -5770.8 C-4 2Z-07 -5766.26 -5816.51 C4 2X-19 -5934.99 -5955.99 A-3 2Z-08 -5998.45 -6023.22 A4 2X-19 -5769.36 -5780.95 C-1 2Z-08 -5980.31 -5988.55 A-5 2X-19 -5767.91 -5769.36 C-1 2Z-08 -5821.03 -5900.52 C-1 2X-19 -5735.9 -5767.91 C-1 2Z-08 -5821.03 -5900.52 C-2 2X-19 -5735.9 -5767.91 C-3 2Z-08 -5821.03 -5900.52 C4 2X-19 -5735.9 -5767.91 C4 2Z -13A -5999.66 -5992.02 A4 2X-19 -5689.07 -5735.9 C4 2Z -13A -5987.54 -5995.56 A4 2X -19A -5709.4 -5753.28 C-3 2Z -13A -5966.65 -5987.17 A4 2X -19A -5709.4 -5753.28 C4 2Z -13A -5919.75 -5924.39 UNIT B 2Z -01A -5922.1 -5939.51 A4 2Z-13AL1 -5919.75 -5924.64 UNIT B 2Z-03 5017.23 5023.4 A-3 2Z-19 -6036.27 5045.11 A-3 2Z-03 -5977.6 -5998.08 A4 2Z-19 -5993.94 5013.32 A4 2Z-03 -5777.91 -5842.1 C-1 2Z-19 -5986.03 -5986.91 A-5 2Z-03 -5777.91 -5842.1 C-2 2Z-19 -5979.87 -5986.03 A-5 2Z-03 -5777.91 -5842.1 C-3 2Z-19 -5824.11 -5860.79 _ C-1 2Z-03 -5777.91 -5842.1 C4 2Z-19 -5824.11 -5860.79 C-2 2Z-04 -6017.3 5020.15 A-3 22-19 -5824.11 -5860.79 C-3 2Z-04 -6008.76 -6014.45 A-3 2Z-19 -5824.11 -5860.79 C4 2Z-04 -5968.92 -5987.89 A4 2Z-19 -5797.89 -5818.86 C-4 2Z-04 5955.64 -5959.43 A-5 2Z-21 -6013.78 5032.12 A-3 2Z-04 -5776.36 -5832.33 C-1 2Z-21 -5979.99 -5997.36 A4 2Z-04 -5776.36 -5832.33 C-2 2Z-21 -5782.3 -5849.76 C-1 2Z-04 -5776.36 -5832.33 C-3 2Z-21 -5782.3 -5849.76 C-2 2Z-04 -5776.36 1 -5832.33 C4 2Z-21 -5782.3 -5849.76 C-3 2Z-05 -6021.96 5046.53 A4 2Z-21 -5782.3 -5849.76 C4 2Z-05 -6009.32 5013.04 A-5 2Z-23 -6001.42 5005.25 A-3 2Z-05 -5920.8 -5923 2Z-23 -5960.08 -5975.38 A-3 2Z-05 -5910.55 -5913.48 2Z-23 -5918.87 -5941.75 A42Z-05 "CI_TB -5887.89 -5888.62 2Z-23 -5905.16 -5912.77 A-5 ZZ -05 -5845.65 -5887.89 2Z-23 -5729.25 -5766.75 C-1 ConocoPhillips Kuparuk River Oil Pool WELL NAME PERF TOP SS PERF BTM SS ZONE 2Z-23 -5729.25 -5766.75 C-2 2Z-23 -5729.25 -5766.75 C-3 2Z-23 -5695.62 -5709.06 C-4 3A-02 5979.41 -6009.63 A-2 3A-02 -5950.67 -5969.59 A3 3A-02 -5950.67 -5969.59 A-4 3A-02 -5790.79 -5866.61 C-1 3A-02 -5790.79 -5866.61 C-3 3A-02 -5790.79 -5866.61 C-0 3A -03B -6102.82 -6120.42 A-2 3A -03B -6063.22 -6102.82 A-2 3A -03B -6063.22 -6102.82 A-3 3A -03B -6063.22 -6102.82 A-4 3A -03B -6063.22 -6102.82 A-5 3A-04 -6002.55 -6025.49 A-2 3A-04 -5971.05 -5989.28 A-3 3A-04 -5856.26 -5881.67 C-1 3A-04 -5856.26 -5881.87 C-2 3A-04 -5856.26 -5881.67 C4 3A-10 -5993.24 -6019.98 A-2 3A-10 -5968.28 -5986.11 A-3 3A-10 -5988.28 -5986.11 A-4 3A-10 -5966.49 -5968.28 A4 3A-11 -6017.18 -6047.91 A-2 3A-11 -5999.41 -6015.56 A-3 3A-11 -5999.41 -6015.56 A4 3A-11 -5902.69 -5931.69 C-1 3A-11 -5902.69 5931.69 C-2 3A-11 -5902.69 -5931.69 C-3 3A-11 -5902.69 -5931.69 C4 3A-14 -6142.54 -6147.35 A-1 3A-14 -6083.4 -6118.51 A-2 3A-14 -6057.94 -6073.85 A-3 3A-14 -6057.94 -6073.85 A4 3A-15 -6107.01 -6127.5 A-1 3A-15 -6067.54 -6097.47 A-2 3A-15 -6047.17 -6059.39 A-3 3A-15 -5952.31 -5976.71 C-1 3A-15 5952.31 -5976.71 C-3 3A-15 -5952.31 -5976.71 C4 3B-03 -6141.47 -6175.92 A-2 3B-03 -6141.47 -6175.92 A-3 3B-03 -6114.7 -6130 A-3 3B-03 -6097.5 -6109.92 A-3 3B-03 -6097.5 -6109.92 A4 ConocoPhillips 2009 Reservoir Surveillance Report WELL NAME PERF TOP SS PERF BTM SS ZONE 3B-03 -6004.89 -6012.52 UNIT B 3B-03 -5974.31 -5983.87 C-1 3B43 -5929.33 -5961.87 C-3 3B-03 -5929.33 -5961.87 C-4 3B-14 -6119.68 -6135.58 A-2 3B-14 -6075.97 -6107.76 A-3 313-14 -6075.97 -6107.76 A-0 3B-14 -5980.63 -5986.59 UNIT B 3B-14 -5901.22 -5956.8 C-1 3B-14 -5901.22 -5956.8 C-3 3B-14 -5901.22 -5956.8 C-4 3C-02 -6279.97 -6294.37 A-2 3C-02 -6238.11 -6265.54 A-3 3C-02 -6232 -6235.06 A-4 3C-02 -6164.38 -6168.24 UNIT B 3C-02 -6158.2 -6162.06 UNIT B 3C-02 -6145.05 -6152.79 UNIT B 3C-02 -6121.78 -6129.54 UNIT B 3C-02 -6098.44 -6106.22 C-1 3C-02 -6095.32 -6098.44 C-1 3C-02 -6094.54 -6095.32 C-1 3C-07 -6445.14 -6472.15 A-2 3C-07 -6403.73 -6429.85 A-3 3C-07 -6293.28 -6311.78 UNIT B 3C-09 -6483.94 -6499.88 A-2 3C-09 -6434.3 -6468.06 A-3 3C-09 -6434.3 -6468.06 A4 3C-09 -6434.3 -6468.06 A-5 3C-09 -6355.45 -6363.91 UNIT B 3C-09 -6310.53 -6321.04 C-1 3C-11 -6474.07 -6503.7 A-3 3C-11 -6465.51 -6470.78 A4 3C-11 -6336.16 -6345.45 C-1 3C -14B -6313.24 -6405.15 A-2 3CA413 -6313.24 -6405.15 A3 3C -14B -6313.24 -6405.15 A4 3C -14B -6313.24 -6405.15 A-5 3C -14B -6313.24 -6405.15 A-6 3C -15A -6333.59 -6363.72 A-2 3C -15A -6318.24 -6320.66 A-3 3C -15A -6301.32 -6317.43 A-3 3C -15A -6282.81 -6300.52 A-3 3C -15A 5282.81 -6300.52 A4 3C -15A 6282.81 -6300.52 A-5 3C -15A -6282.81 -6300.52 A-6 Kuparuk River Oil Pool WELL NAME PERF TOP SS PERF BTM SS ZONE 3C-16 -6427.28 -6442.69 A-3 3C-16 -6408.03 -6421.51 A-3 3C-16 -6408.03 -6421.51 A4 3C-16 -6237 -6256.19 C-1 3C-17 -6471.67 -6517.09 A-2 3C-17 -6444.59 -6462.63 A-3 3C-17 -6443.69 -6444.59 A-3 3C-17 -6415.85 -6443.69 A-3 3C-17 -6415.85 5443.69 A4 3C-17 5408.68 5415.85 A-0 3C-17 5408.68 5415.85 A-5 3F-02 5023.1 5055.73 A-2 3F-02 5004.46 5006.01 A-3 3F-02 -5981.18 5004.46 A-3 3F-02 -5974.2 -5981.18 A-3 3F-02 -5974.2 -5981.18 A4 3F-02 -5748.15 -5841.5 C-1 3F-02 -5748.15 -5841.5 C-2 3F-02 -5748.15 -5841.5 C-3 3F-02 -5748.15 -5841.5 C4 3F-05 5002.97 5032.45 A-2 3F-05 -5965.17 -5992.46 A-3 3F-05 -5823.16 -5875.84 C-1 3F-05 -5823.16 -5875.84 C-2 3F-05 -5823.16 -5875.84 C-3 3F-05 -5823.16 -5875.84 C-4 3F-06 -5922.03 -5953.32 A-2 3F-06 -5879.12 -5907.97 A-3 3F-06 -5879.12 -5907.97 A-4 3F-06 -5724.86 -5779.03 C-1 3F-06 -5724.86 -5779.03 C-3 3F-06 -5724.86 -5779.03 C-4 3F-07 5016.12 -6042.93 A-2 3F-07 -5983.42 5004.22 A-3 3F-07 -5887.73 -5892.86 UNIT B 3F-07 -5826.27 -5881.14 C-1 3F-07 -5826.27 5881.14 C-3 3F-07 -5826.27 -5881.14 C4 3F-08 -5943.84 -5976.82 A-2 3F-08 -5902.44 -5930.81 A-3 3F-08 -5902.44 -5930.81 A4 3F-08 -5811.14 -5819.59 UNIT B 3F-70 -5905.28 -5936.74 A-2 3FA 5871.9 -5890.97 A-3 3F-10 -5698.03 -5759.23 C-1 ConocoPhillips 2009 Reservoir Surveillance Report WELL NAME PERF TOP SS PERF BTM SS ZONE 3F-10 -5698.03 -5759.23 C-3 3F-10 -5698.03 -5759.23 C-4 3F-11 -5756.39 -5796.69 A-2 3F-11 -5724.44 -5739.02 A-3 3F-11 -5632.82 -5649.47 C-1 3F-11 -5632.82 -5649.47 C-4 3F-14 -5976.81 -6010.17 A-2 3F-14 -5960.53 -5962.08 A-3 3F-14 -5945.04 -5960.53 A-3 3F-14 -5943.49 -5945.04 A-3 3F-14 -5785.53 -5825.73 C-1 3F-14 -5785.53 -5825.73 C-3 3F-14 -5785.53 -5825.73 C-4 3F-14 -5753.09 -5785.53 C-4 3F-14 -5743.82 -5753.09 C-4 3G-02 -5729.5 -5764.24 A-2 3G-02 -5701.9 -5719.71 A-3 3G-02 -5701.9 -5719.71 C4 3G-04 -5797.81 -5805.35 A-2 3G-04 -5782.72 -5797.81 A-2 3G-04 -5749.55 -5767.64 A-3 3G-04 -5749.55 -5767.64 A-4 3G-04 -5696.78 -5711.86 C-0 3G-06 -5767.79 -5792.65 A-2 3G-06 -5733.12 -5757.88 A-3 3G-06 -5733.12 -5757.88 A-0 3G-06 -5733.12 -5757.88 A-5 3G-06 -5679.64 -5687.03 C-4 3G-06 -5678.81 -5679.64 C4 3G-08 -5761.91 -5774.97 A-2 3G-08 -5725.35 -5751.47 A-3 3G-08 -5725.35 -5751.47 A4 3G-08 -5662.44 -5675.59 C4 3G-11 -5758.86 -5778.56 A-2 3G-11 -5758.86 1 -5778.56 A-3 3G-11 -5736.21 -5749.01 A-3 3G-11 -5696.81 -5707.64 C4 3G-12 -5748.18 -5770.4 A-2 3G-12 -5748.18 -5770.4 A-3 3G-12 -5718.61 -5740.78 A-3 3G-12 -5718.61 -5740.78 A4 3G-12 -5684.64 -5692.03 C4 3G-13 -5800.38 -5825.02 A-2 3G-13 -5800.38 -5825.02 A-3 3G-13 -5771.16 -5789.37 13 Kuparuk River Oil Pool WELL NAME PERF TOP ss PERF BTM ss ZONE 3G-13 -5771.16 -5789.37 C-4 3G-13 -5750.68 -5771.16 C-4 3G-16 -5797.78 -5821.86 A-2 3G-16 -5780.38 5784.06 A-3 3G-16 -5760.38 -5784.06 A4 3G-16 -5699.06 -5710.69 C-0 3G-18 -5834.49 -5847.98 A-2 313-18 -5825.34 -5834.49 A-2 313-18 -5806.62 -5811.35 A-3 3G-18 -5801.85 -5806.62 A3 3G-18 -5792.22 -5801.85 A-3 3G-18 -5755.7 -5757.7 C-4 3G-18 -5750.68 -5755.7 C4 3G -21A -5773.11 -5777.81 A-2 3G -21A -5768.62 -5773.11 A-2 3G -21A -5747.02 -5750.71 A-3 3G -21A -5743.41 -5747.02 A-3 3G -21A -5743.41 -5747.02 C4 3H-01 -5884.49 -5898.29 A-1 3H-01 -5853.83 -5867.63 A-2 3H-01 -5835.44 -5844.64 A-3 3H-01 -5835.44 -5844.64 A-5 3H-01 -5814.02 -5830.84 C-3 3H-01 -5814.02 -5830.84 C4 3H-01 -5807.91 -5814.02 C4 3H-01 -5803.35 -5807.91 C4 3H-01 -5800.3 -5803.35 C4 3H-01 -5779.06 5800.3 C4 3H-02 -5934.24 -5948.42 A-1 3H-02 -5934.24 -5948.42 A-2 3H-02 -5917.21 -5928.57 A-3 3H-02 -5917.21 -5928.57 A-5 314-02 -5802.77 -5888.81 C-1 3H-02 -5802.77 -5888.81 C-3 3H-02 -5802.77 -5888.81 C4 3H-03 -5969.01 -5972.84 A-2 3H-03 -5960.08 -5963.91 A-2 31-1-03 -5948.59 -5960.08 A-2 31-1-03 -5925.6 -5935.82 A-3 3H-03 -5845.77 -5883.43 C-1 3H-03 -5845.77 -5863.43 C-3 3H-03 -5845.77 -5883.43 C4 3H-06 -5927.81 -5943.23 A-1 31-1-06 -5893.11 -5908.53 A-2 31-1-06 -5833.74 -5883.08 A-3 ConocoPhillips 2009 Reservoir Surveillance Report WELL NAME PERFTOP ss PERF BTM ss ZONE 314-06 -5833.74 -5883.08 C-4 3H-06 -5821.41 -5826.81 UNIT D 3H-09 -6026.02 -6028.01 A-1 3H-09 -6014.07 -6026.02 A-1 3H-09 -6008.1 5014.07 A-1 3H-09 5008.1 -6014.07 A-2 31-1-09 -6006.11 -6008.1 A-2 31-1-09 -5998.14 -6004.11 A-2 31-1-09 -5976.23 -5996.15 A-2 3H-09 -5955.33 -5965.28 A-3 3H-09 -5868.72 -5924.46 C-3 3H-09 -5868.72 -5924.46 C-4 3H-11 -6114.93 -6131.79 A-1 3H-11 -6082.06 5098.92 A-2 3H-11 -6065.2 5075.32 A-3 3H-11 -5983.37 -6008.69 C4 3H -13A -5931.72 -5935.89 A-1 3H -13A -5923.36 -5928.58 A-1 3H -13A -5871.67 -5898.16 A-2 3H -13A -5871.67 -5898.16 A-3 3H -13A -5856.23 -5866.89 C-4 3H-15 -5940.95 -5955.78 A-1 3H-15 -5933.55 -5940.95 A-1 3H-15 -5926.17 -5933.55 A-1 3H-15 -5890.95 5914.39 A-2 3H-15 -5890.95 -5914.39 C4 3H-15 -5858.92 -5886.57 C4 3H-17 5064.17 -6078.84 A-1 31-1-17 5034.11 -6042.9 A-2 3H-17 -6016.52 -6023.85 A-3 31-1-17 -5979.87 -5982.8 C4 31-1-17 -5976.2 -5979.87 C4 3H-17 -5975.47 -5976.2 C4 3H-18 -5914.77 -5925.28 A-1 31-1-18 -5903.23 -5914.24 A-1 31-1-18 5857.41 -5893.81 C4 3H-20 -6042.6 -6056.54 A-1 3H-20 -6028.67 5042.6 A-1 3H-20 -6014.75 -6018.93 A-2 3H-20 -6007.79 -6014.75 A-2 3H-20 5005.01 -6007.79 A-2 3H-20 -5987.63 -5994.58 A-3 3H-22 -6010.2 -6022.37 A-1 3H-22 -5987.08 -5999.25 A-2 3H-22 -5971.26 -5983.43 A-3 Kuparuk River Oil Pool WELL NAME PERF TOP ss PERF BTM SS ZONE 3H-24 -5948.11 -5971.94 A-1 3H-24 -5924.36 -5940.18 A-2 31-1-24 -5924.36 -5940.18 C-0 3H-31 -5948.26 -5971.23 A-1 3H-31 -5948.26 -5971.23 A-2 3H-31 -5928.4 -5942.15 C-0 3H-33 -6063.51 -6081.51 A-2 3H-33 -6063.51 -6081.51 A-3 3H -33A -6006.18 -6068.02 A-2 3H -33A -6006.18 -6068.02 A-3 3H -33A $006.18 -6068.02 A-5 3H -33A -6006.18 -6068.02 A-6 31.01 -6281.32 -6301.73 A-1 31-01 -6269.65 -6274.02 A-2 31-01 -6259.43 -6269.65 A-2 31-01 -6255.04 -6259.43 A-2 31-02 -6284.42 -6294.98 A-2 31-02 -6278.08 -6284.42 A-2 31-02 -6277.38 -6278.08 A-2 31-02 -6272.45 -6277.38 A-2 31-02 -6264 -6268.93 A-3 31-02 -6262.6 -6264 A-3 31-02 -6258.37 -6262.6 A-3 31-04 -6257.05 -6261.43 A-1 31.04 -6176.97 -6206.04 A-2 31.06 -6183.84 -6209.37 A-2 31-06 -6164.44 -6177.67 A-3 31.06 -6164.44 -6177.67 A4 31-06 -6114.99 -6122.06 C4 31-07 -6205.51 -6212.11 A-1 31.07 -6184.91 -6197.56 A-2 31-07 -6184.24 -6184.91 A-2 31.07 -6178.21 -6184.24 A-2 31-07 -6173.51 -6178.21 A-2 31-07 -6170.15 -6173.51 A-2 31-07 -6158.67 -6163.4 A-3 31.07 -6152.56 -6158.67 A-3 31-12 -6246.58 -6270.72 A-1 31-12 -6225.64 -6238.53 A-2 31-12 -6224.83 -6225.64 A-2 31-12 -6222.42 -6224.83 A-2 31-12 -6221.61 -6222.42 A-2 31.12 -6219.19 -6221.61 A-2 31-12 -6211.93 -6214.35 A-3 31-12 1 -6211.13 -6211.93 A3 ConocoPhillips 2009 Reservoir Surveillance Report WELL NAME PERF TOP SS PERF BTM SS ZONE 31.12 -0208.7 -6211.13 A-3 31.12 -6207.9 -6208.7 A-3 31-12 -6201.44 -6207.9 A-3 31-13 -6178.23 -6205.6 A-1 31.13 -6145.67 -6170.83 A-2 31-13 -6145.67 -6170.83 A-3 31-13 -6130.13 -6140.49 A-3 31-13 -6130.13 -6140.49 A-4 31-17 -6141.28 -6165.63 A-2 31-17 -6116.93 -6132.58 A-3 31-17 -6116.93 -6132.58 A-0 3J-02 -6199.72 -0210.45 A-2 3J-02 -6185.96 -6197.92 A-2 3J-02 -6157.04 -6172.74 A-3 3J-02 -6150.38 -6152.2 A-4 3J-02 -6035.37 -6039.79 UNIT B 3J-02 -6025.88 -6032.84 C-1 3J-03 -6161.45 -6166.34 A-2 3J-03 -6136.3 -6160.05 A-2 3J-03 -6123.02 -6131.41 A-3 3J-03 -6122.33 -6123.02 A-3 3J-03 -6118.83 -6122.33 A-3 3J-03 -6118.13 -6118.83 A-3 3J-03 -6116.73 -6118.13 A-3 3J-03 -6116.03 -6116.73 A-3 3J-03 -6114.64 -6116.03 A-3 3J-03 -6113.94 -6114.64 A-3 3J-03 -6110.44 -6113.94 A-3 3J-03 -6109.74 -6110.44 A-3 3J-03 -6103.45 -6109.74 A-3 3J-03 -6095.05 -6099.95 A-5 3J-03 -6015.78 -6029.85 C-2 3J-03 -6015.78 -6029.85 C-3 3J-03 -6015.78 -6029.85 C4 3J-03 -5989.65 -5992.48 C4 3J-06 -6332.89 -6362.28 A-2 3J-06 -6298.71 -6320.97 A-3 3J-06 -6247.77 -6249.36 UNIT B 3J-06 -6151.57 -6162.69 C-1 3J-09 -6327.83 -6336.8 A-1 3J-09 -6277.01 -6279 A-2 3J-09 6275.01 -6277.01 A-2 3J-09 -6262.06 -6275.01 A-2 3J-09 -6258.06 -6262.06 A-2 3J-09 -6245.12 -6248.11 A-3 Kuparuk River Oil Pool 2009 Reservoir Surveillance Report WELL NAME PERF TOP SS PERF BTM 8s ZONE WELL NAME PERFTOP 3S PERF BTM SS ZONE 3J-09 -6242.14 -6245.12 A-3 3K-07 -8597.6 -6599.07 A-2 3J-09 -6234.17 -6242.14 A-3 3K-07 -6582.14 -6597.6 A-2 3J-09 -6234.17 -6242.14 A-4 3K-07 -6582.14 -6597.6 A-3 3J-11 -6346.91 -6360.69 A-2 3K-07 -6569.62 -6574.78 A-3 3J-11 -6338.8 -6343.66 A-2 3K-07 -6568.15 -6569.62 A-3 3J-11 -6329.07 -6338.8 A-2 3K-07 -6566.67 -6568.15 A-3 3J-11 -6311.24 -6316.91 A-3 3K-07 -6563.72 -6566.67 A-3 3J-11 -0305.56 -6311.24 A-3 3K-07 -6553.4 -6563.72 A-3 3J-11 -6299.68 -6305.56 A-3 3K-07 -6553.4 -6563.72 A-4 3J-11 -6246.31 -6249.56 UNIT B 3K-08 -6645.12 -0652.8 A-1 3J-11 -6161.76 -6169.9 C-1 3K-08 -6606.84 -6610.66 A-2 3J-12 -6203.17 -6209.43 A-3 3K-08 -6606.07 -0606.84 A-2 3J-12 -6199.25 -6203.17 A-3 3K-08 -6603.78 -6606.07 A-2 3J-12 -6097.89 -6111.91 C-1 3K-08 -6603.01 -6603.78 A-2 3J-13 -6376.56 -6379.82 A-1 3K-08 -6599.19 -6603.01 A-2 3J-13 -6320.37 -6330.94 A-2 3K-08 -6598.42 -6599.19 A-2 3J-13 -6306.56 -6320.37 A-2 3K-08 -6596.13 -6598.42 A-2 3J-13 -0280.62 -6295.2 A-3 3K-08 -6595.36 -6596.13 A-2 3J-13 -6277.38 -6280.62 A-3 3K-08 -6592.3 -6595.36 A-2 3J-13 -6211.12 -6220.8 UNIT B 3K-08 -6591.54 -6592.3 A-2 3J-13 -6193.37 -6206.28 UNIT B 3K-08 -6589.24 -6591.54 A-2 3J-13 -6185.31 -6193.37 C-1 3K-08 -6588.48 -6589.24 A-2 3J-15 -6378.71 -6405.58 A-2 31K-08 -6586.18 -6588.48 A-2 3J-15 -6363.57 -0364.29 A-3 3K-08 -6585.42 -6586.18 A-2 3J-15 -0362.85 -6363.57 A-3 3K-08 -6580.06 -6585.42 A-2 3J-15 -6358.53 -6362.85 A-3 3K-08 -0579.3 -6580.06 A-2 3J-15 -6357.82 -6358.53 A-3 3K-08 -6577 -6579.3 A-2 3J-15 -6352.79 -6357.82 A-3 3K-08 -6576.24 -6577 A-2 3J-15 -6218.47 -6230.17 C-1 3K-08 -6568.59 -6576.24 A-2 3K-02 -6538.19 -6539.58 A-2 3K-08 -6557.11 -6560.93 A-3 3K-02 -6532.63 -6538.19 A-2 3K-08 -6556.34 -6557.11 A-3 3K-02 -6530.55 -6532.63 A-2 31K-08 -6554.05 -6556.34 A-3 3K-02 -6527.79 -6530.55 A-2 3K-08 -6553.28 -6554.05 A-3 3K-02 -6518.82 -6527.79 A-2 3K-08 -6550.99 -6553.28 A-3 3K-02 -6517.44 -6518.82 A-2 3K-08 -6550.22 -6550.99 A-3 31K-02 -6508.52 -6510.58 A-3 3K-08 -6547.93 -6550.22 A-3 31K-02 -6504.42 -6508.52 A-3 3K-08 -6547.16 -0647.93 A-3 3K-02 -6501.68 -6504.42 A-3 3K-08 -6537.97 -6547.16 A-3 31K-02 -6495.64 -6501.68 A-3 3K-08 -6404.89 -6418.63 C-1 3K-07 -6618.91 -6624.05 A-2 31K -09A -6722.48 -6725.89 A-2 3K-07 -6615.24 -6616.7 A-2 3K -09A -6713.12 -6716.52 A-2 3K-07 -6607.89 -6615.24 A-2 3K -09A -6693.55 -6694.4 A-2 3107 -6606.42 -6607.89 A-2 3K -09A -6685.05 $693.55 A-2 3K-07 -6602.011 -6606.42 A-2 3K -09A -6680.8 -6685.05 A-2 3K-07 -6599.07 1 -6602.01 A-2 3K -09A -6667.2 1 -6669.75 1 A-3 ConocoPhillips Kuparuk River Oil Pool WELL NAME PERF TOP ss PERF BTM ss ZONE 3K -09A -6665.5 -6667.2 A-3 3K -09A -6662.95 -6665.5 A-3 3K -09A -6658.7 -6662.95 A-3 3K -09A -6654.44 -6658.7 A-3 3K-10 -6708.81 -6712.07 A-2 3K-10 -6706.37 -6707.19 A-2 3K-10 3703.11 -6703.93 A-2 3K-10 -6699.85 -6700.67 A-2 3K-10 -6696.59 -6697.41 A-2 3K-10 -6690.06 -6693.33 A-2 3K-10 -6689.25 -6690.06 A-2 3K-10 -6686.8 -6689.25 A-2 3K-10 -6685.98 -6686.8 A-2 3K-10 -6681.89 -6685.98 A-2 3K-10 -6681.07 -6681.89 A-2 3K-10 -6676.17 -6681.07 A-2 3K-10 -6675.35 -6676.17 A-2 3K-10 -6671.26 -6675.35 A-2 3K-10 -6657.32 -6658.96 A -3- 3K-10 -6656.5 -6657.32 A-3 3K-10 -6654.04 -6656.5 A-3 3K-10 -6653.22 -6664.04 A-3 3K-10 -6647.47 -6653.22 A-3 3K-10 -6646.65 -6647.47 A-3 3K-10 -6645.82 -6646.65 A-3 3K-10 -6645 -6645.82 A-3 3K-10 -6642.54 -6645 A-3 3K-12 -6732.21 -6736.33 A-2 3K-12 -6726.44 -6727.27 A-2 3K-12 -6720.68 -6721.5 A-2 3K-12 -6714.91 -6715.74 A-2 3K-12 -6709.97 -6714.91 A-2 3K-12 -6709.15 -6709.97 A-2 3K-12 -6703.39 -6709.15 A-2 3K-12 -6702.56 -6703.39 A-2 3K-12 -6696.8 -6702.56 A-2 3K-12 -6695.98 -6696.8 A-2 3K-12 -6691.86 -6695.98 A-2 3K-12 -6691.04 -6691.86 A-2 3K-12 -6675.4 -6677.04 A-3 3K-12 -6674.57 -6675.4 A-3 3K-12 -6673.75 -6674.57 A-3 3K-12 -6672.93 -6673.75 A-3 3K-12 3672.1 -6672.93 A-3 3K-12 -6671.28 -6672.1 A-3 ConocoPhillips 2009 Reservoir Surveillance Report WELL NAME PERF TOP ss PERF BTM as ZONE 3K-12 -6669.64 -6671.28 A-3 3K-12 -6668.81 -6669.64 A-3 3K-12 3663.05 -6668.81 A-3 3K-15 -6644,01 -6653.41 A-2 3K-15 -6638.63 -6639.3 A-2 3KA5 -6634.6 -6637.29 A-2 3K-15 -6633.93 -6634.6 A-2 3KA5 -6632.59 -6633.93 A-2 3K-15 -6631.91 -6632.59 A-2 3K-15 -6626.54 -6631.91 A-2 3K-15 -6625.87 -6626.54 A-2 3K-15 -6623.85 -6625.87 A-2 3K-15 -6622.51 -6623.18 A-2 3K-15 -6603.69 -6606.38 A-3 3K-15 -6603.02 -6603.69 A-3 3K-15 -6602.35 -6603.02 A-3 3K-15 -6601.68 -6602.35 A-3 3K-15 -6598.99 -6601.68 A-3 3K-15 -6596.97 -6598.99 A-3 3K-15 -6596.3 -6596.97 A-3 3K-15 -6587.56 -6596.3 A-3 3K-15 -6437.81 -6451.32 C-1 3K-15 -6437.81 -6451.32 C-2 3K-16 -6618.48 -6621.82 A-2 3K-16 -6612.46 -6613.13 A-2 3K-16 -6609.77 -6610.44 A-2 3K-16 -6607.09 -6607.76 A-2 3K-16 -6604.39 -6605.07 A-2 3K-16 -6591.55 -6592.23 A-2 3K-16 -6589.52 -6591.55 A-2 3K-16 -6588.84 -6589.52 A-2 3K-16 -6582.72 -6588.84 A-2 3K-16 -6582.03 -6582.72 A-2 3K-16 -6579.99 -6582.03 A-2 3K-16 -6579.31 -6579.99 A-2 3K-16 -6577.26 -6579.31 A-2 3K-16 -6560.79 -6562.17 A-3 3K-16 -6560.1 -6560.79 A-3 3K-16 -6558.03 -6560.1 A3 3K-16 -6557.34 -6558.03 A-3 3K-16 -6555.96 -6557.34 A-3 3K-16 -6555.27 -6555.96 A-3 3K-16 -6553.2 $555.27 A-3 3K-16 -6552.5 -6553.2 A-3 3K-16 -6540.01 -6552.5 A-3 Kuparuk River Oil Pool WELL NAME PERF TOP 88 PERF BTM 88 ZONE 3K-17 -6686.88 -6692.87 A-1 3K-17 -6648.94 -6653.37 A-2 3K-17 -6640.09 -6640.82 A-2 3K-17 -6636.41 -6637.15 A-2 3K-17 -6632.74 -6633.48 A-2 3K-17 -6626.88 -6627.61 A-2 3K-17 -6626.15 -6626.88 A-2 3K-17 -6617.39 -6626.15 A-2 3K-17 -6616.67 -6617.39 A-2 3K-17 -6615.21 -6616.67 A-2 3K-17 -6599.99 -6600.71 A-3 3K-17 -6599.27 -6599.99 A-3 3K-17 -6598.55 -6599.27 A-3 3K-17 -6597.82 -6598.55 A-3 3K-17 -6597.1 -6597.82 A-3 3K-17 -6596.38 -6597.1 A-3 3K-17 -6594.22 -6596.38 A-3 3K-17 -6593.5 -6594.22 A-3 3K-17 -6586.31 -6593.5 A-3 3K-17 -6434.55 -6450.73 C-1 3K-19 -6600.5 -6620.7 A-2 3K-19 -6576.07 -6590 A-3 3K-19 -6479.31 -6487.57 UNIT B 3K-26 -6674.93 -6693.56 A-2 3K-26 -6674.93 -6693.56 A-3 3K-26 -6643.29 -6661.9 A-3 3K-26 -6643.29 -6661.9 A4 3K-26 -6643.29 -6661.9 A-5 3K-27 -6623.85 -6637.62 A-3 3K-30 -6650.06 -6664.53 A-2 3K-30 -6634.13 -6648.61 A-2 3K-30 -6608.05 -6622.55 A-3 3K-31 -6616.31 -6653.46 A-2 3K-31 -6591.3 -6607.04 A-3 3K-34 -6621.26 -6645.33 A-2 3K-34 -6621.26 -6645.33 A-3 3K-34 -6582.16 -6605.77 A-3 3K-34 -6582.16 -6605.77 A4 3K-34 -6582.16 -6605.77 A-5 3M-01 -6310.69 -6322.89 A-1 31VI-01 -6293.26 -6310.69 A-1 31VI-01 -6291.51 -6293.26 A-1 3M-01 -6267.1 -6284.54 A-2 3M-01 -6253.15 -6261.87 A3 3M-01 -6222.6 -6240.06 C4 ConocoPhillips 2009 Reservoir Surveillance Report WELL NAME PERF TOP 8s PERF BTM 58 ZONE 3M-02 -6264.11 -6283.31 A-1 3M-02 -6246.97 $252.45 A-2 3M-02 -6243.54 -6246.97 A-2 3M-02 -6240.11 -6243.54 A-2 3M-02 -6231.2 -6236.69 A-3 3M-02 -6227.78 -6231.2 A-3 3M-02 -6227.09 -6227.78 A-3 3M-02 -6225.72 -6227.09 A-3 3M -03A -6187.74 -6204.42 A-2 31M-04 -6252.84 -6262.53 -Al 3M-04 -6228.55 -6252.84 A-1 310-04 -6200.51 -6212.71 A-2 3M-04 -6200.51 -6212.71 A-3 3M-04 -6183.4 -6195.62 A-3 3M-10 -6172.7 -6197.73 -Al 3M-10 -6172.7 -6197.73 C-4 3M-12 -6152.7 -6166.85 A-1 3M-12 -6140.58 -6141.84 A-2 3M-12 -6113.1 -6121.61 -C4 3M-12 -6104.55 -6113.1 C-4 3M-17 -6242.94 -6267.13 A-1 3M-19 -6153.02 -6184.79 A-1 31VI-19 -6145.81 -6148.7 A-2 3M-19 -6142.93 -6145.81 A-2 3MA9 -6135.71 -6142.93 A-2 3M-19 -6113.32 -6132.1 C4 3M-23 -6142.89 -6148.64 A-1 3M-23 -6135.71 -6142.89 A-1 3M-23 -6128.52 -6135.71 A-1 3M-23 -6111.26 -6122.77 A-2 3M-23 -6111.26 -6122.77 C4 3M-23 -6091.86 -6106.23 C4 3M-24 -6110.96 -6120.81 A-1 3M-24 -6095.47 -6110.96 A-1 3M-24 -6063.06 -6088.43 A-2 310-24 -6063.06 -6088.43 A3 31VI-24 -6041.88 -6056.01 C4 3M -25A -6065.06 -6073.64 A-1 3M -25A -6065.06 -6073.64 C4 3M-28 -5997.84 -6013.76 A-1 3N -02A -6372.45 -6397.79 A-2 3N -02A -6361.35 -6364.52 A-3 3N -02A -6360.56 -6361.35 A3 3N -02A -6358.18 -6360.56 A-3 3N -02A 1 -6357.39 1 -6358.18 A-3 Kuparuk River Oil Pool WELL NAME PERF TOP SS PERF BTM SS ZONE 3N -02A -6348.68 -6357.39 A-3 3N -02A -6255.17 -6264.68 C-1 3N-03 -6284.22 -6289.74 A-1 3N-03 -6251.9 -6270.03 A-2 3N-03 -6240.08 -6244.81 A-3 3N-03 -6239.29 -6240.08 A-3 3N-03 -6238.5 -6239.29 A-3 3N-03 -6237.71 -6238.5 A-3 3N-03 -6230.62 -6237.71 A -3- 3N-07 -6405.23 -6421.66 A-1 3N-07 -6389.54 -6393.28 A-2 3N-07 -6388.05 $389.54 A-2 3N-07 -6378.33 -6388.05 A-2 3N-07 -6378.33 -6388.05 A-3 3N-07 -6334.92 -6340.16 C-4 3N-11 -6408.28 -6425.38 A-1 3N-11 -6405.44 -6406.15 A-1 3N-11 -6403.3 -6404.73 A-1 3N-11 -6402.59 -6403.3 A-1 3N-11 -6399.03 -6402.59 A-1 3N-11 -6398.32 -6399.03 A-1 3N-11 -6390.5 -6398.32 A-1 3N-11 -6378.42 -6379.13 A-2 3N-11 -6369.9 -6374.87 A-2 3N-11 -6369.2 -6369.9 A-2 3N-11 -6368.49 -6369.2 A-2 3N-11 -6367.78 -6368.49 A-2 3N-11 -6364.23 -6367.78 A-2 3N-11 -6363.52 -6364.23 A-2 3N-11 -6360.69 -6363.52 A-2 3N-11 -6344.37 -6355.01 A-3 3N-11 -6305.32 -6315.97 C-4 3N-13 -6406.21 -6431.43 A-1 3N-13 -6390.93 -6392.46 A-2 3N-13 -6389.4 -6390.93 A-2 3N-13 -6386.35 -6389.4 A-2 3N-13 -6383.29 -6386.35 A-2 3N-13 -6374.89 -6383.29 A-2 3N-13 -6367.25 -6368.01 A-3 3N-13 -6365.72 -6367.25 A-3 3N-13 -6364.19 -6365.72 A-3 3N-13 -6361.9 -6364.19 A-3 3N-13 -6357.31 -6361.9 A-3 3N-13 -6302.3 -6317.58 C-1 3N -14A -6341.92 -6358.18 A-2 ConocoPhillips 2009 Reservoir Surveillance Report WELL NAME PERF TOP SS PERF BTM SS ZONE 3N -14A -6313.45 -6325.65 A-3 3N-17 -6502.27 -6508.24 A-1 3N-17 -6473.18 -6488.85 A-1 3N-17 -6453.77 -6456.01 A-2 3N-17 -6453.02 -6453.77 A-2 3N-17 -6449.29 -6453.02 A-2 3N-17 -6441.07 -6449.29 A-2 3N-17 -6426.13 -6430.61 A-3 3N-17 -6424.63 -6426.13 A-3 3N-17 -6423.14 -6424.63 A-3 3N-17 -6415.66 -6423.14 A-3 30-01 -6609.02 -6624.7 A-1 30-01 -6577.74 -6590.24 A-2 30-01 -6563.69 -6575.4 A-3 30.03 -6629.16 -6644.91 A-1 30-03 -6597.78 -6616.59 A-2 30-03 -6580.59 -6592.3 A-3 30.03 -6544.03 -6551.79 C-1 30-03 -6544.03 -6551.79 C-4 30-08 -6644.77 -6660.47 A-1 30.08 -6615.74 -6633.79 A-2 30-08 -6597.71 -6610.25 A-3 30-19 -6581.75 -6589.56 A-1 30-19 -6510.89 -6526.41 A-2 30-19 -6489.22 -6500.05 A-3 3Q -08A -6270.31 -6285.36 A-1 3Q -08A -6270.31 -6285.36 C-4 3S-07 -5792.57 -5817.22 C4 3S -08C -5788.69 -5792.1 C-4 3S-09 -5738.48 -5749.21 C-4 3S-10 -5806.84 -5836.27 C-4 3S-10 -5797.03 -5806.84 C4 3S-19 -5836.89 -5854.09 C-4 3S -23A -5794.24 -5842.82 C-4 ConocoPhillips March 31, 2010 Mr. Dan Seamount, Commissioner Alaska Oil and Gas Conservation Commission 333 West 71h Ave. Suite 100 Anchorage, Alaska 99501-3539 James T. Rodgers Manager, GKA Development Greater Kuparuk Area ConocoPhillips Alaska, Inc. ATO -1326 PO Box 100360 Anchorage AK 99510-0360 Phone (907)263-4027 Fax: (907)265-6133 Re: Kuparuk River Oil Pool — Proposed Injection Profile Survey Plan for 2010 Dear Commissioner Seamount, In compliance with Rule 4, Conservation Order No. 19813, ConocoPhillips Alaska, Inc., operator of the Kuparuk River Oil Pool, is hereby submitting the proposed injection profile survey plan for 2010. There were 45 injection surveys reported for the Kuparuk River Oil Pool to the AOGCC in 2009. In 2010, we expect to conduct approximately 40 injection surveys, including initial surveys for new wells prior to initial sustained injection. If you have any questions concerning this data, please contact Mark Kovar at 265-6097. Sincerely, mes T. Rodgers Manager, GKA Development Greater Kuparuk Area Kuparuk River Oil Pool ATTACHMENT 6 KUPARUK RIVER OIL POOL CONSERVATION ORDER 198B RULE 4 - INJECTIVITY PROFILES 2009 ANNUAL SUBMITTAL 2009 Reservoir Surveillance Report WELL. NUMBER API NUMBER 50- DATE OF INITIAL INJECTION DATE OF PROFILE/ SURVEY DATA TYPE PROFILE/ SURVEY REASON FOR PROFILE/ SURVEY WELL COMPLETION ZONES TAKING INJECTION INJECTION BWPD / MSCFD 1A-10 02920673-00 02/27/94 07/05/09 SPINNER A/C SPLITS Set Single AC 5221 A 0 1A-12 02920688-00 01/27/63 12/05/09 SPINNER OPEN C SANDS Sel Single AC 4200 A 0 1A-13 02920700-00 02/04/83 07/01/09 SPINNER A/C SPLITS Sel Single AC 1487 A 0 PATCH 1A-15 02920711-00 02/15/83 12/06/09 SPINNER INTEGRITY Sel Single AC 4500 CHECK A 45 1A-16RD 02920713-01 02/25/83 06/04/09 SPINNER A/C SPLITS Sel Single AC 5956 A 0 1E-08 02920496-00 08/17/90 10/15/09 SPINNER A/C SPLITS Sel Single AC 1768 A 139 1E-15 02920769-00 08/17/90 02/28/09 SPINNER OPEN C SANDS Sel Single AC 1450 A 149 Conoco Phillips Kuparuk River Oil Pool ATTACHMENT 5 KUPARUK RIVER OIL POOL CONSERVATION ORDER 198B RULE 4 — INJECTIVITY PROFILES 2009 ANNUAL SUBMITTAL 2009 Reservoir Surveillance Report 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 NSCFD 1F-02 02920881-00 10/15/85 02/13/09 SPINNER A/C SPLITS Sel Single AC 2400 A 984 PATCH 1F-10 02920984-00 08/16/84 01/22/09 SPINNER INTEGRITY & Sel Single A 1100 SPLITS 1F-13 02921020-00 08/16/84 03/19/09 SPINNER A/C SPLITS Sel Single AC 3200 A 3059 1L-10 02922026-00 08/05/91 07/25/09 SPINNER A/C SPLITS Sel Single AC 5200 A 156 1L-16 02921202-00 09/15/85 03/21/09 SPINNER A/C SPLITS Sel Single A 300 1L-18 02922145-00 01/27/92 07/23/09 SPINNER A/C SPLITS Single AC 4000 A 120 1L-21DPN 02922043-90 12/06/94 08/08/09 SPINNER A/C SPLITS Single AC 4400 A 0 1R -03A 02921406-01 12/01/00 02/09/09 SPINNER A/C SPLITS Single AC 2425 A 558 ConocoPhillips Kuparuk River Oil Pool ATTACHMENT 5 KUPARUK RIVER OIL POOL CONSERVATION ORDER 198B RULE 4 — INJECTIVITY PROFILES 2009 ANNUAL SUBMITTAL 2009 Reservoir Surveillance Report WELL NUMBER API NUMBER 50- DATE OF INITIAL INJECTION DATE OF PROFILE/ SURVEY DATA TYPE PROFILE/ SURVEY REASON FOR PROFILE/ SURVEY WELL COMPLETION ZONES TAKING INJECTION INJECTION EWPD / MSCFD 1R-10 02921351-00 10/28/85 03/13/09 SPINNER A/C SPLITS Single AC 1500 A 1456 1Y-03 02920943-00 10/25/93 04/17/09 SZT OPEN C SANDS Sel Single AC 4870 A 97 1Y-04 02920948-00 10/25/93 04/28/09 SPINNER A/C SPLITS Triple AC 3503 A 97 1Y-09 02920935-00 04/28/89 04/13/09 SPINNER A/C SPLITS A 2400 1Y-13 02920903-00 10/28/85 12/02/09 SPINNER A/C SPLITS Sel Single AC 2323 A 230 2B-06 02921076-00 11/07/85 02/02/09 SPINNER A/C SPLITS Sel Single AC 5000 A 500 2B-08 02921079-00 11/07/85 07/06/09 SPINNER A/C SPLITS Sel Single AC 2964 A 1036 2F-02 02921063-00 11/22/85 04/19/09 SPINNER A/C SPLITS Single AC 2000 A 1900 ConocoPhillips Kuparuk River Oil Pool ATTACHMENT 5 KUPARUK RIVER OIL POOL CONSERVATION ORDER 198B RULE 4 — INJECTIVITY PROFILES 2009 ANNUAL SUBMITTAL 2009 Reservoir Surveillance Report WELL API DATE OF DATE OF DATA TYPE REASON FOR WELL ZONES INJECTION NUMBER NU6IDER INITIAL PROFILE/ PROFILE/ PROFILE/ COMPLETION TARING BWPD / 50- INJECTION SURVEY SURVEY SURVEY INJECTION MSCFD 2F-16 02921052-00 11/25/85 02/02/09 SPINNER A/C SPLITS Single AC 1400 A 1400 2H-02 10320032-00 11/15/87 12/19/09 SPINNER A/C SPLITS Single AC 2475 A 25 2H-03 10320031-00 11/15/87 11/01/09 SPINNER A/C SPLITS Sel Single AC 4180 A 502 2M-09 10320177-00 05/24/93 10/20/09 SPINNER 0 Single AC 1100 A 1100 2M-16 10320153-00 08/07/92 03/14/09 SPINNER A/C SPLITS Single AC 2750 A 2118 2T-10 10320064-00 07/24/95 01/11/09 SPINNER A/C SPLITS Sel Single A 2000 2U-05 02921281-00 11/11/86 12/18/09 SZT OPEN C SANDS Sel Single AC 7200 A 2520 2V-04 02921041-00 12/08/84 01/20/09 SPINNER A/C SPLITS Sel Single AC 4500 A 3402 ConocoPhillips Kuparuk River Oil Pool ATTACHMENT 5 KUPARUK RIVER OIL POOL CONSERVATION ORDER 1988 RULE 4 - INJECTIVITY PROFILES 2009 ANNUAL SUBMITTAL 2009 Reservoir Surveillance Report WELL NUMBER API NUMBER 50- DATE OF INITIAL INJECTION DATE OF PROFILE/ SURVEY DATA TYPE PROFILE/ SURVEY REASON FOR PROFILE/ SURVEY WELL COMPLETION ZONES TAILING INJECTION INJECTION BWPD / MSCFD 2V-06 02921054-00 12/24/85 01/26/09 SPINNER A/C SPLITS Sel Single AC 5500 A 3541 3B-02 02921319-00 12/30/85 03/23/09 SPINNER A/C SPLITS Sel Single AC 1800 A 868 3B-05 02921335-00 12/30/85 03/29/09 SPINNER A/C SPLITS Sel Single AC 3000 A 1398 3B-15 02921288-00 05/19/87 03/11/09 SPINNER A/C SPLITS Sel Single AC 4860 A 1798 3F-03 02921448-00 01/21/87 03/03/09 SPINNER A/C SPLITS Sel Single AC 5400 A 1018 3F-07 02921463-00 05/06/86 08/21/09 SPINNER A/C SPLITS Sel Single AC 3980 A 677 3G-10 10320134-00 09/04/91 05/31/09 SPINNER A/C SPLITS Sel Single AC 4700 A 1929 3G-12 10320131-00 09/04/91 05/10/09 SPINNER A/C SPLITS Single AC 2700 A 2661 ConocoPhillips Kuparuk River Oil Pool ATTACHMENT 5 KUPARUK RIVER OIL POOL CONSERVATION ORDER 198B RULE 4 — INJECTIVITY PROFILES 2009 ANNUAL SUBMITTAL 2009 Reservoir Surveillance Report WELL NUMBER API NUMBER 50- DATE OF INITIAL INJECTION DATE OF PROFILE/ SURVEY DATA TYPE PROFILE/ SURVEY REASON FOR PROFILE/ SURVEY WELL COMPLETION ZONES TAKING INJECTION INJECTION BWPD / MSCFD 3G-16 10320135-00 09/04/91 05/16/09 SPINNER A/C SPLITS Sel Single AC 4005 A 2619 3J-04 02921400-00 05/21/87 09/01/09 SPINNER PERF C SANDS Single AC 2469 A 2162 3J-05 02921436-00 02/02/87 02/03/09 SPINNER A/C SPLITS Sel Single AC 1211 A 887 3J-13 02921495-00 02/02/87 08/30/09 SPINNER PERF C SANDS Single AC 1200 A 24 3K-08 02921621-00 03/04/90 10/12/09 SZT OPEN A SANDS Sel Single AC 500 A 500 3K-15 02921632-00 11/05/87 01/21/09 SPINNER A/C SPLITS Single AC 740 A 703 45 >> Total IPROF Count for 2009 ConocoPhillips Kuparuk River Oil Pool ATTACHMENT 6 KUPARUK RIVER OIL POOL CONSERVATION ORDER 432 RULE 9 — PRODUCTIVITY PROFILES ANNUAL 2009 SUBMITTAL 2009 Reservoir Surveillance Report WELL NUMBER API NUMBER 50- DATE OF INITIAL PRODUCTION DATE OF PROFILE/ SURVEY DATA TYPE PROFILE/ SURVEY REASON FOR PROFILE/ SURVEY WELL COMPLETION TYPE ZONES PROD- UCING OIL ROPE, PRODUCTION WATER ENPD GAS NSCFD 1A-19 02922111-00 12/24/93 10/01/09 SPINNER A/C SPLITS Triple ALL 227 4310 308 A 0 0 0 1A-25 02922116-00 12/24/93 10/09/09 SPINNER A/C SPLITS Single AC 33 1921 9 A 29 1385 7 1E-29 02920828-00 12/24/93 04/14/09 SPINNER A/C SPLITS Sel Single AC 318 750 1032 A 45 183 19 1F-19 02922660-00 06/20/96 08/23/09 SPINNER EVALUATE NEW Monobore ALL 205 191 126 PERFS FOR RATE A 205 141 126 1L-12 02922033-00 12/24/93 07/16/09 SPINNER A/C SPLITS Single AC 210 669 1594 A 130 78 148 1Y-21 02922387-00 01/24/94 08/11/09 SPINNER A/C SPLITS Sel Single AC 306 3131 1988 A 52 376 318 1Y-25 02921850-00 12/24/93 04/28/09 SZT CLOSE C SANDS Sel Single A 155 142 500 2B-01 02921147-00 12/24/93 07/28/09 SPINNER A/C SPLITS Sel Single AC 511 3889 1015 A 56 350 91 2B-02 02921154-00 02/22/94 08/01/09 SPINNER A/C SPLITS Sel Single AC 113 611 315 A 44 238 123 2D-13 02921070-00 12/24/93 03/20/09 SPINNER A/C SPLITS Single AC 203 755 906 A 167 204 692 ConocoPhillips Kuparuk River Oil Pool ATTACHMENT 6 KUPARUK RIVER OIL POOL CONSERVATION ORDER 432 RULE 9 — PRODUCTIVITY PROFILES ANNUAL 2009 SUBMITTAL 2009 Reservoir Surveillance Report WELL NUMBER API NUMBER 50- DATE OF INITIAL PRODUCTION DATE OF PROFILE/ SURVEY DATA TYPE PROFILE/ SURVEY REASON FOR PROFILE/ SURVEY WELL COMPLETION TYPE ZONES PROD- UCING OIL BOPD PRODUCTION WATER BWPD GAS MSCFD 2G-09 02921139-00 02/22/94 10/16/09 SPINNER A/C SPLITS Single AC 162 307 124 A 32 61 25 2K-07 10320107-00 02/22/94 10/03/09 SPINNER A/C SPLITS Single AC 218 388 152 A 37 66 26 2U-01 02921267-00 02/22/94 03/24/09 SPINNER A/C SPLITS Sel Single AC 170 802 1061 A 95 449 594 2U-10 02921302-00 12/30/93 06/02/09 SPINNER A/C SPLITS Sel Single AC 432 2261 4155 A 148 147 463 2V-10 02921310-00 12/24/93 08/17/09 SPINNER A/C SPLITS Sel Single AC 110 5348 32 A 19 616 2 2W-06 02921211-00 12/24/93 05/02/09 SPINNER A/C SPLITS Sel Single AC 595 4539 1499 A 386 414 376 2W-12 02921240-00 12/24/93 05/03/09 SPINNER A/C SPLITS Sel Single AC 547 2477 821 A 386 414 376 3F-02 02921447-00 02/22/94 04/22/09 SPINNER A/C SPLITS Sel Single AC 542 3587 773 A 220 62 83 3F-18 02922684-00 08/11/96 04/15/09 SPINNER A/C SPLITS Monobore AC 291 1144 249 A 167 729 104 ConocoPhillips Kuparuk River Oil Pool ATTACHMENT KUPARUK RIVER OIL POOL CONSERVATION ORDER 432 RULE 9 — PRODUCTIVITY PROFILES ANNUAL 2009 SUBMITTAL WELL API DATE OF DATE OF DATA TYPE NUMBER NUMBER INITIAL PROFILE/ PROFILE/ WATER 50- PRODUCTION SURVEY SURVEY 3G-03 10320245-00 08/19/96 02/27/09 SPINNER 3G-18 10320142-00 02/22/94 06/30/09 SPINNER 3J-06 02921437-00 02/22/94 03/27/09 SPINNER 3N -02A 02921527-01 05/01/99 10/31/09 S`LT 200 A 23 >> Total PPROF Count for 2009 A/C SPLITS ConocoPhillips 2009 Reservoir Surveillance Report REASON FOR WELL ZONES PRODUCTION PROFILE/ COMPLETION PROD- OIL WATER GAS SURVEY TYPE UCING BOPD BWPD MSCFD A/C SPLITS Single AC 367 323 453 A 171 243 332 A/C SPLITS Single AC 360 747 200 A 360 747 200 A/C SPLITS Sel Single AC 208 251 62 A 125 148 39 OPEN C SANDS Sel Single AC 139 1169 0 A 124 336 0 Kuparuk River Oil Pool 2009 Reservoir Surveillance Report ATTACHMENT Kuparuk River Oil Pool 2009 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. ConocoPhillips Kuparuk River Oil Pool 2009 Reservoir Surveillance Report ConocoPhillips KUPARUK RIVER UNIT MI COMPOSITION: CPF-1 UNIT MI COMPOSITION: CPF-2 Date Facility CO2 N2 C1 C2 C3 iC4 nC4 iC5 nC5 C6 C7 C8+ MMP (Calc), psia 1/29/2009 CPF-1 0.815 0.204 57.052 6.276 5.365 3.632 8.780 4.603 5.541 3.917 2.439 1.376 3257 2/8/2009 CPF-1 0.778 0.226 58.867 5.650 4.543 2.989 7.089 6.841 8.334 2.064 1.597 1.022 3110 3/6/2009 CPF-1 0.804 0.217 58.261 5.864 4.825 3.287 7.847 6.147 7.500 2.577 1.638 1.033 3194 3/23/2009 CPF-1 0.848 0.274 66.242 5.877 4.525 2.912 7.091 3.819 4.545 1.774 1.318 0.775 3049 4/22/2009 CPF-1 1.004 0.323 77.564 6.654 4.994 0.000 0.000 4.361 5.100 0.000 0.000 0.000 3320 5/22/2009 CPF-1 2.654 0.285 61.402 8.724 3.680 2.315 7.417 4.450 5.246 1.879 1.286 0.662 3121 6/17/2009 CPF-1 0.890 0.411 70.601 5.935 4.096 2.498 6.181 2.784 3.357 1.531 1.106 0.610 3226 6/27/2009 CPF-1 0.945 0.517 1 64.761 5.486 1 4.176 2.654 1 7.071 4.729 1 5.402 1.960 1.472 0.827 3175 8/30/2009 CPF-1 0.844 0.264 66.481 6.034 4.539 2.426 1 6.519 3.960 4.858 1.813 1.414 0.848 3215 9/14/2009 CPF-1 -1 1.838 1 0.325 65.991 6.024 4.529 2.745 6.496 3.845 