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Home My WebLink About2006 Greater Kuparuk Arean Co opoPhill ps Greater Kuparuk Area Annual Surveillance Reports Kuparuk, Meltwater, Tabasco, Tarn, and West Sak Oil Pools Reporting Period January 1 December 31, 2006 * 2006 GKA Annual Surveillance Reports Table of Contents KUPARUK RIVER OIL POOL REPORT SUMMARY OF EOR PROJECT 2006 EOR Program Status,,,,,,,,,,,,,,,,,,,, Incremental EOR Oil Rate Plot PRODUCED FLUID VOLUMES INJECTED FLUID VOLUMES..............................................................................................7 RESERVOIR PRESSURE SURVEYS Proposed Pressure Survey Plan .................................... INJECTION SURVEY DATA 16 Proposed Injection Profile Survey Plan,,,,,,,,,,,,,,,, PRODUCTION SURVEY DATA21 ............................................................................................ MISCIBLE INJECTANT COMPOSITION CPF1MI Composition...................................................................................26 CPF1 EOR Analytical Report................................................................ CPF2 MI Composition,,,,,,,,, CPF2 EOR Analytical Report .................... KUPARUK LSEOR DEVELOPMENT PLAN GKA 365 -DAY SHUT-IN WELL REPORT „31 MELTWATER OIL POOL REPORT SUMMARY OF EOR PROJECT AND RESERVOIR MANAGEMENT ,,,,,,,,,,,,,,,,,,,,,,,,,,,,,,,,,,,,,,38 Meltwater Net Pay Map ................................................. PRODUCED FLUID VOLUMES 40 INJECTED FLUID VOLUMES 41 RESERVOIR PRESSURE SURVEYS Proposed Pressure Survey Plan............................................................. PRODUCTION/SPECIAL SURVEYS 46 WELL ALLOCATION 47 SHALLOW GAS SPECIAL MONITORING i 2006 Meltwater Elevated OA Pressures MELTWATER DEVELOPMENT PLAN AND OPERATIONAL REVIEW..................................50 TABASCO OIL POOL REPORT SUMMARY OF EOR PROJECT PRODUCED FLUID VOLUMES INJECTED FLUID VOLUMES RESERVOIR PRESSURE SURVEYS Proposed Pressure Survey Plan .................................................... PRODUCTION LOGS AND SPECIAL SURVEYS WELL ALLOCATION AND TEST EVALUATION SUMMARY FUTURE DEVELOPMENT PLANS ....................................................................................... 61 . TARN OIL POOL REPORT SUMMARY OF EOR PROJECT RESERVOIR MANAGEMENT SUMMARY PRODUCED FLUID VOLUMES INJECTED FLUID VOLUMES RESERVOIR PRESSURE SURVEYS Proposed Pressure Survey Plan ........................................................................ PRODUCTION LOGS AND SPECIAL SURVEYS................................................................... 69 PRODUCTION ALLOCATION FACTORS............................................................................. 70 TARN DEVELOPMENT PLAN AND OPERATIONAL REVIEW WEST SAK OIL POOL REPORT SUMMARY OF EOR PROJECT PRODUCED FLUID VOLUMES INJECTED FLUID VOLUMES RESERVOIR PRESSURE SURVEYS Proposed Pressure Survey Plan ......................................... INJECTION SURVEY DATA PRODUCTION SURVEY DATA GEOCHEMICAL OIL PRODUCTION SPLITS PRODUCTION ALLOCATION FACTORS ...............................85 .............................................. FUTURE DEVELOPMENT PLANS ConocoPhillips March 30, 2007 Mr. Dan Seamount, Commissioner Alaska Oil and Gas Conservation Commission 333 West 7th Ave. Suite #100 Anchorage, Alaska 99501-3539 Re: 2006 KRU Annual Reservoir Surveillance Report Dear Mr. Seamount, James R. Hand Supervisor - Drillsite Petroleum Engineering Greater Kuparuk Area ConocoPhillips Alaska Inc. ATO -1220 PO Box 100360 Anchorage AK 99510-0360 Phone (907)263-4027 Fax: (907)265-6133 In compliance with Rule 3, Conservation Order No. 1986, 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 2006. The following is an outline of the information provided: a. A summary of the enhanced recovery project (Attachment 1, page 2). b. Voidage balance, by month, for produced and injected fluids, including low molecular weight hydrocarbons (Attachment 20, page 6-7). c._ Analysis of reservoir pressure surveys taken in 2005 (Attachment 4, page 8). d. A tabulation of both injection (Attachment 5, page 16) and production (Attachment 6, page 21) logs and surveys analyzed during 2006 from wells in the Kuparuk permit area. e. Composition of enriched gas injected during 2006 and estimate of MMP (Attachment 7, page 24). f. Kuparuk LSEOR development plan (Attachment 8, page 30). g. 365+ days shut in well report (page 30) If you have any questions concerning this data, please contact Paul Burtis at (907) 265-6314. Sincerely, James R. Hand Supervisor Drillsite Petroleum Engineering Greater Kuparuk Area bcc: Central Files ATO -3 Attachment 1 Kuparuk River Unit Kuparuk River Oil Pool 2006 Annual Reservoir Surveillance Report Summary of the Enhanced Recovery Project I• Attachment 1 Kuparuk River Unit Kuparuk River Oil Pool 2006 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. The total number of MWAG drill sites that service the Kuparuk reservoir is 32 with 288 available EOR patterns. Many of these patterns are now mature in that they have received the originally designated volume of miscible gas injection. These mature patterns generally no longer receive miscible injectant (MI) but are available for use as lean gas injection wells when plant upsets occur. 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 NGL 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, all 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 2006, the MWAG project operated in full MI production mode for approximately nine months of the year. For about three months, from early -August into early - November, production problems at the Prudhoe Bay Field significantly impacted their ability to manufacture NGL for export and blending. Lacking an import NGL source for the MWAG project, Kuparuk shifted to an immiscible water -alternating -gas (IWAG) scheme to manage gas and optimize oil production rates. One aspect of this shift to IWAG operations is that the injected gas is placed into mature MWAG patterns so that we can maintain the less mature patterns for only MWAG injection. For the periods that we operated in the MWAG mode, Kuparuk imported an average of 26,800 barrels per day of Prudhoe NGL. This import NGL, when blended with the indigenous NGL and available lean gas generated an average of 252 MMscf/day of MI during the nine month period. Annualized over the entirety of 2006, we imported an average of 20,900 barrels per day of Prudhoe Bay NGL and generated 202 MMscf/day of MI. During full MI generation periods, the average gas injection rate into the Kuparuk Field was 181 MMscf/day with the remaining 71 MMscf/day being utilized for Greater Kuparuk Area satellite fields. Annual average MI injection rates were 148 MMscf/day for the Kuparuk Field and 54 MMscf/day for the satellite fields. The estimated incremental oil recovery in calendar year 2006 from the ongoing miscible WAG project was 32,700 STB/day, For the approximate three-month period of IWAG injection, IWAG injection rates averaged 256 MMscf/d, with 67 MMscf/day supplied to the Satellite fields Tarn and Meltwater and the remaining 189 MMscf/day injected into mature Kuparuk Field patterns. Averaged over the calendar year, total GKA, Kuparuk, and Satellite injection rates averaged 64, 47, and 17 MMscf/day, respectively. 2 [6 The priority for gas management at the Kuparuk field during 2006 was to balance solvent injection between the A -Sand and C -Sand so as to maximize total EOR and returned NGL rate while avoiding excessive gas production rates which would lead to production impacts due to gas handling limitations. Total GKA annual average gas production rate in 2006 was 307 MMscf/day, compared to 326 MMscf/d during 2005. This gas production drop mirrors the trend over the past few years of declining gas production rate. The drop in gas production is mainly driven by higher water injection levels and flat -to -declining gas injection levels and ongoing gas trapping in immature EOR patterns reducing the available returned gas. MWAG Small Scale EOR (SSEOR and SSEORX) Drill Sites 1A, 1Y, and 2Z continued MWAG during 2006. The 2006 average MI injection rate was 3 MMSCF/day. Large Scale EOR (LSEOR) The original LSEOR Drill Sites include: 1 F, 1 G, 1 Q, 1 R, 2A, 2B, 2C, 2D, 2F, 2G, 2H, 2K, 2M, 2T, 2U, 2V, 2W, 2X and 3F. The total MI injection rate into these drill sites averaged 81 MMSCF/day in 2006. EOR Expansions Expansions to the original LSEOR occurred over multiple phases and now include DS1 B, 1 C, 1 E, 1 L, 3B, 3G, 3H, 30, 3Q and 3S. During 2006, the average MI injection rate into these expansion drill sites was 64 MMSCF/day. IWAG During 2006 operations, the the Kuparuk EOR project continued to maximize the volume of available MI by blending all available lean gas with Kuparuk-sourced and imported NGL. IWAG operations were necessary for approximately 3 months beginning in early - August and continuing into early -November when production issues at Prudhoe Bay limited the production of NGL and limited our ability to generate spec MI. During the IWAG period, injection was focused onto mature MWAG patterns to limit the impact on the active flood in less mature gas injection patterns. 3 DE07�DEE (n N 7a)- X ryO d *010O W X O 11J C O LU J r- C) N c c O C I N p N c c O C N O CN 0')c (n co p NN c O C co O N o O4- O C (B Q LLJ - m tY OO 0 � (if [If _I Q. W r- O W Q WW r- O W Y CD O W LU U :3C LL ca o a_ DE07�DEE N .., J � N N ... W *010O W ct ct N N .., J � N N ... Nom•-•- _ ��"'iit� '-�'' � '4�� -.�► r .i■► Rill •�1,.2�..." -- 1 :� -� ter.■■. �li��• � _ ' 11 \ „�i. r NorJO IIIA / � • -' ■■�� -16 �}'?��■■�' .111 /. �♦ F r'1 ;, � � t■■■C III I -� x .: •f •.. t+ Y 5i Jf•.�.. G1 r �` i Attachment 2 Kuparuk River Unit Kuparuk River Oil Pool 2006 Annual Reservoir Surveillance Report Produced Fluid Volumes Attachment 2 Kuparuk River Oil Pool 2006 Annual Reservoir Surveillance Report Produced Fluid Volumes 2006 TOTAL 45,475 90,332 193,776 Cumulatives at Dec 31, 2005 2,022,288 1,368,069 2,669,102 Produced Fluid Volumes (Reservoir Units) OIL GAS WATER CUM OIL CUM GAS CUM WATER MO YR MSTB MMSCF MSTB MSTB MMSCF MSTB 1 2006 3,982 7,711 17,522 2,026,270 1,375,780 2,686,625 2 2006 3,582 6,804 15,301 2,029,852 1,382,584 2,701,926 3 2006 3,999 8,073 17,212 2,033,851 1,390,657 2,719,138 4 2006 3,930 7,733 16,519 2,037,780 1,398,390 2,735,657 5 2006 4,035 7,617 16,949 2,041,815 1,406,008 2,752,606 6 2006 3,761 7,207 15,702 2,045,577 1,413,215 2,768,307 7 2006 3,792 7,272 15,490 2,049,369 1,420,487 2,783,798 8 2006 3,936 7,734 16,209 2,053,305 1,428,221 2,800,007 9 2006 3,717 7,567 16,184 2,057,022 1,435,789 2,816,191 10 2006 3,776 7,835 16,136 2,060,798 1,443,624 2,832,327 11 2006 3,201 6,833 14,096 2,063,999 1,450,457 2,846,423 12 2006 3,765 7,945 16,455 2.067,764,,,,-_ 1,458,401 2,862,879 2006 TOTAL 45,475 90,332 193,776 Cumulatives at Dec 31, 2005 2,022,288 1,368,069 2,669,102 Produced Fluid Volumes (Reservoir Units) Cumulatives at Dec 31, 2005 2,487,404 1,554,554 2,715,950 6 OIL GAS WATER CUM OIL CUM GAS CUM WATER MO YR MRVB MRVB MRVB MRVB MRVB MRVB 1 2006 4,914 5,156 17,873 2,492,317 1,559,710 2,733,823 2 2006 4,420 4,520 15,607 2,496,737 1,564,230 2,749,430 3 2006 4,934 5,471 17,556 2,501,672 1,569,701 2,766,986 4 2006 4,849 5,198 16,850 2,506,521 1,574,899 2,783,835 5 2006 4,979 5,050 17,287 2,511,500 1,579,949 2,801,123 6 2006 4,641 4,802 16,016 2,516,142 1,584,751 2,817,139 7 2006 4,679 4,847 15,800 2,520,821 1,589,598 2,832,939 8 2006 4,857 5,196 16,534 2,525,678 1,594,794 2,849,472 9 2006 4,587 5,141 16,508 2,530,265 1,599,935 2,865,980 10 2006 4,659 5,354 16,459 2,534,924 1,605,289 2,882,439 11 2006 3,950 4,709 14,378 2,538,875 1,609,998 2,896,817 12 2006 4,646 5,456 16,784 2,543,520 1,615,454 2,913,601 2006 TOTAL 56,116 60,900 197,652 Cumulatives at Dec 31, 2005 2,487,404 1,554,554 2,715,950 6 Attachment 3 Kuparuk River Oil Pool 2006 Annual Reservoir Surveillance Report Injected Fluid Volumes Attachment 3 Kuparuk River Oil Pool 2006 Annual Reservoir Surveillance Report Injected Fluid Volumes Cumulatives at Dec 31, 2005 4,838,469 1,080,579 889,576 Injected Fluid Volumes (Reservoir Units) WATER GAS MI CUM WATER CUM GAS CUM MI MO YR MSTB MMSCF MMSCF MSTB MMSCF MMSCF 1 2006 22,201 0 6,522 4,860,670 1,080,579 896,098 2 2006 18,712 0 5,638 4,879,381 1,080,579 901,736 3 2006 21,649 0 6,565 4,901,031 1,080,579 908,301 4 2006 19,316 0 6,025 4,920,347 1,080,579 914,326 5 2006 18,621 0 6,258 4,938,967 1,080,579 920,584 6 2006 18,040 0 6,253 4,957,007 1,080,579 926,837 7 2006 17,529 0 6,126 4,974,536 1,080,579 932,963 8 2006 17,632 3,983 1,842 4,992,169 1,084,562 934,805 9 2006 17,921 5,805 0 5,010,090 1,090,367 934,805 10 2006 18,995 5,670 98 5,029,085 1,096,037 934,903 11 2006 16,853 655 4,795 5,045,937 1,096,692 939,698 12 2006 18,655 0 6,761 5,064,592 .,r 1,096,692 y 946,459y' 2006 TOTAL 226,123 16,113 56,883 Cumulatives at Dec 31, 2005 4,838,469 1,080,579 889,576 Injected Fluid Volumes (Reservoir Units) Cumulatives at Dec 31, 2005 4,923,014 949,107 667,182 7 WATER GAS MI CUM WATER CUM GAS CUM MI MO YR MRVB MRVB MRVB MRVB MRVB MRVB 1 2006 22,645 0 4,937 4,945,659 949,107 672,119 2 2006 19,086 0 4,268 4,964,745 949,107 676,387 3 2006 22,082 0 4,970 4,986,827 949,107 681,357 4 2006 19,702 0 4,561 5,006,529 949,107 685,918 5 2006 18,993 0 4,737 5,025,523 949,107 690,655 6 2006 18,401 0 4,734 5,043,923 949,107 695,389 7 2006 17,880 0 4,637 5,061,803 949,107 700,026 8 2006 17,985 3,541 1,394 5,079,788 952,647 701,420 9 2006 18,280 5,161 0 5,098,068 957,808 701,420 10 2006 19,375 5,041 74 5,117,442 962,849 701,495 11 2006 17,190 582 3,630 5,134,632 963,431 705,124 12 2006 19,028 0 5,118 5,153,660 ' 963,431 710,243 2006 TOTAL 230,646 14,324 43,060 Cumulatives at Dec 31, 2005 4,923,014 949,107 667,182 7 Attachment 4 Kuparuk River Oil Pool 2006 Annual Reservoir Surveillance Report Reservoir Pressure Surveys 8 Q N 1 0 cr. 