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2005 Greater Kuparuk Area
I ConocoPhillips 1 ■ Greater Kuparuk Area Annual Surveillance Reports for the Kuparuk, Meltwater, Tabasco, Tarn, and West Sak Oil Pools Reporting Period January 1 — December 31, 2005 ov commission lasko r] 2005 GKA Annual Surveillance Reports Table of Contents KUPARUK RIVER OIL POOL REPORT ........................................................................... SUMMARY OF EOR PROJECT..................................................... ...................................... 2005 EOR Program Status.......... ....................................... Incremental EOR Oil Rate Plot........................................................................5 PRODUCED FLUID VOLUMES...........................................................................................6 INJECTEDFLUID VOLUMES..............................................................................................7 RESERVOIR PRESSURE SURVEYS Proposed Pressure Survey Plan........................................................................15 INJECTION SURVEY DATA...............................................................................................16 Proposed Injection Profile Survey Plan...........................................................20 PRODUCTION SURVEY DATA...........................................................................................21 MISCIBLE INJECTANT COMPOSITION...............................................................................25 CPFI MI Composition.......................................................................................26 CPFI EOR Analytical Report...........................................................................27 CPF2MI Composition.......................................................................................28 CPF2 EOR Analytical Report...........................................................................29 KUPARUK LSEOR DEVELOPMENT PLAN.......................................................................30 GKA 365 -DAY SHUT-IN WELL REPORT31 ......................................................................... MELTWATER OIL POOL REPORT..................................................................................37 SUMMARY OF EOR PROJECT...........................................................................................3 8 RESERVOIR MANAGEMENT SUMMARY39 ........................................................................... MeltwaterNet Pay Map.....................................................................................40 PRODUCED FLUID VOLUMES...........................................................................................41 INJECTED FLUID VOLUMES,.............................................................................................42 RESERVOIR PRESSURE SURVEYS............................................................... Proposed Pressure Survey Plan .............................................. ........................... 45 PRODUCTION/SPECIAL SURVEYS..........................................................................46 WELLALLOCATION.........................................................................................................47 SHALLOW GAS SPECIAL MONITORING...........................................................................48 1 1 I I I 2005 Meltwater Elevated OA Pressures MELTWATER DEVELOPMENT PLAN AND OPERATIONAL REVIEW..................................50 TABASCO OIL POOL REPORT..........................................................................................52 SUMMARY OF EOR PROJECT..........................................................................................53 PRODUCED FLUID VOLUMES INJECTED FLUID VOLUMES,.............................................................................................55 RESERVOIR PRESSURE SURVEYS Proposed Pressure Survey Plan........................................................................58 PRODUCTION LOGS AND SPECIAL SURVEYS WELL ALLOCATION AND TEST EVALUATION SUMMARY..............................................60 FUTURE DEVELOPMENT PLANS. ...................................................................................... 61 TARN OEL POOL REPORT............................................................ .............................. ........ 62 SUMMARY OF EOR PROJECT..........................................................................................63 RESERVOIR MANAGEMENT SUMMARY........................................................................... 63 PRODUCED FLUID VOLUMES...........................................................................................64 INJECTED FLUID VOLUMES,.............................................................................................65 RESERVOIR PRESSURE SURVEYS.....................................................................................66 Proposed Pressure Survey Plan........................................................................68 PRODUCTION LOGS AND SPECIAL SURVEYS PRODUCTION ALLOCATION FACTORS.................................................................... TARN DEVELOPMENT PLAN AND OPERATIONAL REVIEW .......................71 WEST SAK OIL POOL REPORT,........................................................................................72 SUMMARY OF EOR PROJECT.............................................................................. PRODUCED FLUID VOLUMES INJECTED FLUID VOLUMES,.............................................................................................76 RESERVOIR PRESSURE SURVEYS.....................................................................................77 Proposed Pressure Survey Plan ..................................................: INJECTION SURVEY DATA...............................................................................................80 GEOCHEMICAL OIL PRODUCTION SPLITS PRODUCTION ALLOCATION FACTORS.......................................................................84 FUTURE DEVELOPMENT PLANS.......................................................................................55 1 ConocoPhillips March 31, 2006 Mr. Dan Seamount, Commissioner Alaska Oil and Gas Conservation Commission 333 West 7t' Ave. Suite #100 Anchorage, Alaska 99501-3539 Re: 2005 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. 198B, ConocoPhillips Alaska, Inc., operator of the Kuparuk River Unit, is hereby submitting the annual surveillance report on the Kuparuk River Oil Pool. This report documents the required information pertinent to the field development and enhanced recovery operations from January through December 2005. 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 2005 from wells in the Kuparuk permit area. e. Composition of enriched gas injected during 2005 and estimate of MMP (Attachment 7, page 24). f. Kuparuk LSEOR development plan (Attachment 8, page 29). g. 365+ days shut in well report (page 30) If you have any questions concerning this data, please contact Nick Pysz at (907) 265-6831. ISincerely, /e James R. Hand Supervisor - Drillsite Petroleum Engineering Greater Kuparuk Area bcc: Central Files ATO -3 I 1 Attachment 1 Kuparuk River Unit Kuparuk River Oil Pool 2005 Annual Reservoir Surveillance Report Summary of the Enhanced Recovery Project Enhanced Recovery Miscible water -alternating -gas (MWAG) continues as the predominant EOR process at the Kuparuk field. During 2005 solvent injection was expanded to 6 additional wells. All 6 are on drill sites which had previously received solvent, and all are within approved EOR Projects. No expansion of solvent injection to additional Kuparuk drill sites occurred in 2005. The total number of MWAG drill sites in Kuparuk is 32 and there are 288 active EOR patterns. The field continues to manufacture miscible injectant (MI) at two of its Central Processing Facilities (CPF's). MI manufacture occurs by blending together produced lean gas and natural gas liquids (NGLs). NGLs originate from two sources (1) the Kuparuk field itself (known as indigenous NGLs), and (2) imported from Prudhoe Bay. Importation is utilized to fill any shortfall between total NGL requirement and indigenous NGL production and all available lean gas is blended with these NGLs. There was a period of about 4 months (late March to early August) during which NGL imports were discontinued due to a mechanical failure of a heat exchanger associated with a low temperature separator (LTS3) at Prudhoe Bay's Central Gas Facility (CGF). During this interval the Greater Kuparuk Area (GKA) was under IWAG injection. Over the period during which imports were curtailed, IWAG injection averaged 256 MMscf/d, of which 78 MMscf/d was supplied to the Satellite fields Tarn and Meltwater. Averaged over the calendar year, GKA, Kuparuk, and Satellite injection were 87, 61, and 26 MMscf/d, respectively. While on MWAG for the other —8 months of the year, the