4.554 1.703 1 1.249 0.701 3351 9/26/2009 CPP 0.804 0.291 61.838 4.822 3.174 2.008 5.001 7.834 9.922 1.857 1.505 0.944 3121 11/27/2009 CPF-1 0.855 0.286 66.251 6.031 5.055 2.288 6.215 4.665 5.303 1.524 1.008 0.519 4010 12/5/2009 CPF-1 0.822 0.278 63.826 5.776 4.816 2.844 7.044 5.085 5.917 1.745 1.208 0.639 3009 12/20/200 CPF-1 0.838 0.286 66.420 6.053 5.081 2.682 6.418 4.414 4.992 1.396 0.932 0.488 3358 3179 12/5/2009 CPF-2 0.761 0.247 66.639 6.302 4.171 2.618 6.503 4.027 5.065 1.625 AVG 3251 3278 12/20/2009 CPF-2 0.657 0.203 58.723 6.281 4.822 1 2.502 7.429 6.020 7.711 MMP Target 3300 ConocoPhillips KUPARUK RIVER UNIT MI COMPOSITION: CPF-2 Date Facility CO2 N2 C1 C2 C3 iC4 nC4 iC5 nC5 C6 C7 C8+ MMP (Calc), psia 1/29/2009 CPF-2 0.733 0.170 57.232 7.151 5.918 3.704 8.972 4.638 5.621 2.716 2.001 1.144 2903 2/8/2009 CPF-2 0.771 0.295 66.239 6.669 4.848 2.655 6.188 3.495 4.268 2.509 1.251 0.812 3281 3/6/2009 CPF-2 0.749 0.199 61.782 7.063 5.504 3.180 7.636 4.220 5.058 1.995 1.555 1.059 3386 3/23/2009 CPF-2 0.798 0.238 67.785 6.839 4.993 2.722 6.640 3.133 3.805 1.376 1.045 0.626 3391 4/22/2009 CPF-2 0.815 0.247 72.720 7.402 5.343 3.376 0.000 3.930 4.855 0.577 0.457 0.278 2981 5/22/2009 CPF-2 6.238 0.173 55.058 15.567 5.586 2.151 6.303 2.379 2.996 1.622 1.210 0.717 3546 6/17/2009 CPF-2 4.435 0.605 59.982 11.077 5.516 2.496 6.862 2.543 3.119 1.514 1.178 0.673 3399 6/27/2009 CPF-2 0.761 1 0.247 1 67.165 6.445 1 4.527 2.477 1 6.608 3.634 1 4.531 1 1.555 1.266 1 0.784 3170 7/14/2009 CPF-2 0.802 1 0.342 1 80.596 5.616 3.301 1.274 3.263 1.795 1.979 1 0.556 0.349 0.127 3169 8/30/2009 CPF-2 1.021 0.430 67.767 5.633 4.014 2.205 5.919 3.673 4.411 2.096 1.781 1.050 3302 9/14/2009 CPF-2 2.329 0.263 65.324 8.045 4.789 2.831 6.735 2.891 3.541 1.456 1.126 0.670 3382 9/26/2009 CPF-2 0.818 0.316 80.987 6.228 3.455 1.329 3.065 1.393 1.583 0.423 0.288 0.115 3292 11/17/2009 CPF-2 0.886 0.239 66.407 6.576 4.843 2.342 6.173 4.123 4.679 1.972 1.130 0.630 3832 11/27/2009 CPF-2 0.752 0.246 67.681 6.448 4.387 2.470 6.241 3.824 4.733 1.433 1.120 0.665 3179 12/5/2009 CPF-2 0.761 0.247 66.639 6.302 4.171 2.618 6.503 4.027 5.065 1.625 1.280 0.762 3278 12/20/2009 CPF-2 0.657 0.203 58.723 6.281 4.822 1 2.502 7.429 6.020 7.711 2.435 1.985 1.232 2740 AVG MMP Target 3264 3300 ConocoPhillips Kuparuk Oil Pool 2009 Reservoir Surveillance Report ATTACHMENT Kuparuk River Oil Pool 2009 Annual Reservoir Surveillance Report LSEOR Development Plan During 2009, the Greater Kuparuk Area (GKA) averaged 18,391 BPD of PBU NGL imports and 9,237 BPD of indigenous NGLs for an annual average of 185 MMSCFD of Miscible Injectant (MI) manufacture. Of the total MI production in 2009, 125 MMSCFD was injected into the Kuparuk Field. Within the main Kuparuk Field, the 126 MMSCFD was allocated as: 14 MMSCFD for the SSEOR and SSEORX drillsites, 45 MMSCFD to the LSEOR drillsites and 67 MMSCFD to the LSEOR expansion drillsites. LSEOR expansion drillsites include drillsites: 1 B, 1C, 1 D, 1 E, 1 L, 313, 3G, 3H, 30, 3Q and 3S. Further drilling activity in the Kuparuk River Oil Pool potentially provides new opportunities to maximize field recovery while preventing physical waste. Drilling opportunities, along with their associated miscible gas EOR potential, are under constant evaluation as the field matures, geologic and reservoir performance information is assimilated and as technology improves. Although drillsite 1D is the only recent drillsite-level expansion project being sanctioned, the Kuparuk EOR project may be expanded to include any new wells. MWAG expansion to drillsite 1D was completed during 2008, as part of the LSEOR expansions. Very positive responses from the MI injection have been observed during 2009. ConocoPhillips ConocoPhillips March 31, 2010 Mr. Dan Seamount, Commissioner Alaska Oil and Gas Conservation Commission 333 West 71" Ave. Suite 100 Anchorage, Alaska 99501-3539 Re: Greater Kuparuk Area 2009 Shut-in Well Report Kuparuk, Meltwater, Tarn, Tabasco, and West Sak Oil Pools Dear Commissioner Seamount, James T. Rodgers Manager, GKA Development Greater Kuparuk Area ConocoPhillips Alaska, Inc. ATO -1326 PO Box 100360 Anchorage AK 99510-0360 Phone (907)263-4027 Fax: (907)265-6133 In compliance with AOGCC regulation 20 AAC 25.115(a), ConocoPhillips Alaska, Inc., as operator of the subject oil pools in the Greater Kuparuk Area, is hereby submitting the 2009 Shut-in Well Report for wells shut-in 365 days or longer during 2009. The attached document lists all wells in the Greater Kuparuk Area that were shut-in for 365 days or more during 2009. It also lists the reason the wells were shut-in, as well as the mechanical condition of the well and any future plans for the well. If you have any questions concerning this data, please contact Mark Kovar at 265-6097. Sincerely, T^ OS mes T. Rodgers Manager, GKA Development Greater Kuparuk Area Kuparuk River Oil Pool ATTACHMENT Greater Kuparuk Area 2009 Shut-in Well Report 2009 Reservoir Surveillance Report Well Well Type yPe Date Shut- In Reason Current Mechanical Condition Future Utility Plans ti Comments Shut -Int Possibilities 1A-07 WAG Apr -08 D Failed MITIA 11/13/09 3 Reservoir Management; Surface casing leak 1C-111 PROD Oct -08 E No known problem; Reservoir Survey 3 Reservoir Management 1C-125 WI Jun -08 E Rapid Injection Break through 3 Reservoir Management 1C-127 WI Dec -08 E Reservoir Pressure Survey 3 Reservoir Management IC -170 PROD Mar -07 E No known problems; Tubing pulled 11/05/07 2 Awaiting workover to install 2nd casing string. IC -22 PROD May -06 E No known problems; Passed 3 Reservoir Management MITIAIMITOA on 02/14/06 1D-114 WI Jun -08 D,E Downhole Impairment 3 Awaiting workover 1D-140 PROD Mar -08 D Mechanical Problems 3 ESP Trouble 1E-09 WI Feb -01 E No known problems; Passed MITIA 06/04/06 3 Well line corrosion; Well line removed 1E-11 WAG May -07 E No known problems; Passed MITIA on 2 Well line corrosion; Repairs Scheduled for 06/04/06 102010 1E-13 WAG Oct -01 E No known problems; Passed MITIA 3 Well line corrosion; Well line removed 06/04/06 1E-16 WAG Mar -00 E MITOA failed 9/17/05; MITIA Passed 3 Well line corrosion; Well line removed 06/04/06 1E-19 WAG Feb -98 E No known problems; Passed MITL4 3 Well line corrosion. Well line removed 06/04/06 1 E-26 PROD Mar -04 C, D, E Tbg x IA communication; Suspected 3 Well line corrosion Liner damage 1 E-35 PROD Apr -07 E No known problems; Passed MITIA on 2 Well line corrosion 06/04/06 1 F-08 PROD Jun -04 D Tbg x IA communication; IA x OA 3 No immediate plans; Under evaluation for communication. RWO OA x OCA Communication; Passed 1F-11 PROD May -01 D,E MITIA 06/05/04; Passed MITT 3 Well line corrosion; Shallow easing leak; No 06/16/04; Secured with TTP immediate plans 1F-16 PROD Apr -07 D Tbg x IA communication; Passed 1 OA high pressure pilot candidate; Sludge MITIA on 06/01/08 issues ConocoPhillips Kuparuk River Oil Pool 2009 Reservoir Surveillance Report Well Name Well Type yP Date Shut- In Reason Shut -Ing Current Mechanical Condition s Future Utility Plans & Possibilities Comments 1G-02 PROD Jun -04 E No known problems; Passed MITIA 07/15/07 2 Well line corrosion 1G-05 WAG Jan -08 E No known problems 3 Well line corrosion 1H-12 PROD Mar -07 E No known problems 3 Well line corrosion; no immediate plans 1 H-401 SUSP Aug -07 C No known problems 3 Well line disconnected 1 L-22 WAG Dec -08 E No known problems 3 Well line corrosion 1 L-23 PROD Mar -08 E Tbg x IA communication problems 3 Well line corrosion 1L-25 WI Dec -08 E Passed MITIA & MITOA on 10/06/05 3 Downhole impairment 1L-26 PROD Jan -08 E No known problems 3 Downhole Impairment; Long Term SI 10-01 PROD Dec -99 E No known problems; Passed MITIA 07/17/06 3 Reservoir Management; WI Well line corrosion 1Q-13 WAG Mar -07 E IA x OA communication; Passed MITIA on 07/17/06 3 WI Well line corrosion 10-14 WAG Aug -08 E No known problems 3 Well line corrosion 10-21 PROD Oct -03 B, D, E Tbg x IA communication. Well secured w rTP 3 Well line corrosion; Sidetrack/RWO Candidate 1R-06 WAG Ma -07 y E No known problems; Passed MITIA on 05/09/07 3 Well line corrosion; Repairs In Progress 1R-17 WAG Aug -08 E Well line corrosion 3 Well line corrosion 1R-20 PROD Jan -07 D Tbg x IA communication 1 Sidetrack/RWO Candidate; no immediate plans 1R-23 PROD Nov -07 E No known problems; Passed MITIA on 05/09/07 2 Awaiting piping modifications 1 R-25 PROD Oct -08 E No known problems 3 Well line corrosion 1 R-26 WAG Aug -08 E No known problems 3 Covert to Gas Injection 1 R-33 PROD Oct -07 E No known problems; Passed MITIA on 05/09/07 3 Well line corrosion; 1Y-08 WAG Apr -07 E Failed MITOA on 04/25/06; Passed MITIA on 07/17/06 1 Reservoir Management. 9 1Y-14 WI Oct -05 D Tbg x IA communication; Failed MITIA 10102/05; Passed MITOA 12/10/05 3 No identified immediate plans 1Y-15 WAG Jan -08 D Failed Well line 3 Well line corrosion 2A-01 PROD Jul -08 E No known problems 3 Well integrity 2A-22 PROD Nov -08 D Troubled Well 3 Downhole Impairment; Long Term SI 28-16 PROD Aug -08 D Tubing/casing problems 3 Downhole impairment ConocoPhillips Kuparuk River Oil Pool 2009 Reservoir Surveillance Report Well Name Well Type Date Shut- In Reason Shut-in' Current Mechanical Condition 2 Future Utility3 Plans & Possibilities Comments 2D-04 WAG Jun -08 E No known problems 3 Downhole impainnent 2D-14 ]WAG Oct -08 E No known problems 3 Change well material 2E-07 PROD Oct -94 C No known problems 3 No identified immediate plans 2E-09 PROD Nov -93 C No known problems 3 No identified immediate plans 2E-14 PROD Jul -06 E Tbg x IA Communication; Passed MITIA on 05/31/07 2 WI well line corrosion; Repairs In Progress 2F-13 WAG Oct -08 E No known problems 3 Change well material 2F-18 PROD Aug -08 D Mechanical Problems 3 Mechanical Problems Long term SI 2F-19 PROD Aug -07 C No known problems 3 No immediate plans 2F-20 PROD Jun -98 B Liner collapsed 3 No immediate plans 2G-13 PROD Oct -05 E Reservoir Control 3 Reservoir Management 2L -329A WAG Dec -06 E No known problems; Passed MITIA on 08/08/06 3 Reservoir Management 2M-18 WI Deo -99 D IA x OA communication; Passed MITOA on 01/18/08; Hole In 7" Casing at 7041' 3 No immediate plans 2N-332 PROD Feb -06 C No known problems; Passed MITT/MITIA on 0328106 3 No immediate plans 2N -337B WAG Oct -07 B No known problems; Passed MITIA on 04/14/07 3 No immediate plans 2N-350 PROD Dec -08 E No known problems 3 Reservoir Management 2P-419 WAG Jun -08 E No known problems 3 Reservoir Management 2P-434 WI Aug -07 E No known problems; Passed MITIA on 08/18/06 3 Low Injectivity 2P-438 PROD Sep -08 E No known problems 3 Low productivity 2P-451 PROD Aug -08 E No known problems 3 Downhole Impairment 2T -12A PROD Dec -07 E No known problems 3 Candidate for RWO 2T-204 PROD Oct -08 D ESP failure 3 ESP Trouble Long Term SI 2T-21 PROD Jun -03 D, E Tbg x IA communication; IA x Formation Communication; Failed CMIT 03/07/05; Secured w/TTP. 3 Well line corrosion 2T-210 PROD Jun -06 D Tubing/casing breach by CTU. Passed MITIA on D6/02/07 3 No immediate plans. 2T-36 WAG May -08 E I No known problems 3 Reservoir Management ConocoPhillips Kuparuk River Oil Pool 2009 Reservoir Surveillance Report ConocoPhillips Future Utility3 Well Name Well T Type Date Shut- In Reason Shut -Ing Current Mechanical Condition z Plans 8: Comments Possibilities 2T-37 WI Jul -07 B No known problems 3 No immediate plans 2T-38 PROD May -08 E No known problems 3 Low productivity 2U -07A WI Sep -07 E Tbg x IA communication; Passed 2 Well line corrosion MITIA on 08/18/06 21.1-11 WAG Jul -07 E SC leak; Passed MITIA on 12/22/08 2 Well line corrosion 2W-16 WAG May -08 D No known problems 3 Well line repair 2Z-03 PROD Apr -02 D, E Tbg x IA Communication; Failed MITIA 2 WI well line corrosion on 08/13/07 2Z-04 PROD Jun -06 E No known problems; Passed MITIA on 2 WI well line corrosion 08/13/07 2Z -OS PROD May -07 D IA x OA communication; Passed 2 Formation powered jet pump (FPJP) MITOA on 0627/05 candidate 2Z-09 WAG Jul -08 D No known problems 3 Well line repair 2Z-13 PROD Dec -08 D Tubing/casing problems 3 Downhole Impairment 2Z-14 PROD Aug -07 E No known problems; Passed MITIA on 2 WI well line corrosion 08/13107 Tbg x IA communication; IA x OA 2Z-16 PROD Mar -06 D,E communication; Passed MITIA on 3 WI well line corrosion 09/25/07 2Z-19 PROD Apr -07 B IA x OA communication; Passed 3 No immediate plans MITOA on 0823/05 2Z-22 PROD Aug -06 E No known problems; Passed MITIA on 2 WI well line corrosion 08/13/07 2Z-23 PROD Sep -06 E No known problems; Passed MITIA on 2 WI well line corrosion 08/13/07 3B-13 PROD Apr -08 D No known problems 3 Well line repair 36-14 PROD Jul -08 D ESP trouble 3 Candidate for RWO 36-16 WAG Aug -08 D No known problems 3 Well line repair 3C-05 WAG Dec -07 E No known problems; Passed MITIA on 2 Well line corrosion; Repairs Scheduled for 08/30/05 2010 Tbg x OA communication; Passed 3F -13A PROD Sep -05 D MITOOA 12/01/05; Well secured 3 No immediate plans w/TTP 3G -14A WAG Oct -03 C, E No known problems 3 Well line corrosion 3G -19A PROD Jul -05 C, D Possible Collapsed Csg 3 No immediate plans ConocoPhillips Kuparuk River Oil Pool 2009 Reservoir Surveillance Report Well Well Type Date Shut- Reason Current Mechanical Condition2 Future Utility Plans & Comments Name In Shut -In Possibilities 3G-23 WI Feb -03 E No known problems; Passed MITIA on 1 Reservoir Management 08/20/07 31-1-05 PROD Sep -08 E Downhole Optimization 3 Candidate for RWO 31-1-32 PROD Jul -07 D Tbg x IA communication; Failed CMIT 1 No immediate plans on 08/02/07 3J-09 WI Feb -08 D No known problems 3 Well line repair 3J-12 WI Jun -08 D No known problems 3 Well line repair 3K-18 WI Nov -07 E No known problems; Passed MITIA on 2 Well line corrosion; Repairs Scheduled for 05/21/05 2010 3K-25 WI Oct -07 E No known problems; Passed MITIA on 2 Well line corrosion; Repairs Scheduled for 07/01/06; Failed MITOA 07/01/06 2010 3M-11 WI May -06 y D IA x OA communication; Passed 3 No immediate plans MITOA on 02/27/06 3M-14 WI Au 06 9 C No known problems; Passed MITOA on 02119/06 3 No immediate plans; Evaluating for sidetrack 3M-18 WI Nov -02 D Tbg x IA x OA communication; Passed 3 No immediate plans mme MITIA 02/22/05 3M-29A PROD Oct -05 g No known problems; Passed CMIT x IA 3 No immediate plans 04/15/05 311-06 PROD May -07 D SC leak; IA x OA communication; Attempted brinker platelet repair on surface Failed MITOA 05/05/07 3 casing 1/26/09, unsuccessful. No immediate plans 30-19 WAG Jan -01 D Tbg x IA communication; Secured 3 No immediate plans W17TP 3Q-06 PROD Feb -06 D IA x OA communication; Passed MITT on 11/19/05 3 No immediate plans; Evaluating for sidetrack P 9 3R -11D WI Sep -00 E No known problems; Passed MITIA 3 Class II Disposal P 08/20/07 3R-15 WI Oct -07 E No known problems; Passed MITIA 2 Well line corrosion; Repairs Scheduled for 09/25/08 2010 3R-20 WI Jun -08 D No known problems 3 Well line repair 3S-15 PROD Oct -07 E No known problems 3 Low productivity CPF-1A DISP Jun -05 E No known pr Mems; 5 Passed MITIA 3 No Future Plans; Will not be used for injection CPF-2 DISP Aug -89 E No known problems; MITIA 01/22/04 3 No Future Plans; Will not be used for injection WSW -01 DISP Apr -83 D Tbg x IA Communication 3 No Future Plans; Will not be used for injection ConocoPhillips Kuparuk River Oil Pool 2009 Reservoir Surveillance Report Well Well T Type Date Shut- Reason Current Mechanical Condition' Future Utility Plans & Comments Name In Shut -In Possibilities WSW -02 DISP Mar -94 E No known problems; Passed MITIA 10/05/97 3 No Future Plans; Will not be used for injection 1 WSW -03 DISP Jul -01 E No known problems; Passed MITIA 10/05/97 3 No Future Plans; Will not be used for injection 1 WSW -04 DISP Aug -96 D Failed MITIA 0427/96 3 No Future Plans; Will not be used for injection WSW -05 DISP Jut -01 E No known problems; Passed MITIA 3 No Future Plans; OK for use with CPF1 10/30/06 Supervisor approval WSW -06 DISP Jul -94 E No known problems; Passed MITIA 10/05/97 3 No Future Plans; Will not be used for injection 1 WSW -07 DISP Jul -01 E No known problems; Passed MITIA 10/05/97 3 No Future Plans; Will not be used for injection WSW -08 DISP Oct -96 D Tbg x IA communication; Failed MITIA 0524/93 3 No Future Plans; Will not be used for injection WSW -09 DISP Oct -96 E No known problems; MITIA 10/30/06 3 No Future Plans; OK for use with CPF1 Supervisor approval WSW -10 OBS Apr -83 D Tbg x IA communication; Failed MITIA 3 No Future Plans; Will not be used for injection WSW -11 OBS Aug -92 E Tbg x IA Communication; Passed MITIA 10/05/97 3 No Future Plans; Will not be used for injection 1 (1) Reasons for Well Shut -In A. High Gas Oil Ratio, currently uncompetitive to produce due to facility constraints, no known mechanical problems B. High Water Oil Ratio, currently uneconomic to produce, no known mechanical problems C. Low production rate, no known mechanical problems D. Mechanical Problem E. Other (Specify under comments) (2) Current Mechanical Condition Briefly describe the current mechanical condition including the condition