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N N N N N N N N N N N N N N N N O N O N O N O N O N O N m G N 01 to (A m CA CA [n (n (P lA m CA (n d) m m M M M M M M O N N N N N N N N N N N N N N N N N N N N N N N N N O O O O O O O O O O O O O O O O O O O O O O O O O O O O O O o (U CD r O O E L 0 C Z a CD ..N.. CD c N U - N 4. C7 N N N n C¢D t0 CO M m V LO N LO r- w m m r N 1� m M n W O co m co Q N O Z O Z O Z r Z r Z r Z r Z O 0 r O O (3 O Ci O d O Ci O a O O r 6 r a N 6 N 6 r Q r t[ N (C O m O Co —17 Cn (n r m N m t M M CO M M CO M M M M co M M M M CO M M M M M M M M M M M M MIMI co I N ConocoPhillips March 30, 2007 Mr. Dan Seamount, Commissioner Alaska Oil and Gas Conservation Commission 333 West 7th Ave. Suite #100 Anchorage, Alaska 99501-3539 James R. Hand Supervisor - Drillsite Petroleum Engineering Greater Kuparuk Area ConocoPhillips Alaska Inc. ATO -1220 PO Box 100360 Anchorage AK 99510-0360 Phone (907)263-4027 Fax: (907)265-6133 Re: Kuparuk River Oil Pool — Proposed Pressure Survey Plan for 2007 Dear Mr. Seamount, In compliance with Rule 8, Conservation Order No. 432, ConocoPhillips Alaska, Inc., operator of the Kuparuk River Oil Pool, is hereby submitting the proposed pressure survey plan for 2007. There were 260 pressure surveys reported for the Kuparuk River Oil Pool to the AOGCC in 2006. In 2007, we expect to conduct approximately 200 pressure surveys, including initial surveys for new wells prior to initial sustained production. If you have any questions concerning this data, please contact Paul Burtis at (907) 265-6314. Sincerely, James R. Hand Supervisor - Drillsite Petroleum Engineering Greater Kuparuk Area bcc: Central Files ATO -3 15 Attachment 5 Kuparuk River Oil Pool 2006 Annual Reservoir Surveillance Report Injection Survey Data 16 W 0 O C7 „, � ; , • N - , .-H . ! 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O N N N Ln Ln \D Ln r rl ci r r r w,4 H O O) m O) 00 O 00 N Cry m O 00 co O H E r T M ci M M 'A lD \D -,.I- T c-1 W W H I W O µ' Lfl N I M O ri N 1 M O c -I N I M O H N I M O .-i N I O) N O N I O) N O i I dl N O N I N CN O d� Ln r lD N I 01 N O r a) � dl lD Ln N Ln w H W H E N O O N N N a i-7 W O O H O H z h H N co co N H r1 Ln (3) m O N O q H O 1-1 O O .-i H ri O O O H O H O O O O I O O I O O I O O I O O I O O I O O I O O I O O O O I O O I O O I OD OD M C) O m r H O M Ln H O M H N OH U) In O LP Ln O ri r) M N c OD W N c -i m M ci O H -i 0 O r T M ci M M 'A lD \D -,.I- T c-1 W W H I W O µ' Lfl N I M O ri N 1 M O c -I N I M O H N I M O .-i N I O) N O N I O) N O i I dl N O N I N CN O N I M O c-1 N I M O H N I D) N O N l D) N O N I 01 N O W N 'r lD O l0 r O Ln N O 'A Ln m i-7 W N x c -I 'A 41iI 'A E I O > I O >I c -I I 3 ci I 0.1 .-I I C7. N I C7 O I h O I h O I h .`� N N N N N N N M In m M M In 0) o w 10 0 0 0 0 00 M Ict Gn In d, O O z Ol N N [- 10 to to o � q Uq v R4 5: z z H z 0 z z H U + y' U 9 U � U F:4 N wFD H FC z H z 0 H N N N N a w o, o, rn rn 3 w -4 0 U u U w a a a a w a w Zo o 0 0 0 w114 Hw H o iH� x ° w wH ° 0a El rj 2 z Z z A a m m � W W> o w 0 0 ko 0 o a w w a o N rE a -i ko o m\ q P H o o r, r H N to O O co m o rn O O H HE.N El (JZ N N Lf) In q z N O N O O ri O 41 H 11 V O O O O (Y� O O O O i W N m Ol-4 OD N N O -4 H OM 00 Rei 1-1 r1. H �] WW N N N N H 1 04 O 1 Ol N m N mOI N N EO I A a' to O O O O A M H O CD W 3 ri M h M x M O M V ConocoPhillins March 30, 2007 Mr. Dan Seamount, Commissioner Alaska Oil and Gas Conservation Commission 333 West 7th Ave. Suite #100 Anchorage, Alaska 99501-3539 James R. Hand Supervisor - Drillsite Petroleum Engineering Greater Kuparuk Area ConocoPhillips Alaska Inc. ATO -1220 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 2007 Dear Mr. Seamount, In compliance with Rule 4, Conservation Order No. 1986, ConocoPhillips Alaska, Inc., operator of the Kuparuk River Oil Pool, is hereby submitting the proposed injection profile survey plan for 2006. In 2006, 44 injection profile surveys were reported for the Kuparuk River Oil Pool to the AOGCC. In 2007, we expect to conduct approximately 35 injection profile surveys, including initial surveys. If you have any questions concerning this data, please contact Paul Burtis at (907) 265-6314. Sincerely, "�2 �0;�-e James R. Hand Supervisor - Drillsite Petroleum Engineering Greater Kuparuk Area bcc: Central Files ATO -3 20 Attachment 6 Kuparuk River Oil Pool 2006 Annual Reservoir Surveillance Report Production Survey Data 21 0 Cn LL lfl m rl M !` to O C M �-HLO OD C Q U O O N rl N M m O I- O r- O O O LO O M H N m C O OD CD co H N O (' U) N I- l0 ri c -I C ul N H N M � rH N W W lfl C Z O H U W d cq ko N r- Lo N N OD 00 m N co -4 C u) Ln 1n d' OD r - O Q N C:, -T r, u) N C:> M N O r- O N O � O l\ •-i N N N 11 '-i N !� N O >> CD a J d I to m m H N m I� O O o3 O O C N N M M M m N M O d' M M N M O O O O O N CO O N W O Q 0 -H N N H N N `� .-I d+ N rH lfl ul .-i m N l� h dr -4 C In W Z Q U U U U U U U U U U U U U U Z Q d ? + < Fri + 4 � + 4 � + FC FC + 9 FC + < FCi + FZ4 FCi + 9 FC + < FCi + 4 FI; + FC W � + 9 + W' � + < Fri H a H a H a H a J M LL J O v 0 Q OQ LL > Of M U a, m a, U) a ul a U U a U a In Z a, cn ai uz N N a U)Q ~' a W a i-- < w M 0 a N N U U N N O U U U U U \ U \ U \ J of \ FC F:4 FC < J P W a ,�j \ FC FC \ < \ FC Fl; FC FC . it O co j W> d } r u) ul uz c G G u) ,(in > I- L- -H u) > u) u) U U O U —010 C) N u) N u) N ul N r N m N u) W O _ m E m E u) E m E m E Q 2 m E co E m E w E uz El m E m E m E LU N J LL Z W J_ W H a H a H a H a H a FL' m H a H a H a H a H a H a H a H a J M LL J O v 0 Q OQ LL > Of M U a, m a, U) a ul a U U a U a In a, m a, cn ai uz a, m ai W a U)Q ~' a W a i-- < w M 0 a U U U U U 2 U U U U U U \ U \ U \ J of \ FC F:4 FC < FC w \ FCi \ FC FC \ < \ FC Fl; FC FC . it O co j O z N > —010 C) ! Q O N x w¢ a `w x x x x x x a x a x Ix x W p, 0 } J W W w w w W w w w w w 2 w 2 w Z ! aU) L Z Z 01 Z I- L� > 2 2 2 Z Z 2 2 2 2 2 E N 2 2 E N 2 Z Z Z 2 2 Z Z 2 Y O w Q U ~ Q W� fn a a a a a CO a ` a U a En a U) a ul a m a ul J nlaze 0 d U m M U ul U LL uJ } o O 0 O 0 O 0 O O o O kD O to O io O io O to O to O to O to O Q J W \ \ \ \ \ \ \ \ \ \ \ \ \ \ LL > O 110 O CD rH H O 1- N M N O Cl) r-1 O N O ri -1-1 M t0 O N -4 m H I- O \ a I) C N OD m lf7 \ Q O 0 O O O O rl .--1 Cl O C) O O O O O CD O z O LL Q Q U m 0) m m m O m O m m m m m m W E \ N \ N \ N \ N \ m \ H \ rl \ d' \ N \ \ t0 \ lfl \ N \ N Q0 0 Z Q 11 c -I O H O rl rH O O O O O O H d Q' O O I N H O O I l0 cH O O I t0 N O O I M O O O 1 N L- r1 O I .-I l0 O O I O C O O I W O O O I M m O O I O N O O I 1 LO O O I rH t0 O O I N r O O I aD O LU m cL to O N cH N N -4 N N to O N C' N N OD N N m N N N M N C' O N m O N to N N m l0 N N m O O N m O c-1 N m a Q 0 p Z Lo m N O m N Cl m N O m N O m N O m N O m N O m N O m N O m N O N O N O N O N O w M N OD lfl OD �' N .-i t0 t0 1- O 1` '-i J [p O N N O -4 c -I d' O O .-i N Cl IH WW FC FC FC .-H Pa .-i fA I O Q W W I IW I C7 I U' Z 0 LL Ol dl 0\ N N CO O t` to -i r- ri ri M M ('j ri to Q U O O m 0l t- O � �--I N l0 O O I- 0\ M O CD m 00 OD O O Ow 0) ri LO N (� (n N N h LO Ol to N 01$ IH r- N m M W ao H H N N l0 M. 1-I Z O 0 W a N O N O W w N 0 W N l0 CD m m M coC M O l0 O N l0 tl' m c -i rl l0 O N N I- m O ko M O � dl O H H [0 M to to m ri CO N m M N H m H M H , N N CO CO N rl l- M H O 00 CL J in r -o w w w N H 0) l0 m m co W u'1 I` U-) N d' -W d' r- dl O dl O O m N O t- t- H O Ul H N O O m N H N H l0 M N M N t- to (3) (3) l� t- I, l0 CO M M H N N l0 LO -4 r1 M H ri H r1 li W z 0 z p U t U t C U t rC U t FC U t rC U t W U t C U t L U + 4 U t 4 U t rC U + 4 U +< U + O I pd ? 4 FC FC 9 FC < FC FC � � FC 4 4 FC t N W N O (� N O N O M N O N O M N O N O M N 0) N O aOD N m N O N co N O N O N N a) N O N N. O N O N N 0) N O LO 00 N M O J co LU Z O O rn N N N N O N z N Cl N ri r N to { N N J p 1- w ,� G +� (D y 0) c m c a W d d to u) a �_ <A (n !n N c c c In (n ~ u)in 4) in U)a)in O c in ,` ci n W O _ W ca m Q H I- LL :?Z m ca N J J M 1i. J z J W IL i H a s H a a FC M J J a Q J CL J o. H a a H a a J a J n. J d j ca m U (� (� U W in Ui O 0 '- boa '_ 0 �`�� 0 °- \\ W U V p w U a U a V a O a U a o a a LL o X05 z > O U o Q N am W � w> a 0 w cc w w � Of of CL Q J W W w w w w w w w w w w W ! c t Z z os z I---- Q a' 2 H E E � z z z z Z z z z z z Z z z z z z Z z Z z z z Z) Y O J< Q O a uai � N W W W � W W W U) U U) 0 0' LL p Lj} J W\ io O \ IDo O \ c0 O c0 OO c0 O O O O O O O c0 O c0 O O O t9 O c0 O V„ i 0 r \ N ri \ H O \ LO NQ co � M c0 N ao N c0 N N O tor N - N Q E- U) O O O O O O O O O O O O O O Z LL p O QU rn m o rn rn rn rn rn rn rn rn rn rn W Q PZ) Z 0 \ 0 \ 0 \ o O O rn �N- O O O O - O O O 0 0 d C) O .-i O I O I O I O O O O O O O O O O O O O O O O O O O O o O w m L0 CD Q z to d m N N 0) N O N N O N N m N O � l- .-i N N m N O t N W N O (� N O N O M N O N O M N O N O M N 0) N O aOD N m N O N co N O N O N N a) N O N N. O N O N N 0) N O LO 00 N M O J co LU Z O O rn N N N N O N N N Cl N � N r N to { N N 0 0 M U • ¢ U a> t0 r- r N r- O 00 r - co M r O O O O 00 I M co (D (n d' M N N r LO LO r M M M M W d' r r a0 r N M M r (0 N V) N • Z O F- D • U wd rl rl -V u'> N O M r- n r0 O O Cl) M O Cl) O) d. 0 O O � .d. O N n I`. N 't V N C')M �OT M M cr M coM Cl) Cl)N m d • • J_ O .1 M N m rn u) u7 c N M .-I O O M co N r 00 00 M O O O N N N 00 N� �t O N r d' O ti N 00 (O O d' N N O N O n r r` O d. O N 00 O r m H -i .-I ,-� N v -I r r r CO Cl) N r r • •U z o?