GKA utilized an average of 16 MBPD of indigenous NGLs and 27 MBPD of imported NGLs to manufacture and average of 273 MMscf/d MI for 2005. Of this total, the Kuparuk injection averaged 205 MMscf/d, while the satellite fields Tarn and Meltwater averaged 68 MMscf/d during 2005 MWAG injection. Year 2005 calendar year averages for GKA, Kuparuk, and Satellite fields MWAG were 179, 133, and 46 MMscf/d, respectively. Incremental oil production from MWAG at Kuparuk averaged 33 MBPD during 2005. The priority for gas management at the Kuparuk field during 2005 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 impacts due to gas handling limitations. Total GKA annual average gas production rate in 2005 was 326 MMscf/d, compared to 343 MMscf/d during 2004. This gas production drop is largely due to reduced gas production at CPF2, associated with additional water injection brought on line at the end of 2004 to assist in voidage management. MWAG Small Scale EOR (SSEOR and SSEORX) Drill Sites 1A, 1Y, and 2Z continued MWAG during 2005. The 2005 average MI injection rate was 4 MMSCFD. Pa IJ 11 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 65 MMSCFD in 2005. EOR Expansions Expansions to the original LSEOR now include DS B, 1 C, 1 E, 1 L, 3B, 3G, 3H, 30, 3Q and 3S. During 2005, the average MI injection rate into these expansion drillsites was 64 MMSCFD. IWAG With available NGL imports, the Kuparuk EOR project continues to maximize MWAG operation by blending all available lean gas for MI. IWAG operations were undertaken for approximately 4 months beginning in late March, 2005 after a mechanical failure at the Prudhoe Bay plant which makes NGL. During the IWAG period, injection priority was given to mature MWAG patterns to test the IWAG-after-MWAG process. Due to the relatively short duration of the IWAG period, results of this test have not been conclusive. 11 rj) C0 0 w 00 U2 C14 x ry ................... W X cq CD CD CD C) CN cq X ch m CN C) C) CD CD CN CN C6 m 0 C) Z CD r - CN cu CO CO -0 C) LU 0 0 Cf) CO Cf) _j m ka a,W 0 (n a) (13 0 x a) 0 C o W OL OL x x W w C) x x W tf x CL a) w cur Cf) X 0 w LL. cu _F3 - I.- c a) ................. Uaj w 0 0 I w w w 0 T-- IL m rL7 7 1". rj) C0 0 w 00 U2 00 ................... ................... ................ ................. m W >M C3 CA > LL 03 CA N 04 0 0 o a o 0 o a a 0 0 0 0 0 0 0 0 0 U-) o Ln o V) o U-) o uo I�r CN ry U013 s0-Inp 90-UBP ttr0-I of b0-uer €0-Inf €0-uer ZO-I of Z0-uep L0-inr W-uer a0-Inr 00-UOP 66-Inf 66-uer 86-I nr 86-uuP L6-Inf L6-uer 96-I of 96-uer S6-Inf 96-uer i76-Inf t76-uer €6-Inf €6-uer 0 R MO 1 2 3 4 5 6 7 8 9 10 11 12 MO 1 2 3 4 5 6 7 8 9 10 11 12 Attachment 2 Kuparuk River Oil Pool 2005 Annual Reservoir Surveillance Report Produced Fluid Volumes Cumulatives at Dec 31, 2004 1,971,846 1,270,777 2,467,126 Produced Fluid Volumes (Reservoir Units) OIL GAS WATER CUM OIL CUM GAS CUM WATER YR MSTB MMSCF MSTB MSTB MMSCF MSTB 2005 4,297 8,469 16,471 1,976,143 1,279,246 2,483,597 2005 4,065 8,122 15,816 1,980,208 1,287,367 2,499,413 2005 4,350 8,629 17,261 1,984,558 1,295,997 2,516,675 2005 4,378 8,637 17,013 1,988,935 1,304,634 2,533,687 2005 4,346 8,201 16,602 1,993,281 1,312,836 2,550,289 2005 4,122 8,097 15,975 1,997,403 1,320,932 2,566,265 2005 4,258 8,016 16,801 2,001,661 1,328,948 2,583,065 2005 4,265 7,991 17,011 2,005,926 1,336,939 2,600,076 2005 4,118 7,661 16,977 2,010,044 1,344,600 2,617,053 2005 4,194 7,970 17,762 2,014,238 1,352,571 2,634,815 2005 3,988 7,632 16,805 2,018,227 1,360,203 2,651,620 2005 4,062 7,866 17,482 , -1 022:2-� 6 ,-5 6691 2 2005 TOTAL 50,442 97,292 201,976 Cumulatives at Dec 31, 2004 1,971,846 1,270,777 2,467,126 Produced Fluid Volumes (Reservoir Units) 2005 TOTAL 62,044 55,639 205,515 CUM OIL OIL GAS WATER YR MRVB MRVB MRVB 2005 5,285 4,884 16,760 2005 5,000 4,709 16,093 2005 5,350 4,989 17,564 2005 5,384 4,984 17,311 2005 5,345 4,649 16,892 2005 5,070 4,664 16,255 2005 5,238 4,539 17,095 2005 5,246 4,517 17,309 2005 5,065 4,317 17,274 2005 5,159 4,531 18,074 2005 4,906 4,351 17,100 2005 4,996 4,506 17,789 2005 TOTAL 62,044 55,639 205,515 CUM OIL CUM GAS CUM WATER MRVB MRVB MRVB 2,430,645 1,503,800 2,527,195 2,435,644 1,508,508 2,543,288 2,440,995 1,513,498 2,560,852 2,446,379 1,518,482 2,578,163 2,451,725 1,523,131 2,595, 055 2,456,795 1,527,794 2,611,310 2,462,032 1,532,333 2,628,405 2,467,278 1,536,850 2,645,713 2,472,343 1,541,167 2,662,987 2,477,502 1,545,697 2,681,061 2,482,408 1,550,048 2,698,161 x;48'714= '5.54 555 Cumulatives at Dec 31, 2004 2,425,360 1,498,915 2,510,435 C. MO 1 2 3 4 5 6 7 8 9 10 11 12 MO 1 2 3 4 5 6 7 8 9 10 11 12 Attachment 3 Kuparuk River Oil Pool 2005 Annual Reservoir Surveillance Report Injected Fluid Volumes Cumulatives at Dec 31, 2004 4,579,081 Injected Fluid Volumes (Reservoir Units) WATER GAS MI CUM WATER CUM GAS CUM MI YR MSTB MMSCF MMSCF MSTB MMSCF MMSCF 2005 22,308 0 6,536 4,601,389 1,058,152 847,382 2005 20,235 0 6,120 4,621,624 1,058,152 853,502 2005 22,856 539 5,655 4,644,480 1,058,691 859,158 2005 21,932 5,101 0 4,666,412 1,063,792 859,158 2005 21,530 5,735 0 4,687,942 1,069,527 859,158 2005 19,680 5,482 0 4,707,622 1,075,009 859,158 2005 21,141 5,508 0 4,728,763 1,080,517 859,158 2005 21,382 63 6,201 4,750,145 1,080,579 865,359 2005 21,702 0 5,887 4,771,846 1,080,579 871,246 2005 22,749 0 6,223 4,794,595 1,080,579 877,469 2005 21,583 0 5,882 4,816,179 1,080,579 883,352 5 22,290 0 6,225 x 4;1;3$4469` 1OS0 57 & x389,57G':' ' 2005 TOTAL 259,388 22,427 48,730 Cumulatives at Dec 31, 2004 4,579,081 Injected Fluid Volumes (Reservoir Units) 1,058,152 840,847 CUM WATER WATER GAS MI YR MRVB MRVB MRVB 2005 22,699 0 4,902 2005 20,589 0 4,590 2005 23,257 431 4,241 2005 22,317 4,081 0 2005 21,907 4,588 0 2005 20,025 4,385 0 2005 21,511 4,406 0 2005 21,756 50 4,651 2005 22,081 0 4,415 2005 23,147 0 4,667 2005 21,961 0 4,412 2005 22,681 0 4,668 2005 TOTAL 263,931 17,942 36,547 1,058,152 840,847 CUM WATER CUM GAS CUM MI MRVB MRVB MRVB 4,681,781 931,165 635,537 4,702,371 931,165 640,127 4,725,628 931,596 644,368 4,747,944 935,677 644,368 4,769,851 940,265 644,368 4,789,876 944,650 644,368 4,811,388 949,057 644,368 4,833,144 949,107 649,019 4,855,225 949,107 653,435 4,878,372 949,107 658,102 4,900,334 949,107 662,514 IRA$_ . Cumulatives at Dec 31, 2004 4,659,083 931,165 630,635 7 Attachment 4 Kuparuk River Oil Pool 2005 Annual Reservoir Surveillance Report Reservoir Pressure Surveys 1 t LJ O ' N Z vJ O �a O U W Z _ I L 0Cl) i >NN 'Vw♦ I.I. z W O Z INI� W '°^^ a vI N F w U)v0 C Z J W O(J) U W Q a D Z a i_J M Co N CA N 0 U- N l6 vM OD M M CA r -n M N OD h LO w M N V M M O N 0 O LO N m W to M O 1` N P- 0 M O O N OD CA N N 0 O O O O O a' w wh O C N v h CA CA OO OD aD M O O O 0 O M LO M M M O O M N 0 M M MM P- V Nto N N M N N N M N M N M N N M M M N M N M N N N N N N 7 d � a0 T •� y` tO llf tf) M 1n (O O m LO 0 (O N h 1n O lO N h CD t0 0 LO LL') � LO M M M M M M M M M Cl) M M M M Cl) M O M M M M M LO M M M M tl71 N 0. 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M C+) O M O M c M O M O r M Co r M M O mm M CD O m� M O M O M r r M r M r M CA r M C.o O M M O M O M O M Co M O N M f� N M N M M M r M M r M � M n �" M N CV M O O M Co r Z M N O O M W O O M co r O M co 7 O M M O Ci M el' O Ci M to O O M O) O O M w 0 U) w U) w z O U) Z O U D t- Z w N d' O O LL NLD qr m CO N h fOD O 0 M co R M N 0 N N M m r O M O M CN M M Cl)0 4N7 Cl)0 OO O O O O O O O N Co N CD O N N CO N CD CO N O N CO N 0 N O V 00D et 0 O CO OMD OrD co, Cl) O Cl) N N C`M7 N N Nco �+ N \� m N LO LO 0 to N 000 6 M I-- Cao P- O `1` LO M =N N � C �l O C�O CO CMO COD W COO 0 � 0 47 i it CD W cc CO N 47 407 CMO 407 CMD CMD COD COD U N N r r m Q C7 v c O toY l6 Q 2 2 2 2� S 2 S 2 N +L .— m m m m m m m m m o cn w CO CO a CO CO v) Cn V> N O Cl t- LO O N C- h N ti O N U M r CA 2 �, N C_ O C N O OO O O O O O O O C O C` N N N CO O t` N tD N Cf7 OO tD O O O O O O O O N N j y to N 0 ` N d O '+ 1 CO Y { V C � W n 3 U � 0 0 0 0 0 0 010 0 C V cc o U U U O `- m q 0 0 0 0 0 0 0 0 o Cc E- h n N M C00 V0' C00 N [� CMC) � C --� to N N N N O N N O 3 O CA N N N N N N N N N C N O O N O O Co O O O O r L N 7 E O « C6 Z Q. d o N N C m a N6 N v w N N O N Q N 6 M M M M M M M M M N 0 O N N _O E O CL ii 1 ConocoPhillips March 31, 2006 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: Kuparuk River Oil Pool — Proposed Pressure Survey Plan for 2006 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 2006. There were 198 pressure surveys reported for the Kuparuk River Oil Pool to the AOGCC in 2005. In 2006, we expect to conduct approximately 190 pressure surveys, including initial surveys for new wells prior to initial sustained production. If you have any questions concerning this data, please contact Nick Pysz at (907) 265- 6831. Sincerely, James R. Hand Supervisor - Drillsite Petroleum Engineering Greater Kuparuk Area bcc: Central Files ATO -3 15 Attachment 5 ' Kuparuk River Oil Pool 2005 Annual Reservoir Surveillance Report Injection Survey Data 11 C L 16 M W p M O M I- N OD fM - r O N [- Ln 0) m N O O O O v' 1- M �-i O O O c LD M , O Ln N N O LA O !