of installed tubing and casing strings. (3) Future Utility 1. Evaluating remedial, sidetrack and/or redrill opportunities 2. Remedial well work planned 3. Long term Shut-in well/ No immediate plans 4. Suspended well 5. P&A planned 6. Other (specified under comments) ConocoPhillips ConocoPhillips March 31, 2010 Mr. Dan Seamount, Commissioner Alaska Oil and Gas Conservation Commission 333 West 7h Ave. Suite 100 Anchorage, Alaska 99501-3539 Re: 2009 Meltwater Oil Pool Annual Reservoir Surveillance Report Dear Commissioner Seamount, James T. Rodgers Manager, GKA Development Greater Kuparuk Area ConocoPhillips Alaska, Inc. ATO -1326 PO Box 100360 Anchorage AK 99510-0360 Phone(907)263-4027 Fax: (907)265-6133 In compliance with Rule 10, Conservation Order No. 456, ConocoPhillips Alaska, Inc., operator of the Kuparuk River Field, is hereby submitting the annual surveillance report on the Meltwater Oil Pool. This report documents the required information pertinent to the field development and enhanced recovery operations from January through December 2009. The following is an outline of the information provided: a. Progress of EOR project and reservoir management summary (Attachment 1). b. Voidage balance, by month, for produced and injected fluids (Attachments 2 and 3). c. Analysis of reservoir pressure surveys taken in 2009 (Attachment 4). d. Results of production surveys, and any special surveys, taken on the Meltwater Oil Pool in 2009 (Attachment 5). e. Results of well allocation and test evaluation for Rule 7, and any other special monitoring (Attachment 6). f. Development Plan and Operation Review (Attachments 7 and 8). If you have any questions concerning this data, please contact Mark Kovar at (907) 265-6097. Sincerely, lj�x� Ili - James T. Rodgers Manager, GKA Development Greater Kuparuk Area ConocoPhillips Meltwater Oil Pool 2009 Reservoir Surveillance Report ATTACHMENT Meltwater Oil Pool 2009 Annual Reservoir Surveillance Report Summary of EOR Project and Reservoir Management Summary Background In 2001, CPAI received approvals for formation of the Meltwater Oil Pool in the Kuparuk River Unit, an Area Injection Order for Meltwater, expansion of the Kuparuk River Unit, and formation of the Meltwater Participating Area. The Meltwater Pool Rules and Area Injection Order were approved on August 1, 2001. The Unit Expansion and Participating area were approved effective June 1, 2001. Injection of miscible injectant (MI) began in January 2002 and the MWAG (miscible water alternating gas) process was implemented during May 2003. The Meltwater MWAG process uses Kuparuk spec MI which is injected above the minimum miscibility pressure. For compositional analysis of the Kuparuk spec MI, refer to the Kuparuk section of the annual surveillance report. The Meltwater field currently has 19 total wells (13 producers and 6 injectors). See Attachment 8 for well locations. Progress of EOR Project Development activities in 2009 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 2009: 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. ConocoPhillips expects to complete these studies by Q3 2010 and will update the AOGCC in Q4 2010. 2. Due to the high reservoir pressure and lack of clear interactions with offset producers well 2P-434 was shut in August 2007. In June 2008, two additional injection wells, 2P-419 and 2P-432, were shut in. In order to facilitate pressure reductions that would allow wells to 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. Well 2P-432 began flowback in February 2009 and plant constraints will dictate when the other injectors can commence flowbacks. Shut-in bottomhole pressure for this well was >4,000 psi as of January 2009. The initial flowrate for well 2P-432 was 3,000 BWPD with very small amounts of oil and gas. As of December 31, 2009, the water cut had decreased to approximately 95% with the total liquid rate still choked back to 3,000 BBUD. 3. A total of seven (7) producers are currently shut-in. Wells 2P-441, 213-448A and 2P-451 are shut- in due to insufficient pressure support (reservoir compartmentalization). Well 2P-438 suffered early water breakthrough in 2007 and was been shut in since then. Wells 2P-406, 2P-415 and 213- 443 were lifted via surface -powered jet pumps (SPJP) that utilized injection water as power fluid. These wells were shut in on October 15, 2009 when the water injection line to Meltwater was taken out of service (See point 1). Well 213-424A was also shut in for the same reason, but has been converted to gas lift service to restore production. Plans for 2010 include converting well 213- 406 from SPJP to gas lift in an attempt to restore its production. Well 213-415 was tested at less than 10 (ten) BOPD before it had to be shut in. This well cannot be produced economically at this point. Well 2P-443 has a history of severe paraffin deposition and freezing problems and it was converted from gas lift to SPJP in 2005 for that reason. A conversion of well 2L-443 back to gas ConocoPhillips Meltwater Oil Pool 2009 Reservoir Surveillance Report lift is not planned for 2010, but the conversion of this well will be evaluated after analyzing the performance of other wells on gas lift (2P -424A and 2P-406). 4. While most producer/injector patterns see fairly limited communication, producer 213-424A saw a relatively strong response beginning December 2008. This production response is suspected to be a result of offset gas injection into 2P427 which commenced in June 2008. This improved performance has been observed all throughout 2009. Early 2009, well 2P417 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 has been declining steadily since then. 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 in the form of lineaments that match the location of active injectors and trend in a NNW -SSE direction. This direction 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. As mentioned earlier in this document, a flowback from the injection 213-432 was started in February 2009 in an attempt to decrease reservoir pressures to levels at which sidetracks can 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 the year indicated no change in reservoir pressure. 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. The flowback well 2P-432 started producing increasing rates of oil and gas. The last pressure survey (December 22, 2009) showed that the pressure decreased approximately 400 psi after injection in well 2P-429 ceased. Proper understanding of these phenomena may enable additional development opportunities once the conditions to sidetrack wells and the compartmentalization of the reservoir are better understood. Seismic interpretations and reservoir modeling are ongoing at the time of this writing. 2. Outer annuli pressures in 2P-406, 2P-431, 2P-432, 2P-438, 2P-447, 2P -448A, and 2P-451 remained at elevated levels in 2009. Fluid levels continue to be shot monthly for all problem wells and the calculated pressures at the C-80 interval are still below the measured/calculated leak off (refer to table of elevated OA pressures in Meltwater -Attachment 6). Reservoir Management Summary Meltwater came on-line in November of 2001 and has cumulatively produced 14.1 MMBO, 2.07 MMBW, and 32.0 BCF of gas by year-end 2009. Miscible gas injection began in 2002 with water injection beginning in 2003 (MWAG cycles). Cumulative injection through year-end 2009 at Meltwater has been 25.1 MMBW and 43.2 BCF of gas (39.4 BCF of MI gas and 3.8 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 INV reached 1.0 and has been steadily climbing since. Despite ConocoPhillips Meltwater Oil Pool 2009 Reservoir Surveillance Report three injectors being taken off-line in 2008, instantaneous 1/W has remained above 2.0 for much of 2008. The cumulative year-end 2008 VW ratio increased to 1.3. While it would have been advantageous to continue decreasing injection at that time, a minimum amount of both gas and water had to be transported to Meltwater to maintain line velocities in order to minimize corrosion in the water line and freezing in the gas line. Despite these efforts, the water injection line to Meltwater had to be taken out of service on October 15, 2009 based on results obtained from a "smart pig" run and additional follow-up surveys completed during 2009. Currently, the plan is to balance voidage with gas injection until the studies to evaluate development alternatives for Meltwater are completed and implemented. (Refer to letter to AOGCC dated December 21, 2009). The cumulative year-end 2009 lfW ratio is 1.3. ConocoPhillips Meltwater Oil Pool 2009 Reservoir Surveillance Report ATTACHMENT Meltwater Oil Pool 2009 Annual Reservoir Surveillance Report Produced Fluid Volumes Cumulatives at Dec 31, 2008 13092875 30698002 1042078 Produced Fluid Volumes (Reservoir Units) OIL GAS WATER CUM OIL CUM GAS CUM WATER MO YR STB MSCF STB STB MSCF STB 1 2009 70770 93269 9622 13163645 30791271 1051700 2 2009 64150 69173 55890 13227795 30860444 1107590 3 2009 64543 69543 111892 13292338 30929987 1219482 4 2009 73252 57130 98226 13365590 30987117 1317708 5 2009 74439 66192 85980 13440029 31053309 1403688 6 2009 91504 132964 59050 13531533 31186273 1462738 7 2009 86607 118964 9680 13618140 31305237 1472418 8 2009 92220 150933 119716 13710360 31456170 1592134 9 2009 97820 144889 151701 13808180 31601059 1743835 10 2009 97704 133297 96635 13905884 31734356 1840470 11 2009 96924 106418 107972 14002808 31840774 1948442 12 2009 89571 163808 117850 14092379 32004582 2066292 2009 TOTAL 999504 1306580 1024214 Cumulatives at Dec 31, 2008 13092875 30698002 1042078 Produced Fluid Volumes (Reservoir Units) 2009 TOTAL 1334338 ConocoPhillips 551109 1038553 Cumulatives at Dec 31, 2008 17437675 21154313 1050924 OIL GAS WATER CUM OIL CUM GAS CUM WATER MO YR RVB RVB RVB RVB RVB RVB 1 2009 94478 39627 9757 17532153 21193940 1060681 2 2009 85640 23623 56672 17617794 21217562 1117353 3 2009 86165 23724 113458 17703958 21241287 1230812 4 2009 97791 9488 99601 17801750 21250775 1330413 5 2009 99376 16151 87184 17901126 21266926 1417597 6 2009 122158 61132 59877 18023284 21328057 1477473 7 2009 115620 52353 9816 18138904 21380410 1487289 8 2009 123114 75153 121392 18262018 21455563 1608681 9 2009 130590 67549 153825 18392607 21523112 1762506 10 2009 130435 58333 97988 18523042 21581445 1860494 11 2009 129394 37215 109484 18652436 21618660 1969977 12 2009 119577 86762 119500 18772013 21705422 2089477 2009 TOTAL 1334338 ConocoPhillips 551109 1038553 Cumulatives at Dec 31, 2008 17437675 21154313 1050924 Meltwater Oil Pool 2009 Reservoir Surveillance Report ATTACHMENT Meltwater Oil Pool 2009 Annual Reservoir Surveillance Report Injected Fluid Volumes 2009 TOTAL 1844889 290993 3503717 Cumulatives at Dec 31, 2008 23291561 3530929 35895844 Injected Fluid Volumes (Reservoir Units) WATER GAS MI CUM WATER CUM GAS CUM MI MO YR STB MSCF MSCF STB MSCF MSCF 1 2009 221142 0 291775 23512703 3530929 36187619 2 2009 195694 0 284670 23708397 3530929 36472289 3 2009 212086 0 332204 23920483 3530929 36804493 4 2009 195041 0 294454 24115624 3530929 37098947 5 2009 202066 73425 195951 24317590 3604354 37294898 6 2009 170934 0 255613 24488524 3604354 37550511 7 2009 169536 0 293255 24658060 3604364 37843766 8 2009 210689 217568 75593 24868749 3821922 37919359 9 2009 185620 0 299784 25054369 3821922 38219143 10 2009 82081 0 393756 25136450 3821922 38612899 11 2009 0 0 403740 25136450 3821922 39016639 12 2009 0 0 382922 26136450 3821922 39399561 2009 TOTAL 1844889 290993 3503717 Cumulatives at Dec 31, 2008 23291561 3530929 35895844 Injected Fluid Volumes (Reservoir Units) Cumulatives at Dec 31, 2008 23617643 4259787 31144183 ConocoPhillips WATER GAS MI CUM WATER CUM GAS CUM MI MO YR RVB RVB RVB RVB RVB RVB 1 2009 224238 0 233420 23841881 4259787 31377603 2 2009 198434 0 227736 24040315 4259787 31605339 3 2009 215055 0 265763 24255370 4259787 31871102 4 2009 197772 0 235563 24453141 4259787 32106665 5 2009 204895 81428 156761 24658036 4341216 32263426 6 2009 173327 0 204490 24831363 4341216 32467916 7 2009 171910 0 234604 25003273 4341216 32702520 8 2009 213639 241283 60474 25216911 4582498 32762995 9 2009 188219 0 239827 25405130 4582498 33002822 10 2009 83230 0 315005 25488360 4582498 33317827 11 2009 0 0 322992 25488360 4582498 33640819 12 2009 0 0 306338 25488360 4582498 33947156 2009 TOTAL 1870717 322711 2802974 Cumulatives at Dec 31, 2008 23617643 4259787 31144183 ConocoPhillips Meltwater Oil Pool ATTACHMENT 2009 Reservoir Surveillance Report Meltwater Oil Pool 2009 Annual Reservoir Surveillance Report Reservoir Pressure Surveys ConocoPhillips ConocoPhillips March 31, 2010 Mr. Dan Seamount, Commissioner Alaska Oil and Gas Conservation Commission 333 West 71' Ave. Suite 100 Anchorage, Alaska 99501-3539 Re: Meltwater Oil Pool — Proposed Pressure Survey Plan for 2010 James T. Rodgers Manager, GKA Development Greater Kuparuk Area ConocoPhillips Alaska, Inc. ATO -1326 PO Box 100360 Anchorage AK 99510-0360 Phone(907)263-4027 Fax: (907)265-6133 Dear Commissioner Seamount, In compliance with Rule 7, Conservation Order No. 456A, ConocoPhillips Alaska, Inc., operator of the Meltwater Oil Pool, is hereby submitting the proposed pressure survey plan for 2010. There were 17 pressure surveys reported for the Meltwater Oil Pool to the AOGCC in 2009. In 2010, we expect to conduct approximately 12 pressure surveys, including regularly scheduled surveys to assess the progress of injector flowbacks currently underway. If you have any questions concerning this data, please contact Mark Kovar at (907) 265-6097. Sincerely, ames T. Rodgers Manager, GKA Development Greater Kuparuk Area ConocoPhillips Meltwater Oil Pool 2009 Reservoir Surveillance Report ConocoPhillips STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION RESERVOIR PRESSURE REPORT 1. Operator conoctsPhillips Alaska Inc. 2. Address: P.O. Box 100360. Anchomao. AK 99510-0360 3. Unit or Lase Nam.: K amk River Unit 4. Field and pool: Meltwater Oil Pool 5. Datum Reference: 45400 SS fie Oil Gnmly: 0.85 Nester =1.00.74 7. Gas Gravity: 8. Well Name and Number 9. API Number S0� NO DASHES 10. Type Sea Instmctlons 11. AOGCC Pool Cod. 12. Zone 13. Penoratsd Intervale Tap - Bottom TVDSS 14. Fine! Test Date 15. Shut-in 16. one". Time. Hours Sum. Type (see instrudlonsfor codes) 17. B.H. Tamp, 18. Depth Tool 19. Final TVDSS Observed Pressure at Tool Depth 20. Datum WOES Mput) 21. Pressure Grealenl. psu8. 22. Prossuro st Datum (cap 2P406 50103204840000 0 490140 A 121112009 1281 SBHP 137 5346 1638 5400 0.081 1642 2P415A 501032038301DD 0 490140 A Bre2009 72 SBHP 141 5431 725 5400 0.33 715 2P417 5010320375000D 0 490140 A 122009 72 S8HP 130 5235 920 540D 0.32 973 2P419 1501032048300DO O 1490140 A I 12212009 13550 ISBIHP 128 14948 3606 15400 0.32 3751 21"429 50103203780000 O 490140 A 5182009 72 SBHP 122 5109 4096 5400 0.4 4212 2P429 50103203780000 O 490140 A 7272009 109 SBHP 126 5109 4116 5400 0.32 4209 2P429 50103203780000 0 490140 A 12/222509 1584 SBHP 129 5109 3674 5400 0.44 3802 2P432 50103204200000 O 490140 A 113112009 5650 SBHP 122 5248 4317 5400 0.32 4365 2P-032 W10320420D000 O 490140 A 58.2009 96 SBHP 128 5248 4160 5400 0.4 4221 21`432 ISMOMN201=0 O 490140 A 7252009 850 SBHP 131 5248 4185 5400 0.32 4230 2P434 50103204670000 0 490140 A 1202009 12700 SBHP 127 15025 4216 5400 0.32 43W 2P434 50103204670000 0 490140 A 5/92050 15216 SBHP 129 5025 4070 5400 0.368 4208 2P434 50103204670000 0 490140 A 7252009 83DD SBHP 129 5025 4091 5400 0.32 14211 2P434 50103204670000 0 490140 A 12122/2009 20698 SBHP 128 5025 3661 5400 0.33 3785 2P447 50103204680000 0 490140 A 12/202009 1565 SBHP 126 5064 W97 5400 0.43 4033 2P451 50103204020000 0 490140 IA SWIX)9 6646 SBHP 129 5106 12778 5400 0.4 2895 2P451 50103204020000 O 1490140 A 7252009 1850 ISBHp 132 5106 2779 lum 0.32 2873 23. All tests reported horem ware made In accardenco with the applicable Mies. regulations and Instructions of the Alaska 011 and Gas Conservation Commission. I honesty comity that the forego m and cemacl to Its my k edge. Signature TIOe Pdnlsa Name ,f _ �J Dale {� /r :5 ((�� . % '!/.�/�J✓J �Y11'/IA ;,0CY14CI /' ConocoPhillips Meltwater Oil Pool Meltwater Perforated Intervals and Stratigraphic Zones WELL NAME PERF TOP SS PERF BTM SS ZONE 2P-406 -5338 -5353 A 2P -415A -5431 -5440 A 2P-417 -5228 -5248 A 2P-419 -5275 -5285 A 2P-419 -5224 -5242 A 2P-419 -5215 -5224 A 2P-419 -5102 -5119 A 2P-419 -5087 -5096 A 2P -424A -5388 -5392 A 2P-429 -5481 -5487 A 2P-429 -5433 -5447 A 2P-429 -5419 -5433 A 2P-429 -5384 -5398 A 2P-429 -5370 -5384 A 2P-429 -5298 -5335 A 2P-432 -5236 -5255 A 2P-432 -5210 -5229 A 2P-432 -5266 -5287 A 2P-434 -5114 -5118 A 2P-434 -5106 -5109 A 2P-434 -5045 -5098 A 2P-441 -5266 -5273 A 2P-447 -5167 -5178 A 2P-447 -5124 -5167 A 2P-447 -5073 -5094 A 2P-451 -5113 -5129 A ConocoPhillips 2009 Reservoir Surveillance Report Meltwater Oil Pool 2009 Reservoir Surveillance Report ATTACHMENT Meltwater Oil Pool 2009 Annual Reservoir Surveillance Report Production & Special Surveys During 2009, no production/injection profile logs or special surveillance logs were run. No special surveillance logs are planned to be run in 2010. ConocoPhillips Meltwater Oil Pool 2009 Reservoir Surveillance Report ATTACHMENT Meltwater Oil Pool 2009 Annual Reservoir Surveillance Report Results of Well Allocation, Test Evaluation, and Special Monitoring Well Allocation Meltwater D82P 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 DS2P. 