+� U U +� U +� U +¢ U +a U +¢ U +a U +¢ U +a U +a U +¢ U +Q U +¢ U +a • O a C) � ¢ ¢ Q ¢ a a ¢ ¢ ¢ ¢ ¢ Z Lu 0) c c m c rn c •- w- a �n c c c c c c in i) (1) � CO U) in in <� v� u> cn is u� to . o ui cn a CO U • • p c� U) CO U) CO U) CO U) CO U U) U) to to W LL L�L i- I_- F- H H H H F- F- H H I_ H H- H • N J Z J W J JD J J J J J J J J J J J J M !L J LL > a a. d d IL a d 0.. CL IL d d IL IL O v p¢ O O a' w U U) U) U) U U) U co) U) co U co U)F • O R P � XD U U U U U U U U U U U U U U Zaoa� a- Cl' a a a a a a a a a a a a a a > w O j > 0 (0 Q' • Q D Y N > O J w ( w a D • J w W w w w w w w w w w w w w w Y73 z; Z ¢ 0 M Z Z Z Z Z Z Z Z Z Z Z Z Z Z YOU ¢ • ? (L U) U vi can U can can ai U) U U U U � U) LL L�L >- co O co O co O O O CO O O cD cO co • Q J W O O O O O O O O O O O O O O LL > CO 4 ila M 0) d' O O 00 r4 O •0 of f� O Iz NZZN n c0 M N M N O N O N. ` N n O M f0 O Of CO O O O O o O O O O o O O O • Z • O LL O Q U d' 't V d' It LO d' M. M M M M M • w= O 0) a) Q Q Q O O O O O Q OT ~ D O O O O O O a Z O O r r r r r r • IL • • O O O O O o O O O O O O O O O O O O O O O O O O O O O O v N n O CR c0 O N h N M O M O �. w N M N_ M N N_ M N N CD 0 N N N N N NN N N N N N N N • _ a 0 O_ O O O O O N N04 N N N N Q Z O r _O r _ r r O O O O O O O • J m r O O O r r O O r w Y Y N N r Cl) O N N N • �j Z) N N N N N N N N N N N Z • • • • 0 • • • • • • • • • • • • • • W J J M LL. J • —O w z 0- WQ CL F LU O O LLJ • >OU(° • Q N Y d W d 5 • Z:) d U Z Y Y O W Q • U J • • • • • • • • • • • • • J_ d W M O00 M a0 N O O O O 6) N 00 CD N N N d' O (fl r W W O O O O Om M N N N N r I r N N �` Cl) Cl) LO LO Z O ZIUQ UQ UQ UQ UQ UQ UQ UQ UQ O W U Q Q Q Q Q Q Q Q Q NCL Z 0 W Z (°n W Z U) W Z (n W Z U) W Z � W Z (°n W Z (°n W Z (an OLL O U) LL Lf) d' M It M M Cl) �� M Cl) M 00 co co O W Q. H Q U M M N N O N N I- co O 0 O co to M M U (/� r r rr 00 CO r r LL r r d d OJ_, 2 CL d CL IL OJ_. O O C' (n (n Z U) U) (n (n U) U) �a O O Z W° a a a a Of a a a 0: Cl) cN- m Cl) r m O rn eN- Cl) eN- N rn W NO 41 U U W Qom„ O O N r- V d' M f- M M ~ O O O O C Q 0- 0,� 04{ (n 0 W Cl) Cl) N N 0) M 0) to O I- 00 00 co O O Cl) Cl) N N O WL m Z m N O O O co N N 0 O O M M N N 0 O o O) co N N 0 o 0 M O N O o VN' O N N 0 o CD d' n N N 0 o W 0 ti co -W O 0 N H N n o n Of IL W L n M1� 07 N (O J_ d W M O00 M a0 N O O O O 6) N 00 CD N N N d' O (fl r W W O O O O Om M N N N N r I r N N �` Cl) Cl) LO LO Z O ZIUQ UQ UQ UQ UQ UQ UQ UQ UQ O W U Q Q Q Q Q Q Q Q Q NCL ui Q Q 0 Z W W U) W Z (°n W Z U) W Z (n W Z U) W Z � W Z (°n W Z (°n W Z (an OLL O W J a) (fl O @ M O M O O O (O O (O O J W F- J O W Q. H m (n m Jco .5 a) a) C U N C� U m (n U) a� C (n U) M LO O U ui Q Q 0 0 a W W U) W Z (°n W Z U) W Z (n W Z U) W Z � W Z (°n W Z (°n W Z (an OLL W O W J i- W (fl O M O M O M O O O (O O (O O (O O J W PF > Q' U co r co O Cl) O V' O O O co O O r M O - M LO O O N (O O Z LL > d d OJ_, d CL d CL IL OJ_. O O C' (n (n U) U) U) (n (n U) U) �a O Z W° a a a a a a a a 0: Cl) cN- m Cl) r m O rn eN- Cl) eN- N rn W NO 41 U ui Q Q 0 0 a W W U) W Z (°n W Z U) W Z (n W Z U) W Z � W Z (°n W Z (°n W Z (an U) W O W J i- W (fl O M O M O M O O O (O O (O O (O O (O O LU LL o W > Q' U co r co O Cl) O V' O O O co O O r M O N r N O M LO O O N (O O b O O Z N LL_ O ~ Q Q F- Z O U O d rn N rn O Cl) cN- m Cl) r m O rn eN- Cl) eN- N rn W NO 41 U O V4 _ 0- Q WL m Z O (n C) O N N N o O O O co N N 0 O O M M N N 0 O o O) co N N 0 o 0 M O N O o VN' O N o O O O N 0 o CD d' n N N 0 o W 0 ti co -W O 0 N H N n o n Of J J W L n M1� 07 N (O LU N X N N N Q Cl) U M C7 M 2 Cl) Cl) Z h Cl) Z Conservation Order 1988 Rule 3. Kuparuk River Unit Reservoir Surveillance Program Attachment 7 Kuparuk River Oil Pool 2006 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). An example of the EOR Analytical Report from each of CPF-1 and CPF-2 showing these measurements are provided on the following pages. Additionally, the detailed compositional analysis of the MI from each CPF is provided in tabular form on the following pages. The monthly average Minimum Miscible Pressures (MMP) of the MI is presented by CPF in the table below. Miscible Injectant supplied to CPF-3 drill sites comes from a combination of CPF-1 and CPF-2 sources. Based on volumes manufactured at each plant on a monthly basis and the active set of EOR patterns throughout the field, the MI at CPF-3 may be sourced from a single CPF or be a blend of sources from both MI plants. The MMP of the blended CPF-1 and CPF-2 MI provided to CPF-3 patterns is estimated on a monthly average basis and is reported in the attached table in the column for CPF-3. The fraction of CPF-3 MI sourced from each CPF is similarly summarized on a monthly basis in the table below. Minimum Miscible Pressures of MI Supplied to Each CPF MMP Target Spec = 3300 psia Notes: (1) Calculated value (2) Mechanical problems at CPF-1 (3) NGL Production problems at Prudhoe Bay 25 CPF1 CPF2 CPF3 (1) CPF3 MI Source Month CALC MMP** (psia) CPF1(0/.) CPF2(%) Jan -06 3703 3479 3479 0 100 Feb -06 3365 3532 3532 0 100 Mar -06 3348 3438 3438 0 100 Apr -06 Note(2) 3256 3256 0 100 May -06 Note(2) 3311 3311 0 100 Jun -06 3358 3372 3363 66 34 Jul -06 3569 3542 3558 59 41 Aug -06 Note(3) Note(3) Note(3) 0 100 Sep -06 Note(3) Note(3) Note(3) 0 100 Oct -06 Note(3) Note(3) Note(3) 0 100 Nov -06 3558 3543 3543 0 100 Dec -06 3414 3434 3434 0 100 Average 3474 3434 3435 12 88 Notes: (1) Calculated value (2) Mechanical problems at CPF-1 (3) NGL Production problems at Prudhoe Bay 25 + OOMr,1*,NMOrOl00 NMCDU)Od'000MO coM(Of�Mrf�f�d V 0000-0-000 Md'r-LOIt0ll�MLnrrl- t� 't d- M (0 M N 0 Lot"t N (� c0 N (+7 LO c0 cq M d' C7 c4 N r r r r r r N CV r r r MMr(OM0'It MMOCM (DnL)rNO2cOOMwr-P- ()Nr-00rrr,fl: Or-:r(p (V r r N N r M Ch r CV r M W (D M O't 1- O M M r't 9 OM Lo O M It M 0 W M d' Or Op�Mt�Nh(O7U') ZCMCV rNNNO�GV MCV r O (O 0 M f� CM (O M (O M (O LO (O I� M d M M V LOCOLOOMNrdgN(Or �cOMM(OLOMNNMOM V MML000f�rMN(Od'M N a0 1� N d r- LO d US aD Z w 20 (O r- r 0 O) o w ill 0 MM0(UNMrONMO �tnOrLONrMMLOU]� V Naol-rnMd-MOMIlao M N N N N N M M N N N 001`LOd'MrOrM'It MOI,OrMMMTLONO (� (p r r, q— q UO 7 M M d M 00 00 M M M d) U) N OD O I- NN,tM'd MTT-M(OM V d'�Md-M�r QOU)r-: (0 co c0 co c0 Lr) o o Lr) Lr) Lri OwM(OMO(ONMO� 01l-wM1�coOM'IT0M Tr a0M1�0Ur"�000r(p iiLr)of or-r-r(00.-wo co co r. o(or�w0r-0P, LONMMN(OdOrr�OM NU)MOCOONf�rM00M Z N N M N M M 7 N N g q O O O O o O O o o o O NNO(OWMMU)rMMO M( 0'I 00N't0r-M 011:(\Mtl�r*r-r-r-oo�r*-: 0 0 0 0 0 0 0 0 0 0 0 0 y"r r r r T T T T T T LL LL LL LL LL LL LL U- U- r.t_ U ^ •V rZ rL 1..1� rL rL rL rL cL rL rL rL WOOOOOOOOOOO O co co O O O (O 0 (O co O 0 0 0 0 o 0 o o o O O o o 0 0 o 0 o o o o o T N N N N N N N N NN Rf U)f�r�4(p�l`O�O ONZ�MM't(0w aN T 26 EOR ANALYTICAL REPORT KUPARUK LABORATORY CONOCOPHILLIPS ALASKA INC. Facility CPF-1 Distribution: Solvent (Lab) (Mole %) Lean Gas (Lab) (Mole %) MI (Target) (Mole %) Date/Time 2/24/06 2:07 PM 2/24/06 2:42 PM 2/24/06 2:30M 1.145 NGL Anal sis Sample Blending Gas Sample Mi Gas Sample LIMS # ABO9056 AB09055 r A-BO9067 Line Pressure 400 1400 3900 Line Temp. NA 0 0 SETCIM Tag FI-20GC F1-21GC Calculated Flow (MSCFD) 14286 55968 70254 Component Solvent (Lab) (Mole %) Lean Gas (Lab) (Mole %) MI (Target) (Mole %) MI (Lab) (Mole %) MI (Calc) (Mole %) CO2 0.322 1.145 0.980 0.760 0.978 N2 0.000 0.769 0.614 0.292 0.613 C1 6.648 84.254 68.651 69.878 68.473 C2 5.574 6.616 6.406 6.448 6.404 C3 10.295 3.629 4.969 5.175 4.985 iC4 10.120 0.865 2.726 2.803 2.747 nC4 27.707 1.700 6.929 6.899 6.988 iC5 8.110 0.462 2.000 1.861 2.017 nC5 10.102 0.411 2.359 2.186 2.382 C6 7.667 0.101 1.622 1.759 1.640 C7 7.774 0.038 1.593 1.244 1.611 C8+ 5.681 0.010 1.150 0.695 1.163 Total Moles 100.00 100.00 100.00 100.00 100.00 MW 64.22 20.08 28.96 28.06 Density (Ibs/scfl 37.52 Actual ENFL Rate Ideal BG Rate Actual Gas Rate Rate (Ib/d) 2,414,297 3,000,446 2,958,138 Rate (Mol/d) 37,595 149,391 Rate (MMSCFD) 56,768,452 Target Blend Gas Ratio (lb BG/Ib EF) 1.24 Actual Blend Rati( (From measured flow rates) 1.23 Youngren MMP 3300 Actual MMP (Using Lab MI Composition) 3503 Calc MMP (Using Lab BG/ENFL comp and rates) 3269 N LL a U Z O H N O IL m O U I— Z fY W Y fY IL D Y 0+0 r 000 N o00 I,- d' dam' CM7 N rn � U0or�0oM(ot�(?rr(or 0 0 0 0 0 0 x 0 0 0 0 ti m L() M M L() d' N M t N N U M ad N O r aD M S M (O Ln M N M Ln N N N N r r N T T r r T T N T T T T O CO m I-- M (O ;t r- M M N M U h co (�O ao co c�O 00 c�O dM- Ln CMO T T T T T r N r r T r d O d M y r- 00 m O M O U M O M r - (D M o O M M M N O P� 00 (fl (O M r� co t Ln Z N N T r- N N 4 N N N N LO O r- M M r tt CO O 00 00 M VOM0 (00 � � 7 r d' Oro 0000 0 O r r T T N N Cl) N r T N et r r d' (0 LO 't M M LO N d) U (D N O (D N d) M (O 1- 00 O M 00 N 1" I\ M 00 (O N I` co Z r (O t` O (O O 00 (D (O (O r-� M t� � (D 't W M"t M N O U M O O r M M P, qt d' M N S.O ti M f\ M' Un O N d O (h (V N N N N M N N N M Urn0rorr,.�(qrnti0CR(gCR00 It It Lo It It d' LO d= It u) N (p M O d' (O M T T O M O U (rO � M Cq Ln (NO 000 U1 OM0 M � (00N00(0000(00 r N M M N� Lfi M M Ln 00 � 060600600.=606 zw[I-mwr-wm(owlqtdt N N N N N N r N N N N 00000000000 U co co 00 (o r (o q (q (D (D q 00000000000 > N N N N N N N N N N N =LLLLLLLLLLLLLLLLLLLLLL a a a a a a a a a a a LLUUUUUUUUUUU (o (o (o to (o (o (o (o m (0 (o 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 a; N N N N N N N N N N N ,v T Lo 'fit \;t (o O z T N N co Lli CO r r N T 2 a Of N 10 O W n 2 IL co T 0 N � LL V M C N n N O O W r r 0 0 P M N O r o 9 - co - O N LL 0 W a 0 m N Y � d 0o N d® a E ohcn o';` LL U. r _ tmm',m _d d C r N. 01 A O U U LL m N E W W UIFm- U(n co C6 N N C% to co N J' �, aaaaaaaaaaa- E E E E E E E E E E E E N co 0p m m m m m m m m m m m m N In N N N N tl! Vl N N N N co m m2 0 0 0 0 0 0 0 0 0 0 0 0 3 m Z Z Z Z Z Z Z Z Z Z Z Z a x_ N <D N m M � LO P ED O a M U V O M W N OD tD OD Op fD M P O O m 0 47 N 0— 0 0 w P N w 4Y N 00 N O O O O �? c oU OtDh w� NCDMM0006 W a C LL N m r O P w w r N 0 0 0 0 0 O C7 m 0 E n N O r O e0 Q' M N m N 0 3 0 �'. O LL M p x x_ Es . w U� m Wco O U°� O LO Lu O O H N O, j S' O w M M O V N N N N O O r CG { Z J N O O 6 a a P N N co W M M O O N c;co 0 x 0 0 0 0 0 H 0 a U � U O 0�O �# a 5I- � LL U U`d m N N P P O P N d CO Lo 'r cO P W O O W O N M M t() of P T O O 0 m d co a N [t 'd N N d' tD tD O c N O C a) 4`SI J N a N m m m r a w P N N w r N r r 0 x�( �-a>-<U U Im M O O 7 M o1 i(7 M o1 M O M p co O JM coJ (� y ,,,� P tD M QO O t0 00 O P P M 1D N N N 't tD r P t0 N P O T M N '_ O 0 0 (o w IT N co N N r r 0 0 a d LL .. OI c Q O d' N M V' 0) M sT M <0 N O P a s V' Lo N N It�9 O O F O N"t O LQ V 7 t0 tD O"t N . O — rL r 0 f0 P N N t0 N r r r 0 0 (0 F O O O c0 � m o u'1 49 N P oo co M P P O M p O o T c0 N N d N Qi 0 O �f1 N P N O 00 47 m 0 " d. O N M M M cq M M 0 0 0 O ci mN co O O U r O n c6 wD r N 6 0 a o o 0 a a `- LL N LL O) C o u[ O O d' N O N N N V N P Cl O r O z 00 � m a w N r M O d h O) C m M ZM O 0 0 0 'R N u7 D) N Ol Qi P O a LL _ � c ❑ c 3 yaFU-oma 0Z000VCUCUUVN 02 aL - o (LI--v 0 2 d N F y 49 m 0 _ C C W Om.. -O. o J J J !n LLF- M C N n N O O W r r 0 0 P M N O r o 9 - co - O N LL 0 W a 0 m N Y � d 0o N d® a E ohcn o';` LL U. r _ tmm',m _d d C r N. 01 A O U U LL m N E W W UIFm- U(n co C6 N N C% to co N r M M N co co m N 3 U a N <D N m M � LO P ED O ED W) d m N N.•' N � w � lL W a C m C7 m 0 E n N O r O e0 Q' M N m N 0 3 0 �'. O LL M p E a.. �P a O Z Es . w U� m Wco O U°� O y �o N 0] m :..,W':'a a J m E a. U wlLL O 0�O �# a LL U c c c 9 a 0 m d co a C a) 4`SI 7 7 7 0 N m m m m 'm 0 O V m �o x�( �-a>-<U Attachment 8 Kuparuk Rive Unit Kuparuk River Oil Pool 2006 Annual Reservoir Surveillance Report LSEOR Development Plan During 2006, the Greater Kuparuk Area (GKA) averaged 20,900 BPD of PBU NGL imports and 8,300 BPD of indigenous NGLs for an annual average of 202 MMSCFD of Miscible Injectant (MI) manufacture. Of the total MI production in 2006, 148 MMSCFD was injected into the Kuparuk Field and 54 MMSCFD was allocated to the GKA satellite fields. Within the main Kuparuk Field, the 148 MMSCFD was allocated as: 3 MMSCFD for the SSEOR and SSEORX drill sites, 81 MMSCFD to the LSEOR drill sites and 64 MMSCFD to the LSEOR expansion drill sites. LSEOR expansion drillsites include drillsites: 1 B, 1 C, 1 E, 1 L, 3B, 3G, 3H, 30, 3Q and 3S. Currently MI is injected into all of the 22 drillsites sanctioned under the SSEOR/SSEORX/LSEOR project and the CPF-3 EOR expansion drill site 3F. Further drilling' .activity in the Kuparuk Rives 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 no new drill site -level expansions projects are currently sanctioned, the Kuparuk EOR project may be expanded to include any new wells. During a portion of 2006, from early -August through early -November, NGL imports were discontinued because of NGL manufacturing problems at the Prudhoe Bay Field. During this period, the Greater Kuparuk Area (GKA) fields were managed under IWAG injection. Over the period during which imports were curtailed, IWAG injection averaged 256 MMscf/d, with 67 MMscf/d supplied to the Tarn and Meltwater satellite fields. Averaged over the entire year, the IWAG injection rates were 64 MMSCFD total with 17 MMSCF going to the satellite fields. 