` o 0 O N O .--I -1 �--� -, at l0 N O M 01 1 6 N N N O [� O . 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N U � N LO OO (D N CO N N O LO O cn h � O co O O O O — O z � U H O W Z F U U U U U U U U U U Z Y U + Q + Q + Q + Q + Q + Q + Q + Q + Q + Q O� w Q Q Q Q Q Q Q Q Q Q Z Z w w w w w w w w w O a) 4) C Z Z C a Z Z > n J W �_ C N N a) () a) N N N J w i 3 3 3 m m m m m m 0) UJ J Ln U)m O o 0 0 0 0 0 0 > LL LL LL LL (n 'cn 6 (n (n � O N (n N Cl) LO O LO O LO O LL > FO X OO t!') N U � N LO OO (D N CO N N O LO O M (n � O a w r } J w w w w w w w w w w O w F- L> Q O lY 0_ C Z Z C a Z Z > n J W Z Z i- W a 3 a a :3 a Z u_ > 3 3 3 3 3 3 3 3 3 3 O O O o O o 0 0 0 0 0 0 LL LL LL LL LL '5LLL L LLw LO O LO OO LO O LO O LO O LO O LL > FO X OO t!') N M � N LO OO (D N CO N N O LO O M (n � O a w r } J w w w w w w w w w w w F- L> Q O lY Z Z Z Z Z Z Z Z Z Z Z Z Z Z Z Z Z Z Z Z i- W a a a a a a a a i a CL CO U) cn U U U U cn cn U 0 0 0 o W D Z LL W > O J W LO OO LO O Ln O LO OO LO O LO OO LO O LO O LO O LO O LL > FO X OO t!') N M � N LO OO (D N CO N N O LO O M (n � O co O O O O — O Ln LL Z O Q O 0) O) 6) co W O 6) (0 0) 0) 00 N W h OO N 0) O O N � I_ U O O N O O m W rn \ Ln }L Q Z_' o 0 LO r o 0 0 0 0 o W D Z 4J 0 U O w N O O O O O O O O O O O O O O O O O O O O M 00 w LOO O O O N O r_ LO co m N o N O N O N O N O N N N N N Ei O NO M O Cl) O M O Cl) O co O CN O 0) O O O ^ QZ O O O n _j LLI O O r 00 N O O - O J m � LL O 2 Z z = Z O � M M Cl) Cl) CO M Cl) M M Cl) Z 1 ConocoPhillips a n J March 31, 2006 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: Kuparuk River Oil Pool — Proposed Injection Profile Survey Plan for 2006 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 2005, 37 injection profile surveys were reported for the Kuparuk River Oil Pool to the AOGCC. In 2006, we expect to conduct approximately 35 injection profile surveys, including initial surveys. If you have any questions concerning this data, please contact Nick Pysz at (907) 265- 6831. Sincerely, James R. Hand Supervisor - Drillsite Petroleum Engineering Greater Kuparuk Area bcc: Central Files ATO -3 20 11 Attachment 6 Kuparuk River Oil Pool 2005 Annual Reservoir Surveillance Report Production Survey Data 1 �I 1 21 0 0 LL Q (� r -I H M M 01 01 O O O O N N O C O1 rl h 01 lD (7 N N N N 0) C m O N N N N N N lD l0 H r O N ri N M r N of M N M M 0) N N O 111 H H H .-1 .-1 ri .-I Z O UJ ?L N O O O M r a N O �i 14 CN N N (Ni N N %D koO C' N N O m 04 04 11 0) M M r N 10 m 0 Q > C r I ri C r -i rNi H .1 N rMi N N M N M N .q eD 01 LL W lD N N �O r 1D _J 0 w 01 r r C O m O M M N N O O M M N N O O O O N O O W r C N m eW M N 0) N M w .1 M N N v C O d' .--4 M N 01 -4 ri N N M M N N ri 14 ri N N C Q1 N C N N W U U U Z Z O + 4 + a' + 4 U + 4 U U U U U U U U U U p Q U 4 4 FC 4 + 4 4 + 4 FC + r.0 4 + FI'i 4 + r•4' 4 + 4 9c + 4 4 + r.0 4 + 4 Fc + < 4 N a. 5 Z v d m a) w J LL J t1 d' O m b' •� •� m 'H m b O LL a r ' a �' �' a m a a c z m m 0 W 3 m H r -I m H m m 'a m U m vi of Cl) [�, co C/3 m O Cl) Q7-. m m (� O Z U) O 2 m m m to m m m LL -i H H N J Z W a m a m m to m 14 a a a a a a J C) IL J O v p li > p a m U a m U w m a m a m a m a CO a Cl) a m a W CLI- CO j d m U) U) w z c> U v U U U v D J p g o o o w o c c a a c c c W O O j U U U G4 U iR LU >g�IL o CD D Q O 04 QY x w Q a u�3 x x a x x a x a Z x d w a w Q }} J W w W W w w w w w w w u • Z Y LL I— > Z E Z E E Z E Z Z Z Z Z Z Z Z O) Z Q 0 X O z H N m Z H N CO N Z N ,7, Z Z z Z z Z p Q Y W H � a a, m H a m H a, H w H a H P. H 0, H H QLL CO m m m m m m m m w m w CO R' LL O } -- N O \ N O \ N O \ N O \ N O N O N O N O N O N O N O N O N O' N O LLJ > �y, % W C O X17 \ r \ r \ N \ C \ N \ C \ O \ lD \ M \ N LL H O M O O H r-1 N O N ri eq O N N H d> N tD ID 0 �- z O O O O N O O m m lD CO m Z O -4 O ri O O O O O O 0 LL O Q i'- C 01 C 01 m C C to M C m M C dl C M W f- 0 :) \ \ al \ W \ Q7 \ dl \ of \ 01 \ Ol \ Ol \ Q) \ 01 \ 01 \ 01 \ Q0 Z 01 O N O N N N C N H N N N N N p O O O O ri O O r -I O O C) O ri O � a O O o o 14 0 O 0 0 C. C. 0 0 o 0 O .H O o O o O H o O o O O LL' W O M O O O O co m ri O1 M C C v M m O O r N 01 M m N of N m m N m N O .-i ri N N H N N M .-i M ri 01 O Cl) N M m N co H M N m r -I N N N N N N N N N N N N N N Q. 0) Ol of 01 Ol a) of dl d> m 0l 0) 01 0) Q O Z W) N O N O N O N O N O N O N O N O N O N O N O N O N O N O _j J LL LLI m M '"� r O p C N C O lD N N O ID rH m N N N r-1 M N Cl) W � 'w H 0 a a a a a O � N N N �, r r z ,_., r� , r4 r+ r4 � r� H � r� r 0 O N p CO LLO (i O M M O O W W d+ In W N W W H r-1 N In -W O W r� O In W H O w In rq m O "D r M M 10 l0 M N W M N N a W tD O M N C' w M M 1-1 -4 d� C� W Hr cliN H .-•I M -4-W " an I!) � In W ill to � 'i Z 0 U w d Q an N N N r r W W N O W u) O O C -0 C-4 O .-I 0) In O O 04 W r In W C o) N N Il) N N O L, N O M M �--I O o1 N a o to N N N In 01 CA M N M O N a [- N M N lw sP N Ul W In a N O d' r O M r-1 N N °0 m 3 0- 00 H r-1 O O ID O r r N H N In M C r C T H H H M H N 01 to N O to to M M N N m M 0) D) r M �P O W M M a O to -W w r Im W r O O ON to m M M N '-i ri r-I N N M N M Ow e-i C 14 N N to N N In wp Z U U U U U U U U U U U U U U Z O x U + 14 + + r$ a + C + aC + r•C + FCC + 4 + 4 + < + 4 + r� + 4 + 4 p 0 a D a a a Kc a a a a a a 4 a a z v d d m m a) d a) 4) a� J H w f." G O) O O O O) d) m m y O J Wa •'I O -.i C C C C C C C C w a } W `n c CO Cl) V) U) in U) in in C _ ~ w U U O .-i m 1 � � D n ua � � � � U U) u) M 0 0 0 ui n Uco . �_ W W U] H F- F- F- F- F F- FC F- F- F- N J M LL Z LL% �7 o' JD J J J J v) W J J J J O O O O U U m d U LL co a UW a a U) a U `' U a Ct) a CO a fA F- 0 LL' U �' = W W U U U U U U U w z U U U �aoa� a o o a a a a a a o a a a a U O W O O j U U >.Oc~jo Y�< C14 �YaoN ¢�x�¢ a u� x Ix ix w Ix w a W o. � co J w w w w w w w w w w w Y d Z cEi ca Z p� Y O J Q Q a CO W m 2 ED Z Z Z Lo Z U) Z � N Cl) N U Z w Z Z w p ra fa U) co R' LL O L71 w J W In 0 In 0 \ u-, 0 \ �n O u> �n OO In O o u� O �n O In O In O Ire O )n 0 W N to N_ _O �O co O O O �-•i N O N N aO IL N V O— cli U O O N O O O O O O O O r ' Z 0 LL O Q V OM) m rn Cl) M M ch co rl Cl) V M er W N p\ \ \ rn rn rn rn o> rn e rn rn rn rn Q Z p C) r r r r O r 04 r O r p p O 0' CL O 0 o 0 O 0 o O o 0 0 0 0 0 0 0 0 1 O O O O O O O O O O O w W N o N W r N ap N O N M Cl) 0 0 CY) W O N co N OD 01 [p O O H r-1 m m f7 m N _ _ 2 cN•7 Cl) cq N N N N N _ N _N N N N N N LL p O O N O N O N O N O N O N O N O N O N 0) N 0) N 0) N Q Z In r-I .-I O O O O O O O O O O O O J J W m N W rIO W) N O O N> M> N rl0 � Z D > > >M >0 ZN N N N N N N N N l �0 0 M I W J_ J M LL J I jaLWL,IML ~ > CC a �_ 0 00 t) > D N aazWe:Q IM d CO d z Y Y °W Q U J I I i 0 i Z I U U 4 U U U F:4Q¢ U Q¢ U Q a U U Q¢ Q a U U U Q a Q¢ Q N a H ham-a zLL ° W > O N� O r r r d d d c c CD V) CO -T N r O N O U(L�U U U) U) U) U) U) COD U) i4 O SND (D co U M CO U a' o Z Z a a a a a a a a a o LU CL CD M CN 101n m (3) O N CO O IT v co - CC13COO LO N CD d' 'T O W O Q> m M Cl) C '-1 m r O N _ M d' V n N f W N N Lf) 0) _JO O CO C a N O CD N O n r O n CC) O )Y) CL N 'w O rn m N n n Cl) M O) N n )n O O O) O ° m r-1 `-1 N r-1 ,-1 r-1 N r r M M r r CV O co CO CD co LU p i Z I U U 4 U U U F:4Q¢ U Q¢ U Q a U U Q¢ Q a U U U Q a Q¢ Q N a H ham-a zLL ° W > a U) a CA W z O w a a a) e CD d d d c c CD V) CO d c U) d c U) d c a) U) c m d a) c c U(L�U U U) U) U) U) U) U) U) i4 co CO CO CO U co U CO U CO U Z Z Z a Ir O J ~ CO H H Ff n- F-- Cl) H H ham-a zLL ° W > a U) a CA a U) a a a a. a a a o U(L�U ° (L Cl) z U U co U co U U) ca CO U co U CO U CO U Z Z Z a a a a a a a a a o Of a n. a a a n. a o a v> U) co Cl) a a a a Ir Of a a a cc of 0: J W W w w w w w w w w w w LL> z z z z z z z z z z z Z z Z Z Z Z z Z z z z it D Cl) FL a E -L E -L a n. a a a n. a o a v> U) co Cl) Cl) Cl) co U)(1) N (1)C0 LL ul i to LO M) O N N O 0) 0) T m ° J w CD O O O O O O O OO O O LL> a' rn O n N co N co r )n O rn r C+') rn N n N n in N CD C) O N CO Cn C� O � (A O Q O O 4D O r a O O O O O z O O CA O O O O O M M LL J > 5 Cl)m cr)m M M M M a U Lu ~= rn f� rn N m l`i1 m m rn N rn rn N v N o 0 O Q Z O O O � � O (� O O O O Q w a O O O O O O O O O O O O O O O O O O O O O O O N Cl) n CD n M O O w v a) C14 toco m N N N N N N N N N N N O 0) 0) T m O C) m Om O M M Q Z LC) N O N O N Co N O N O N O N O N O N O O O of O - O r co n O J CO O O CA O O O O M M > 5 Cl)m cr)m M M M M Cl) M M Z Conservation Order 1986 Rule 3. Kuoaruk River Unit Reservoir Surveillance Program IAttachment 7 11 L 11 1 u r Kuparuk River Oil Pool 2005 Annual Reservoir Surveillance Report Miscible Injectant Composition Miscible Injectant (MI) compositions and corresponding Minimum Miscible Pressures (MMP) for the three CPF's are presented in the table below. No MI composition data is reported for CPF-3 for 2005 because MI manufacture at CPF-3 ceased in 2000 with the installation of the 1Y Jumper Line. This jumper enabled the expansion of the EOR Project to DS 1Q, 30 and 3Q, as well as continued MI supply to DS -3F. MI is now supplied to the CPF-3 drill sites from both CPF-1 and CPF-2. The MMP of the blended CPF-1 and CPF-2 MI is estimated on a monthly average basis and is reported in the attached Table in the column for CPF-3. Prior to 2001, CPF-3 manufactured a small amount of MI for DS -3F with indigenous NGL's. Now, these CPF-3 indigenous NGL's are routed to the wet oil line for transport to CPF-1 and 2 for stabilization in the GKA sales oil, or else recovery as indigenous NGL for reuse within the EOR project. Minimum Miscible Pressures of MI Supplied to Each CPF MMP Target Spec = 3300 psia * Calculated **Considers NGL pump downtime & gas compressor downtime ***MI curtailment due to mechanical failure mid-March - early Aug. Individual CPF MI compositions follow. 