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 2009 Meltwater allocation factors by month are listed below. Shallow Gas Special Monitoring Wells 2P-406, 213-431, 2P432, 2P-434, 2P-438, 2P441, 2P447, 213-448A and 2P-451 have a history of elevated outer annulus (OA) pressures that may rebuild pressure after bleeding. The surface pressures are monitored daily via SetCIM (wells have pressure transducers that transmit real-time OA pressures). Fluid levels are surveyed approximately once per month via echometer measurements. Calculations are then made to determine the approximate pressures in the outer annulus at the C-80 interval in each of the wells that have elevated surface OA pressures. This data is then sent to the AOGCC on a quarterly basis. (See table on following page). Throughout 2009 most wells exhibited relatively stable OA pressures with the exception of 2P-434 and 213- 438 which experienced gradual decreasing OA pressures. While there appears to be a connection between the cessation of injection in these wells and declining OA pressures, OAP and injection rates do not match up in time. Therefore, there is inconclusive evidence to say there is a relationship between the two. The OA pressure of well 213-434 has declined to less than 150 psig at surface since cessation of injection into this well in August 2007. ConocoPhillips Oil Gas Water Jan -09 0.8610968 1.0202903 0.9671290 Feb -09 0.8691071 1.0018929 0.9378929 Mar -09 0.8660323 1.0075161 0.9483226 Apr -09 0.8550667 0.9962333 0.9486333 May -09 0.8507419 1.0132903 0.9394839 Jun -09 0.9377333 1.0258667 0.9343333 Jul -09 0.9154194 1.0190000 0.9549355 Aug -09 0.9157419 1.0521290 0.9497097 Sep -09 0.9202000 1.0371000 0.9786000 Oct -09 0.8802903 1.0168710 0.9820000 Nov -09 0.8217000 1.0409000 1.0031333 Dec -09 0.8796452 1.0691613 0.9851935 Shallow Gas Special Monitoring Wells 2P-406, 213-431, 2P432, 2P-434, 2P-438, 2P441, 2P447, 213-448A and 2P-451 have a history of elevated outer annulus (OA) pressures that may rebuild pressure after bleeding. The surface pressures are monitored daily via SetCIM (wells have pressure transducers that transmit real-time OA pressures). Fluid levels are surveyed approximately once per month via echometer measurements. Calculations are then made to determine the approximate pressures in the outer annulus at the C-80 interval in each of the wells that have elevated surface OA pressures. This data is then sent to the AOGCC on a quarterly basis. (See table on following page). Throughout 2009 most wells exhibited relatively stable OA pressures with the exception of 2P-434 and 213- 438 which experienced gradual decreasing OA pressures. While there appears to be a connection between the cessation of injection in these wells and declining OA pressures, OAP and injection rates do not match up in time. Therefore, there is inconclusive evidence to say there is a relationship between the two. The OA pressure of well 213-434 has declined to less than 150 psig at surface since cessation of injection into this well in August 2007. ConocoPhillips Meltwater Oil Pool Meltwater OA pressure survey for 2009 2009 Reservoir Surveillance Report Date 2P-406 2P431 2P432 2P434 Surf. Press (Psig) OA FL (Nd from surf) Press C C- 80 Top Equiv. Mud VA (Ppg) Surf, Press (psig) OA FL (Nd from surf) Press ® G 80 Top Equiv. Mud wt (PDB) Surf. Press (pslg) OA FL (Ivd from surf) Press Q C- 80 Top Equiv. Mud wt (ppg) Surf. Press (psig) OA FL (tw from sura Press e C- 80 Top Equiv. Mud wt (Ppg) SFeb-09 468 1.738 681 5.26 1,542 2.417 1.682 13.31 666 7,909 829 6.55 258 2.918 160 1.26 3 -Mar -09 531 894 940 7.26 1.528 2.427 1,665 13.17 1.515 1.631 1,762 13.92 243 1.377 555 4.34 6 -Apr -09 455 847 885 6.84 1.536 2.436 1,674 13.24 1.432 1,759 1.657 13.09 222 1,418 525 4.11 5 -Ma 710 835 1,116 8.62 1,492 2,451 1,623 12.84 1.401 1.698 1,633 12.90 208 1,377 523 4.09 8Jun-09 685 406 1.195 9.15 1.548 2.417 1,688 13.36 1,512 2.479 1,397 17.04 192 1,264 540 4.23 4JuW9 687 782 1.105 8.54 1.544 2,417 1,684 13.32 1,435 1,982 1,626 12.85 1S0 1.611 434 3.40 7 -Au 673 776 1,093 8.44 1,523 2,433 1,659 13.12 1.526 2.299 1.681 13.28 171 1,222 532 4.17 3 -Sep -09 686 729 1 16 8.62 1.530 2.442 1.667 13.19 1,422 2,343 1,560 12.32 164 1,169 541 4.24 6-0ct-09 684 688 1,123 8.68 669 1,913 1,245 9.85 1.4031 2,327 1 1.5411 12.171 1541 1,127 544 4.26 10 -Nov -09 646 6291 1,101 1 8.51 1 1.5401 2.3991 1.6831 13.31 1 1.3791 2.2771 1,522 1 12.031 1461 1,0851 548 4.29 10 -Dec -09 6LO4921 1.518 1,171 1 9.051 1.5351 2A171 1.6751 13.251 1.3391 2.2431 1.4831 11.721 1401 9721 574 4.50 15Jan-10 7241 420 1 1.2171 9.41 1 1,5331 2,424 1 1,6731 13.231 1,2791 2.1821 1.4271 11.271 1331 1,002 1 560 4.39 Date 2P-438 2P441 2P -448A 2P451 Surf. Press (psig) OA FL (Nd from surf) Press Q C- 60 Top EquN. Mud wt (Ppg) Surf. Press (pslg) OA FL (Nd from surf) Press @ C- 80 Top Equiv. Mud Wl (ppg) Sud, Press WSW OA FL (Ivd from surf) Press @ C- 80 Top Equiv. Mud Wt On) Surf. Press (psig) OA FL (tvd from surf) Press Q C. 80 Top Equiv. Mud wt (PPO) SFeb-09 993 1,529 1.238 9.78 967 1,862 1,152 9.07 1.315 2.492 1,418 11.21 1,018 2.315 1,114 8.84 3 -Mar -09 989 1.524 1.236 9.76 986 1,826 1,177 9.27 1,400 2.430 1,522 12.03 1,009 1,964 1,169 9.28 6 -Apr -09 977 1,540 1,221 9.64 993 1,903 1,169 9.20 1,289 2.501 1.385 10.95 1,000 2.332 1,090 8.65 S -09 971 1.497 1.223 9.66 1,023 1,872 1,206 9.49 1,298 2.446 1.405 11.11 999 2,315 1.092 8.97 8Jun09 959 1,529 1,206 9.52 1.013 1.888 1,193 9.39 1,295 2.479 1,397 17.04 995 2,286 1,094 8.68 4JuW9 950 1,529 1,198 9.46 1,029 1,903 1,206 9.50 1,295 2,492 1,395 11.03 989 2.303 1,085 8.61 7 -Aug -09 933 1.529 1.181 9.33 1,021 1,913 1,196 9.42 1.297 2,485 1,398 11.05 983 2.303 1,079 8.56 3-S 922 1,518 1,173 9.26 1,013 1.943 1,183 9.31 1,298 2.492 1,398 11.05 980 2,303 1.076 8.54 6-041-09 908 1,578 1,760 9.76 931 1,913 1,107 8.71 7,301 2.951 7,328 10.49 972 2.298 1,069 8.48 10-09 892 1,524 1,163 9.02 7,000 7,908 1,775 9.25 7,308 2,498 1,407 77.72 977 2,303 7,073 8.51 10 -Dec -09 883 1.518 1,136 8.97 998 1,913 1,172 9.23 1,306 2,482 1,406 11.17 969 2,303 1,065 8.45 1Sao-10 873 1,518 7,726 8.89 1,012 1,933 1,184 9.32 1,304 2,472 1,407 11.12 962 2,292 1,060 8.41 ConocoPhillips Meltwater Oil Pool 2009 Reservoir Surveillance Report ATTACHMENT Meltwater Oil Pool 2009 Annual Reservoir Surveillance Report Meltwater Development Plan and Operational Review Following are summaries of key activities that are planned for 2010 and subsequent years. Development Drilling Development opportunities are being analyzed in the light of the new seismic data, recent surveillance findings and the absence of injection water supply. Digital processing of the 2007-2008 winter seismic survey is complete and the data is being analyzed. This data will help in evaluating the potential of the peripheral edges of the Meltwater pool, analyzing producer -injector patterns, and identifying infill drilling potential. In preparation for the potential CTD sidetracks, three injectors (213419, 213432 and 2P-434) have been taken off-line. 213-432 began flowback operations in February 2009 to decrease the elevated reservoir pressures in this portion of the reservoir. This will make potential CTD sidetrack operations safer. Further flowbacks will be started based on results from 2P-432 and operational constraints (processing facility impacts). Pipeline Operations Due to low flow rates through the water injection line, there has been awareness of increased risk for microbial -induced under -deposit corrosion and increased diagnostic work was being conducted. Frequent pigging of the production and water injection lines was conducted to minimize effects of under -deposit corrosion. Despite these efforts the water injection line had to be taken out of service on October 15, 2009, due to operational constraints caused by areas of excessive under -deposit corrosion pitting. Exploration/Delineation No further exploration work is currently planned for the Bermuda interval. However, the overlying Cairn sand, believed to be gas bearing, had been targeted for 2009 development in order to supply fuel gas to the Kuparuk facilities. Pre -drill engineering assessments determined that probable volumes accessible from the 2P pad were insufficient for economic development at this time. ConocoPhillips Meltwater Oil Pool 2009 Reservoir Surveillance Report ATTACHMENT Meltwater Oil Pool 2009 Annual Reservoir Surveillance Report Map showing Development as of December 31, 2009 51 7P -"44H 2P-448 2P'448A_ 2P-422 2P-441 �. 0.9 2P 438 2P=42 - ConocoPhillips s Disposal Well Z IWAG MWAG Inj: 5WJPW \-_ Oil Producer + P+A \� \ �� \14p- f Suspended 22 j2P-424 ConocoPhillips James T., Rodgers Manager, GKA Development Greater Kuparuk Area ConocoPhillips Alaska, Inc. ATO -1326 PO Box 100360 Anchorage AK 99510-0360 Phone(907)263-4027 Fax: (907)265-6133 March 31, 2010 Mr. Dan Seamount, Commissioner Alaska Oil and Gas Conservation Commission 333 West 7s' Ave. Suite 100 Anchorage, Alaska 99501-3539 Re: 2009 Tabasco Oil Pool Annual Reservoir Surveillance Report Dear Commissioner Seamount, In compliance with Rule 11, Conservation Order No. 435, ConocoPhillips Alaska, Inc., operator of the Kuparuk River Field, is hereby submitting the annual surveillance report on the Tabasco Oil Pool. This report documents the required information pertinent to the field development and enhanced recovery operations from January through December 2009. The following is an outline of the information provided: a. A summary of the enhanced recovery project (Attachment 1). b. Voidage balance, by month, for produced and injected fluids (Attachments 2 and 3). c. Analysis of reservoir pressure surveys taken in 2009 (Attachment 4). d. Results of production surveys, and any special surveys, taken on the Tabasco Oil Pool in 2009 (Attachment 5). e. Results of well allocation and test evaluation for Rule 7, and any other special monitoring (Attachment 6). f. Future development plans (Attachment 7). If you have any questions concerning this data, please contact Mark Kovar at (907) 265-6097. Sincerely, PAO James T. Rodgers Manager, GKA Development Greater Kuparuk Area Tabasco Oil Pool 2009 Reservoir Surveillance Report ATTACHMENT Tabasco Oil Pool 2009 Annual Reservoir Surveillance Report Summary of the Enhanced Recovery Project Tabasco produced 704 MBO of crude, 94 MMSCF of gas, and 5972 MBW during 2009. Water injection was 7493 MBW over the same period. Cumulative oil, gas, water production, and water injection through year end 2009 were 15.6 MMBO, 2.6 BCF, 60.5 MMBW, and 70.5 MMBWI, respectively. The cumulative year-end 2009 I/W ratio, based on current FVFs, is estimated at 0.90 for Tabasco. ➢ Producer 2T-208 began producing in May 2009 after the rig workover to replace the tubing retrievable ESP with a tubing retrievable PCP. ➢ A rig workover was completed in March 2009 on producer 2T-220 to replace the ESP. The equipment was not run in the hole properly; therefore, a patch had to be set to isolate the IA from the tubing. The patch or the tubing appears to be leaking. More diagnostic work is being done to determine the leak point. Currently, a plan forward is being worked to get the well back on production. ➢ Injector 2T -217A was shut-in July 2009 for injection management and to control water breakthrough in offset producers. ➢ Producer 2T-209 was shut-in in July 2009 for water flood management. ➢ The full field model for Tabasco has been used to optimize waterflood strategy and explore development options. ➢ 2T-204 is not scheduled for a rig workover due to challenging economics in the current price environment. Year end 2009 Tabasco well count (all at Kuparuk River Unit Drill Site 2T) was: Producers: 9 completed 5 on line Injectors: 3 completed 1 on line The water oil ratio (WOR) was 6.9 at the end of 2009 compared to 7.1 at the end of 2008. 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. Pending leak diagnostics on the patch, attempts will be made to restart production from producer 2T-220 in 1Q 2010. The full field model for Tabasco will continue to be used in 2010 to optimize waterflood strategy and explore development options. ConocoPhillips Tabasco Oil Pool 2009 Reservoir Surveillance Report ATTACHMENT 2 Tabasco Oil Pool 2009 Annual Reservoir Surveillance Report Produced Fluid Volumes Cumulatives at Dec 31, 2008 14898947 2496823 54557564 Produced Fluid Volumes (Reservoir Units) OIL GAS WATER CUM OIL CUM GAS CUM WATER MO YR STB MSCF STB STB MSCF STB 1 2009 69340 8343 634008 14968287 2505166 55191572 2 2009 57271 8003 601520 15025558 2513169 55793092 3 2009 49355 7421 639313 15074913 2520590 56432405 4 2009 50652 7748 654848 15125565 2528338 57087253 5 2009 55414 8007 694862 15180979 2536345 57782115 6 2009 46760 6056 429506 15227739 2542401 58211621 7 2009 37981 5216 184023 15265720 2547617 58395644 8 2009 73042 9333 430374 15338762 2556950 58826018 9 2009 70487 9172 409339 15409249 2566122 59235357 10 2009 71149 8862 431339 15480398 2574984 59666696 11 2009 58959 7427 422286 15539357 2582411 60088982 12 2009 63626 8719 440697 15602983 2591130 60529679 2009 TOTAL 704036 94307 5972115 Cumulatives at Dec 31, 2008 14898947 2496823 54557564 Produced Fluid Volumes (Reservoir Units) Cumulatives at Dec 31, 2008 15773681 76165 54557564 ConocoPhillips OIL GAS WATER CUM OIL CUM GAS CUM WATER MO YR RVB RVB RVB RVB RVB RVB 1 2009 72807 0 634008 15846488 76165 55191572 2 2009 60135 0 601520 15906623 76165 55793092 3 2009 51823 0 639313 15958445 76165 56432405 4 2009 53185 0 654848 16011630 76165 57087253 5 2009 58185 0 694862 16069815 76165 57782115 6 2009 49098 0 429506 16118913 76165 58211621 7 2009 39880 0 184023 16158793 76165 58395644 8 2009 76694 0 430374 16235487 76165 58826018 9 2009 74011 0 409339 16309498 76165 59235357 10 2009 74706 0 431339 16384205 76165 59666696 11 2009 61907 0 422286 16446112 76165 60088982 12 2009 66807 0 440697 16512919 76165 60529679 2009 TOTAL 739238 0 5972115 Cumulatives at Dec 31, 2008 15773681 76165 54557564 ConocoPhillips Tabasco Oil Pool 2009 Reservoir Surveillance Report ATTACHMENT 3 Tabasco Oil Pool 2009 Annual Reservoir Surveillance Report Injected Fluid Volumes WATER MO YR STB 1 2009 692429 2 2009 704257 3 2009 782358 4 2009 641456 5 2009 863578 6 2009 806308 7 2009 620645 8 2009 485793 9 2009 432996 10 2009 502590 11 2009 469035 12 2009 471407 2009 TOTAL 7472852 GAS MI CUM WATER CUM GAS CUM MI MSCF MSCF STB MSCF MSCF 0 0 63716810 0 0 0 0 64421067 0 0 0 0 65203425 0 0 0 0 65844881 0 0 0 0 66708459 0 0 0 0 67514767 0 0 0 0 68135412 0 0 0 0 68621205 0 0 0 0 69054201 0 0 0 0 69556791 0 0 0 0 70025826 0 0 0 0 70497233 0 0 0 0 Cumulatives at Dec 31, 2008 63024381 0 0 Injected Fluid Volumes (Reservoir Units) Cumulatives at Dec 31, 2008 63024381 0 0 ConocoPhillips WATER GAS MI CUM WATER CUM GAS CUM MI MO YR RVB RVB RVB RVB RVB RVB 1 2009 692429 0 0 63716810 0 0 2 2009 704257 0 0 64421067 0 0 3 2009 782358 0 0 65203425 0 0 4 2009 641456 0 0 65844881 0 0 5 2009 863578 0 0 66708459 0 0 6 2009 806308 0 0 67514767 0 0 7 2009 620645 0 0 68135412 0 0 8 2009 485793 0 0 68621205 0 0 9 2009 432996 0 0 69054201 0 0 10 2009 502590 0 0 69556791 0 0 11 2009 469035 0 0 70025826 0 0 12 2009 471407 0 0 70497233 0 0 2009 TOTAL 7472852 0 0 Cumulatives at Dec 31, 2008 63024381 0 0 ConocoPhillips Tabasco Oil Pool ATTACHMENT 4 2009 Reservoir Surveillance Report Tabasco Oil Pool 2009 Annual Reservoir Surveillance Report Reservoir Pressure Surveys ConocoPhillips ConocoPhillips March 31, 2010 Mr. Dan Seamount, Commissioner Alaska Oil and Gas Conservation Commission 333 West 71h Ave. Suite 100 Anchorage, Alaska 99501-3539 Re: Tabasco Oil Pool — Proposed Pressure Survey Plan for 2010 James T. Rodgers Manager, GKA Development Greater Kuparuk Area ConocoPhillips Alaska, Inc. ATO -1326 PO Box 100360 Anchorage AK 99510-0360 Phone(907)263-4027 Fax: (907)265-6133 Dear Commissioner Seamount, In compliance with Rule 8, Conservation Order No. 435A, ConocoPhillips Alaska, Inc., operator of the Tabasco Oil Pool, is hereby submitting the proposed pressure survey plan for 2010. There were four pressure surveys reported for the Tabasco Oil Pool to the AOGCC in 2009. No formal pressure surveys are scheduled for 2010, though surveys may be conducted using ESP pressure gauges should any well be shut in for an extended period. If you have any questions concerning this data, please contact Mark Kovar at (907) 265-6097. Sincerely, James T. Rodgers Manager, GKA Development Greater Kuparuk Area Tabasco Oil Pool 2009 Reservoir Surveillance Report STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION RESERVOIR PRESSURE REPORT 1. Operator: ConowPhllll s Alaska Inc. 2. Address: P. O. Bax 100360, Anchora e. AK 99510-0360 3. Unit or Lease Noma: Ku aruk River Unit 4. Field and Pool: Tabasco Oil Pool 5. Datum Reference: -3000' SS 6. Oil Gravity: 0.96 water = 1.0 7. Gas Gravity: 0.572 8. Well Name and 9. API Number 10. Type 11. AOGCC 12. Zone 13. Perforated 14, Final Test Number So%%KK%%KXX%XX Sea Pool Coca Intorvals Date NO DASHES Instructions Top - Bottom TVDSS 15. Shut -In 16, Press. 