30 ConocoPhilfips March 30, 2006 Mr. Dan Seamount, Commissioner Alaska Oil and Gas Conservation Commission 333 West 7th Ave. Suite #100 Anchorage, Alaska 99501-3539 Re: GKA 365 -Day Shut-in Well Report Dear Mr. Seamount, James R. Hand Supervisor - Drillsite Petroleum Engineering Greater Kuparuk Area ConocoPhillips Alaska Inc. ATO -1220 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 Kuparuk River Field, is hereby submitting our 365+ days Shut In Well Report. The attached document lists all wells in the Greater Kuparuk Area that have been shut in for more than 365 days. It also lists the reason the wells were shut in as well as the mechanical condition of the well and any future plans. These wells are different from the suspended wells, which have a separate report. If you have any questions concerning this data, please contact Paul Burtis at (907) 265-6314. Sincerely, James R. Hand Supervisor - Drillsite Petroleum Engineering Greater Kuparuk Area bcc: Central Files ATO -3 31 Lo 0 0 L O C. 0 w O c O a m 0 0 O L a) > c m ca 0 W .9 ,0 m ti - >0 > m Ca C6 3: >0> 3: y ZO a O O L O �. O 'E U Q a t � E CD 7 N � C p LL. +` ,N a) •Q N i ° i � C a iei �Q C.) ?r d 1,- N � c ti 1— otio Qr 0 °DU a LO ❑ nQO N O O \ E EO = O cm O OL a 'O O O o O EEOo0 O O> ca 0 O Fn p-0 a p 5 V a n . o�� p Lo o•E `o °� m oo ww C) 0-0 0a� L o 0 0- a 0 o 0 0) 0 m m O O c O O$ a) ca m o 0 m 0 cLa a) = a) c � ti (D __ a ' c ao cn m m m a) a) m m m -0a aai E 2 00 m m 0� O O °) (D o -C 'm ca 0) aa) :9 � o o 2 0 o c o c=a � L a�S�a zz��cn DT �o W co � w LLd LE Z) 2iL0 H C d a N N r CD r M M CD CD N N M r M M M N M M r O d CL 3 eta O LL Q° a Q ¢ Q �• . 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Y to d 'Ln V 1) j > — C O ca) O Y U 0 E U O Q O fa O c ca O c+a O $ p c a) yy Wi co N N a) ti OU C N Q N "a a) � '6 w- tl5 Q a) _ O (� (n N ❑ C N L -0 a) fa "� a) E "a c L O a) c 'O fl f6 v E N O O L �iL a) ..U.. -p � O N E M U Co 3U t- a) a) LL.� nc Cl) ca O O ZZ E V O O O .0 Q O a a3 C"5" CLW N a) U a) U UCD 0. �2�-i C) a) i a) a) o C C a) ..�. O Z U (D U .� O m L C a) E co CU O LL O LL J LL U LL J L ) w U LL O Z O Z a) W 0 n 0 ;O L fn 3: C OaU Z N _ e0 N d 'N M M N M N M N N Cl) M d' CO O L a �06 _ C ¢ ¢ a a a g a a_ Q gam, F-' �� N H a) I- 2 D 7 F= OQ �0 C a3 U �p y V N N w N U y fp N H (o N (D U) N N c C4 N M co to C N — F- y N U) c O LL Q = vIL d a d oma Cr-cs Nwd d oLp Q c cF- tq M N O N Co � N O N C co 3 �0-� to U) VJ fq CC �.... O N O E E E E E a� jZ E E E E E 2— c m E a) S z a) a) a) a) E� a) o � a) oo a) a) 0 a) 0� a) o E u � o g a) wv' W 0 L Q 0 L a 0 L Q a� Evan o L ai o o L n V)i< Ea_ u o L L aCL L L a ami (n EyE L QEa (a �+ C C C E C D U C EO ~ QU)a QO C C m C cu V C = Qi 3 CO OC 3 CO o� 3 COO O0 as U p 3 O o U) 3 O 0000 CO V 0OOo 3 coC O� 3 O 306 O 3 O O�Q O U O O 1p UOQ '- cv YOY c� OYO cd Q L a)Y fid' o x cvQ�� N Qm X�\Yp Od c Y�C�Y\ C� cr�On x� Q�- cQN Y O O� O� O� X C OCO.0 O�YOO a) OCO x0 f6Q—CO Oti O O O� X O XO V Z O Z O Z O I- J Z O I- J Z O F- r- L L O� O Z 0 Z Z 3 Z O Q 3 H 3 Z F d c LU LU O ❑ W ❑ w ❑ W W ❑ ui U CO ❑ ❑ W ❑ U) Q CU CJ ❑ m d _ T 4+ tr co It OO r O O Oa)N O O Oo OOiO Ovi Ov O0) -0 CL a) as ca o : �a) 0 a) a) a) :3LL O O i O co Q ❑ 2 ❑ d r- CN N N N M O O 0 - C Lo N M N d Z i W I W i W I W i W W W LL LL 04 2 d a d � i- LO 0 0 M Plo O Q. 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E� § @%§ o § _ $ $ � e £ f & t §: ck�� \) /k/. �� k°�� :3 �k�k2§: ° eo: ��0k��$� %\=kav ,0 co 0—) kA7\Ekk� r34k/��£§#°°§C� -0 § K0 CD ,� = > ( 0 / % f ■$Ia�3,�auOf-in10 �kad6w06 uwww4wa . w C -i ConocoPhillips March 30, 2007 Mr. Dan Seamount, Commissioner Alaska Oil and Gas Conservation Commission 333 West 7th Ave. Suite #100 Anchorage, Alaska 99501-3539 James R. Hand Supervisor - Drillsite Petroleum Engineering Greater Kuparuk Area ConocoPhillips Alaska Inc. ATO -1220 PO Box 100360 Anchorage AK 99510-0360 Phone (907)263-4027 Fax: (907)265-6133 Re: 2006 Meltwater Oil Pool Annual Reservoir Surveillance Report Dear Mr. Seamount, In compliance with Rule 10, Conservation Order No. 456, ConocoPhillips Alaska, Inc., operator of the Kuparuk River Field, is hereby submitting the annual surveillance report on the Meltwater Oil Pool. This report documents the required information pertinent to the field development and enhanced recovery operations from January through December 2006. The following is an outline of the information provided: a. Progress of EOR project and reservoir management summary (Attachment 1, page 38). b. Voidage balance, by month, for produced and injected fluids (Attachment 2&3, page 40-41). c. Analysis of reservoir pressure surveys taken in 2006 (Attachment 4, page 42). d. Results of production surveys, and any special surveys, taken on the Meltwater Oil Pool in 2006 (Attachment 5, page 46). e. Results of well allocation and test evaluation for Rule 7, and any other special monitoring (Attachment 6, page 47). f. Development Plan and Operation Review (Attachment 7, page 50). If you have any questions concerning this data, please contact Paul Burtis at (907) 265-6314. Sincerely, James R. Hand Supervisor - Drillsite Petroleum Engineering Greater Kuparuk Area bcc: Central Files ATO -3 37 Attachment 1 Kuparuk River Unit' Meltwater Oil Pool 2006 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 the Kuparuk section of the annual surveillance report. During the second quarter 2004, the 2P-427 was converted from production to injection service and injection began in the well during April 2005. The Meltwater field now has 19 total wells (12 producers and 7 injectors). Progress of EOR Project Development activities in 2006 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 2006: 1. Continued data acquisition program to collect valuable information on production and injection wells with limited data. The bulk of this program should. be completed in 2007. 2. IWAG (lean gas injection)' was implemented for a three (3) month period from early August through early November 2006 when production issues at Prudhoe Bay limited our ability to make spec Mi. Below is a listing of the most important new findings derived from the 2006 Meltwater development efforts: 1. Work began in 2006 and will continue through out 2007 on rebuilding the Meltwater subsurface model. Much of the work involves reanalyzing the current seismic data in order to better interpret the reservoir architecture and communication / support between the producers and injectors. 2. Outer annuli pressures in 2P-431, 2P-432, 2P-434, 2P-438, 2P-447, 2P -448A, and 213-451 remained at elevated levels in 2006. 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 11.15 MMSTBO, 733 MBW, and 26.8 BCF of gas by year-end 2006. Miscible gas injection began in 2002 with water injection beginning in 2003 (MWAG cycles). Cumulative injection through year-end 2006 at Meltwater has been 17.4 MMBW and 34.4 BCF of MI gas. Performance and surveillance data from the Meltwater producers indicates that they were receiving partial to limited support from the offset injection wells. Further work will be, done in 2007 to assess voidage replacement and support issues in the field. 38 Meltwater Field — Net Pay Map r 1 v 20 _—� 2P. saroeco 2 -45 (/� _ O `` P- 6 ATER / ,[-J/l12 -415 2P-448 k0 2 -�'P g 44 a _�2 -422A Net Pay (ft.) 0 rte- ✓/ 2 '44- 2P-4 \\ �Y -- 5865c00 10 20 30 40 MELT)�ATE" 50 60 -424 j7 \ i 70 80 f11 �P-424A 0 t � 90 o _ MILES — fo —_— 1O.lL - 5860000 110 0 1000 2000 1 3000 4000 5000 J i 120 FEET i 130 140 TRANSVERSE MERCATOR PROJECTION G.R.S. 198Q SPHEROID 150 CENTRAL MERIDIAN 150 CO 001A? Ivbpsheet datum:" Unknown" 160 170 Sb56232 1580000 1585000 1590000 1595000 1597659 39 Attachment 2 Meltwater Oil Pool 2006 Annual Reservoir Surveillance Report Produced Fluid Volumes Produced Fluid Volumes (Reservoir Units) OIL GAS WATER CUM OIL CUM GAS CUM WATER MO YR STB MSCF STB STB MSCF STB 1 2006 139186 339128 23771 9895778 22882596 470647 2 2006 121884 336997 17928 10017662 23219593 488575 3 2006 142587 528276 27472 10160249 23747869 516047 4 2006 131606 456992 25581 10291855 24204861 541628 5 2006 132456 486679 21952 10424311 24691540 563580 6 2006 123059 430412 15800 10547370 25121952 579380 7 2006 109030 328790 18634 10656400 25450742 598014 8 2006 113738 330758 24734 10770138 25781500 622748 9 2006 99319 282049 23501 10869457 26063549 646249 10 2006 99380 276948 28659 10968837 26340497 674908 11 2006 85462 260906 25148 11054299 26601403 700056 12 2006 91338 221219 15832 11145637 ' 26822622 715888 2006 TOTAL 1389045 4279154 269012 Cumulatives at Dec 31, 2005 9756592 22543468 446876 Produced Fluid Volumes (Reservoir Units) 2006 TOTAL 1854375 2736579 272778 Cumulatives at Dec 31, 2005 12983738 16280144 447389 Hsi OIL GAS WATER CUM OIL CUM GAS CUM WATER MO YR RVB RVB RVB RVB RVB RVB 1 2006 185813 202489 24104 13169551 16482633 471493 2 2006 162715 209338 18179 13332266 16691971 489672 3 2006 190354 352126 27857 13522620 17044097 517529 4 2006 175694 300528 25939 13698314 17344625 543468 5 2006 176829 323857 22259 13875142 17668482 565727 6 2006 164284 283489 16021 14039426 17951971 581748 7 2006 145555 209128 18895 14184981 18161098 600643 8 2006 151840 208374 25080 14336821 18369473 625723 9 2006 132591 176536 23830 14469412 18546009 649553 10 2006 132672 172425 29060 14602085 18718434 678614 11 2006 114092 166472 25500 14716176 18884906 704114 12 2006 121936 131818 16054 14838113';.-, 19076724" ., .,,72067,. 2006 TOTAL 1854375 2736579 272778 Cumulatives at Dec 31, 2005 12983738 16280144 447389 Hsi Attachment 3 Meltwater Oil Pool 2006 Annual Reservoir Surveillance Report Injected Fluid Volumes Cumulatives at Dec 31, 2005 11505513 2372323 27916984 Injected Fluid Volumes (Reservoir Units) WATER GAS MI CUM WATER CUM GAS MI MO YR STB MSCF MSCF STB MSCF MSCF 1 2006 622316 0 306208 12127829 2372323 28223192 2 2006 499520 0 333467 12627349 2372323 28556659 3 2006 598621 0 396351 13225970 2372323 28953010 4 2006 553024 0 332199 13778994 2372323 29285209 5 2006 577862 0 431309 14356856 2372323 29716518 6 2006 531777 0 394654 14888633 2372323 30111172 7 2006 497191 0 242890 15385824 2372323 30354062 8 2006 396202 174347 90184 15782026 2546670 30444246 9 2006 339569 341019 0 16121595 2887689 30444246 10 2006 331721 440471 8852 16453316 3328160 30453098 11 2006 353419 55276 307563 16806735 3383436 30760661 12 2006 628746 0 252537 774354$1 3383436 31013198 2006 TOTAL 5929968 1011113 3096214 Cumulatives at Dec 31, 2005 11505513 2372323 27916984 Injected Fluid Volumes (Reservoir Units) Cumulatives at Dec 31, 2005 11666590 2974893 24761095 41 WATER GAS MI CUM WATER CUM GAS CUM MI MO YR RVB RVB RVB RVB RVB RVB 1 2006 631028 0 244966 12297619 2974893 25006061 2 2006 506513 0 266774 12804132 2974893 25272835 3 2006 607002 0 317081 13411134 2974893 25589916 4 2006 560766 0 265759 13971900 2974893 25855675 5 2006 585952 0 345047 14557852 2974893 26200722 6 2006 539222 0 315723 15097074 2974893 26516445 7 2006 504152 0 194312 15601226 2974893 26710757 8 2006 401749 193351 72147 16002974 3168244 26782904 9 2006 344323 378190 0 16347297 3546434 26782904 10 2006 336365 488482 7082 16683662 4034916 26789986 11 2006 358367 61301 246050 17042029 4096217 27036036 12 2006 637548 0 202030 17679578 4096217 27238066 2006 TOTAL 6012988 1121324 2476971 Cumulatives at Dec 31, 2005 11666590 2974893 24761095 41 Attachment 4 Meltwater Oil Pool 2006 Annual Reservoir Surveillance Report Reservoir Pressure Surveys n v 0) n 0000 CO c M N 0 CO N N E 2 ly�V ao M M M M M rN d w O O O O OCD y co co 2 O d 0. 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O a c o J ZL w V- U) a) CD C IL a)o0. 1 O .. — 7 a) Z N 00 c0 m O U O U M G0 N N N N N CD N L ConocoPhillips March 30, 2007 Mr. Dan Seamount, Commissioner Alaska Oil and Gas Conservation Commission 333 West 7th Ave. Suite #100 Anchorage, Alaska 99501-3539 James R. Hand Supervisor - Drillsite Petroleum Engineering Greater Kuparuk Area ConocoPhillips Alaska Inc. ATO -1220 PO Box 100360 Anchorage AK 99510-0360 Phone (907)263-4027 Fax: (907)265-6133 Re: Kuparuk River Unit, Meltwater Oil Pool — Proposed Pressure Survey Plan for 2006 Dear Mr. 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 2006. There were 5 pressure surveys reported for the Meltwater Oil Pool to the AOGCC in 2006. In 2007, we expect to conduct approximately 6 pressure surveys, including initial surveys for new wells prior to initial sustained production. If you have any questions concerning this data, please contact Paul Burtis at (907) 265-6314. Sincerely, v James R. Hand Supervisor - Drillsite Petroleum Engineering Greater Kuparuk Area bcc: Central Files ATO -3 44 Attachment 5 Metwater Oil Pool 2006 Annual Reservoir Surveillance Report Production Surveys Special Surveys Attachment 5 Meltwater Oil Pool 2006 Annual Reservoir Surveillance Report Production/Special Surveys • Four (4) injection surveys were run during 2006. These logs, which in addition to pressure / temperature / spinner tools also contained waterflow tools, were run on 2P-427, 213-429, 2P-432, and 2P-447 while they were injecting produced water. There was no apparent out of zone injection identified on any of the injection profile logs. Well Survey Date Fluid Rate (BWPD) BHIP (prig) BHT (degF) 2P-427 20-00-2006 water 976 4581 108 2P-429 22 -Oct -2006 water 4086 4485 124 2P-432 26 -Oct -2006 water 2880 4326 121 2P-447 6-00-2006 water 1818 4378 1.20 Attachment 6 Meltwater Oil Pool 2006 Annual Reservoir Surveillance Report Results of Well Allocation, Test Evaluation, and Special Monitoring Well Allocation Meltwater DS 2P facilities were fabricated with a conventional test separator. A portable test separator system is utilized at DS 2P to handle the solids production during initial flowback (<1 week) of the fracture stimulated producers. 