1 25 CPF1 CPF2 CPF3* CPF3 MI Source Month CALC MMP** (psia) CPF1(%) CPF2(%) Jan -05 3222 3403 3325 43 57 Feb -05 3384 3253 3253 0 100 Mar -05*** Apr -05*** May -05*** Jun -04*** Jul -05**" Aug -05 3286 3346 3337 15 85 Sep -05 3239 3268 3268 0 1 100 Oct -05 3337 3422 3422 0 100 Nov -05 3325 3286 3286 0 100 Dec -05 3371 3432 3432 0 100 Average 3309 3344 3332 81 19 * Calculated **Considers NGL pump downtime & gas compressor downtime ***MI curtailment due to mechanical failure mid-March - early Aug. Individual CPF MI compositions follow. 1 25 0 0 0 0 0 0 0 0 M 0 0 0 0 0 0 0 0 u 0 0 0 0 0 0 0 0 V 00000000 00000000 N 00000000 V 0 0 0 0 0 0 0 0 00000000 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 V 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0rNNowDC M V-NNNMT- ce) V 0 0 0 0 0 0 0 0 00000000 000DrOM�ON OftAONnCtOTO 0 0 0 0 0 0 0 0 CDNMMNOON�t ODN�T'd'rCDCDnr V rnnCDNCignN 000-000- M OOrO00r M n r M M n M n hCOrMf00�tt)t1') V (ogCONnMgN T T r N O r r N V r r V M O r M tO 0 N O LA n v m N V T 0> CR90000 NTfV(�jrTrC'7 Iq M n O M M M r Cl' ()MnOONnOT M r M M M r T T ZCV NCV CMTNN4 01-0TONtDn � N O V O N N- M V O CO M CD N CD CO M �TTrNTrTco vvoMm0mMto V w ou O O N M W 00 n IT O O Un CO CO z 6C6r-v-w 0w nNIT0OMM0 W N V O MOM N :1 MCOMCOrf000N N N N N N N N M M 0 C ON �- 0 W M %1OTM(flT�MO n m w w o o w N N W M N M T o m vU�vgCRcgngrn wcoOcomcococo MrN�00nLn0 n N n n O M n 0 V NnNNO"tON 0004 mil—omm w 0 0 0 0 0 W M) M O 0 T M r N 0 NCOCDOd'OOON Z N N M N t 0 N M N 0 0 0 0 0 0 0 0 NNITOOM0)OO Onncq(q coon V 0 0 0 0 0 0 0 0 r r r T T r T T U- LL LL LL U- LL LL LL 2aaQ-o_aaao_ 000000000 LO Un U) Lf) LO Lf) Un 00000000 200000000 , N N N N c -) N c) co f� a O T T (� • v T T T 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 2117/05 3:35 PM 2/17105 4:00 PM 2117/05 3:45 PM 1.130 NGL Analysis Sample Blending Gas Sam le Mi Gas Sam le LIMS # AA98388 AA98387 AA98389 Line Pressure 320 1420 3800 Line Temp. NA 44 44 SETCIM Tag FI-20GC F1-21GC Calculated Flow (MSCFD) 14260 57048 71308 Component Solvent (Lab) Mole % Lean Gas (Lab) Mole %) MI (Target) Mole % MI (Lab) Mole % MI (Calc) Mole % CO2 0.338 1.130 0.968 0.784 0.972 N2 0.000 0.352 0.280 0.260 0.282 C1 6.793 85.039 69.079 69.721 69.392 C2 5.660 6.733 6.514 6.483 6.518 C3 10.606 3.615 5.041 5.181 5.013 iC4 9.486 0.816 2.584 2.622 2.550 nC4 26.030 1.650 6.623 6.756 6.525 iC5 8.236 0.311 1.928 1.807 1.896 nC5 10.123 0.263 2.274 2.177 2.235 C6 9.589 0.091 2.028 1.921 1.990 C7 8.016 0.000 1.635 1.417 1.603 C8+ 5.123 0.000 1.045 0.871 1.024 Total Moles 100.00 100.00 100.00 100.00 100.00 MW 64.36 Density (lbs/sco 37.62 Actual ENFL Rate Rate (Ib/d) 2415183.67 Rate (Mol/d) 37526.32 Rate (MMSCFD) Target Blend Gas Ratio (lb BG/Ib EF) Actual Blend Ratic (From measured flow rates) Youngren MMP Actual MMP (Using Lab MI Composition) Calc MMP (Using Lab BG/ENFL comp and rates) 19.78 28.88 28.35 Ideal BG Rate Actual Gas Rate 2897207.844 2969997.24 146446.9842 55649854 1.20 1.23 3300.00 3429 3355 27 "00000000 00000000 V00000000 000000co 00000000 N 0 0 0 0 0 0 0 0 V 0 0 0 0 0 0 0 0 C O C C C O C C 0 0 0 0 0 0 0 0 X 0 0 0 0 0 0 0 0 V 0 0 0 0 0 0 0 0 C C C O C O O G COtiO�M0CD0 O T T T T T T T T 0 0 0 0 0 0 0 0 V O C O O O C O O 01-0 LOMI-NO 0Cow0CD000O 000000000 0 0 0 0 0 0 0 0 co V IhV' 0 T O N 0 (i CO CO t` m Ln ti co f. 00066660 t,OCNOCmomm VM'- UM Cr q V'OMNM T T T T T T T T C- 0 CD MN T 0 wMN00T0000O IL) 000000 I - COQ O CD 0 n O W T V 0 U T n 0 o V' M w T 0- N V W- M 0 ZNC�NNN-:N Ln N V N T T �0 CO 0000 Co V CO r• t` m Lo LO V'M V'C0000MNN VNr—V•TtiLOM0 � CO�COaOMh-COLn ZCDtiCOCDCOCDCO(O O M 0 0 t` N LO I- 0 0 M V T o w 0 0 V MCRq V• V•tlCDN -NNCV NNNCV N I+ LO h CD Ih V CM MCDLorl- MT(�T ()NTCli W O 0 L6 Ui LLj Vorn°'occ! 000 Cc cc; rnt�[-.:t, CO T Mc0 t` 0 co co ONLAhNCOM V;C0 Ocgm0CD UOaCi00iCA0>OC hCOOCOCOCOf�i� N V'MtC>O V'O LnM Z N N N N M N N M 00000000 N 0 M V V'v1'-00 o LC>MF-WMCDOT OCO0woCDti ti 0 0 6 6 6 0 6 0 0 w N N N N N N N N lL LL_ U- CL LL LL LL LL a- m M a M a m m �UUUUUUUU LO LO LO to Lo 0 0 0 0000 + O O O O N N N N R���NMC�MT a co 0 0 T N T T T T 28 0 W Z O Q Z m J NaNga 11. '0 lJ l CL O Y U 2 IL O O A N CL CL N N O h N 2 IL r N 0 a U co N w0 d d d d d d d d d d d d w�C W) d a— E E E E E E E E E E E E .� o Y7 C9 O m m m m m m m m m m m m N 0 0 0 W N N N N N N N a6 to co mCD N Q m 0 0 0 0 0 0 0 0 0 0 0 0 O O N O C4 LO U 2 2 Z Z Z Z Z Z Z Z Z Z rn H C7 LU ry m U) m co V r can,m t0w-mN NOa co to OO 00 N N a > m F G1000 V yohN�M p mNtDh 0700 Go CM M O d' MM 000 d tj. d N LL m 6 6 ,6 4 N O O O O O O d C _ m ;.. � > - m v ; .y v g.E 0000 LL0(DD G mot LIJ r c- y N m P9 O J O O l C4 pp 0 i d �O M M h O Ot 0 0 M h O O w M N O 00 0 Q Q a UO'O Q - LL O a� O 1 �O M O O O O O 60 4 r- "D O U V l= N UC L L N m .D.r. p. d v y • ��IIy��,,: 07 A E m Q❑ Jcom . W t11�U• F 0 to d H N m t0 t0 /OD <@ r M N N O 0 20 Cca m,C20m F �QU J " ivi h N N M to M P< to 0 0 t� w mom h N O Q a U � Go p O h J 8-1 0 o d M O ? w M V A m 10 N M M M O h N O W O O Q m� z �-6IR N N " M Cl m toms m11h O O � O N N O a a LL OI e A N � N� O N O M N t0 t0 O m ~ r N N a n N n r 0 0 h N N h N O p O N t- m F050 to m n r a 0 0 N a W t0 h O N t0 W N O O N N O N M M O O 0 0 Om tq t0 N 0 0 0 0 0 O 0 a� LL U M co ❑ N C o O O N w h w 0 to n Q TT Z j d{ N O h O O O t0 O C M N^ M- M O N M N t0 O M O V N Z � Oto li � O O c ` In d m G.m d 02UUV V CV CUUU N y C.m. 5 2? U 2 a w N d V C CW O m O Oi J J J N u. (7 t- H, co N w0 w�C W) p C m .� o Y7 10 O (D a6 to co mCD N Q O O N O C4 LO U rn H C7 LU ry m U) m co O O and N - 00 N N a > m F > O d tj. d N W A C _ m ;.. � > - m v ; .y v g.E C E Z LL0(DD G mot LIJ r c- y N m G 9 N to m v N U d D LL E m m m 0 C LL c« m m m mi 4 r- "D O O C C m l= N UC L L N m .D.r. p. d v y • ��IIy��,,: 07 A E m m c'aano a . W t11�U• F 0 to O O Z Z co N 29 m Y7 10 O (D a6 to co mCD N Q O O N O C4 LO rn C7 m co O and N - 00 N N m W A r 2 E o E N W N m ; .y v M o� d C E Z LL0(DD G y U W LIJ r c- y N m tD m m w m n a v E J J LL E 0 U u`. > j O O o am' a o UC s � CL n l a vU) m c'aano a 75 2() 222 0 20 Cca m,C20m F �QU 29 Attachment 8 Kuparuk Rive Unit Kuparuk River Oil Pool 2005 Annual Reservoir Surveillance Report LSEOR Development Plan During 2005, the Greater Kuparuk Area (GKA) averaged 17 MBPD of PBU NGL imports and 10 MBPD of indigenous NGLs for an annual average of 179 MMSCFD of Miscible Injectant (MI) manufacture. Of the GKA manufactured MI volume, 133 MMSCFD was distributed to Kuparuk: 65 MMSCFD to LSEOR drillsites (including 3F), 4 MMSCFD to SSEOR and SSEORX drillsites, and 64 MMSCFD to LSEOR expansion drillsites. The remaining 46 MMSCFD was distributed to the GKA satellites. 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 River Oil Pool potentially provides new opportunities to maximize field recovery while preventing physical waste. Drilling opportunities are under constant evaluation as the field matures, geologic and reservoir performance information is assimilated and as technology improves. The Kuparuk EOR project may be expanded to include any new wells. There was a period of about 4 months (late March to early August) during which NGL imports were discontinued due to a mechanical failure of a heat exchanger associated with low temperature separator #3 (LTS3) at Prudhoe Bay's Central Gas Facility (CGF). During this interval the Greater Kuparuk Area (GKA) was under IWAG injection. Over the period during which imports were curtailed, IWAG injection averaged 256 MMscf/d, of which 78 MMscf/d was supplied to the Satellite fields Tarn and Meltwater. Averaged over the calendar year, GKA, Kuparuk, and Satellite IWAG injection were 87, 61, and 26 MMscf/d, respectively. 30 n 1 ConocoPhillips 0 i J F 0 March 31, 2006 Mr. Dan Seamount, Commissioner Alaska Oil and Gas Conservation Commission 333 West 7t" 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 Nick Pysz at (907) 265- 6831. Sincerely, James R. Hand Supervisor - Drillsite Petroleum Engineering Greater Kuparuk Area bcc: Central Files ATO -3 31 J LO 0 r 0 J c c cd do c 0 0 0 3 ° c Ma3= m LL 30 2 co 3 io 3 Z� 0 as 'D Q co -0 =o O O O 0 00 OO °o O L E 3 O a) a a) '00 -O_ w X w N Ln o w w w v w E Lw) O a) co U 3 C6 C6 U C6 O U U O ` 3 U 3 ci C2 r N V 0� c Ora? a3 0ma) �C 0 0 ° ..ca0 'Lo 0wccV N co 'O R 'O L6 m .O C > U O. d > U— CWo N U C d t U a) O O E U O U U U N N U a) U N Co ;O > O v C6 mcE L`oEa)� L` cct`a c �cc(n D> O C E 00 O p 0 O O 0 E a) O Cn CL > m Q O_ Cn LL O Z O Z .O fA O Z d V? Cn Z J ;O M Co. LL CA J C ai a) w N N M r M M M M M r r M M r r r M r O �a 7 0N = O cli O a) N O Q O `t .0 p r r CL (C r F- a) ca w a) w a) 0)NJ C C C 3 Q ~ f) &, N U) ;O I+ O O CU O r O to LL N a. 