17. B.H. Time, Hours Surv. Type Temp, (see Instructions for codes) 18. Depth Tool 19, Final TVOSS Observed Pressure at Tool Depth 20. Datum TVDSS (input) 21. Pressure Gradient, psil8. 22. Pressure al Datum (Cal) 2T-202 501032025400 O 490160 A 6/26/2009 140 SBHP 85 2607 1208 3000 .40 1365 2T-209 501032028100 O 490160 A 7/18/2009 696 SBHP 81 2709 1247 13000 .43 1372 2T-218 501032044900 O 490160 A 7/10/2009 520 SBHP 67 2838 1319 3000 .45 1392 2T-220 501032028300 O 490160 A 7/27/2009 480 SBHP 66 2761 1279 3000 .43 11382 23. All tests reported herein were made in accordance with the applicable rules, regulations and instructions of the Alaska Oil and Gas Conservation Commission. I hereby certify that atu the for in s true and c0 est of77 /k�nowledge. �n ` L Signature 1 k u— Title Y ` ,,, r/1� pep - OM Pn.f ' iMPne.'w��- Printed Name J/'-�" P -J Date ConocoPhillips Tabasco Oil Pool Tabasco Perforated Intervals and Stratigraphic Zones WELL NAME PERF TOP SS PERF BTM SS ZONE 2T-202 -2994.60 -3270.30 A 2T-209 -2940.60 -3276.10 A 2T-218 -2996.00 -3039.00 A 2T-220 -2992.49 -3311.49 A ConocoPhillips 2009 Reservoir Surveillance Report Tabasco Oil Pool 2009 Reservoir Surveillance Report ATTACHMENTS Tabasco Oil Pool 2009 Annual Reservoir Surveillance Report Production Logs and Special Surveys No logs or surveys were run in 2009. Since production wells are completed with gravel pack screens and electrical submersible pumps, no production logs or special surveys are planned for 2010. ConocoPhillips Tabasco Oil Pool 2009 Reservoir Surveillance Report ATTACHMENT Tabasco Oil Pool 2009 Annual Reservoir Surveillance Report Results of Well Allocation A minimum of two well tests per month were conducted on production wells. Fluid samples were obtained on a regular basis, and water cut corrections were 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 were 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 2009 production allocation factors were as follows: ConocoPhillips Tabasco Oil Pool 2009 Allocation Factors Oil Gas Water Jan -09 0.9671 0.8610 1.0203 Feb -09 0.9379 0.8693 1.0021 Mar -09 0.9483 0.8660 1.0075 Apr -09 0.9487 0.8548 0.9963 May -09 0.9395 0.8512 1.0133 June -09 0.9342 0.9373 1.0258 July -09 0.9551 0.9156 1.0188 Aug -09 0.9497 0.9156 1.0521 Sept -09 0.9786 0.9202 1.0371 Oct -09 0.9820 0.8800 1.0168 Nov -09 1.0032 0.8217 1.0409 Dec -09 0.9853 0.8797 1.0692 ConocoPhillips Tabasco Oil Pool 2009 Reservoir Surveillance Report ATTACHMENT Tabasco Oil Pool 2009 Annual Reservoir Surveillance Report Future Development Plans Tabasco injection withdrawal ratios (I/W ratio) will be monitored to maintain an instantaneous value of 1.0 or greater. Adjustments to injection and/or production rates will be made to maintain an instantaneous IM ratio of 1.0 or greater so that gas will remain in solution and pressure support maintained for the Tabasco reservoir. The Tabasco full field model will continue to be used to optimize waterflood management and explore future development opportunities. Diagnostic work is being done on 2T-220. Once the leak location is determined, the well will be fixed either with a patch or a rig workover. Screening evaluations indicate that Tabasco development beyond Drill Site 2T is most prospective at Kuparuk River Unit Drill Sites 3H and 3G. Tabasco geologic and engineering studies in 1999 identified Drill Site 3H appraisal well locations which may be drilled in the future. Tabasco development beyond Drill Site 2T continues to prove challenging due to smaller accumulations, lower quality reservoir, and higher viscosity oil. ConocoPhillips James T. Rodgers ConocoPhillips Manager, Development Greater Kuparuk Area ConocoPhillips Alaska, Inc. ATO -1326 PO Box 100360 Anchorage AK 99510-0360 Phone (907)263-4027 Fax: (907)265-6133 March 31. 2010 Mr. Dan Seamount, Commissioner Alaska Oil and Gas Conservation Commission 333 West 7"' Ave. Suite 100 Anchorage, Alaska 99501-3539 Re: 2009 Tarn Oil Pool Annual Reservoir Surveillance Report Dear Commissioner Seamount, In compliance with Rule 11, Conservation Order No. 430, ConocoPhillips Alaska, operator of the Kuparuk River Field, is hereby submitting the annual surveillance report on the Tarn Oil Pool. This report documents the required information pertinent to the field development and enhanced recovery operations from January through December 2009. The following is an outline of the information provided: a. A summary of the enhanced recovery project (Attachment 1). b. Voidage balance, by month, for produced and injected fluids (Attachments 2 and 3). c. Analysis of reservoir pressure surveys taken in 2009 (Attachment 4). d. Results of production surveys, and any special surveys, taken on the Tarn Oil Pool in 2009 (Attachment 5). e. Results of well allocation and test evaluation for Rule 7, and any other special monitoring (Attachment 6). f. Development Plan and Operational Review (Attachments 7 and 8). If you have any questions concerning this data, please contact Mark Kovar at (907) 265-6097. Sincerely, James T. Rodgers Manager, GKA Development Greater Kuparuk Area Tarn Oil Pool ATTACHMENT Tarn Oil Pool 2009 Reservoir Surveillance Report 2009 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 21'' 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 injectivity has remained strong with no signs of formation damage. Tarn is operating at injection pressures above parting pressure which enables water injection to match offtake. The Tarn MWAG process uses Kuparuk spec MI which is injected above the minimum miscibility pressure. For compositional analysis of the Kuparuk spec MI, refer to the Kuparuk section of the annual surveillance report. Reservoir Management Summary In 2009, Tarn produced 5.12 MMBO, 8.26 MMBW, and 11.75 BSCF gas. The injection totals for 2009 were 1.44 BSCF Lean Gas, 13.30 BSCF of MI and 12.86 MMBW. The cumulative year-end 2009 1/W ratio, based on current FVFs, is estimated at 1.02 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. ConocoPhillips Tarn Oil Pool 2009 Reservoir Surveillance Report ATTACHMENT Tarn Oil Pool 2009 Annual Reservoir Surveillance Report Produced Fluid Volumes 2009 TOTAL 5116000 11754429 8255696 Cum ulatives at Dec 31, 2008 91515001 140245797 35640952 Produced Fluid Volumes (Reservoir Units) OIL GAS WATER CUM OIL CUM GAS CUM WATER MO YR STB MSCF STB STB MSCF STB 1 2009 404953 926556 670535 91919954 141172353 36311487 2 2009 369019 900788 672990 92288973 142073141 36984477 3 2009 410072 1002927 764673 92699045 143076068 37749150 4 2009 433058 927699 694387 93132103 144003767 38443537 5 2009 457261 923858 753538 93589364 144927625 39197075 6 2009 418222 1085665 664834 94007586 146013310 39861909 7 2009 431113 1020755 646393 94438699 147034065 40510302 8 2009 476091 1200927 718318 94914790 148234992 41228620 9 2009 462002 1113419 587871 95376792 149348411 41816491 10 2009 444307 1007686 664915 95821099 150356097 42481406 11 2009 412643 838338 670392 96233742 151194435 43151798 12 2009 397259 805791 744850 96631001 152000226 43896648 2009 TOTAL 5116000 11754429 8255696 Cum ulatives at Dec 31, 2008 91515001 140245797 35640952 Produced Fluid Volumes (Reservoir Units) Cumulatives at Dec 31, 2008 122748786 124819170 36139925 ConocoPhillips OIL GAS WATER CUM OIL CUM GAS CUM WATER MO YR RVB RVB RVB RVB RVB RVB 1 2009 546120 760463 679922 123294906 125579633 36819848 2 2009 497940 756980 682412 123792846 126336613 37502259 3 2009 553798 842316 775378 124346644 127178929 38277638 4 2009 584934 737698 704108 124931578 127916627 38981746 5 2009 617396 714766 764088 125548974 128631393 39745834 6 2009 564540 931264 674142 126113514 129562657 40419976 7 2009 582032 846540 657471 126695546 130409197 41077446 8 2009 642282 1022045 728374 127337829 131431242 41805820 9 2009 622982 934064 596101 127960810 132365306 42401922 10 2009 599759 822839 674224 128560569 133188145 43076145 11 2009 557399 654164 679777 129117968 133842308 43755923 12 2009 536085 627895 755278 129654053 134470203 44511201 2009 TOTAL 6905267 9651034 8371276 Cumulatives at Dec 31, 2008 122748786 124819170 36139925 ConocoPhillips Tarn Oil Pool 2009 Reservoir Surveillance Report ATTACHMENT Tarn Oil Pool 2009 Annual Reservoir Surveillance Report Injected Fluid Volumes Cumulatives at Dec 31, 2008 123176758 11823033 155842713 Injected Fluid Volumes (Reservoir Units) WATER GAS MI CUM WATER CUM GAS CUM MI MO YR STB MSCF MSCF STB MSCF MSCF 1 2009 1094765 0 1434512 124271523 11823033 157277225 2 2009 879695 0 1291993 125151218 11823033 158569218 3 2009 779289 0 1277964 125930507 11823033 159847182 4 2009 992008 0 1513172 126922515 11823033 161360354 5 2009 956224 0 1560825 127878739 11823033 162921179 6 2009 936515 0 1493791 128815254 11823033 164414970 7 2009 1061234 0 1306885 129876488 11823033 165721855 8 2009 1002843 1439683 0 130879331 13262716 165721855 9 2009 1205672 0 1303269 132085003 13262716 167025124 10 2009 1156131 0 553709 133241134 13262716 167578833 11 2009 1206588 0 822312 134447722 13262716 168401145 12 2009 1593503 0 738311 136041225 13262716 169139456 2009 TOTAL 12864467 1439683 13296743 Cumulatives at Dec 31, 2008 123176758 11823033 155842713 Injected Fluid Volumes (Reservoir Units) Cumulatives at Dec 31, 2008 124901236 13393807 127287139 ConocoPhillips WATER GAS MI CUM WATER CUM GAS CUM MI MO YR RVB RVB RVB RVB RVB RVB 1 2009 1110092 0 1173297 126011328 13393807 128460436 2 2009 892011 0 1058099 126903339 13393807 129518535 3 2009 790199 0 1037934 127693538 13393807 130556468 4 2009 1005896 0 1220869 128699434 13393807 131777338 5 2009 969611 0 1269570 129669045 13393807 133046908 6 2009 949626 0 1211935 130618671 13393807 134258843 7 2009 1076091 0 1063358 131694763 13393807 135322200 8 2009 1016883 1636676 0 132711645 15030483 135322200 9 2009 1222551 0 1050514 133934197 15030483 136372715 10 2009 1172317 0 438348 135106514 15030483 136811063 11 2009 1223480 0 663765 136329994 15030483 137474828 12 2009 1615812 0 606601 137946806 15030483 138081429 2009 TOTAL 13044570 1636676 10794290 Cumulatives at Dec 31, 2008 124901236 13393807 127287139 ConocoPhillips Tarn Oil Pool ATTACHMENT 2009 Reservoir Surveillance Report Tarn Oil Pool 2009 Annual Reservoir Surveillance Report Reservoir Pressure Surveys ConocoPhillips ConocoPhillips March 31. 2010 Mr. Dan Seamount, Commissioner Alaska Oil and Gas Conservation Commission 333 West 7u' Ave. Suite 100 Anchorage, Alaska 99501-3539 Re: Tarn Oil Pool — Proposed Pressure Survey Plan for 2010 James T. Rodgers Manager, GKA Development Greater Kuparuk Area ConocoPhillips Alaska, Inc. ATO -1326 PO Box 100360 Anchorage AK 99510-0360 Phone (907)263-4027 Fax: (907)265-6133 Dear Commissioner Seamount, In compliance with Rule 8, Conservation Order No. 430A, ConocoPhillips Alaska, Inc., operator of the Tarn Oil Pool, is hereby submitting the proposed pressure survey plan for 2010. There were 24 pressure surveys reported for the Tarn Oil Pool to the AOGCC in 2009. In 2010, we expect to conduct approximately 20 pressure surveys, including initial surveys for new wells prior to initial sustained production or injection. If you have any questions concerning this data, please contact Mark Kovar at (907) 265-6097. Sincerely, James T. Rodaers Manager, GKA Development Greater Kuparuk Area ConocoPhillips Tarn Oil Pool 2009 Reservoir Surveillance Report ConocoPhillips STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION RESERVOIR PRESSURE REPORT 1. Operator ConocoPhllll s Alaska Inc. 2. Address: P. O. Box 100300, Anchom e, AK 9951D.OWD 3. Unit or Leeso Nemo: 4, Field and Pel: Tam 011 Pool S. Datum Reference: -520' SS 6. Oil Gravity. 7. Gas Grandry: 0.83 ar= 1.0 0.74 and! 9. API Number 50� NO DASHES 10. Type Sae Instructions 11. AOGCC Pool Cotle 12. Zana 13. Federated /4. Final Test Intervals Dab Top- Bottom WOES 15. Shut -In Time, Noun 16. Press. Sun, Typo (see Inarucllonsfor codes) 17. B.H. Tamp. 18. Depth Tool TVOSS 19. Final Observed Pressure at Tool Depth 20. Daum WOES Qnput) 21. Pressure Gradient, pot. M. Pressure at Datum (cal) E2L-Ml 501032D588W O 490165 A 01292009 84 SBHP 145 5440 2300 52W 0.32 M63 501032058800 O 490165 A 12272006 100 SBHP 135 5168 1228 5200 0.03 1229 501032027900 WAG 490165 A 12/302009 5472 SBHP 129 5218 4314 6200 0.42 4307 2L-311 501032M0900 0 490165 A 07/142009 99999 SBHP 136 5207 1686 5200 0.32 1839 24313 501032027700 O 490165 A M72W9 72 SBHP 138 5090 3176 5200 0.41 3221 2L-313 501032027700 0 490165 A 1013N2009 98 SBHP 143 5361 3458 5200 0.44 3385 2L -317A 501032033601 WAG 490165 A 01/09x2009 69 SBHP t2A 5335 3822 5200 0.42 3785 2L-325 501032027500 0 490165 A 02/122009 14000 SBHP 137 5042 1450 5200 0.31 1499 24329A 501032027200 1W 490185 A 07272009 15200 SBHP 122 4397 3193 5200 0.32 3450 2N305 501032034900 0 490165 A 01/092009 %999 SBHP 136 5220 3334 6200 0.39 3326 2N-W5A 501032034901 0 460165 A 04/042006 99999 SBHP 138 5100 3394 5200 0.35 3401 2N -3W 501032028800 0 490165 A 013242003 4200 SBHP 136 5084 2051 152M 0.37 2094 2N-309 501032029300 WAG 490165 A 07/07/2006 720 SBHP 126 5147 W13 5200 0.43 3838 2N-313 501032025900 0 490165 A 07/04/2009 2352 SBHP 132 5057 2527 5200 0.43 2589 2N-317 501032020000 O 490165 JA 07/122009 31W SBHP 130 5089 3502 5200 0.09 3571 2N-318 501032034300 0 490165 A I 04/2&2009 84 SBHP 134 4993 2735 5200 0.32 2799 2N-319 IM10320271M O 490165 A I 11MV20M 7464 SBHP 138 5147 2594 5200 0.44 2017 2N-323 501032025800 0 490165 A 1 08113/2009 11544 ISBHP 128 4990 2020 5200 0.32 2087 2N-325 W1032026900 WAG 490165 A 1 07/08/2009 85900 SBHP 130 5080 3582 5200 0.43 3614 2N-332 WIW2034000 O 490165 A I 0S24I2009 13896 SBHP 130 4883 3183 5200 0.32 3291 2N332 501032034000 O 490165 A 08127/2009 99999 SBHP 128 4854 3177 5200 0.32 3285 2W333 501032052500 O 490185 A 0722/2009 04 SBHP 131 4987 2540 5200 0.44 2534 214-345A WIM202MOl 0 490165 A 11/24/2009 04 SBHP 134 5052 1569 5200 0.36 1822 2N-350 W103203MM 0 490165 A 01/31/2009 13509 SBHP 126 4781 2720 5200 0.44 2910 23, All tests reported heroin mad O In uccordane with mo a icable rales, re0ulations and instructions of the Alaska OII and Gas Conservator, Commission. horoby codify that the fore9 Is entl ertad to o frit Sl9mtum Title �• Punted Noma Date li - �l/✓'� o /✓�i�'2.% /,til �� O� G il�i� ConocoPhillips Tarn Oil Pool Tarn Perforated Intervals and Stratigraphic Zones WELL NAME PERF TOP SS PERF BTM SS ZONE 2L-301 -5431 -5444 A 2L-305 -5274 -5279 A 2L-305 -5263 -5268 A 2L-305 -5242 -5262 A 2L-305 -5211 -5220 A 2L-305 1 -5191 -5195 A 2L-305 -5180 -5184 A 2L-311 -5343 -5349 A 2L-311 -5302 -5313 A 2L-313 -5391 -5402 A 2L-313 -5380 -5391 A 2L -317A -5386 -5397 A 2L -317A -5374 -5386 A 2L -317A -5362 -5374 A 2L -317A -5351 -5362 A 2L -317A -5348 -5351 A 2L-325 -5194 -5216 A 2L -329A -5041 -5066 A 2N-305 -5217 -5223 A 2N -305A -5177 -5184 A 2N-308 -5082 -5096 A 2N-308 -5073 -5082 A 2N-309 -5147 -5171 A 2N-309 -5120 -5144 A 2N-313 -5064 -5078 A 2N-313 -5050 -5064 A 2N-317 -5101 -5129 A 2N-318 -4934 -4939 A 2N-319 -5140 -5154 A 2N-323 -4980 -5007 A 2N-323 -4932 -4946 A 2N-325 -5112 -5121 A 2N-325 -5097 -5102 A 2N-325 -5088 -5092 A 2N-325 -5072 -5084 A 2N-325 -5063 -5072 A 2N-325 -5052 -5060 A 2N-325 -5038 -5048 A 2N-332 -4856 -4872 A 2N-333 -4986 -4997 A 2N 345A -5048 -5056 A r2N-350 -4780 -47821 A ConocoPhillips 2009 Reservoir Surveillance Report Tarn Oil Pool 2009 Reservoir Surveillance Report ATTACHMENT Tarn Oil Pool 2009 Annual Reservoir Surveillance Report Production Logs and Special Surveys One injection profile survey was conducted at drill site 2N. Results from this survey indicate there are no casing or tubing leaks and all injection is within the Bermuda interval. Tarn Injection Profile Data Well Date Fluid Rate (bwpd) 2N-310 3/21/2009 Water 2,140 One production profile was conducted on 2N-327 at drill site 2N to determine production coming from deeper perforated interval (Albian). Tarn Production Profile Data Well Date Fluid Rate (bbl/d) 2N-327 12/9/2009 45% Water 320 Special logs were run to identify leaks and casing corrosion. Special Leak Detection and Corrosion Logs Well Date Company Comments 2L-311 7/19/2009 PDS Multi -Finger Caliper (MFC) from 11,012 ft MD to surface. No significant wall penetrations (>17%) recorded. 