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 gas lift and injection at DS 2P. For the wells that were on MI lift during a well test, the metered liquid rates were adjusted for NGLs associated with MI lift. A Peng-Robinson equation of state calculated the NGL recycle volume based on MI volume, separator temperature and pressure. Production volumes were tracked through Setcim production monitoring systems. The 2006 Meltwater allocation factors by month are listed below. Meltwater Oil Pool 2006 Production Allocation Factors Oil Gas Water Jan -06 0.9130 0.8671 1.0766 Feb -06 0.9454 0.8804 1.0646 Mar -06 0.9413 0.89 19 1.0486 Apr -06 0.9484 0.87 58 1.0519 May -06 0.9367 0.8735 1.0423 Jun -06 0.9318 0.9099 1.0421 Jul -06 0.9638 0.9425 1.0839 Aug -06 0.9802 0.9341 1.0368 Sep -06 0.9556 0.9366 1.0300 Oct -06 0.9665 0.9078 1.0103 No�06 0.9728 0.9227 1.0065 Dec -061 0.9395 0. 8E 1.0100 47 Shallow Gas Special Monitoring 2P-431, 2P-432, 2P-434, 2P-438, 2P-441, 2P-447, 2P -448A and 2P-451 have elevated outer annuli (OA) pressures that rebuild pressure after bleeding. During 2006, no additional wells had OA pressures that increased to anomalous levels (2_900 psig). Three of the Phase II injection wells (2P-432, 2P-434, and 2P-447) have seen elevated OA pressures. The surface pressures are monitored daily via Setcim (wells have pressure transducers that transmit the real-time OA pressures). The OA fluid levels are shot once per month. Calculations are made monthly to determine the approximate pressures in the outer annuli at the C-80 interval in each of the wells that have elevated surface OA pressures. This data is then sent to the AOGCC. At the beginning of 2006, plans were put in place to take additional samples from the OA's to be sent off for isotopic analysis. However, as most wells exhibited relatively stable OA pressures throughout the year, this data gathering has been postponed to 2007. Upon completion, the results of the analysis will be compared with work done during 2003 and 2005. There are also plans to perform short term bleeds (approximately 1-3 hours) that will allow CPAI to monitor the fall-off and build-up pressures of the subject wells with elevated OA pressures. A report outlining the results of these bleeds will be submitted to the AOGCC in 2007. M. 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N. N J Lan N N" N N N N N C N C N M cli Q p 0 w 0 0 0 0 0 0 0 N O 0 0 av (D LO LO LD (D LO U) LO O O C a In r LL7 Ln LP Ln LO � � � N t0) ¢ O tDc0 t0 c0 t0 c0 t0 10 O c0 O O NNN O O O O O O O O O O N O O N O O N O O N O O N O O N c - O) 0 co r- LO 0 LO I- 0 Li) M 00 0 0 0 1` N C N CO CO O j et O C-1 r OCO N N O O r CL -C-1 v � ¢ c On n a UNT C Lo LO C 00 co N C ti 00 M O) LO C (D C r- C 0 a Mm r Cl) co — M - O - LO U) M M M d � d m rnLnLOv cD Cr`Ln ;NIE C 00 O CoO cD J N N N N N N N N Cco r N r- O N N N LL a O O ," 0 0 0 0 0 0 0 0 0 0 LO L() C N co N N LO LO N O LO ` N N N N N 00 N N N N N a � fn N �- 00 O O M N co (D M CO 0 - O- CO -- N N N Lf r r O O r •- C . r 3 r a CL Lu 2 a U CD O M r- N CV N O LI r M ¢ M r M M M C C M C O Qa ~ a a c, ti000OrnocODCODornOCD IL M N '-�' GV N ('M CV M C N M M J u�i N N N (V N N N N N N LL O t 0 0 0 0 0 0 0 0 0 0 0 ` C N. I- U) N U") N O M OO M M 0 N C M O M O M a r r r r r r r - r r r -- � V1 � Q O C N ' aD M O N N M . �' N j O 0 m 0 O O) . 0 0 O) 0 . 0 j Q � Lu C) Ltj M O CD M (D 00 00 O (D 00 co cD -q- O N M N M � a` g N c0 O O O 00 C O C co O) M co 00 M co C N CD N M O 00 c0 r 0 0 0 0 0 O (D J N LL E Q O O - O O Lf) O O O O O O O M y M O r- O O O N O O (O LO r 00 t ` 00 00 M co M 00 M 00 a 7 N c Q O O O O O O O O C0 O O O O O O O O O 10 O 10 O O N O N O N O N O N O N O N O N O N O N O N .- 0 Attachment 7 Meltwater Oil Pool 2006 Annual Reservoir Surveillance Report Meltwater Development Plan and Operational Review Following are summaries of key activities that are planned for 2007 and subsequent years. Development Drilling — One or two additional development well locations have been identified and tentative plans are to pursue drilling these well locations during 2008- 2010 timeframe. The total well count after the final portions of the development drilling program are completed is expected to be 20-22 wells. The acquisition of additional seismic data is currently being evaluated. This new seismic data would help to further evaluate the potential of the peripheral edges of the Meltwater pool, help to analyze producer -injector patterns, and identify infill potential. The total well count after the final portions of the development drilling program are completed is expected to be 20-22 wells. In 2006, it was discovered that injection wells 2P-419 and 2P-420 each had fill covering the lower perforated Bermuda intervals. This fill was unable to be circulated out with coiled tubing during fill clean out and milling operations; furthermore, each well had damaged casing as a result of the unsuccessful fill clean outs and milling operations. In 2007, coiled tubing sidetracks will be evaluated for both of these wells in order to restore injection into the entire Bermuda interval Exploration/Delineation — No further exploration work is currently planned for the Bermuda interval. However, the acquisition of additional seismic data could assist in identifying drilling potential of the peripheral edges of the field. Additionally, this data could help to evaluate the hydrocarbon potential of the overlying Cairn sand. 50 Con Phill s oco p 2006 Surveillance Reports Tabasco Oil Pool ConocoPhillips March 30, 2007 Mr. Dan Seamount, Commissioner Alaska Oil and Gas Conservation Commission 333 West 7t" Ave. Suite #100 Anchorage, Alaska 99501-3539 James R. Hand Supervisor - Drillsite Petroleum Engineering Greater Kuparuk Area ConocoPhillips Alaska Inc. ATO -1220 PO Box 100360 Anchorage AK 99510-0360 Phone (907)263-4027 Fax: (907)265-6133 Re: 2006 Tabasco Oil Pool Annual Reservoir Surveillance Report Dear Mr. 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 2006. The following is an outline of the information provided: a. A summary of the enhanced recovery project (Attachment 1, page 53). b. Voidage balance, by month, for produced and injected fluids (Attachment 2&3, page 54-55). c. Analysis of reservoir pressure surveys taken in 2006 (Attachment 4, page 56). d. Results of production surveys, and any special surveys, taken on the Tabasco Oil Pool in 2006 (Attachment 5, page 59). e. Results of well allocation and test evaluation for Rule 7, and any, other special monitoring (Attachment 6, page 60). f. Future development plans (Attachment 7, page 61). If you have any questions concerning this data, please contact Paul Burtis at (907) 265-6314. Sincerely, �> James R. Hand Supervisor - Drillsite Petroleum Engineering Greater Kuparuk Area bcc: Central Files ATO -3 52 Attachment 1 • Kuparuk River Unit Tabasco Oil Pool 2006 Annual Reservoir Surveillance Report Summary of the Enhanced Recovery Project Tabasco produced 1417 MSTB of crude, 335 MMSCF of formation gas, and 7401 MB of water during 2006. Water injection was 7845 MBW over the same period. Cumulative oil, gas, and water production and water injection through year end 2006 were 12680 MSTBO, 2012 MMSCF, 41217 MBW, and 45942 MBWI, respectively. The cumulative injection/withdrawal ratio was 0.84 on a reservoir barrel basis through year end 2006. Injector 2T-210 remained shut-in with mechanical problems which continue to prevent water injection. New wells 2T-203 and 2T-208 were completed but not on production at year end 2006. Year end 2006 Tabasco well count (all at Kuparuk River Unit Drill Site 2T) was: Producers: 10 completed 8 on line Injectors: 2 completed 1 on line The water:oil ratio (WOR) was 5.1 at the end of 2006 compared to 5.0 at the end of 2005. Water breakthrough has occurred at all 8 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. Work to develop a full field model for Tabasco is in progress and will continue through 2007. The model will be used to optimize the existing water flood and evaluate alternate recovery strategies. 53 Attachment 2 Tabasco Oil Pool 2006 Annual Reservoir Surveillance Report Produced Fluid Volumes 2006 TOTAL 1417146 335181 7400899 Cumulatives at Dec 31, 2005 11263223 1676458 33815882 Produced Fluid Volumes (Reservoir Units) OIL GAS WATER CUM OIL CUM GAS CUM WATER MO YR STB MSCF STB STB MSCF STB 1 2006 126595 27813 660899 11389818 1704271 34476781 2 2006 114967 23538 599788 11504785 1727809 35076569 3 2006 117442 18107 657724 11622227 1745916 35734293 4 2006 122840 19415 656707 11745067 1765331 36391000 5 2006 139073 35104 635632 11884140 1800435 37026632 6 2006 116499 33967 567070 12000639 1834402 37593702 7 2006 131847 37175 667264 12132486 1871577 38260966 8 2006 120701 40533 611493 12253187 1912110 38872459 9 2006 103407 25616 579179 12356594 1937726 39451638 10 2006 107961 20674 630735 12464555 1958400 40082373 11 2006 104110 26144 564808 12568665 1984544 40647181 12 2006 111704 27095 569600 126803692011639 4121678i> 2006 TOTAL 1417146 335181 7400899 Cumulatives at Dec 31, 2005 11263223 1676458 33815882 Produced Fluid Volumes (Reservoir Units) Cumulatives at Dec 31, 2005 11916490 13388 33815882 54 OIL GAS WATER CUM OIL CUM GAS CUM WATER MO YR RVB RVB RVB RVB RVB RVB 1 2006 136469 1294 660899 12052960 14682 34476781 2 2006 123934 842 599788 12176894 15524 35076569 3 2006 126602 0 657724 12303497 15524 35734293 4 2006 132422 0 656707 12435918 15524 36391000 5 2006 149921 2304 635632 12585839 17828 37026632 6 2006 125586 2815 567070 12711425 20643 37593702 7 2006 142131 2940 667264 12853556 23584 38260966 8 2006 130116 3953 611493 12983672 27537 38872459 9 2006 111473 1619 579179 13095144 29156 39451638 10 2006 116382 513 630735 13211526 29669 40082373 11 2006 112231 1699 564808 13323757 31368 40647181 12 2006 120417 1637 569600 1344417433006 41216781 2006 TOTAL 1527683 19618 7400899 Cumulatives at Dec 31, 2005 11916490 13388 33815882 54 Attachment 3 Tabasco Oil Pool 2006 Annual Reservoir Surveillance Report Injected Fluid Volumes Injected Fluid Volumes (Reservoir Units) WATER GAS MI CUM WATER CUM GAS MI MO YR STB MSCF MSCF STB MSCF MSCF 1 2006 679413 0 0 38776729 0 0 2 2006 622173 0 0 39398902 0 0 3 2006 690510 0 0 40089412 0 0 4 2006 658443 0 0 40747855 0 0 5 2006 688852 0 0 41436707 0 0 6 2006 647685 0 0 42084392 0 0 7 2006 631875 0 0 42716267 0 0 8 2006 665980 0 0 43382247 0 0 9 2006 650897 0 0 44033144 0 0 10 2006 666644 0 0 44699788 0 0 11 2006 576491 0 0 45276279 0 0 12 2006 665837 0 0 45942116 0 0 2006 TOTAL 7844800 0 0 0 Cumulatives at Dec 31, 2005 38097316 0 0 Injected Fluid Volumes (Reservoir Units) Cumulatives at Dec 31, 2005 38097316 0 0 55 WATER GAS MI CUM WATER CUM GAS CUM MI MO YR RVB RVB RVB RVB RVB RVB 1 2006 679413 0 0 38776729 0 0 2 2006 622173 0 0 39398902 0 0 3 2006 690510 0 0 40089412 0 0 4 2006 658443 0 0 40747855 0 0 5 2006 688852 0 0 41436707 0 0 6 2006 647685 0 0 42084392 0 0 7 2006 631875 0 0 42716267 0 0 8 2006 665980 0 0 43382247 0 0 9 2006 650897 0 0 44033144 0 0 10 2006 666644 0 0 44699788 0 0 11 2006 576491 0 0 45276279 0 0 12 2006 665837 0 0 45942116' 0 0 2006 TOTAL 7844800 0 0 Cumulatives at Dec 31, 2005 38097316 0 0 55 Attachment 4 Tabasco Oil Pool 2006 Annual Reservoir Surveillance Report Reservoir Pressure Surveys 56 m U .Q 7 C L 0 w w cn of w z O Z O U Of Z M O O N O N Of N_ O E `o LL �6^ Uf w v N N N O O O O N 7 y 2 p@ IL ` •> O O O O O O U N mM O IL CL � O Or O y O co O M O co O co O M M w �T m E Q 3 c 0 m O �� O m e M mo O O �� O � �(�Q O LL cn O 0 w LO C o f O O N E p p 0 CO Iq n rn n rn M � M n (0 m. Y Q V Q v m E co R V% cx N N N N N N L m O C Q O ui M 6 — w C 0 N co O (0 co 0 0 w w ca co O= Q (, ~ O a oo E x � L6 (D m a 0ca CD - o O w ca IL Y N n w w w m ` O O N Q � n Y a N•� a 8 a a a a a a � c ��„` N p O a a C (n (n (n (n (n (4 C 0 v a) co m v n 0 c N 0 CN `° MCU m j O O rn n N rn N U w c LL m cei E a F - 000000C M m co co co M O O O N_ N N m O O O co O C O) N y r N i U C m Y 0 O00 Qm Q Q Q Q m n 0 m U _ w w CD L w w m O w o O 0 0 0 0 0 0 72 U X U cc a c co m Z O O O O O O m E N F a X N N LO N O M � N . CD � I e j O O Cl O O O 3 p) oi X �( N N N N N N C y U C Y O O O O O O N Y N E m Z 7 a w w E Q Y m ca :3 D L m Z U) 0 U) CO 0 E a`> CLc �' O1 a O L J m w 05 C Na0 U O N Z y V M M GO OO N_ .0. T a L O C F N N N N N N Q a M O F- N N N N N N N L m U .Q 7 C L 0 w w cn of w z O Z O U Of Z M O O N O N Of N_ O E `o LL ConocoPhiffimm" March 30, 2007 Mr. Dan Seamount, Commissioner Alaska Oil and Gas Conservation Commission 333 West 7th Ave. Suite #100 Anchorage, Alaska 99501-3539 James R. Hand Supervisor - Drillsite Petroleum Engineering Greater Kuparuk Area ConocoPhillips Alaska Inc. ATO -1220 PO Box 100360 Anchorage AK 99510-0360 Phone (907)263-4027 Fax: (907)265-6133 Re: Tabasco Oil Pool — Proposed Pressure Survey Plan for 2007 Dear Mr. 