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Qc. a n QQ QoLO c c O 0 ¢ c O c O t c c O C c O R Q OO V� Y N C) Y D d ` Y r Q � C LO CU Y d X QY Vd3 OZ � L LZ — LLO Z�Z 11ZOZ�Z LL L I-YXY d O O W W 0 W W 0 W W W 0 W 0 W R d C T 3 L 9O O M Cfl r O r O W W m co CV y -� 7CL Q Q N 7 t 7 3 7 U O V O L Q Q l4 Q N r O NM O O V O LO O CD O I- O 00 O O O O r �— r Z LI UU uj 0 1 1 t i P-1 y E O p- C U L � C (0 p) C L U 'y as O E U c a c W m o Y y C O L C O " y Q' N C m iA tC C O U O U N > E 0 'm0 0 0 p � U 7 C w U 0 0 a m o o a .n c 0 oCL CL 0.2 U_ — 0 CO) > E v c a 0 E o o n E o aa) v m V 3 E N C E C N ^ >' o E a) c aoi E " a 0 of c0a a E E aa)i o U V C CD r_0 C_ U L C U) U O d E N N l0 N as = 3 _ Q N _ +� a O�' -.0 7 .0 U a O C C CL 0 is Q.N da) 25m3: O N 3 C (� M- C N � cL Ca> QL �•6U ca N Q CM w N 3 % S c) w E c w =2 1 0 U ) LL LU W—iU) 0 a=QcdbciW NC" OM:c'!C64 6 6 i 1 ConocoPhillips d i] 1 March 31, 2006 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: 2005 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 2005. 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 20, page 41-42). c. Analysis of reservoir pressure surveys taken in 2005 (Attachment 4, page 43). d. Results of production surveys, and any special surveys, taken on the Meltwater Oil Pool in 2005 (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 Nick Pysz at (907) 265-6831. Sincerely, �.mes R. Hand Supervisor - Drillsite Petroleum Engineering Greater Kuparuk Area bcc: Central Files ATO -3 37 Pi Attachment 1 Kuparuk River Unit Meltwater Oil Pool ' 2005 Annual Reservoir Surveillance Report Summary of EOR Project and Reservoir Management Summary Background 1 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. iInjection of miscible injectant (MI) began in January 2002 and the MWAG (miscible water alternating gas) process was implemented during May 2003. Nineteen wells were online and producing (injecting) at the end of 2004. During the second quarter 2004, the 2P-427 was converted from production to injection service. 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 2005 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 2005: ' 1. 2P427 was converted to injection service and injection began in the well during April 2005. 2. Performed a microbial treatment on 2P-431 to test the effectiveness of microbes in reducing ' paraffin deposition. Early test data indicates the introduction of the microbes has had minimal impact on paraffin deposition. 3. During the second quarter 2005, installed surface powered jet pumps in three additional wells. These installations were made to reduce the cost of paraffin mitigation efforts (hot diesel flushes and paraffin scrapes) while also increasing the drawdown in the wells compared to the use of gas lift. The jet pumps were installed in 2P-406, 2P -424A, and 2P-443. 4. Completed a HPBD (high pressure breakdown) on the uppermost Bermuda intervals in the 2P- 447 in an attempt to establish better communication between the injector and the wells to the NW 1 (2P-441 and 2P -448A) 5. Returned 213-448A to production during December 2004 after performing a fracture stimulation on the well (re -frac). Below is a listing of the most important new findings derived from the 2005 Meltwater development efforts: 1. The producing well 2P-438 showed response to the new injectors drilled during the 1st half of 2004; ' however, production rates dropped significantly once water breakthrough occurred. 2. Paraffin deposition in the Meltwater wellbores and pipelines continues to occur. The main techniques employed to combat the paraffin deposition are hot oil treatments (wellbore and surface line) and wireline paraffin cutting in the tubing. Surface powered jet pumps were installed in three additional wells (213406, 2P -424A, and 2P-443) in order to minimize paraffin deposition. Paraffin deposition is mitigated in the 24" production line by cycling produced water through the 12" line, through the pigging facilities at 2P, and down the 24" production pipeline. This water cycling mitigation technique uses as ' little as 1,000 bwpd during the summer months to as much as 20,000 bwpd in the winter months to maintain the production header temperature above the cloud point 3. Outer annuli pressures in 2P-431, 2P432, 213-434, 2P-438, 2P-441, 2P-447, 2P -448A, and 2P-451 remained at elevated levels in 2005. 4. In wells with elevated outer annuli pressures, the calculated pressure at the C-80 interval is still below the measured/calculated leak off. Refer to table of elevated OA pressures below. i1 38 P, 1 C Reservoir Management Summary Meltwater came on-line in November of 2001 and has cumulatively produced 9.76 MMSTBO, 447 MBW, and 22.5 BCF of gas by year-end 2005. Miscible gas injection began in 2002 with water injection beginning in 2003 (MWAG cycles). Cumulative injection through year-end 2005 at Meltwater has been 11.5 MMBW and 30.3 BCF of MI gas. Early performance from five of the nine original Meltwater producers indicated that they were receiving voidage replacement from the two original injectors. The pressure support was indicated by stabilized oil rates and stable GORs. The phase II development drilling program included four (4) new injection wells to provide additional support to the field while specifically targeting areas that were not receiving adequate voidage replacement support. Four (4) additional production wells were drilled around the edge of the field to recover additional oil not accessed by the original drilling program. Recent production data from 2P-431, 213-438, and 2P-449 indicates that the wells are now receiving pressure support from the two new injection wells drilled in the southern portion of the field (2P-419 and 2P-447). Production data from 2P-441 and 2P -448A show that they are receiving limited support from the new injection wells drilled in the field. 2P-451 still appears to be receiving only limited support from the injection wells. 2P-406, 424A, and 2P-443 (production wells on the edge of the field) all seem to be getting support from nearby injection wells. These three edge wells are among the poorer performing wells in the field. 2P -415A has not exhibited a discernible response to offset injection. 2P -415A is the poorest performing producer at Meltwater. The bottom hole location of 2P -415A is located in lower permeability sand at the distal portion of the northern channel. 39 Meltwater Phase II Development Drilling Bermuda Nlet Pay Map C1 = 20 fa -amt A 2003-04 Injectors 0 2003-04 Producers 1e_Q000 STATUTE BILES 0 SSTRTUTE MILES KIL0KETERS0 5 1.0 KILOMETERS Conoc©Phillips 40 Attachment 2 Meltwater Oil Pool 2005 Annual Reservoir Surveillance Report Produced Fluid Volumes OIL GAS WATER CUM OIL CUM GAS CUM WATER MO YR STB MSCF STB STB MSCF STB 1 2005 239755 597371 22234 7893090 17773126 236262 2 2005 210823 506945 7079 8103913 18280071 243341 3 2005 225284 466601 10125 8329197 18746672 253466 4 2005 194520 412507 12196 8523717 19159179 265662 5 2005 173029 379539 16626 8696746 19538718 282288 6 2005 160948 441008 18007 8857694 19979726 300295 7 2005 148587 416494 26163 9006281 20396220 326459 8 2005 153308 502150 35251 9159589 20898370 361709 9 2005 143551 479819 38237 9303140 21378189 399947 10 2005 155753 426228 17289 9458893 21804417 417236 11 2005 148597 392465 14288 9607490 22196882 431524 12 2005 149102 346586 153529 2005 TOTAL 2103257 5367713 232848 Cumulatives at Dec 31, 2004 7653335 17175755 214028 Produced Fluid Volumes (Reservoir Units) OIL GAS WATER CUM OIL CUM GAS CUM WATER MO YR RVB RVB RVB RVB RVB RVB 1 2005 321032 397095 22545 10488508 13081215 233826 2 2005 282292 332964 7178 10770800 13414180 241004 3 2005 301655 289400 10267 11072456 13703580 251271 4 2005 260462 258388 12367 11332918 13961967 263638 5 2005 231686 240985 16859 11564604 14202952 280497 6 2005 215509 301923 18259 11780113 14504875 298756 7 2005 198958 287006 26530 11979071 14791881 325286 8 2005 205279 360147 35744 12184350 15152028 361030 9 2005 192215 345736 38773 12376565 15497764 399803 10 2005 208553 291696 17531 12585119 15789460 417334 11 2005 198971 265759 14488 12784090 16055218 431822 12 2005 199648 224926 15567 2005 TOTAL 2816261 3596024 236108 Cumulatives at Dec 31, 2004 10167476 12684121 211281 41 I 0 I7 Ll Attachment 3 Meltwater Oil Pool 2005 Annual Reservoir Surveillance Report Injected Fluid Volumes Cumulatives at Dec 31, 2004 5439593 0 20858741 42 WATER GAS MI CUM WATER CUM GAS MI MO YR STB MSCF MSCF STB MSCF MSCF 1 2005 602391 0 672653 5966881 0 24175209 2 2005 490147 0 638734 6457028 0 24813943 3 2005 581593 0 390970 7038621 0 25204913 4 2005 696255 475015 0 7734876 475015 25204913 5 2005 564878 638039 0 8299754 1113054 25204913 6 2005 422807 