2L 10/3/2009 EXPRO Downhole Video Log with filtered seawater to look at 317A obstruction at 12,190' MD. Leak Detection Log (LDL) from 8,320 ft MD to 8,150 ft 2L-325 1/10/2009 Schlumberger MD. Found tubing at bottom of gas lift mandrel at 8,282 ft MD. Patched accordingly. Multi -Finger Caliper (MFC) and 12 -arm Magnetic 2N-304 7/15/2009 PDS Thickness Tool (MTT) from 9,302 ft MD to surface. No significant change since previous log (11/3/2007) MFC run in surface casing for ongoing subsidence study. Surface casing found in good condition. This log 2N-305 2/23/2009 PDS was possible after the production casing had been cut and pulled as part of the procedure to sidetrack well 2N- 305. ConocoPhillips Tarn Oil Pool 2009 Reservoir Surveillance Report Special Leak Detection and Corrosion Logs Well Date Company Comments Water -Flow -Log (WFL) indicated no upflow above or 2N-310 3/21/2009 Schlumberger g below the casing patch that is isolating the shallower Cairn interval perforations. 100% of injection is going into Bermuda (Tarn) sands. 2N-319 8/28/2009 HES Spectra Flow Log (WFL) to determine leak behind casing. Log data being reviewed in Houston. Multi -Finger Caliper (MFC) and 12 -arm Magnetic 2N-342 7/16/2009 PDS Thickness Tool (MTT) from 10,116 ft MD to surface. No significant wall penetrations (>17%) recorded. ConocoPhillips Tarn Oil Pool ATTACHMENT 2009 Reservoir Surveillance Report Tarn Oil Pool 2009 Annual Reservoir Surveillance Report Results of Well Allocation ConocoPhillips Oil Gas Water Jan -09 0.9670 0.8611 1.0203 Feb -09 0.9379 0.8690 1.0021 Mar -09 0.9483 0.8661 1.0075 Apr -09 0.9486 0.8551 0.9962 May -09 0.9395 0.8509 1.0133 Jun -09 0.9343 0.9377 1.0258 Jul -09 0.9550 0.9154 1.0188 Aug -09 0.9497 0.9158 1.0520 Sep -09 0.9787 0.9203 1.0372 Oct -09 0.9820 0.8802 1.0168 Nov -09 1.0032 0.8217 1.0410 Dec -09 0.9852 0.8796 1.0692 ConocoPhillips Tarn Oil Pool 2009 Reservoir Surveillance Report ATTACHMENT Tarn Oil Pool 2009 Annual Reservoir Surveillance Report Tarn Development Plan and Operational Review Development Drilling Well 2L-301, planned as a pre -produced injector, was spud December 26, 2008 and put on production April 18 2009. This grassroots well was the first well drilled out of a three well program for the winter of 2008/9. Well 2L-301 targeted turbidite deposits in the eastern fringe of the 2L accumulation to provide injection support to current (2L-309) and future producers (2L-304) in the surrounding outboard area. Well 2N -305A, a rotary sidetrack out of the broken 2N-305 jet pump lifted producer, was spud February 14, 2009 and put on production April 20, 2009. This sidetrack targeted potentially unswept reservoir approximately 500 ft ENE of the original bottom -hole location. Well 2N-305 was shut in and secured in 2007 due to a casing leak caused by corrosion during surface -powered jet pump service. The jet pump was installed in well 2N-305 in 2001 to increase tubing flowing temperatures to mitigate paraffin deposition. The original wellbore was plugged and abandoned before the 2N -305A sidetrack was drilled. Well 2N -318A, a rotary sidetrack out of the broken 2N-318 jet pump lifted producer, was spud March 21, 2009 and brought online April 24, 2009. This sidetrack targeted a slightly thicker reservoir section approximately 600 ft south of the original reservoir penetration. Well 2N-318 was shut in and secured in 2006 due to a casing leak caused by corrosion during surface -powered jet pump service. The jet pump was installed in well 2N-318 in 2001 to increase tubing flowing temperatures to mitigate paraffin deposition. The original wellbore was plugged and abandoned before the 2N -318A sidetrack was drilled. Both sidetracks were tied -in as gas -lifted producers in an effort to transition away from jet pump lift that has proven to be very effective to mitigate paraffin deposition problems but seemed to be the cause of casing leaks and other corrosion -related problems. Well 2L-326, a new grassroots pre -produced injection well from Tarn drillsite 2L targeting the channel to amalgamated turbidite transition zone in the NW portion of the 2N accumulation, was spud December 12, 2009 and put on production January 31, 2010. The 12 -month pre -production period will provide valuable information about reservoir quality in updip, proximal turbidite channel facies. This data will help evaluate future updip proximal locations (e.g. 2L -Delta) that are structurally higher and involve substantial geological development risks. The 2N-342, drilled in 2007, targeted a promising seismic anomaly adjacent to the main Tarn Field with similar attributes being named 'Tarn South'; initial flow testing was successful although production issues have resulted in this well shut-in for extended periods. In 2008, perforations were added and a second hydraulic frac job was pumped with the intent of obtaining additional rate and temperature characteristics to keep the well from freezing. Despite these efforts, the well had to be shut-in due to the same production issues. A temporary conversion to surface powered jet pump was completed in August 2009 and the well has been flowing uninterrupted since then. Production rate and reservoir pressures will be evaluated during 2010 to asses the feasibility of additional development for the 'Tarn South' accumulation. Opportunities to maximize Tarn Field recovery while preventing physical waste are under constant evaluation as the field matures, geologic and reservoir performance information is assimilated, and as technology improves. Plans for 2010 include two rotary grassroots wells to be drilled from Drillsite 2L. Well 2L-304 is currently scheduled to spud 3/12/2010. This wellbore is planned to be a producer drilled outboard of well 2L-301 in the eastern distal portion of the Tarn 2L accumulation. Well 2L-301, mentioned at the beginning of this section, will be converted to an MWAG (miscible gas alternating with water) injector in 2010 to provide sweep, pressure support and EOR benefit from the west to well 2L-304 and from the east to the existing producer 2L-309. The second well planned for 2010 is 2L-310. This well is planned as a pre -produced injector approximately 1,600 ft WNW of well 2L-311. The current plan is to pre -produce well 2L-310 for ConocoPhillips Tarn Oil Pool 2009 Reservoir Surveillance Report approximately one year. After the conversion to an MWAG injector, well 2L-310 will provide sweep, pressure support and EOR benefit to the offset wells 2L-307 and 2L-311 plus any future producers that may be drilled in the future ENE and WNW of well 2L-310. An update of the geologic and full -field reservoir model is almost complete. Integration with the new 2008 3D seismic is being used for development planning and flood optimization. The Tarn Team is evaluating additional development prospects that could possibly be drilled in 2010, depending on rig availability and business climate. If drilled in 2010, they would be drilled late in the year and production would not likely commence until 2011. Producer to Injector Conversions Well 2L-319 was converted to an MWAG injector to provide pressure support to well 2L-311 and future producers in the north-east distal area. Well 2N-310, drilled in 2007, was placed in service as an injector for the Bermuda (Tarn) reservoir on January 31, 2009 after infrastructure led exploration related activities in other intervals of the Tarn Pool were finalized. Additional conversion plans for 2010 include converting the pre -produced well 2L-301 to an MWAG injector to provide sweep, pressure support and EOR benefit from the west to well 2L-304 and from the east to the existing producer 2L-309. 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 section that runs across the permafrost occurs when the production Fluid temperature falls below the cloud point of 92°F. This is the case of longer reach wells and lower liquid rate production wells. Excessive paraffin build-up and the high frequency of required paraffin scrapes in some wells led to a change in artificial lift methodology towards surface -powered downhole jet pumps. In 2001, after successful pilot tests in 1999 and 2000, 13 of the gas lifted wells were converted to jet pump using hot produced water as power fluid. This technique has proven to be very successful in mitigating paraffin deposits. Slickline scrapes and hot oil treatments have been virtually eliminated leading to production increases of about 10%. Unfortunately the untreated saline produced water injected down the inner annuli (power fluid) has accelerated tubing and casing corrosion. Three (3) well integrity failures occurred on jet -pumped wells due to both tubing and casing corrosion in 2006-2007: 2L-321, 2N-318 and 2N-305. These wells were shut-in and secured. 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. During 2009, well 2N-319 failed a surface casing integrity test, making it the fourth well to fail for the same reason at Tarn. Well 2N-319 will likely remain secured and shut in until a sidetrack targeting more prolific reservoir is executed and the original 2N-319 wellbore is plugged and abandoned. Consequently, completion designs and alternatives to jet pumps are being considered for new and existing wells. Capillary chemical injection tubes are being installed in several new wells. This will enable lower productivity, lower temperature, gas -lifted wells to produce with reduced paraffin deposition problems when a chemical (paraffin inhibitor) is injected down the capillary tube to treat produced oil flowing up the tubing. Five chemical paraffin inhibitors from different vendors have been analyzed with Tarn crude in a cold -finger laboratory test with varying results. A field test of one or more products is being designed for well 2L-301 (before the well is converted to an injector later in 2010). This field test and other surface facility issues will be evaluated before considering the implementation of a field -wide program. After water breaks through in a producing well, the need for jet pumps and other means of paraffin inhibition or removal may not be necessary, because water has a higher heat capacity and the overall higher production rate yields higher flowing temperatures. Plans to convert wells after water break -through back to gas lift are under way. In 2007, 2L-307 was converted from jet pump back to gas lift. In 2008, two additional well were converted from jet pump back to gas lift: 2L-315 and 2L-325. ConocoPhillips Tarn Oil Pool ATTACHMENT Tarn Oil Pool 2009 Annual Reservoir Surveillance Report t�t014 a44v1ry IIU f V�VlI\ UVVVIUNmenL Wt:JI5 2009 Reservoir Surveillance Report 32 - x-310. I 2L 327 24305 1L -3a 2L.309PB1" Q--: 2015 �G307 2 381 cow .i TARN 2 2L-313 G I gG,2-328 24325 2L-323 24317A -.p L__✓i-��:J _- .:, 24317 lam' 2N.305A 2L.330 24321 - _ 2L.309 2N3152N-308' - 2N-305'' 2N-314 TARN 3A !` 2N.302 2N31,1A .3 2N-318 M „2N32N-307 13 2N1311- - 2N-321 - 2N -32.1A 2N-309TARN I ' 2N-304PM1 2N-304 F 2N.326 2N-317 TARN 3 . ' .3 2W303 2N-310 2N-320 2N-323 y - - 2N.308. 2N332 " 2N325 2N.319. '. 2N-392PB1 ".'69 2N-329 2N -340.2N347 2N-331 - • 2N.345A= 2N349A2N349 2N341 2N-315 2N-333 Y TARN 4 2N.350 - 2N-343 \( 2N-339 12N-327 2N-335 2N337B 2N:342 ConocoPhillips ConocoPhillips March 31, 2010 Mr. Dan Seamount, Commissioner Alaska Oil and Gas Conservation Commission 333 West 7v' Ave. Suite 100 Anchorage, Alaska 99501-3539 Re: 2009 West Sak Oil Pool Annual Reservoir Surveillance Report Dear Commissioner Seamount, James T. Rodgers Manager, GKA Development Greater Kuparuk Area ConocoPhillips Alaska, Inc. ATO -1326 PO Box 100360 Anchorage AK 99510-0360 Phone(907)263-4027 Fax: (907)265-6133 In compliance with Rule 11, Conservation Order No. 406A, ConocoPhillips Alaska, Inc., operator of the Kuparuk River Unit, is hereby submitting the annual surveillance report on the West Sak Oil Pool. This report documents information pertinent to field development and enhanced recovery operations from January 2009 through December 2009. The following is an outline of the information provided: a. A summary of the current enhanced oil recovery in the West Sak Oil Pool (Attachment 1). b. Voidage balance, by month, for produced and injected fluid (Attachments 2 and 3). c. Analysis of reservoir pressure surveys taken in 2009 and pressure survey plans for 2010 (Attachment 4). d. Results of injection surveys, production surveys, and any special surveys, conducted in the West Sak Oil Pool in 2009 (Attachments 5 through 7). e. Results of pool production allocation factors (Attachment 8). f. Future development plans (Attachment 9). If you have any questions concerning this data, please contact Mark Kovar at (907) 265-6097. Sincerely, James T. Rodgers Manager, GKA Development Greater Kuparuk Area West Sak Oil Pool 2009 Reservoir Surveillance Report ATTACHMENT West Sak Oil Pool 2009 Annual Reservoir Surveillance Report Summary of the Enhanced Oil Recovery Project At the end of 2009 there were fifty-seven active water injectors and fifty-four active producers in the West Sak Oil Pool. This represents an increase of two dual injection wells or four active injectors in West Sak from January 2009 to December 2009. The following wells were completed and placed in service in 2009 in the West Sak Oil Pool: Name Well Type Target Service 3K -103B* Lateral B Injector 3K -103D* Lateral D Injector 3K -108B* Lateral B Injector 3K -108D* Lateral D Injector * indicates wells spud in 2008, but placed in service in 2009. Waterflooding the reservoir with CPF-1 produced water for pressure maintenance and improved sweep continues to be the main enhanced oil recovery mechanism in the West Sak oil pool. Waterflood performance was good in the majority of the West Sak patterns. During 2009 the West Sak oil pool experienced two rapid water breakthrough events and possibly a third. These events create highly conductive pathways between an injector and a producer, otherwise known as a matrix bypass event. A list of the matrix bypass events in 2009 is provided below: Injector Producer Event Date Breakthrough Zone 1J-160 1J-158 May 2009 BSand 1J-164 1J-166 May 2009 BSand 1E-102* IE -123 December 2009 D Sand * Pressure data similar to matrix bypass event was seen, however diagnosis is not final at the time of this report. Analysis and review of the bypass events is an ongoing activity. Measures to mitigate future matrix bypass events were implemented in 2005 and 2007 resulting in reductions in the frequency of new bypass events. In addition, remediation repairs were implemented in 2009 that successfully isolated five bypass events. New remediation strategies are in development. During 2003, ConocoPhillips Alaska, Inc. received approval to commence a West Sak Small Scale EOR (SSEOR) Pilot Project using Kuparuk MI in a water -alternating gas (WAG) pilot. The SSEOR Pilot Project is completed. In 2009, a West Sak Viscosity Reducing Water Alternating Gas Pilot project was approved for four West Sak injectors at 1E & 1J. Initial VRWAG gas injection began in November 2009 in two injectors, 1 E-102 and 1E-117. Two additional injectors, 1J-170 and 1J-122, will start gas injection in 2010. Well 1 E-102 is SI following a possible matrix bypass event. ConocoPhillips West Sak Oil Pool 2009 Reservoir Surveillance Report ATTACHMENT West Salk Oil Pool 2009 Annual Reservoir Surveillance Report Produced Fluid Volumes 2009 TOTAL 6881344 2635526 1932452 Cumulatives at Dec 31, 2008 38191816 19419848 9153191 Produced Fluid Volumes (Reservoir Units) OIL GAS WATER CUM OIL CUM GAS CUM WATER MO YR STB MSCF STB STB MSCF STB 1 2009 535943 187556 137649 38727759 19607404 9290840 2 2009 507934 216937 92062 39235693 19824341 9382902 3 2009 578802 212566 123415 39814495 20036907 9506317 4 2009 597724 186767 166333 40412219 20223674 9672650 5 2009 624305 224941 154364 41036524 20448615 9827014 6 2009 611300 283608 164029 41647824 20732223 9991043 7 2009 628847 231078 164153 42276671 20963301 10155196 8 2009 612032 225740 173307 42888703 21189041 10328503 9 2009 574175 220584 204534 43462878 21409625 10533037 10 2009 583421 214923 228056 44046299 21624548 10761093 11 2009 520814 198779 149593 44567113 21823327 10910686 12 2009 506047 232047 174957 45073160 22065374 11085643 2009 TOTAL 6881344 2635526 1932452 Cumulatives at Dec 31, 2008 38191816 19419848 9153191 Produced Fluid Volumes (Reservoir Units) Cumulatives at Dec 31, 2008 40826968 18796601 9153191 ConocoPhillips OIL GAS WATER CUM OIL CUM GAS CUM WATER MO YR RVB RVB RVB RVB RVB RVB 1 2009 572387 129863 137649 41399356 18926464 9290840 2 2009 542474 150832 92062 41941829 19077296 9382902 3 2009 618161 130619 123415 42559990 19207915 9506317 4 2009 638369 77773 166333 43198359 19285688 9672650 5 2009 666758 139406 154364 43865117 19425094 9827014 6 2009 652868 234215 164029 44517985 19659309 9991043 7 2009 671609 141412 164153 45189594 19800720 10155196 8 2009 663650 139189 173307 45843244 19939909 10328503 9 2009 613219 143442 204634 46466463 20083351 10533037 10 2009 623094 137142 228056 47079556 20220494 10761093 11 2009 566229 123661 149593 47635786 20344155 10910686 12 2009 540458 179095 174957 48176244 20523249 11085643 2009 TOTAL 7349275 1726649 1932452 Cumulatives at Dec 31, 2008 40826968 18796601 9153191 ConocoPhillips West Sak Oil Pool 2009 Reservoir Surveillance Report ATTACHMENT 3 West Sak Oil Pool 2009 Annual