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 2007. There were 6 pressure surveys reported for the Tabasco Oil Pool to the AOGCC in 2006. In 2007, we expect to conduct approximately 2 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 Paul Burtis at (907) 265-6314. Sincerely, James R. Hand Supervisor - Drillsite Petroleum Engineering Greater Kuparuk Area bcc: Central Files ATO -3 58 Attachment 5 Kuparuk River Unit Tabasco Oil Pool 2006 Annual Reservoir Surveillance Report Production Logs and Special Surveys MWD open hole logs were completed for the new horizontal production wells (2T-203 and 2T-208) which were drilled in 2006. The logging suite for both wells included density, neutron, and resistivity. The 2T-208 well was also logged with a field test LWD Laterolog. The Tabasco interval is frequently logged with high resistivity which can limit the effectiveness of the resistivity tool. The purpose of the Laterolog was to test an alternate logging technology for Tabasco. Since production wells are completed with gravel pack screens and' electrical submersible pumps, no production logs or special surveys are planned for 2007. _ 59 Attachment 6 Kuparuk River Unit Tabasco Oil Pool 2006 Annual Reservoir Surveillance Report Well Allocation and Test Evaluation Summary A minimum of two well tests per month was taken on production wells. Fluid . samples were obtained on a regular basis, and water cut corrections were applied to well tests as required based on the subsequent lab analysis. Generally, very good agreement was observed between the phase dynamics and the shakeout analysis. Production volumes were tracked through the Setcim production monitoring system. In 2002, Tabasco switched from an allocation factor of 1.0 to floating production allocation factors. Tabasco 2006 production allocation factors were as follows: Tabasco Oil Pool 2006 Production Allocation Factors Oil Gas Water Jan -06 0.9129 0.8670 1.0769 Feb -06 0.9453 0.8805 1.0647 Mar -06 0.9413 0.8918 1.0487 Apr -06 0.9484 0.8757 1.0518 • May -06 0.9367 0.8735 1.0423 • Jun -06 0.9317 0.9099 1.0421 Jul -06 0.9638 0.9426 1.0838 • Aug -06 0.9801 0.9340 1.0367 Sep -06 0.9556 0.9365 1.0298 Oct -06 0.9666 0.9079 1.0103 Nov -06 0.9727 0.9227 1.0065 Dec -06 0.9469 0.8772 1.0195 60 Attachment 7 Kuparuk River Unit Tabasco Oil Pool 2006 Annual Reservoir Surveillance Report Future Development Plans Two new horizontal production wells, 2T-203 and 2T-208, were drilled and completed in 2006. The wells were drilled at the top of the Tabasco structure to provide offset from slumping water injection. Both wells were shut in at the end of 2006 due to mechanical problems but have been returned to production in 2007. The installation of a 10" water injection pipeline to drill site 2T in 2007 will provide the ability to increase injection in the Tabasco and Kuparuk reservoirs. An injector conversion will be evaluated in 2007 since all Tabasco injection is currently from well 2T-201. Work continues on the development of a full field model. The model will be used to evaluate the potential for infill locations on the peripheral edges of the. field. Alternate recovery mechanisms such as gas gravity drainage will also be evaluated and may result in a re -development strategy for the field. 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. 61 March 30, 2007 Mr. Dan Seamount, Commissioner Alaska Oil and Gas Conservation Commission 333 West 7th Ave. Suite #100 Anchorage, Alaska 99501-3539. James R. Hand Supervisor - Drillsite Petroleum Engineering Greater Kuparuk Area ConocoPhillips Alaska Inc. ATO -1220 PO Box 100360 Anchorage AK 99510-0360 Phone (907)263-4027 Fax: (907)265-6133 Re: 2006 Tarn Oil Pool Annual Reservoir:_ Surveillance Report Dear Mr. 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 2006. The following is an outline of the information provided: a. A summary of the enhanced recovery project (Attachment 1, page 63). b. Voidage balance, by month, for produced and injected fluids (Attachment 2&3, page 64-65). c. Analysis of reservoir pressure surveys taken in 2006 (Attachment 4, page 66). d. Results of production surveys, and any special surveys, taken on the Tarn Oil Pool in 2006 (Attachment 5, page 69). e. Results of well allocation and test evaluation for Rule 7, and any other special monitoring (Attachment 6, page 70). f. Development Plan and Operation Review (Attachment 7, page 71). If you have any questions concerning this data, please contact Paul Burtis at (907) 265-6314. Sincerely, ames R. Hand C Supervisor - Drillsite Petroleum Engineering Greater Kuparuk Area bcc: Central Files ATO -3 62 Attachment 1 Kuparuk River Unit Tarn Oil Pool 2006 Annual Reservoir Surveillance Report Summary of EOR Project and Reservoir Management Summary Background In 1998 Arco Alaska, Inc received approvals for formation of the Tarn Oil Pool in the Kuparuk River Unit, an Area Injection Order for Tarn, expansion of the Kuparuk River Unit, and formation of the Tarn Participating Area. The Tarn Pool Rules and Area Injection Order were approved on July 21St and July 20tH 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 has allowed Tarn to switch from strictly an MI flood to an MWAG recovery process which will increase 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. IWAG (lean gas injection) was implemented for a three (3) month period from early August through early November 2006 when production issues at Prudhoe Bay Limited our ability to make spec MI. Reservoir Management Summary In 2006, Tarn produced 7.59 MMSTB oil, 7.45 MMBW water, and 12,269 MMSCF gas. The injection totals for 2006 were 12,895 MMSCF of Ml, 3,186 MMSCF of GAS and 15.92 MMBW of water:: The cumulative year-end 2006 UW ratio for Drill Site 2N is estimated at 0.99, while the estimated cumulative I/W for Drill Site 2L is 1.29. The average annual 2006 I/W ratios for Drill Sites 2N and 2L were 1.02 and 1.29, respectively. `Plans are to continue maintaining reservoir pressure by balancing monthly injection and production rates. 63 Attachment 2 Tarn River Oil Pool 2006 Annual Reservoir Surveillance Report Produced Fluid Volumes Cumulatives at Dec 31, 2005 72597320 104637373 11806647 Produced Fluid Volumes (Reservoir Units) OIL GAS WATER CUM OIL CUM GAS CUM WATER MO YR STB MSCF STB STB MSCF STB 1 2006 634640 1032919 476547 73231960 105670292 12283194 2 2006 609922 966351 455873: 73841882 106636643 12739067 3 2006 664712 1033995 514625 74506594 107670638 13253692 4 2006 656131 996797 487301 75162725 108667435 13740993 5 2006 692452 1079409 552903 75855177 109746844; 14293896 6 2006 761189 1158310 601967 76616366 110905154 14895863 7 2006 717230 1151937 690204 77333596 112057091 15586067 8 2006 651413 1092385 697664 7.7985009 113149476 16283731 9 2006 584419 933369 711114 78569428 114082845 16994845 10 2006 589052 909514 788143 79158480 114992359 17782988 11 2006 496248 882123 698439 79654728 115874482 18481427 12 2006 531005 1032724 771603 80185733 116907206 19253030 2006 TOTAL 7588413 12269833 7446383 Cumulatives at Dec 31, 2005 72597320 104637373 11806647 Produced Fluid Volumes (Reservoir Units) Cumulatives at Dec 31, 2005 97310845 97921049 11971940 64 OIL GAS WATER CUM OIL CUM GAS CUM WATER MO YR RVB RVB RVB RVB RVB RVB 1 2006 852456 722166 483219 98163301 98643215 12455159 2 2006 819108 664384 462255 98982409 99307599 12917414 3 2006 892636 702607 521830 99875045 100010206 13439243 4 2006 882767 660834 494123 100757812 100671041 13933367 5 2006 931087 730563 560644 101688899 101401604 14494010 6 2006 1022478 773485 610395 102711377 102175089 15104405 7 2006 963680 796476 699867 103675057 102971565 15804272 8 2006 875072 775946 707431 104550129 103747511 16511703 9 2006 785159 640455 721070 105335288 104387965 17232773 10 2006 791170 609375 799177 106126459 104997340 18031950 11 2006 666051 648182 708217 106792510 105645523 18740167 12 2006 712405 795643 782405 107504914 106441166 19522572 2006 TOTAL 10194069 8520117 7550632 Cumulatives at Dec 31, 2005 97310845 97921049 11971940 64 Attachment 3 Tarn River Oil Pool 2006 Annual Reservoir Surveillance Report Injected Fluid Volumes 2006 TOTAL 15924690 3186098 12895286 Cumulatives at Dec 31, 2005 79302615 Injected Fluid Volumes (Reservoir Units) 7087523 114121752 WATER GAS MI CUM WATER CUM GAS MI MO YR STB MSCF MSCF STB MSCF MSCF 1 2006 1214645 0 1071793 80517260 7087523 115193545 2 2006 1250653 0 1164722 81767913 7087523 116358267 3 2006 1279567 0 1511821 83047480 7087523 117870088 4 2006 1437831 0 1552837 84485311 7087523 119422925 5 2006 1553944 0 1464939 86039255 7087523 120887864 6 2006 1248912 0 1549226, 87288167 7087523 122437090 7 2006 1005265 0 1780978- 88293432 7087523 124218068 8 2006 1276073 1295682 447096 89569505 8383205 124665164. 9 2006 1794539 991495 0 91364044 9374700 124665164 10 2006 1566026 811003 14288 92930070 10185703 124679452 11 2006 1083644 87918 925679 94013714 10273621 125605131 12 2006 1213591 0 1411907 95227305`' 10273621 127017038 2006 TOTAL 15924690 3186098 12895286 Cumulatives at Dec 31, 2005 79302615 Injected Fluid Volumes (Reservoir Units) 7087523 114121752 2006 TOTAL 16147636 3605280 10489867 Cumulatives at Dec 31, 2005 80412855 8038668 93324565 65 WATER GAS MI CUM WATER CUM GAS CUM MI MO YR RVB RVB RVB RVB RVB RVB 1 2006 1231650 0 873221 81644505 8038668 94197786 2 2006 1268162 0 950765 82912668 8038668 9514855/ 3 2006 1297481 0 1229553 84210148 8038668 96378104 4 2006 1457961 0 1267955 85668109 8038668 97646059 5 2006 1575699 0 1183382 87243808 8038668- 98829441 6 2006 1266397 0 1251714 88510205 8038668 100081154 7 2006 1019339 0 1443094 89529544 8038668• 101524249 8 2006. 1293938 1445104 363185 90823482 9483771 101887434- 9 2006 1819663 1131874 0 92643144 10615646 101887434 10 2006 1587950 928543 11773 94231095 11544188 101899207 11 2006 1098815 99759 760293 95329910 11643948 102659500 12 2006 1230581 0 1154932 96560491;' 11643948 103814432 2006 TOTAL 16147636 3605280 10489867 Cumulatives at Dec 31, 2005 80412855 8038668 93324565 65 Attachment 4 Tarn Oil Pool 2006 Annual Reservoir Surveillance Report Reservoir Pressure Surveys 66 • i i • i i i • i Q i N i zH • o oC i Da i w. • 0 cc Z Wi 1.1.. i cc iLL ZCC Z i 000 d P i o— O i cc ¢ • �w • O Cl) i Y W • Qa i • z i z • a i • • • • • • i i N cz U CL ❑ E Q Cn W W cn Ir W W Ir Z O U) Z O U W Z d• n zg '� V lO M CO (A N O mm to Ln N f� O d' M O CA CO M O M N M O O N m N M M M O N N E Ocu N M N N M m 4• `\• N W a ❑(�CO V M V M M 7 ct' M d' -It V d• d' d• V 0NC CLDw 000000000000 t CIS LL fi O a O r k O O O O O O O O O O O O II N ❑ NNNNNNN to (.O O to � � 0 NNN M N 0 N w N M a`) Imo - .