789835 0 8722561 1902889 25204913 7 2005 436435 469434 0 9158996 2372323 25204913 8 2005 442594 0 682963 9601590 2372323 25887876 9 2005 504860 0 625260 10106450 2372323 26513136 10 2005 486044 0 640966 10592494 2372323 27154102 11 2005 394687 0 452783 10987181 2372323 27606885 12 2005 518332 0 3100991 2005 TOTAL 6141023 2372323 4414428 Cumulatives at Dec 31, 2004 5364490 0 23502556 Injected Fluid Volumes (Reservoir Units) WATER GAS MI CUM WATER CUM GAS CUM MI MO YR RVB RVB RVB RVB RVB RVB 1 2005 610824 0 594625 6050417 0 21453366 2 2005 497009 0 564641 6547426 0 22018007 3 2005 589735 0 345617 7137162 0 22363624 4 2005 706003 595669 0 7843164 595669 22363624 5 2005 572786 800101 0 8415951 1395770 22363624 6 2005 428726 990453 0 8844677 2386223 22363624 7 2005 442545 588670 0 9287222 2974893 22363624 8 2005 448790 0 603739 9736012 2974893 22967363 9 2005 511928 0 552730 10247940 2974893 23520093 10 2005 492849 0 566614 10740789 2974893 24086707 11 2005 400213 0 400260 11141002 2974893 24486967 12 2005 525589 0 274128 1666590 29 $93 ^241!0.45` 2005 TOTAL 6226997 2974893 3902354 Cumulatives at Dec 31, 2004 5439593 0 20858741 42 1 J 11 1 0 1 C � I 1 II d Attachment 4 Meltwater Oil Pool 2005 Annual Reservoir Surveillance Report Reservoir Pressure Surveys 1 43 1 [ I O N Z U)O �a LLIU Z ui g>� 'L- Z it ° W a C0 Q U) (D O 'Q � W O (n I LUW Q J � a Z a W 0 W ff W W Z O co z 0 U D N Z Cl) 0 N rn ami N _O 0 LL (C CD COD d' N co M M O W co h N O w N N OOD T COD M N y N M N � d O O O N M (N) M M M LO M (7 W N_ O O O O O O O O O O O a l6 W Q y� 1 w Oi , N 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 L Q LO O 0 M ((7 M l(i (() lq (l') to to2 ♦� VN Cc � 2� v c� co`" c O 06 co ' O r N W N C. C N (M7 o COD M O tL p 0 C !� o ayc �; \ On � o Tai n a, V 0) 0)c °' E 3 E 0 p H n tf) M g M M 6 OD O O 0 Ch m N N N c0 (P M N `1 Q a�`> (D 0 V N N M M N 0 LO O N_ C �/! .+ W Q 20 It 1C) O co0 O IN Ul) o O v � In O (f) p U OO d L? �- a 0 co N M M v N M M M M M N O tDnd N w M 2 QCD to 0 v to E 0 O ~ N m�=- o� o dY Na N y d ` T C W(6 a~ 0° Q a 3 0 V d 0. a 0. d n. a. d d dt0. Q Y -6 C,) h S 2 2 S S 2 2 2 S 2 o C M [o M ao M M M M m co M cV p d cn CO cn M CO CO d CO CO CO cn rn s u) (0 M n `� 0 O m C6v n ooD rn rn m LL t 2 E ai V M o M 0 to 0 O QR an in 0 0 0 M 0 (f) 0 (n M oLO C) c ~_ a) O N N Z: N N O Z: N 0 N N is N C O O h O 1- O CD O N O h o (O O co O h O h O h O p N ` N 75 U v U 0 a O Q a EX 0 H H H H H 1— H H F- I— F- p •- J W J W J W J W J W J W J W J W J W J W J W a) V) t O C9 m �o OO Z `0 0 0 0 0 0 0 0 0 0 0 7' t U cc � 7G a C ' Z o 0 0 0 0 0 0 0 0 0 0 cc E !� RN. a Q M M LO M o CD LO 'd' ao o r� Oc M CO oo M (o M Oc 00 d rn N C 0 0 0 0 0 0 et 0 V 0 0 0 3 N N N N N N N N N N N C N V C Y M O M O M O M O M O M O M O M O M O M O M O N p (6 cc E cc r t N cn R ca C Z v c $ � m N = E Y y 0 c Z W Q ` to a 0 L- aa) OEa .0 Z E U) ami N m c dp CL p C N Z n LO t` N t0 M (� (A 2 �' d O o Dco a a N N N M M et aOj ¢ 0 M N N d N a N a N a N a� N N a N N n� N L N— W 0 W ff W W Z O co z 0 U D N Z Cl) 0 N rn ami N _O 0 LL f 1 ConocoPhillips 1 P e i J 1 March 31, 2006 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: 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 11 pressure surveys reported for the Meltwater Oil Pool to the AOGCC in 2005. In 2006, we expect to conduct approximately 5 pressure surveys, including initial surveys for new wells prior to initial sustained production. If you have any questions concerning this data, please contact Nick Pysz at (907) 265- 6831. Sincerely, James R. Hand Supervisor - Drillsite Petroleum Engineering Greater Kuparuk Area bcc: Central Files ATO -3 1 45 Attachment 5 Meltwater Oil Pool 2005 Annual Reservoir Surveillance Report Production/Special Surveys • Four (4) injection surveys were run during 2005. Injection surveys were run on 2P-419, 2P-429, 2P-434, and 213-447 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 (psig) BHT (deg F) 213-419 9/17/2005 water 5844 4307 123 2P-429 9/18/2005 water 3900 4086 124 2P-434 9/16/2005 water 4770 4033 123 2P-447 8/18/2005 water 9500 4158 114 • Cement bond logs were run on the 2P-427 Meltwater prior to conversion to injection service. Logs indicated adequate cement bond above the perforations. EM I 1 11 Attachment 6 Meltwater Oil Pool 2005 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 2005 Meltwater allocation factors by month are listed below. ;Meltwater Oil Pool 2005 Production Allocation Factors i Oil j Gas ; Water i Jan -051 0.9346 ; 0.9741 1.1696 i Feb -05; 0.9273 0.9561 i 1.1692 i Mar -051 0.9366 i 0.9375 1.1674 F -Apr -05; 0.9644 0.9617 1.2042 May -051 0.9618 i 0.9498 1.1878-1 j Jun -05; 0.9526 0.9543 1.1858 Jul -0-51 0.9019 0.9380 1.1435 Aug - 05 0.9410 i 0.9216 1.1813 -j-'- Sep -051 0.927T 0.9095 1.1758 Oct -051 0.9398 ' 0.8793 j 1.1738 Nov -05 0.9159 0.8546 1.0441 _ Dec -05; 0.9115 _ 1 0.8383_L , --I.0426 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 2005, no additional wells had OA pressures that increased to anomalous levels (2_900 psig). Three of the recently drilled injection wells (2P-432, 2P-434, and 2P-447) also 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. Plans have been put in place to take additional samples from the OA's to be sent off for isotopic analysis. 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 2006. 1 1 48 O 47 CLI ? t• .- L(i co M a, Di L`7L7 c,Na00M m m C*477 L[7 o�JRm o-LOr.�mc1c, = .r U ? G1 LD Lo m ? n ? nO NR O LD 03 h- n Ln n O N cV n C•7 U N- OO tom. O -? n m Lo ? m co ? o ? 'r, m Lncn r� O F a O � C O)O mm R 0 1--om I- m, O , a m N o 0 M 1 � N CV N N CV n N N N N N NN r4N N N N ry N Cl 0- J N L' LD n N m� n m? n c, c, o LL - Q O LL -_ Q O O O O O O O O Q O r O G r?i.��ncmvnronrNnon_n � 11 a` 0 0 0- c 0 LO O O O I m- N CLO'J VJ � - N m [Loo M pp 47 (V m14`7. t� pp 47 4 N - 7 O co 0 0 0 0 0 0 I - 9) ff, LO m S LO G G L N- �- n m 6l ? O M n m G, G1 cN- N Li0C7 mN IN ? N m M M 6~7 N Lf] tD M M M M v � - U 47 LD LD LD m M m ttDD t• ? Lf LO Q6f N 4 CO M N O M N N- N LD f• LD N �? M Lf7 n N N Lt7 LD LO CO m N m N m M ON B (`7 ^'7 t� ('PV N N N N d ~ - N N N rV N N CV CV N N � d � d- N Z LNomC,nn6' a'LoLLnrrN 'Q Q O N N N CI4 N M N M??? N N N N J N Yd O m18 oom p MNpp O OLD Q o M CV N N N � � •N CO CA m O 0 0 CD O vJ m N a` _ _ M'• ON = .H N OJ C'ND m N Cm7 ? m M N r.. V1 - CCpp L m ��,,,�� n M .... Cr7Ln m M CO CO U M m O f� ? N me f� LO ? 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G1 LD Lo m ? n ? nO NR O LD 03 h- n Ln n O N cV n C•7 F a - s C O)O mm R 0 1--om I- m, O , a m N o 0 N N CV N N CV n N N N N N NN r4N N N N ry N Cl J N LL Q O O O O O O O O Q O r O G r?i.��ncmvnronrNnon_n � 11 a` VJ � m [Loo M pp 47 (V m14`7. t� pp 47 4 7 O co 0 0 0 0 0 0 0 L ? CENJ p Li0C7 mN N ? N m M M 6~7 N Lf] tD M M M M C, � - N O �••' Q6f LO CO m N m N m M ON B (`7 ^'7 t� ('PV N N N N - N N N rV N N CV CV N N LL N LL0 Q O � Yd O m18 oom p MNpp O OLD M CV N N N � � •N I N ...- M'• ON N OJ C'ND m N Cm7 ? m M N .... U M m O f� ? N me f� LO ? O O ce omc,m�n nNm2 mm - �n d - ?N CD ? N Lo N ? N R 0 ? CD? LD n O ? m O? t� CO N C ✓? L m O m m m LJ f" m m m m m J N LL O Oy Vi OM r4iO 6Oi n O O m m c mcoLo mmmIl- a ,r• v In .... O m Lo m m N o) m fmm O OM Lo U ry G m? 'D n c O LD ? O7 G1 O M LD M rye n O rl m? M m O J N LL as o� NN ppp 0 0 0 0 0 0 0 N L( -J O rJ u N v fA O G7 iDr�cvoc�.- t� m O c O Jr:r� d - - - •N N -= 0 L4y77 0 0 0 0 0 4477 0 L4[7� 0 0 O C 11 F1 1 i11 Attachment 7 Meltwater Oil Pool 2005 Annual Reservoir Surveillance Report Meltwater Development Plan and Operational Review Following are summaries of key activities that are planned for 2006 and subsequent years. Development Drilling — One or two additional development well locations have been identified. Tentative plans are to pursue drilling these two injection well locations during 2007-2010 time frame. Additional seismic work is being performed to further evaluate the potential at the peripheral edges of the Meltwater pool. The total well count after the final portions of the development drilling program are completed is expected to be 20-22 wells. MIMater Injection — Miscible gas injection was initiated at DS 2P in January 2002 into two injectors. The facilities of both injectors are hooked up to implement a WAG (Water Alternating Gas) process. Water injection began in the field during May 2003. Plans are to continue the MWAG process during the life of the field. The 2P-427 was converted to injection during the 2nd quarter of 2005. Conversion of this well was necessary to provide voidage replacement support for the offsetting producing wells 2P-431 and 2P -424A. Artificial Lift — Meltwater currently uses miscible gas (MI) for artificial lift. One 8" pipeline transports gas to drillsites 2N, 2L, and 2P. The miscible gas will be utilized for injection and gas lift until the miscible gas EOR flood is complete at Tarn and Meltwater. Once the targeted MI slug size is injected into both reservoirs, the gas pipeline will transfer lean gas. This lean gas will be used