Reservoir Surveillance Report Injected Fluid Volumes Injected Fluid Volumes (Reservoir Units) WATER GAS MI CUM WATER CUM GAS CUM MI MO YR STB MSCF MSCF STB MSCF MSCF 1 2009 821417 0 0 58759842 0 447212 2 2009 713614 0 0 59473456 0 447212 3 2009 828130 0 0 60301586 0 447212 4 2009 773991 0 0 61075577 0 447212 5 2009 734662 0 0 61810239 0 447212 6 2009 712162 0 0 62522401 0 447212 7 2009 767357 0 0 63289758 0 447212 8 2009 857685 0 0 64147443 0 447212 9 2009 826209 0 0 64973652 0 447212 10 2009 934957 0 0 65908609 0 447212 11 2009 882.289 0 20076 66790898 0 467288 12 2009 837641 0 91773 67628539 0 559061 2009 TOTAL 9690114 0 111849 Cumulatives at Dec 31, 2008 57938425 0 447212 Injected Fluid Volumes (Reservoir Units) Cumulatives at Dec 31, 2008 57938425 0 334962 ConocoPhillips WATER GAS MI CUM WATER CUM GAS CUM MI MO YR RVB RVB RVB RVB RVB RVB 1 2009 821417 0 0 58759842 0 334962 2 2009 713614 0 0 59473456 0 334962 3 2009 828130 0 0 60301586 0 334962 4 2009 773991 0 0 61075577 0 334962 5 2009 734662 0 0 61810239 0 334962 6 2009 712162 0 0 62522401 0 334962 7 2009 767357 0 0 63289758 0 334962 8 2009 857685 0 0 64147443 0 334962 9 2009 826209 0 0 64973652 0 334962 10 2009 934957 0 0 65908609 0 334962 11 2009 882289 0 15037 66790898 0 349999 12 2009 837641 0 68738 67628539 0 418737 2009 TOTAL 9690114 0 83775 Cumulatives at Dec 31, 2008 57938425 0 334962 ConocoPhillips West Sak Oil Pool ATTACHMENT 4 2009 Reservoir Surveillance Report West Sak Oil Pool 2009 Annual Reservoir Surveillance Report Reservoir Pressure Surveys Perforated Intervals and Stratigraphic Zones Proposed Pressure Survey Plan for 2010 ConocoPhillips ConocoPhillips March 31, 2010 Mr. Dan Seamount, Commissioner Alaska Oil and Gas Conservation Commission 333 West 7s' Ave. Suite 100 Anchorage, Alaska 99501-3539 Re: West Sak Oil Pool — Proposed Pressure Survey Plan for 2010 James T. Rodgers Manager, GKA Development Greater Kuparuk Area ConocoPhillips Alaska, Inc. ATO -1326 PO Box 100360 Anchorage AK 99510-0360 Phone (907)263-4027 Fax: (907)265-6133 Dear Commissioner Seamount, In compliance with Rule 8, Conservation Order No. 406A, ConocoPhillips Alaska, Inc., operator of the West Sak Oil Pool, is hereby submitting the proposed pressure survey plan for 2010. There were 20 pressure surveys reported for the West Sak Oil Pool to the AOGCC in 2009. In 2010, we expect to conduct approximately 11 pressure surveys, including initial surveys for new wells prior to initial sustained production or injection. If you have any questions concerning this data, please contact Mark Kovar at (907) 265-6097. Sincerely, James T. Rodgers Manager, GKA Development Greater Kuparuk Area ConocoPhillips West Sak Oil Pool 2009 Reservoir Surveillance Report STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION RESERVOIR PRESSURE REPORT 1. Operator: 2. Address: ConocoPhilli s Alaska Inc. P. O. Boz 100360, Anchors o, AK 99510-0360 3. Unit or Leese Name: Ku aruk River Unit S. Wail Name and Number: 9. API Number 50%%%%%%%%%X7(% NO DASHES 10, Type See Instructions 11. AOGCC Pool Code 12. Zana 13. Partorated 14, Final Test Intervals Date Top -Bottom 4. Field and Pool: Wosl Salk Oil Pool 15. Shut -In 16. Press. Timo, Hours Surv. Type (sea 17. B.H. Tamp. S. Datum Reference: -3500' SS 18. Oepm Tool 19. Final NDSS Observed Pressure at 6. Oil Gravity: 0.94 water = 1.0 20. Datum NDSS(inpud) 7. Gas Gravity: 0.57 21. Pressure Gradient, psi/(t. 22. Pressure at Datum (ca)NO NDSS instructions for Tool Depth codes) 18-101 50029231730000 O 490150 SO 01/16/2009 15528 SBHP 68 3332 1085 3500 0.39 1151 16-101 50029231730000 0 490150 BD 05/312009 19000 SBHP 71 3572 1154 3500 0.34 1130 18-102 50029231670000 WINJ 490150 BD 03/31/2009 840 SBHP 75 3540 1393 3500 0.45 1375 1C-111 50029230290000 WINJ 490150 ABO 07/01/2009 6480SBHP 81 3745 1840 350D 0.37 1750 IC -1 17 50029230270000 WINJ 490150 A 07/09/2009 1440 SBHP 80 3802 1921 3500 0.44 1788 1C-119 50029230340000 WINJ 490150 ABD 07/01/2009 1440 SBHP 73 3716 2092 3500 0.44 1997 1C-121 50029230150000 WINJ 490150 ABD 07/052009 1440 SBHP 56 2759 1446 3500 0.42 1757 1C-125 50029230440000 WINJ 490150 AD 07/14/2009 1440 SBHP 74 3541 950 350D 0.42 933 IC -127 50029230240000 WINJ 490150 A 01/01/2009 360 SBHP 83 3756 2475 3500 0.38 2378 1C-127 50029230240000 WINJ 490150 A 07/07/2009 5040 SBHP 74 3756 2100 3500 0.38 2003 1C-131 50029230410000 WINJ 490150 BD 07/05/2009 1440 SBHP 90 3710 1985 3500 0.44 1893 1C-133 50029230130000 WINJ 490150 BD 07/05/2009 1440 SBHP 72 3710 2064 3500 0.40 1950 ID -102 50029229600000 0 490150 SO 04/2812009 1000 SBHP 66 2962 1415 3500 0.40 1628 ID -107 50029229830000 WINJ 490150 BD 07/05/2009 720 SBHP 71 3662 2322 3500 0.43 2252 1D -125A 50029229040100 WINJ 490150 ABD 07/06/2009 6480 SBHP 79 3597 2335 3500 0.36 2300 1E-112 50029232110000 WINJ 490150 ABO 07/14/2009 8760 SBHP 78 3324 1260 3500 0,36 1324 1J-107 50029233660000 0 490150 BD 07/12/2009 37 PBU 70 3528 887 3500 0.39 876 1J-162 50029233600000 O 490150 BO I 05262009 120 PBU 1 70 2686 682 3500 0.39 1002 1J-176 50029233640000 WINJ 490150 BD 02/112009 999 SBHP 67 3036 1278 35W 0.39 1460 11-182 50029233210000 23. All tests reported herein were made in accordance 0 490150 BD with the applicable rules, regulations and 01/28/2009 Instructions of the Alaska Oil and 140 Gas Conservation PBU Commission. 70 3014 670 3500 0.39 861 I hereby certify that the foregoi two and c� to bast o y knowledge, Signature V/4/ --- T >•y ��yJl /' 49-1,ills / Printed Name AML' d erS Date h� ocoPhillioc West Sak Oil Pool West Sak Perforated Intervals and Stratigraphic Zones WELL NAME PERF TOP ss PERF BTM ss ZONE 1B-101 -3,645.39 -3,624.87 BD 1 B-102 -3,595.50 -3,633.64 BD IB -102 -3,633.64 -3,633.93 BD 1 B-102 -3,633.93 -3,680.21 BD 1C-111 -3,630.39 -3,672.53 ABD 1C-111 -3,692.79 -3,724.17 ABD 1C-111 -3,735.27 -3,744.53 ABD 1C-111 -3,748.23 -3,757.49 ABD 1C-111 -3,774.16 -3,788.98 ABD 1C-111 -3,798.24 -3,807.51 ABD 1C-111 -3,814.93 -3,824.20 ABD 1C-111 -3,844.61 -3,859.46 ABD 1C-117 -3,629.52 -3,666.31 A 1C-117 -3,691.60 -3,711.11 A 1C-117 -3,738.50 -3,758.13 A 1C-117 -3,773.86 -3,789.61 A 1C-117 -3,795.52 -3,807.33 A 1C-117 -3,807.33 -3,825.06 A 1C-117 -3,825.06 -3,827.03 A 1C-117 -3,834.91 -3,846.73 A 1 C-117 -3,846.73 -3,866.44 A 1C-119 -3,595.26 -3,609.20 ABD 1C-119 -3,609.20 -3,626.70 ABD 1C-119 -3,654.87 -3,670.85 ABD 1C-119 -3,670.85 -3,688.70 ABD 1C-119 -3,700.37 -3,722.93 ABD 1C-119 -3,782.48 -3,788.97 ABD 1C-119 -3,833.75 -3,842.17 ABD 1C-121 -3,548.27 -3,588.84 ABD 1C-121 -3,612.95 -3,648.20 ABD 1C-121 -3,657.48 -3,681.58 ABD 1C-121 -3,701.97 -3,713.10 ABD 1C-121 -3,720.52 -3,746.50 ABD 1C-121 -3,783.63 -3,811.47 ABD 1C-125 -3,648.65 -3,653.46 AD 1C-125 -3,673.70 -3,681.50 AD 1C-125 -3,691.34 -3,721.38 AD 1C-125 -3,526.15 -3,545.64 AD 1C-125 -3,545.64 -3,555.69 AD 1C-125 -3,584.26 -3,606.83 AD 1C-12 3,6351 3,639.00 AD 1C25 3752 -3,778.51 AD ConocoPhillips 2009 Reservoir Surveillance Report WELL PERF TOP NAME ss 1C-127 -3,598.18 1C-127 -3,662.98 1C-127 -3,663.92 1C-127 -3,698.14 1C-127 -3,748.07 1C-127 -3,773.24 1C-127 -3,835.65 1C-131 -3,661.46 1C-131 -3,723.26 1C-133 -3,665.28 1C-133 -3,725.22 1C-133 -3,769.17 1C-133 -3,811.10 1CA33 -3,827.06 1C-133 -3,845.02 1C-133 -3,874.95 1D-102 -3,651.23 1D-107 -3,620.54 1D-107 -3,685.00 1D-107 -3,715.11 1D-107 -3,846.34 1D-107 -3,912.66 1D -125A -3,452.07 1D -125A -3,511.27 ID -125A -3,557.36 1D -125A -3,595.97 1D -125A -3,612.49 1D -125A -3,638.17 1D -125A -3,661.99 1 D-1 25A -3,685.81 1D -125A -3,708.71 1D -125A -3,727.96 1E-112 -3,521.53 1 E-112 -3,499.85 1 E-112 -3,486.06 1 E-112 -3,479.85 1E-112 -3,507.18 1J-107 -3,554.08 1J-162 -3,122.25 1J-162 -3,140.15 1J-162 -3,107.31 1J-162 -3,115.67 PERFBTM ZONE ss -3,635.62 A -3,663.92 A -3,698.14 A -3,729.76 A -3,763.54 A -3,794.63 A -3,857.23 A -3,699.79 BD -3,758.03 BD -3,695.25 BD -3,755.18 BD -3,791.14 BD -3,821.08 BD -3,841.03 BD -3,856.99 BD -3,944.87 BD -3,619.36 BD -3,653.50 BD -3,704.60 BD -3,750.71 BD -3,879.85 BD -3,923.61 BD -3,483.54 ABD -3,542.63 ABD -3,579.43 ABD -3,603.31 ABD -3,629.00 ABD -3,643.67 ABD -3,674.81 ABD -3,699.55 ABD -3,716.96 ABD -3,740.80 ABD -3,515.79 ABD -3,497.32 ABD -3,478.52 ABD -3,491.50 ABD -3,508.45 ABD -3,550.59 BD -3,129.86 BD -3,107.31 BD -3,119.82 BD -3,098.00 BD West Sak Oil Pool 2009 Reservoir Surveillance Report West Sak Perforated Intervals and Stratigraphic Zones (continued) WELL NAME PERF TOP SS PERF BTM SS ZONE 1J-176 -3,091.61 -3,132.93 BD 1J-176 -3,132.93 -3,136.67 BD 1J-176 -3,136.67 -3,136.19 BD 1J-176 -3,136.19 -3,139.13 BD 1J-176 -3,139.13 -3,136.99 BD 1J-176 -3,136.99 -3,136.78 BD 1J-176 -3,136.78 3,134.99 BD 1J-176 -3,134.99 -3,133.38 BD 1J-176 -3,133.38 -3,127.61 BD 1J-176 -3,127.61 -3,124.98 BD 1J-176 -3,124.98 -3,125.34 BD 1J-176 -3,125.34 -3,126.30 BD 1J-176 -3,126.30 -3,125.67 BD 1J-176 -3,125.67 -3,121.79 BD 1J-176 -3,121.79 -3,121.22 BD 1J-176 -3,121.22 -3,121.54 BD 1J-176 -3,121.54 -3,123.80 BD 1J-176 -3,123.80 -3,126.54 BD 1J-176 -3,126.54 -3,123.27 BD 1J-176 -3,123.27 -3,122.22 BD 1J-176 -3,122.22 -3,122.47 BD 1J-176 -3,122.47 -3,121.52 BD 1J-176 -3,121.52 -3,119.40 BD 1J-176 -3,119.40 -3,118.17 BD 1J-176 -3,118.17 -3,116.70 BD 1J-176 -3,116.70 -3,116.91 BD 1J-176 -3,116.91 -3,120.53 BD 1J-176 -3,120.53 -3,121.67 BD 1J-176 -3,121.67 -3,120.69 BD 1J-176 -3,120.69 -3,117.68 BD 1J-176 -3,117.68 -3,109.85 BD 1J-176 -3,109.85 -3,108.78 BE 1J-176 -3,108.78 -3,103.67 BD 1J-176 -3,103.67 -3,102.18 BD 1J-176 -3,102.18 -3,105.84 BD 1J-176 -3,105.84 -3,106.12 BD 1J-176 -3,106.12 -3,101.61 BD 1J-176 -3,101.61 -3,094.08 BD 1J-176 -3,094.08 -3,088.07 BD 1J-182 -3,252.15 -3,323.71 BD 1J-182 -3,323.77 -3,238.19 BD 1J-182 3,237.38 -3,238.07 1 BD ConocoPhillips West Sak Oil Pool ATTACHMENT West Sak Oil Pool 2009 Annual Reservoir Surveillance Report Injection Survey Data 2009 Reservoir Surveillance Report WELL NUMBER API NUMBER 50- DATE OF INITIAL INJECTION DATE OF PROFILE/ SURVEY DATA TYPE PROFILE/ SURVEY REASON FOR PROFILE/ SURVEY WELL COMPLETION ZONES TAKING INJECTION INJECTION BWPD / MSCFD 1C-131 02923041-00 12/8/2001 03/20/09 SPINNER A/C SPLITS Dual Lateral B+D 1011 B 101 1D-130 02922815-00 1/23/2008 02/12/09 SPINNER A/C SPLITS Multi Lateral A+B+D 560 B 168 A 353 1E-105 02923243-00 8/11/2005 01/23/09 SPINNER A/C SPLITS Multi Lateral A+D 768 A 0 1J-105 02923346-00 6/1.5/2007 07/23/09 SPINNER FOLLOW-UP Multi Lateral A+B+D 710 B A 1J-136 02923331-00 4/1/2007 08/24/09 SPINNER FOLLOW-UP Multi Lateral B+D 1100 B 1J-170 02923310-00 10/2/2006 07/10/09 SPINNER A/C SPLITS Multi Lateral A+B+D 1800 B A Covet for ConocoPhillips West Sak Oil Pool 2009 Reservoir Surveillance Report ATTACHMENT West Salk Oil Pool 2009 Annual Reservoir Surveillance Report Production Survey Data During 2009, one production profile survey was attempted in well 1C -172A on August 29, 2009. The survey equipment could not pass through the well's lateral entry module (LEM) and thus the survey results were inconclusive. No production profile survey data is reported for 2009. ConocoPhillips West Sak Oil Pool 2009 Reservoir Surveillance Report I'_Ty:hnl21►IMFA West Sak Oil Pool 2009 Annual Reservoir Surveillance Report Special Survey Data Geochemical Oil Production Splits Well Name Sample Date A Sand B Sand D Sand 1B-101 06/05/09 0% 40% 60% 1C-102 05/31/09 0% 3% 97% 1C-102 10/30/09 0% 11% 89% 1C-104 05/31109 0% 61% 40% 1C-109 05/31/09 0% 35% 66% 1C-109 10/30/09 0% 28% 72% 1C-131 03/20/09 10% 0% 90% 1C-178 10/30/09 0% 39% 61% 1D-102 06/13/09 0% 63% 37% 1 D-102 10/30/09 0% 53% 47% 1 D-108 06/13/09 31% 29% 40% 1D-108 10/30/09 36% 24% 40% 1D -110A 06/13/09 39% 14% 47% 1D -110A 10/30/09 36% 19% 46% 1D-112 07/02/09 46% 17% 37% 1D-112 10/30/09 41% 30% 29% 1 D-113 07/02/09 38% 16% 46% 1D-113 10/30/09 36% 33% 31% 1 D-115 06/13/09 44% 28% 28% 1 D-115 10/30/09 35% 39% 26% 1 D-116 06/14/09 36% 38% 27% 1D-116 10/30/09 30% 40% 30% 1D-118 10/30/09 63% 0% 37% 1D-121 06/14/09 65% 0% 35% 1D-123 06/14/09 40% 29% 31% 1D-123 10/30/09 55% 32% 13% 1D-124 06/15/09 50% 24% 26% 1D-124 10/30/09 38% 42% 20% 1D-126 10/30/09 56% 36% 7% 1D-129 11/06/09 60% 36% 5% 1D-130 02/12/09 63% 30% 7% 1D-131 06/15/09 48% 50% 1% 1D-131 10/30/09 43% 57% 0% 1D-133 06/14/09 71% 7% 22% 1 D-133 10/30/09 40% 49% 11% 1D-134 06/15/09 55% 21% 24% 1 D-134 10/30/09 1 55% 25% 20% 1 D-135 06/15/09 19% 20% 61% 1D-135 11/02/09 4% 22% 73% 1E-105 01/23/09 1% 0% 99% 1E-121 05/31/09 0% 30% 70% ConocoPhillips West Sak Oil Pool 2009 Reservoir Surveillance Report Well Name Sample Date A Sand B Sand D Sand 1E-121 11/01/09 0% 11% 89% 1E-123 11/01/09 0% 33% 67% 1E-126 05/31/09 22% 0% 78% 1E-126 11/01/09 43% 0% 57% 1E-166 03/21/09 31% 0% 69% IE -168 05/31/09 31% 0% 70% 1E-168 11/01/09 9% 0% 91% 1E-170 05/31/09 5% 54% 41% 1E-170 11/01/09 21% 45% 34% 1J-101 06/07/09 26% 40% 33% 1J-101 11/01/09 24% 34% 42% 1J-103 06/06/09 0% 55% 45% 1J-103 10/30/09 0% 51% 49% 1J-105 07/23/09 0% 0% 100% 1J-107 10/30/09 0% 9% 91% 1J-115 06/05/09 11% 37% 52% 1J-115 10/30/09 14% 40% 46% 1J-120 06/05/09 5% 22% 73% 1J-120 10/30/09 7% 22% 72% 1J-135 06/05/09 0% 13% 87% 1J-135 09/09/09 0% 100% 0% 1J-136 08/24/09 0% 87% 13% 1J-137 1 06/05/09 0% 62% 38% 1J-152 06/04/09 27% 32% 41% 1J-152 10/30/09 23% 52% 26% 1J-158 06/04/09 0% 85% 15% 1J-159 10/30/09 35% 2% 63% 1J-162 06/05/09 0% 54% 46% 1J-162 10/31/09 0% 19% 81% 1J-166 06/05/09 20% 4% 77% 1J-166 10/30/09 17% 74% 9% 1J-168 06/05/09 38% 36% 26% 1J-168 10/30/09 20% 71% 10% 1J-170 07/10/09 40% 0% 60% 1J-174 06/05/09 0% 59% 41% 1J-174 10/30/09 0% 100% 0% 1J-178 06/05/09 0% 72% 28% 1J-178 10/30/09 0% 66% 34% 1J-182 06/05/09 0% 77% 23% 1J-182 10/30/09 0% 76% 24% ConocoPhillips West Sak Oil Pool ATTACHMENT 8 2009 Reservoir Surveillance Report West Sak Oil Pool 2009 Annual Reservoir Surveillance Report Allocation Factors ConocoPhillips Oil Gas Water Jan -09 0.9478 0.8895 1.009 Feb -09 0.9487 0.8901 1.0137 Mar -09 0.9551 0.9323 1.0108 Apr -09 0.9844 0.8857 1.0103 May -09 0.9695 0.8722 1.0125 Jun -09 0.9584 0.8326 1.03 Jul -09 0.9811 1.0108 1.0394 Aug -09 0.9468 0.9473 1.0122 Sep -09 0.9685 0.9386 1.0252 Oct -09 0.9562 0.9219 1.0177 Nov -09 0.9476 0.903 1.0344 Dec -09 0.9442 0.8725 1.0356 ConocoPhillips West Sak Oil Pool 2009 Reservoir Surveillance Report ATTACHMENT West Sak Oil Pool 2009 Annual Reservoir Surveillance Report Future Development Plans West Sak Development The Kuparuk River Unit working interest owners plan to progress two or three West Sak wells to a drill - ready state during 2010. Likely possibilities are two offsets to 3K Phase 1 development, an injector and a producer, and a replacement well for 1D-140. All wells are anticipated to be multi -lateral horizontal completions. Timing will depend on rig availability and economic business climate. If drilled in 2010, these wells will be drilled late in the year and thus it is likely production will not commence until 2011. Ugnu Pilots/ Studies Plans to test an induction heater in well 1 H-Ugnu-01 are postponed due to the economic business climate. Feasibility studies and engineering for a thermal pilot in the DS -30 area are also deferred. Resource -wide subsurface description (reservoir and oil quality) activities are required to enable a more robust analysis of the resource target and identify the required piloting design and/or technologies. ConocoPhillips ConocoPhillips March 31, 2010 Mr. Dan Seamount, Commissioner Alaska Oil and Gas Conservation Commission 333 West 7v' Ave. Suite 100 Anchorage, Alaska 99501-3539 Re: 2009 Allowable Gas Offtake from Kuparuk River Oil Pool Dear Commissioner Seamount, James T. Rodgers Manager, GKA Development Greater Kuparuk Area ConocoPhillips Alaska, Inc. ATO -1326 PO Box 100360 Anchorage AK 99510-0360 Phone(907)263-4027 Fax: (907)265-6133 In compliance with Rule 13, Conservation Order No. 432D, ConocoPhillips Alaska, Inc., operator of the Kuparuk River Oil Pool, is hereby submitting the gas offtake volume information for 2009 (Attachment 1). During 2009, the annualized average gas offtake was 1,073 MSCFD, considerably less than the maximum allowable annual average gas offtake rate of 5 MMSCFD as stated in Rule 13 for Kuparuk River Oil Pool. If you have any questions concerning this data, please contact Mark Kovar at (907) 265-6097. Sincerely, James T. Rodgers Manager, GKA Development Greater Kuparuk Area Kuparuk River Gas Off Take 2009 Reservoir Surveillance Report ATTACHMENT Kuparuk River Oil Pool 2009 Annual Reservoir Surveillance Report Gas Offtake Data Iso^ 1401 120( 100C 0 LL w 800 600 400 200 0 Kuparuk Gas Offtake ,�cJV Fev�J� �aN _ PQ` day ,Jce ,J\� PJQJy` `e�'oec cY00 e �eQ c � �o�eF O ConocoPhillips 2009 I'vlonthly Gas Offtake IVISCPft SCFD RB D FAPrf'I 828 827839 731 1012 8 894 957 95690 956903 845 830 829733733 June 990 989710 July Jul 1177874 0 1039 August 993 9 993484 9348 877 September 982 1021867 981677 October 1435 1020600 901 November 1181 1435290 1267 December 14721043 1181133 4verape 1.073 1472387 1 mz io- 1300 _ Iso^ 1401 120( 100C 0 LL w 800 600 400 200 0 Kuparuk Gas Offtake ,�cJV Fev�J� �aN _ PQ` day ,Jce ,J\� PJQJy` `e�'oec cY00 e �eQ c � �o�eF O ConocoPhillips