�' 3 a ti O 3 C J J O CO ❑ v O 00 Co O ,p Cd L N M V co O M N N 0 � V fl, v N I M N fA N CA N M M (O N N N It N O co V co M N N C LL N N ❑ O , r;a 0) U 2 oco r ° Q. I- .E p 0)Y U0) m p 00 r*.: r (O 'cP M O- M OR H O O)V M d' d'0) m d' V C p E ��' O M CMO co i!) M M 000 W co •z O, LO V M LO � V to U O O ❑ ~ N C❑ a (t) � fO r O COt1• N N COC 'Cd N N M V M M M M Z Z Z 0 ❑ o _a co x °) V L6 F O m - CL -�e i a) N O. O O _ y 0.00 N Q a LL Z -So o a n a a a LL LL a s Q v n r m m m m m m 2 m m 0 0 0 n p C m m m m m m m m m LL LL LL O N O IL p (n U) U) (n (n (n (n (n (n LL LL LL c i O O O) co - (O N O () (O CO N N0. a p a o 0) N O N O N to M N CO co rn O ani d• rn (n n n V L (n 0) +N- o LLL E c6 E a d FT rP co (n C m m m m m m m co m m o m OO �O O O O �O �O O �O OO OO OO ~_ (� O N N N O O CO N N N 5 O M N d' V O 0 0 O m 0 0 m O ❑ O O O O O O O O O 2 N_ o U(u U o � Y (� 00 m m M m m m m m m m m m `C •a E o ❑ ❑ ❑ ❑ ❑ ❑ ❑ ❑ ❑ ❑ ❑ ❑ a p Z Z Z Z Z Z Z Z Z Z Z Z CC O r aCD H H I H H F 0 cu c;T o c o o° -10 O O O - - i\ OO U U-0 c Z5 X c (ts 9 x CD C EX Z x o 0 0 0 0 0 0 0 o 0� E 0 4 0 FL x N N o O M C7 N 4 O CNOO In m CZd0A a LO O M(t� O LO O OO NM M7 M CO C\l NnO MVO O �cdCU N N N N N O N CV N N OOO N N N SU M M M Cl) co M M Cl) Cl) Cl) Cl) CUjlrN> D OOOOOOOOO co (EC Q - NOj a m m a Z Y� (u E a Y Z a� E a) m= a o L Z� Na U) d C d 0 "� 7Q N Z (A (O M r -W CO Q h (D M (A w O C D. CO N CO CO N N M M Cl) M M M - •O a N O ao J Z Z Z J J Z Z Z Z Z Z L U of N N N N N N N N N N N N N_ N cz U CL ❑ E Q Cn W W cn Ir W W Ir Z O U) Z O U W Z ConocoPhillips March 31, 2007 Mr. Dan Seamount, Commissioner Alaska Oil and Gas Conservation Commission 333 West 7th Ave. Suite #100 Anchorage, Alaska 99501-3539 James R. Hand Supervisor - Drillsite Petroleum Engineering Greater Kuparuk Area ConocoPhillips Alaska Inc. ATO -1220 PO Box 100360 Anchorage AK 99510-0360 Phone (907)263-4027 Fax: (907)265-6133 Re: Tarn Oil Pool — Proposed Pressure Survey Plan for 2007 Dear Mr. 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 2006. There were 12 pressure surveys reported for the Tarn Oil Pool to the AOGCC in 2006. In 2007, 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 Paul Burtis at (907) 265-6314. Sincerely, �ames R. Hand Supervisor - Drillsite Petroleum Engineering Greater Kuparuk Area bcc: Central Files ATO -3 68 Attachment 5 Kuparuk River Unit Tarn Oil Pool 2006 Annual Reservoir Surveillance Report Production Logs and Special Surveys One injection profile survey was conducted at drill site 2N. Results from the survey indicate there is no casing or tubing leaks and all injection is within the Bermuda interval. Injection rate, pressure, and temperature are summarized in the table below. Tarn Injection Profile Survey ❑ata Well Survey Date Fluid Rate BWPD) SHIP (psia) BHT (de F 2N-314, 2/20/2006 Water 1884 3760 116 Attachment 6 Tarn Oil Pool 2006 Annual Reservoir Surveillance Report Production Allocation Factors Oil Gas Water Jan -06 0.9129 0.8671 1.0769 Feb -06 0.9454 0.8805 1.0647 Mar -06 0.9413 0.8919 1.0488 Apr -06 0.9484 0.8758 1.0518 May -06 0.9366 0.8735 1.0423 Jun -06 0.9318 0.9099 1.0421 Jul -06 0.9638 0.9425 1.0838 Aug -06 0.9801 0.9341 1.0367 Sep -06 0.9556 0.9366 1.0298 Oct -06 0.9665 0.9078 1.0103 Nov -06 0.9727 0.9226 1.0065 Dec -06 0.9396 0.8637 1.0099 70 Attachment 7 Kuparuk River Unit Tarn Oil Pool 2006 Annual Reservoir Surveillance Report Tarn Development Plan and Operational Review Development Drilling — 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 2007 include a drilling program consisting of eight new wells on Tarn drillsites, 2L and 2N. Depending on rig availability and timing, an additional 2 wells may be drilled in the Tarn field during 2007. Currently, approximately 20 potential drilling opportunities are being evaluated. These opportunities include wells that may be drilled in 2007 in addition to a development program that would include 2008 and beyond. A portion of these penetrations would test the productivity of the peripheral edges of the field.: An update of the geologic and full -field reservoir model is being considered for use in development planning and flood optimization. Producer to Injector Conversions — There are no plans to convert any producers to injectors in 2007 at Tarn. 71 ConocoPhillips March 30, 2007 Ms. Dan Seamount, Commissioner Alaska Oil and Gas Conservation Commission 333 West 7th Ave. Suite #100 Anchorage, Alaska 99501-3539 Blaine M. Campbell Supervisor — Heavy Oil Development Greater Kuparuk Area ConocoPhillips Alaska Inc. ATO -1170 PO Box 100360 Anchorage AK 99510-0360 Phone (907)265-6220 Fax: (907)263-4486 Re: 2006 West Sak Oil Pool Annual Reservoir Surveillance Report Dear Mr. Seamount, In compliance with Rule 11, Conservation Order No. 406A, ConocoPhillips Alaska, Inc., operator of the Kuparuk River Field, is hereby submitting the annual surveillance report on the West Sak Oil Pool. This report documents the required information pertinent to the field development and enhanced recovery operations from January through December 2006. The following is an outline of the information provided: a. A summary of the DS 1C small scale enhanced recovery pilot project — 1CSSEOR (Attachment 1, page 73-75). b. Voidage balance, by month, for produced and injected fluids (Attachment 2 & 3, page 76-77). c. Analysis of reservoir pressure surveys taken in 2006 and pressure survey plans for 2007 (Attachment 4, page 78-79). d. Results of injection surveys, production surveys, and any special surveys, taken on the West Sak Oil Pool in 2006 (Attachment 5-7, page 80-84). e. Results of well allocation and test evaluation for Rule 7, and any other special monitoring (Attachment 8, page 85). f. Future development plans (Attachment 9, page 86). If you have any questions concerning this data, please call Paul Burtis at (907) 265-6314. Sincerely, �� Ine M. Campbell2 Supervisor — Heavy Oil Development Greater Kuparuk Area bcc: Central Files ATO — 3 72 Attachment 1 Kuparuk River Unit West Sak Oil Pool 2006 Annual Reservoir Surveillance Report Summary of the Enhanced Recovery Project At the end of 2006 there were 45 water injectors and 45 producers in service in the West Sak oil pool. Of those wells, 7 injectors and 9 producers were active at Drill Site 1J at the end of 2006. This represents an increase of 8 active producers and 5 active injectors within the West Sak pool from YE 2005 to YE 2006. Three appraisal wells were drilled north of the existing core area development to penetrate isolated fault blocks. MWD logging, side-wall coring, and fluid sample collection was performed to verify oil quality and oil water contacts within their respective fault blocks. This data will be used to optimize the future Northeast West Sak (NEWS) developments. The following wells were drilled and completed in 2006 into the West Sak oil pool: Name Well Type Target Service ii -101 Multilateral D/B/A Sand Producer 1J-102 Multilateral D/B/A Sand Injector 1J_109 Multilateral D/B Sand Producer 1J-115 Multilateral D/B/A Sand Producer 1J-127 Multilateral D/B/A Sand Injector 1J-137 Multilateral D/B Sand Producer 1J-152 Multilateral D/B Sand Producer 1J-156 Multilateral D/B/A Sand Injector 1J-159 Multilateral D/B/A Sand Producer 1J-166 Multilateral D/B/A Sand Producer 1J-170 Multilateral D/B/A Sand Injector 1J-182 Multilateral D/B Sand Producer 1J-184 Multilateral D/B Sand Injector The following appraisal wells were drilled and data collected in the Northeast West Sak area in 2006: Name Well Type Target Service 1 H -North Vertical (Ice Pad) D/B/A Sand Appraisal 1 H -South Vertical (Ice Pad) D/B/A Sand Appraisal 1 R -East Vertical (Ice Pad) D/B/A Sand Appraisal 73 Waterflooding the reservoir with CPF-1 produced water for pressure maintenance and improved sweep continues to be the main enhanced recovery mechanism in the West Sak oil pool. Waterflood performance has been good in the majority of the patterns; however, two rapid water breakthrough events occurred in 2006. These events created high conductive pathways between an injector and a producer. A list of the breakthrough events in 2006 are shown below: Injector Producer Event Date Breakthrough Zone 1 E-114 1E-168 March 2006 B Sand 1E-102 1E-121 June 2006 B Sand A study to understand the mechanism of these breakthrough events is ongoing. Some early recommendations to mitigate future breakthrough events have been implemented and the pace of these events has dropped off significantly. A remediation strategy is being developed for these wells as well as others that have previously failed. As of the submission of this report, no breakthrough events have been experienced within patterns where mitigation measures have been implemented on both the injector and producer. 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 consists of three phases in two permitted areas: Phase I : WAG wellbore completion integrity test; Phase 11 : WAG injectivity test; and Phase III : WAG breakthrough test. Phase I of the Pilot Project was initiated on September 22, 2003 with the commencement of injection of Kuparuk MI into 1C-135. Injection was continued for approximately two months. 1C-135 was returned to long-term production in April 2004. Production from the well indicated that slotted liner wells are suitable for gas production. Phase II of the Pilot Project was initiated in March 2004 with injection into deviated conventional injectors 1 C-119 and 1 C-121. 1 C-119 received one month of gas injection and the well was returned to water injection. Water injectivity after gas injection was initially lower, but recovered over about two weeks to the pre -gas injection levels. The 1 C-121 injector received 5 months of gas injection, was shut-in for several weeks and then returned to water injection. This well also recovered to the pre -gas injection levels. Due to surface casing leaks found in both 1 C-119 and 1 C-121, no additional wag cycles have been completed. Repairs have been made and the wells have been returned to water service only in August 2006 for 1 C-121, and late January 2007 for 1 C-119 74 Phase III of the Pilot Project was also initiated on March 2004 with gas injection into 1 C-121. Well 1 C-121 was on continuous gas injection for 5 months and resulted in an increase in the GOR of offset producer 1 C-102. Once 1 C-121 was switched to water injection, the GOR in 1 C-102 dropped back to its pre -gas injection level. No additional gas breakthrough was noted in 1 C-102 as subsequent WAG cycles in 1 C-119 and 1 C-121 were suspended as a result of failed surface casing which was detected early in 2005 in 1 C-121 and mid year in 1 C-119. In Late Nov. 2005, the first WAG cycle in horizontal undulating injector well 1 C-174 was completed. This first cycle was just over a month in duration and pre -gas injection water rates were established within a few days of returning to water injection. No gas breakthrough for this first cycle was observed in offset producers 1 C-178 and 1 C-170. The second WAG cycle in April 2006 lasted just over a month but no definitive GOR response was observed in offset producers 1 C-178 and 1 C-170. The West Sak Small Scale EOR (SSEOR) Pilot Project has been completed. The feasibility of future gas injection into the existing 1 C pilot injectors is under evaluation. No area injection order for continued gas injection is planned at this time. 75 Attachment 2 West Sak Oil Pool 2006 Annual Reservoir Surveillance Report Produced Fluid Volumes Cumulatives at Dec 31, 2005 19054450 7704765 4286386 Produced Fluid Volumes (Reservoir Units) OIL GAS WATER CUM OIL CUM GAS CUM WATER MO YR STB MSCF STB STB MSCF STB 1 2006 485812 439060 114236 19540262 8143825 4400622 2 2006 414795 296546 142663 19955057 8440371 4543285 3 2006 447154 239863 161929 20402211 8680234 4705214 4 2006 478901 238274 215281 20881112 8918508 4920495 5 2006 617386 412367 185806 21498498 9330875 5106301 6 2006 560194 515392 251790 22058692 9846267 5358091 7 2006 597609 478782 201586 22656301 10325049 5559677 8 2006 747431 661135 151594 23403732 10986184 5711271 9 2006 646158 611227 134815 24049890 11597411 5846086 10 2006 538927 388809 106177 24588817 11986220 5952263 11 2006 490616 367197 95324 25079433 12353417 6047587 12 2006 587307 431360 97766 25666740 12784777 6145353- 2006 TOTAL 6612290 5080012 1858967 Cumulatives at Dec 31, 2005 19054450 7704765 4286386 Produced Fluid Volumes (Reservoir Units) Cumulatives at Dec 31, 2005 20388261 5553524 4286386 OIL GAS WATER CUM OIL CUM GAS CUM WATER MO YR RVB RVB RVB RVB RVB RVB 1 2006 518847 569406 114236 20907109 6122930 4400622 2 2006 443001 366694 142663 21350110 6489624 4543285 3 2006 477560 262685 161929 21827670 6752309 4705214 4 2006 511466 248649 215281 22339137 7000958 4920495 5 2006 659368 484152 185806 22998505 7485110 5106301 6 2006 598287 661088 251790 23596792 8146198 5358091 7 2006 638246 587750 201586 24235038- 8733948 5559677 8 2006 798256 840773 151594 25033295 9574721 5711271 9 2006 690097 793943 134815 25723391 10368664 5846086 10 2006 575574 465580 106177 26298965 10834244 5952263 11 2006 523978 446230 95324 26822943 11280475 6047587 12 2006 627244 519830 97766 27450187 11800304 6145353 2006 TOTAL 7061926 6246781 1858967 Cumulatives at Dec 31, 2005 20388261 5553524 4286386 Attachment 3 West Sak Oil Pool 2006 Annual Reservoir Surveillance Report Injected Fluid Volumes Cumulatives at Dec 31, 2005 31442631 0 358765 Injected Fluid Volumes (Reservoir Units) WATER GAS MI CUM WATER CUM GAS MI MO YR STB MSCF MSCF STB MSCF MSCF 1 2006 518140 0 2294 31960771 0 361059 2 2006 539987 0 0 32500758 0 361059 3 2006 650520 0 0 33151278 0 361059 4 2006 685552 0 44316 33836830 0 405375 5 2006 692007 0 41837 34528837 0 447212 6 2006 651813 0 0 35180650 0 447212 7 2006 555327 0 0 35735977 0 447212 8 2006 470196 0 0 36206173 0 447212 9 2006 408151 0 0 36614324 0 447212 10 2006 641298 0 0 37255622 0 447212 11 2006 798146 0 0 38053768 0 447212 12 2006 961056 0 0 39014824 0 447212 2006 TOTAL 7572193 0 88447 Cumulatives at Dec 31, 2005 31442631 0 358765 Injected Fluid Volumes (Reservoir Units) Cumulatives at Dec 31, 2005 31442631 0 268715 WATER GAS MI CUM WATER CUM GAS CUM MI MO YR RVB RVB RVB RVB RVB RVB 1 2006 518140 0 1718 31960771 0 270433 2 2006 539987 0 0 32500758, 0 270433 3 2006 650520 0 0 33151278- 0 270433, 4 2006 685552 0 33193 33836830 0 303626 5 2006 692007 0 31336 34528837 0 334962 6 2006 651813 0 0 35180650 0 334962 7 2006 555327 0 0 35735977 0 334962 8 2006 470196 0 0 36206173 0 334962 9 2006 408151 0 0 36614324 0 334962 10 2006 641298 0 0 37255622 0 334962 11 2006 798146 0 0 38053768 0 334962 12 2006 961056 0 0 390148240 334962 2006 TOTAL 7572193 0 66247 Cumulatives at Dec 31, 2005 31442631 0 268715 Attachment 4 West Sak Oil Pool 2006 Annual Reservoir Surveillance Report Reservoir Pressure Surveys 78 M O N N cc N O LL I,, to NV' t0 co O d' M M M N (D M 00 N V Cl) M N V' I� 00 Cl) t. 