for gas lift. The lowest oil rate producer, 2P -415A, employs a water powered jet pump for artificial lift. Three (3) additional surface powered jet pumps were installed during the 1St half of 2005. These pumps were installed at 2P-406, 2P -424A, and 2P-443 to both increase fluid rates and mitigate paraffin remediation work (hot diesel flushes and wireline scrapes). The metered oil rates of surface powered jet pump wells fluctuate with the variance in water injection header pressure. Exploration/Delineation — No further exploration work is currently planned. Additional seismic processing has been performed and is currently being analyzed to determine the drilling potential of the peripheral edges of the field. Gravel — Excessive clay content was discovered in the gravel used for the 2P dnllsite and road causing soft gravel conditions in the summer of 2001-2002. Remediation efforts to restore the pad condition were evaluated in 2003; but, due to improvements in the condition of the gravel, the decision was made to postpone any further remedial work to the pad and road while continuing to monitor the gravel conditions. In 2005 the 1 50 gravel conditions continued to improve. However, the road and pad remains softer than normal gravel conditions, thus all major work (heavy loads) including drilling and workovers still need to performed during the winter months. 1 1 1 11� 1 51 1 ConocoPhillips 11 0 �I i March 31, 2006 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: 2005 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 2005. 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 2005 (Attachment 4, page 56). d. Results of production surveys, and any special surveys, taken on the Tabasco Oil Pool in 2005 (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 Nick Pysz at (907) 265-6831. Sincerely, ames R. Hand Supervisor - Drillsite Petroleum Engineering Greater Kuparuk Area bcc: Central Files ATO -3 52 C' Attachment 1 Kuparuk River Unit Tabasco Oil Pool 2005 Annual Reservoir Surveillance Report Summary of the Enhanced Recovery Project Tabasco produced 1531 MSTB of crude, 345 MMSCF of formation gas, and 7636 MB of water during 2005. Water injection was 7677 MBW over the same ' period. Cumulative oil, gas, and water production and water injection through year end 2005 were 11263 MSTBO, 1676 MMSCF, 33816 MBW, and 38097 MBWI, respectively. The cumulative injectiontwithdrawal ratio was 0.82 on a reservoir barrel basis through year end 2005. Reservoir pressure decreased slightly from 1030 psi to approximately 950 psi during 2005. Injector 2T-210 remained shut-in with mechanical problems which continue to prevent water injection. Year end 2005 Tabasco well count (all at Kuparuk River Unit Drill Site 2T) was: Producers: 8 completed 8 on line Injectors: 2 completed 1 on line ' Water production increased slightly to a year end water:oil ratio (WOR) of 4.97 bbl water per STBO as compared to 4.2 at year end 2004. 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. ' In addition, static temperatures logs across the Tabasco interval in deeper Kuparuk wells clearly show warm injection water flow through the bottom portion of the reservoir. 0 u 1 53 Attachment 2 Tabasco Oil Pool 2005 Annual Reservoir Surveillance Report Produced Fluid Volumes Cumulatives at Dec 31, 2004 9732231 1331667 26179658 WATER OIL GAS WATER CUM OIL CUM GAS CUM WATER MO YR STB MSCF STB STB MSCF STB 1 2005 157055 43756 616876 9889286 1375423 26796534 2 2005 129792 36058 553221 10019078 1411481 27349756 3 2005 134804 28283 647097 10153882 1439764 27996853 4 2005 138452 30143 639889 10292334 1469907 28636742 5 2005 139254 35489 663714 10431588 1505396 29300456 6 2005 125365 33079 650796 10556953 1538475 29951252 7 2005 110313 29002 619038 10667266 1567477 30570290 8 2005 108005 21676 594571 10775271 1589153 31164861 9 2005 115760 14806 700966 10891031 1603959 31865827 10 2005 124708 20219 684043 11015739 1624178 32549870 11 2005 119983 21981 631358 11135722 1646159 33181228 12 2005 127501 30299 634654, 2633 9, aT 6y'x 3385$82` 2005 TOTAL 1530992 344791 7636224 Cumulatives at Dec 31, 2004 9732231 1331667 26179658 Produced Fluid Volumes (Reservoir Units) GAS WATER OIL MO YR RVB 1 2005 166164 2 2005 137320 3 2005 142623 4 2005 146482 5 2005 147331 6 2005 132636 7 2005 116711 8 2005 114269 9 2005 122474 10 2005 131941 11 2005 126942 12 2005 134896 Produced Fluid Volumes (Reservoir Units) GAS WATER CUM OIL CUM GAS CUM WATER RVB RVB RVB RVB RVB 2150 616876 10462865 2553 26796534 1767 553221 10600185 4320 27349756 973 647097 10742808 5294 27996853 1103 639889 10889290 6396 28636742 1595 663714 11036621 7991 29300456 1542 650796 11169257 9533 29951252 1347 619038 11285968 10880 30570290 687 594571 11400237 11567 31164861 0 700966 11522711 11567 31865827 0 684043 11654652 11567 32549870 566 631358 11781594 12134 33181228 1254 634654 1= 9I3,._. X13388 .. u8 5882 2005 TOTAL 1619790 12984 7636224 Cumulatives at Dec 31, 2004 10296701 404 26179658 54 Attachment 3 Tabasco Oil Pool 2005 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 2005 565410 0 0 30985846 0 0 2 2005 593354 0 0 31579200 0 0 3 2005 671777 0 0 32250977 0 0 4 2005 612242 0 0 32863219 0 0 5 2005 675369 0 0 33538588 0 0 6 2005 654785 0 0 34193373 0 0 7 2005 616837 0 0 34810210 0 0 8 2005 653141 0 0 35463351 0 0 9 2005 660725 0 0 36124076 0 0 10 2005 668611 0 0 36792687 0 0 11 2005 655806 0 0 37448493 0 0 12 2005 648823 0 0 38093 ,,. 2005 TOTAL 7676880 0 0 Cumulatives at Dec 31, 2004 30420436 0 0 Injected Fluid Volumes (Reservoir Units) Cumulatives at Dec 31, 2004 30420436 0 0 55 WATER GAS MI CUM WATER CUM GAS CUM MI MO YR RVB RVB RVB RVB RVB RVB 1 2005 565410 0 0 30985846 0 0 2 2005 593354 0 0 31579200 0 0 3 2005 671777 0 0 32250977 0 0 4 2005 612242 0 0 32863219 0 0 5 2005 675369 0 0 33538588 0 0 6 2005 654785 0 0 34193373 0 0 7 2005 616837 0 0 34810210 0 0 8 2005 653141 0 0 35463351 0 0 9 2005 660725 0 0 36124076 0 0 10 2005 668611 0 0 36792687 0 0 11 2005 655806 0 0 37448493 0 0 12 2005 648823 0 0 _'38fl7FUME,4 2005 TOTAL 7676880 0 0 Cumulatives at Dec 31, 2004 30420436 0 0 55 �I Attachment 4 ' Tabasco Oil Pool 2005 Annual Reservoir Surveillance Report Reservoir Pressure Surveys 1 0 1 56 Q N O ILW m NW Y� LU w Na Y� O LU U) ui Y� a Z Z a J m Co N O a' N O E O LL cli�^ Lo m y 00 o o rn rn Nns rn LO O 0 Nm 7 co T ao o c o 0 o O o 0 0 (� co N q 42a of C7 0 C. 0 0 0 0 0 0 0 � N C07 c� M c07 [O'J C'09 M M 3 E a Dov � 0cc co Lo NN aOD W Cao (00 ca co 0) CD O r -CO M O C C Il y y o r; a o C g T�(L q IM Cn E Q a ^� O M U O COO. N r e} 4 COD N N tm (o y M W — co co C @ j (n O coo N CND N N r- N O M N CMD N N V Q00 O O F- N Q 0 C - 0 coco U N d C00 C00 C00 c00 CO o 0 C0 C00 C00 H o 2 a t6 0 CD v m E C7 X N Il H O C O M O m _O 10 a Y O p y a 0^ Y N O @ ~ N C N Q CL a Zvv a Y 2 0 a a a a a a a a t°' N p O 0 o CL IL O C m f/i m CA m CD m CA m CO m Cn m CD m CA 0 0 O C 00 0 N N n N C lG o .: �= N N U 2 w U a� o ii � c i E -o H c0 c o 0 0 0 0 0 0 o Fy N N N N N N N N N 0 t6 R /0 C lL O O O O O O O O d \a eN•• N to U 0 p OU a � Cl) Cl) a E a ¢ ¢ m ¢ ¢ Q o n ` y H H H F FQ- H FQ- H w a _p O0 o p 010 01010 0 0 0 0 U R C E c 3 Z o 0 0 0 0 0 0 o E y D N a Q 't I-- co N CO rn O C 'a-. 0 N Cl)N N N N N N CM'7 'I7 N ; o V N N N N C m C Y ` C0 O O O O O O O O �' O (D L N Q o Y o co w a COco,O� Ea m p Z 0 rn L p t m J Z E0 .y. U) Oji c Cl. V C CD 3: Z O O O O 0 � CD O `� M a O C D N N N N N N N N a U ri co N N N N � N N N N d N m Co N O a' N O E O LL u 1 ConocoPhillips March 31, 2006 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 2006 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 2006. There were 8 pressure surveys reported for the Tabasco Oil Pool to the AOGCC in 2005. In 2006, we expect to conduct approximately 10 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 Nick Pysz at (907) 265- 6831. Sincerely, 2 •'' `` James R. Hand Supervisor - Drillsite Petroleum Engineering Greater Kuparuk Area bcc: Central Files ATO -3 58 I Attachment 5 Kuparuk River Unit Tabasco Oil Pool 2005 Annual Reservoir Surveillance Report Production Logs and Special Surveys During December 2005, the 2T-208 was spudded as a horizontal Tabasco well. The well plan included a pilot hole to penetrate and log the lower Tabasco interval. This interval was logged using a standard MWD suite (GR, LDT/ CNL, Resistivity). These logs were taken in order to better evaluate the production and reserve potential of the lower Tabasco interval underlying the main Tabasco pay. n 1 59 u Attachment 6 Kuparuk River Unit Tabasco Oil Pool 2005 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 2005 production allocation factors were as follows: 0 1 60 Tabasco Oil Pool 2005 Production Allocation Factors Oil Gas Water Jan -05 Feb -05 0.9346 0.9273 0.9741 0.9561 1.1696 1.1692 Mar -05 0.9366 0.9375 1.1674 Apr -05 0.9644 0.9617 1.2042 May -05 0.9618 0.9498 1.1878 Jun -05 Jul -05 0.9526 0.9019 0.9543 0.9380 1.1858 1.1435 Aug -05 0.9410 0.9216 1.1813 Sep -05 0.9274 0.9095 1.1758 Oct -05 