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O O O O O O -2 O O V O x jC X co a c CO a X a> .c :1o xx o 0 0 0 0 0 0 o 0 o 0 o 0 O 0 O o o f _Z FL X O .o ..o O N 7 .O m 6 4 00 N a x to M N M V M M DD M co I� M 0 N M N w N t0 N Il N5 N C S X N N N N N N N M M M M M pt C p to N N N N W N N m N N W N N M N O � N E O O O O O O O O O O O a) L m C U) A cza Z a � aD a) 7 E Q Y w 0 w (o c Z U) co .. E a`) o_ rn LJ Ofi Z _O .N C U) N a) a. �_ > � O O � r � � r N � n 0Z a m 0CL 7 r71 O Q ❑ ❑ ❑. ❑ ❑ ❑ W W N .0 U M M O N N cc N O LL ConocoPhillips March 30, 2007 Mr. Dan Seamount, Commissioner Alaska Oil and Gas Conservation Commission 333 West 7th Ave. Suite #100 Anchorage, Alaska 99501-3539 Blaine M. Campbell Supervisor — Heavy Oil Development Greater Kuparuk Area ConocoPhillips Alaska Inc. ATO -1170 PO Box 100360 Anchorage AK 99510-0360 Phone (907)265-6220 Fax: (907)263-4486 Re: 2006 West Sak Oil Pool Annual Reservoir Surveillance Report Dear Mr. Seamount, In compliance with Rule 11, Conservation Order No. 406A, ConocoPhillips Alaska, Inc., operator of the Kuparuk River Field, is hereby submitting the annual surveillance report on the West Sak Oil Pool. This report documents the required information pertinent to the field development and enhanced recovery operations from January through December 2006. The following is an outline of the information provided: a. A summary of the DS 1C small scale enhanced recovery pilot project — 1CSSEOR (Attachment 1, page 73-75). b. Voidage balance, by month, for produced and injected fluids (Attachment 2 & 3, page 76-77). c. Analysis of reservoir pressure surreys taken in 2006 and pressure survey plans for 2007 (Attachment 4, page 78-79). d. Results of injection surveys, production surveys, and any special surveys, taken on the West Sak Oil Pool in 2006 (Attachment 5-7, page 80-84). e. Results of well allocation and test evaluation for Rule 7, and any other special monitoring (Attachment 8, page 85). f. Future development plans (Attachment 9, page 86). If you have any questions concerning this data, please call Paul Burtis at (907) 265-6314. Sincerely, � 2- ` o, -e/ , � Blaine M. Campbell 1412-- Supervisor 2Supervisor - Heavy Oil Development Greater Kuparuk Area bcc: Central Files ATO — 3 72 Attachment 5 West Sak Oil Pool 2006 Annual Reservoir Surveillance Report Injection Survey Data 80 �a�7 .ca ao zo zo zo zo z to M d� v -i N rM U U U �-I OJ d� � M W dl N N aN M `-I11 W 1O 0 F� r 0 m N 0 m M 0 u� � m r o z O O O O M Ol Ifl dl r ci r O O O O O O r m O ri N H N m M T N O Ifl O M lD z to M d� v -i N rM I r -I M l0 U1 M W M �-I OJ d� � M W dl N N N M `-I11 2 u H � Q mm m 4 m m C +W m 4 m+ m 4 N H z Ol Q W F4 9 H N O cq N O N O a U N O N N O z In r r c o v w w z � z H f7 w e-+ I '-i I I z O 1 I O O O O O O O O � a 1p I 1 1p I 1 M I r -I I l0 I W z W tT M W dl N In N O M r N 2 u m m w m 4 mm m 4 m m C +W m 4 m+ m 4 N H z Ol a F4 9 H N O cq N O N O N O N O N N O z In r r c o v w w v f7 w e-+ I '-i I I 3 P4 H tm a a a a O 4J u u u U 5 5� P4 � w a a a a a a r o 0 0 0 0 0 o w a M O .D to r -I r-1 ri r -I ri N ri r -i r -I rl ri rl W W ai w° w° w° W° w° w° P, W a a a x a x W fY m P4 y N N a can tail W W F 0 0 0 0 0 0 o a H WW OD N 1p O N N 1p NE, rl Ol O D (x m io r M o io q W z W o W rn 111 o In o l0 o \D 0 O � H E+ W H W r H O N El N CN N .-I Na a O Q H H O O O O O O 1 I O O O O O O O O 1p I 1 1p I 1 M I r -I I l0 I W W tT M W dl N In N O M r N W W N N M N M N M N M N. H 1 Ol O\ a 0 !l, Ifl N O cq N O N O N O N O N N O In r r c N io f7 ri e-+ I '-i I I A ca w w h h Attachment 6 West Sak Oil Pool 2006 Annual Reservoir Surveillance Report Production Survey Data 81 1O O 40 `o 0 04 U � w " ko o 11 P4 .1 r,H 00 r, E H O H El a QEl aa' -i O O 11 -1 O O � Q Aa a a H q a r ,1 ui N 11. In rn 00 co O N Ln O 0 0 O W 111 N O H > i W R7 W+ W 9 O w U 0r UI 0% T q 0 o O .1 H f4 04a N 1 N 11 a b 3 P4 E O ,� , 11 H L U ro 0 a a w w �+ H E O a w E � 0 P4 a � o 0 H 04 P4 E H aa' Q W O 0 H > i 0r UI 0% T q a o O b 0 O z ro 0 O H E O O W E � W cDa H Q a a, u 0 0 o x a 0 o a o b a M M +� W M M O N N H H T Ol a F� O 1f1 N O N O A A P I- O W N r a to Attachment 7 West Sak Oil Pool 2006 Annual Reservoir Surveillance Report Special Survey Data Geochemical Oil Production Splits 84 Attachment 5 Kuparuk River Unit West Sak Oil Pool 2006 Annual Reservoir Surveillance Report Production Logs and Special Surveys Geochemical Oil Production Splits: Well Name Sample Date A Sand B Sand D Sand 1 B-101 02/11/06: 0% 47°la 53% 1 B-101 05/11106 0% - 48% 52% 1 B-101 09/17/06 0% 39%. 61% 1B-101 09/30/06 0% 35% 65% 1 C-102 05/11/06 0% 3% 97% 1C-102 09/17/06 0% 5% 95% 1 C-102 12/20/06 0% 15% 85% 1 C-104 02/09/06 < 0% 56% 44% 1 C-104 . 05/11/06 ; 0% 41% 59% 1 C-104 09/18/06 0% 36% 64% 1C-104 12/20/06 0%, 53°l0 47% 1 C-109 02/09/06 0% 39% 61% 1C-109 05/11/06 0% 30% 70% 1 C-109 09/18/06 0% 36% 64% i C-109 12/20/06 0% 52% 48% 1C-133 11/27/06 0% 23% 77% 1 C-135 05/11/06 0% 19% 81% 1C-174 ': 08/30/06. 0% 100% 0% 1C-178 05/11/06 0% 23% 77% 1 C-178 09/19/06 0% 31% 69% 1 D-102 02/07/06 12% 37% 52% 1D-102 02/16/06 7% ; 17% 76% 1' D-102 10101/06 1% 54% 46% 1 D-108 02/16/06 35% 33% 32% 1 D-108 05/10/06 31% 24% 45% 1D -110A 02/16/06 41% 2% 56% 1D -110A 05/10/06 36% '; 12% 52% 1 D -i 1OA, 10/01/06 53% " 9% 38°l0'' 1 D-11OA, 12124/06 46% 11% 44% 1 D-112 02/17/06 45% 24% 31% 1 D-112 05/10/06 45% 29% 26% 1 D-112 09/14/06 46% 30% 24% 1 D-112 12/25/06 42% 42% 17% 1'' D-113 12/25106 38% 31% 31% 1 D-115 02/16/06 51% 27% 22% 1 D-115 05/10/06 45% 34% 21% 1 D-115 12/25/06 45.% 35% 20% 1'D 116 02/16/06 ', 42°Io 40°/a 18% 1 D-116 05/10/06 33% ` 44% 23% 1 D-116 09/14/06 44% 36% 21% -- ID -116 ` 12/24/06 42% 38%" 21%, 1 D-118 02/16/06 80% 0% 20% 1 D-118 05/10/06 77% 0% 23% 1 D-118 09/13/06 74% 0% 26% 1 D-118 12/23/06 73% 0% 27% D-123 1 02/15/06 49%' 52% 0% Geochemical Oil Production Splits: Well Name Sample Date A Sand B Sand D Sand 1 D-123 _ 05/10/06 49% 48% 3% 1 D-123 09/13/06 51% 45% 4% 1 D-123 " 12/23106 56%: 39% 6% 1D-124 02/15/06 49% 32% 19% 1D-124 05/10/06 48% 37% 15% 1D-124 09/13/06 44% 38% 18% 1D-124 12/23/06 43% 39% 18% 1D-126 02/15/06 50°!0": 50% 0% 1 D-126 05/10/06 51% 47% 1 % 1 D-126 ' 09/14/06 54% ": 34% 12% 1 D-126 12/22/06 ' 59% 34% 7% 1D-129 02/15/06 52% 36% 1'2% 1D-129 05/10/06 52% 34% 14% 1D-129 09/13/06 61% 18% 21% 1D-129 12/22/06 50% 31% 18% ID -131 +++ 02!15/06 ''' 21% ` 79% 0% ID -131 ! 05/10/06 46% 46% 8% 1 D-131 09/13/06 ' 53% 45% 2% 1 D-133 02/15/06 68% 20% 11% 1 D-133 .05/10/06 54% 28% 18% 1 D-133 09/13/06 53% 28% 120% 1 D-133 12/23/06 53% 24% .23% 1D-134: 02/15/06 ': 27°10`: 58% 15%`. 1 D-134 05/10/06 54% 28% 19% 1 D-140 02/16/06 0% 49% 51% 1 D-140 05/10/06 0% 51% 49% 1D-140 12/24/06 0% 55% 45% 1 E-121 ; 12/12/06 0°J0 48% 53% 1E-121 09/16/06 + 0% ;' 51% 49% 1' E-121 05/08/06 0% 52% 48°la IE -121 02107/06 `; 0% 61% 39% 1E-123 12/11/06 0% 57% 43% 1E-123 09/16/06 0% 34% 66% 1E-123 05/08/06 0% 52% 48% 1E-123 02/07/06 0% 55% 45% 1 E-126 12/11/06 13% %' 73% 14%, IE -126: 09/17/06 ' 27% ' 63% 10% 1E-126 05/08/06 ' 21% 76% 3% 1E-126 03/01/06 21% 76% 3% 1 E-166 12/11/06 8% 56% 36% 1E-166 09/17/06 9% 52% 39% 1 E-166 05/08/06 10% 59% 32% 1E-166 02/07/06 27% 19% 54% 1E-168 09/17/06 2°J0 48°l0 50% 1' E-168 05/08/06 1% '' 41% 57% 1 E-168 ` 02110/06: 15% 58% 27% 1E-170 12/12/06 38% 40% 22% 1E-170 09/17/06 45% 32% 23% 1E-170 05/08/06 35% 34% 30% 1E-170 02/06/06 48% 33% 19% 1J-101 03/05/06 21%,, 38% 41% 1J-101 03/12/06 19% ' 38% 43% 1J-101 03/21/06 0% ''' 100°Jo 0% 1:J-101 03/27/06 ' 0% 99% 1% , Geochemical Oil Production Splits: Well Name Sample Date A Sand B Sand D Sand 1J-101 04/02/06 " 11% 50% 39% 1J-101 09/13/06 41% 13% 46%°: 1J-101 12/11/06 31°I° 22% 47% U-102 11/28/06 25% 36% 39% U-102 12/09/06 25% 36% 39% 1J-109 09/01/06 0°l° 0% 100% iJ-115 12/26/06 30% 30% 40% U-127 09/06/06 31% 16% 53% U-127 09/13/06 33% 12% 55% U-127 09/14/06 18% 40% 42% 1J-137 10/15/06 0°I° 54% 46%. U-152 05/01/06 12% 42% 46% U-152 12/11/06 37% 20% 43% 1J-156 < 09/05/06 16% 34% 50%d U-159 09/13/06 34% 21% 45% iJ-159 .12/11/06 30% 26% 44% 1J-164 01/31/06 17% 50%° 34% IJ -164 02/06/06 21% < 50%° 29% U-166 04/03/06 29% 45% 26% U-166 04/10/06 26% 44% 30% U-166 04/20/06 8% 61% 31% U-166 05/06/06 19% 50% 31% U-166 09/13/06 46% 15% 40% U-166 12/11/06 51% 17% 32% iJ-170 09/01/06 24% 57°I° 19% IJ -170 09/03/06 60% 2% 38% U-184 07/11/06 0% 100% 0% U-184 09/03/06 3% 86% 12% iJ-184 12/28/06 7% 71% 22% Attachment 8 West Sak Oil Pool 2006 Annual Reservoir Surveillance Report Production Allocation Factors 85 Oil Gas Water Jan -06 0.9129 0.8671 1.0768 Feb -06 0.9454 0.8804 1.0647 Mar -06 0.9413 0.8919 1.0487 Apr -06 0.9483 0.8758 1.0518 May -06 0.9366 0.8735 1.0423 Jun -06 0.9318 0.9099 1.0421 Jul -06 0.9638 0.9425 1.0838 Aug -06 0.9801 0.9340 1.0367 Sep -06 0.9556 0.9366 1.0299 Oct -06 0.9665 0.9078 1.0103 Nov -06 0.9727 0.9227 1.0065 Dec -06 0.9396 0.8637 1.0099 85 Kuparuk River Unit West Sak Oil Pool 2006 Annual Reservoir Surveillance Report Future Development Plans • DRILL SITE 1J -WEST SAK DEVELOPMENT The KRU working interest owners intend to complete 14 wells from Drill Site 1J in 2007. The West Sak Wells 1J-103, and 1J-118 have been drilled and completed with Doyon 141 in early 2007 and are either currently on production/injection or in the process of being hooked up. Well 1J-180 has been drilled and completed by the Doyon 15 and the rig is currently drilling the 1J-160 injector laterals. The Drill Site 1J drilling program should be complete in March, 2008. Information regarding the expected 2007 well program is listed below: Name Well Type Target Inj/Prod 1 J-103 Multilateral D/B/A2 Sand Producer 1J-180 Multilateral D/B Sand Injector 1J-118 Multilateral D/B/A2 Sand Injector 1J-160 Multilateral D/B/A2 Sand Injector 1 J-105 Multilateral D/B Sand Injector 1J-135 Multilateral D/B Sand Producer 1J-120 Multilateral D/B/A2 Sand Producer 1J-158 Multilateral D/B/A2 Sand Producer 1J-122 Multilateral D/B/A2 Sand Injector 1J-162 Multilateral D/B/A2 Sand Producer 1J-124 Multilateral D/B/A2 Sand Producer 1 J-107 Multilateral D/B Sand Producer 1 J-176 Multilateral D/B Sand Injector 1J-178 Multilateral D/B Sand Producer • DRILL SITE 1 H - UGNU PILOTS Attempts will be made during 2007 to re -complete the 1 H-Ugnui well. Plans are to install a new downhole electric submersible progressive cavity pump (ESPCP) into the well during the first half of the 2007. Evaluations and planning are progressing for an additional Ugnu cold production horizontal pilot well (1 H-502), which is currently anticipated to spud during the first quarter of 2008. 86