0.9398 0.8793 1.1738 Nov -05 0.9159 0.8546 1.0441 Dec -05 0.9115 0.8383 1.0426 0 1 60 Attachment 7 Kuparuk River Unit Tabasco Oil Pool 2005 Annual Reservoir Surveillance Report Future Development Plans The current Tabasco Drill Site 2T development plan was designed to take advantage of gravity -induced water slumping. The first horizontal producer, near the top of the interval to provide vertical standoff from the water, was successfully drilled and completed in 2003. Two additional horizontal producers with similar structural positioning are planned with the first well, 2T- 208 being spud in December 2005. One additional horizontal well will be drilled during the first quarter 2006. A future redevelopment utilizing gravity stable gas injection to improve ultimate recovery is also being evaluated. Injection plans call for increasing injection to accomplish a cumulative net zero voidage and restore original reservoir pressure. Another workover to mitigate mechanical problems at injector 2T-210, which prevent water injection, continues to be considered. Conversion(s) of an existing producer(s) to water injection is planned if additional horizontal producers can be justified. Currently a study is underway to evaluate the feasibility of installing a new water injection pipeline to increase water injection rate at Tabasco. An update of the full -field reservoir model is being considered for use in development planning and flood ■ optimization. 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 1 Site 2T continues to prove challenging due to smaller accumulations, lower quality reservoir, and higher viscosity oil. 1 1 61 1 ConocoPhillips ' March 31, 2006 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: 2005 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 2005. 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 2005 (Attachment 4, page 66). d. Results of production surveys, and any special surveys, taken on the Tarn Oil Pool in 2005 (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 Nick Pysz at (907) 265-6831 1 Sincerely, James R. Hand Supervisor - Drillsite Petroleum Engineering Greater Kuparuk Area bcc: Central Files ATO -3 62 1 0 �F] Attachment 1 Kuparuk River Unit Tarn Oil Pool 2005 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 21t 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. Reservoir Management Summary In 2005, Tarn produced 8.09 MMSTB oil, 4.45 MMBW water, and 13,366 MMSCF gas. The injection totals for 2005 were 19,379 MMSCF of MI and 12.23 MMBW water. The cumulative year-end 2005 INV ratio for Drill Site 2N is estimated at 0.99, while the estimated cumulative INV for Drill Site 2L is 1.29. The average annual 2005 INV ratios for Drill Sites 2N and 2L were 1.16 and 1.58, respectively. Until a cumulative INV of 1.0 is reached in the 2N area, plans are to maintain reservoir pressure by balancing monthly injection and production rates. 63 MO 1 2 3 4 5 6 7 8 9 10 11 12 MO 1 2 3 4 5 6 7 8 9 10 11 12 Attachment 2 Tarn River Oil Pool 2005 Annual Reservoir Surveillance Report Produced Fluid Volumes 2005 TOTAL 8085327 13366242 4450798 CUM OIL OIL GAS WATER YR STB MSCF STB 2005 696248 909298 400823 2005 666887 935964 334877 2005 769228 1120780 323027 2005 774569 1248762 326964 2005 777123 1363841 340526 2005 727454 1252747 335284 2005 631263 1316517 369459 2005 674332 1165766 432231 2005 605878 1071211 417957 2005 619673 1095056 386066 2005 572519 960504 376316 2005 570153 925796 407270 2005 TOTAL 8085327 13366242 4450798 CUM OIL CUM GAS CUM WATER STB MSCF STB 65208241 92180429 7756672 65875128 93116393 8091549 66644356 94237173 8414576 67418925 95485935 8741540 68196048 96849776 9082066 68923502 98102523 9417349 69554765 99419040 9786808 70229097 100584806 10219039 70834975 101656017 10636995 71454648 102751073 11023061 72027167 103711577 11399377 72597320_ f 03T37.0.0o Cumulatives at Dec 31, 2004 64511993 91271131 7355849 Produced Fluid Volumes (Reservoir Units) Cumulatives at Dec 31, 2004 86455797 88415962 7458830 64 OIL GAS WATER CUM OIL CUM GAS CUM WATER YR RVB RVB RVB RVB RVB RVB 2005 934098 541225 406435 87389895 88957187 7865265 2005 894732 594744 339565 88284627 89551931 8204831 2005 1031847 734272 327549 89316474 90286203 8532380 2005 1039249 877054 331541 90355722 91163256 8863921 2005 1043073 1006300 345293 91398795 92169556 9209214 2005 977050 912735 339978 92375845 93082291 9549192 2005 847400 1056871 374631 93223246 94139162 9923823 2005 905628 850044 438282 94128874 94989205 10362105 2005 813827 790545 423808 94942701 95779751 10785913 2005 832532 807458 391471 95775233 96587209 11177384 2005 769318 686437 381584 96544551 97273646 11558968 2005 766294 647403 412972 97 0845J7S4 . ..7:.94 2005 TOTAL 10855047 9505087 4513109 Cumulatives at Dec 31, 2004 86455797 88415962 7458830 64 Attachment 3 Tarn River Oil Pool 2005 Annual Reservoir Surveillance Report Injected Fluid Volumes MI CUM WATER WATER GAS MO YR STB MSCF 1 2005 1134866 0 2 2005 892240 0 3 2005 872438 5867 4 2005 659365 2549461 5 2005 1079635 1440600 6 2005 986334 1455681 7 2005 1090925 1624368 8 2005 950335 11546 9 2005 881949 0 10 2005 1165516 0 11 2005 1200960 0 12 2005 1320086 0 MI CUM WATER CUM GAS MI MSCF STB MSCF MSCF 1687950 68202832 0 103518313 1807126 69095072 0 105325439 2118946 69967510 5867 107444385 0 70626875 2555328 107444385 0 71706510 3995928 107444385 0 72692844 5451609 107444385 0 73783769 7075977 107444385 1471405 74734104 7087523 108915790 1364428 75616053 7087523 110280218 1424972 76781569 7087523 111705190 1273973 77982529 7087523 112979163 1142589 .. 93026: 7ti23 ;: X152 2005 TOTAL 12234649 7087523 12291389 Cumulatives at Dec 31, 2004 67067966 0 101830363 Injected Fluid Volumes (Reservoir Units) 2005 TOTAL 12405934 8038668 10040696 Cumulatives at Dec 31, 2004 68006921 0 83283869 65 WATER GAS MI CUM WATER CUM GAS CUM MI MO YR RVB RVB RVB RVB RVB RVB 1 2005 1150754 0 1372145 69157675 0 84656014 2 2005 904731 0 1473713 70062407 0 86129727 3 2005 884652 6765 1733506 70947059 6765 87863232 4 2005 668596 2903073 0 71615655 2909837 87863232 5 2005 1094750 1611118 0 72710405 4520955 87863232 6 2005 1000143 1655198 0 73710548 6176153 87863232 7 2005 1106198 1850171 0 74816746 8026325 87863232 8 2005 963640 12343 1203230 75780385 8038668 89066462 9 2005 894296 0 1114944 76674681 8038668 90181406 10 2005 1181833 0 1163740 77856515 8038668 91345146 11 2005 1217773 0 1043462 79074288 8038668 92388607 12 2005 1338567 0 935958 tai'° 5_ 3 3 2005 TOTAL 12405934 8038668 10040696 Cumulatives at Dec 31, 2004 68006921 0 83283869 65 n Attachment 4 ' Tarn Oil Pool 2005 Annual Reservoir Surveillance Report Reservoir Pressure Surveys C 1 66 U Z 0 Q Q W LL Z 'LU10____ Z r O Q CD LL 'rr, `Rva Z J 11 d f�l 1 W g U) w U) m LU w m Z O U) z O V Z Cl) O O N W aa) m N E 0 LL r m W V'M W V• 0 O N N M h v O Cl) W O V' N h V' O r � M M 1- Lr) Cl) W M O CO O M W O N O O M O O r N W O C, v N W N Cl) N O N O M F M W N N O N CO CD O V' M N N N Cl) N N N ao N N Cl) W N Cl) N N M CO V• M M N N CO W W N N N N N 9' O C M M O N Q Cl) M M M O M V• N W ClV; V O O M O O O O v M O M R M O M M O M M M O t; w m� O O o 0 0 0 O 0 0 o O O o 0 0 O 0 0 0 0 O 0 o O a Cw Ori � r` 5 c 0 O 0 O 0 O 0 O 0 O 0 O 0 O 0 0 C. 0 0 0 0 0 O 0 O 0 O 0 O 0 O 0 O 0 O 0 O 0 O 0 O 0 O 0 O 0 O r y y N O N O N O NN O O N O N O O N O O N O N O NCM O O N O O N O N O N O NN O O N O N O N O N O N O N O N O N O N an 11 g ❑ .. O O O O 0 3 .. U� co Q aD cc; t6 O co co N M N CO V' M M W N_ CD W V' O V' CO M O W N W W P- N M O W r CO W CO M O O CO CO c0 CO r r N r_ CD O ` 9 CD O N N N W O M N M W N N V• O tD O M N O O N m N M V' M N N N NO Cl) LLZ Q d O t LN O O �3 roams y CD y N p r N O 00 N N N Cn W W t� W 0 t� M CO W M r O Cl W V. O r O O M Cl) V• a0 N r M V• O N O W V' M N r N N E Q It f•' y CC'i C(i h CO W n C O : O M CO m W r r c7 V• CO h N CO V' CV O C) m (/j L y O O M N_ W O W V' V• M V' M v M Cl) O O co V' r O O co O CO O N O M V• W N CO W O h V' r O O CO h h _W c0 Cl) CO C @E 0 y co to d ❑ O O O O O O O O O O O O O O co O v v O O v v v v O cc ❑N❑� Z C V' V' V' M V' N V' CO M co O O N M N V' N V' M M M M CD M M M V' M CO O CO M W Co M N N CO M V• M M � N O N O a) w 0 M 2 Q to to H O m Ecc o M ~ c m 0 O o o O d x96 T. y Y Y a n. a a a a a a a a a n. n. a a a a a a n. a a. a a a 4=" 2 U) 75x x x x x x x x x x x x x x x x x x x x= x x x x 0> 6 mmmmmmmmmmmmmmmmmmmmmmmmmmmo c i $ U- a O' C 12 m � m CD m O rn v m 0T m Co m CO m V' m W m O to Cl) m V' m CO m N m N m M m r m n m y OD rn N m O O m fl m O O m N m V' t� D- O CO G O O W M O co r V• O N CO 0 CO V' O CO O O w W h O � n M h M t0 CO w w � M co n , N O O m a — O L x co CC, 7 D 32 O N N LLL a) vi E c ar r H c LO 0 LO O to Lo O o O O O O O 0 LO O O O O 0 O O O 0 O O LO m y OO OO. O O O O O N r Q O " O c0 M M O O O O O V'• V' N 7 N V � V � O N V N O N O r O N 0 N O c—,, to Q v N p :3 la ..0) C r- O O O r O A O r O n 01 N . r h h n i Q Q F t c'7 r O h r r f0 7 E O O O O O O O O O O O O O O O O O O O O O o c N _N 2 i U L CD O o 0 m m m m m m m m m m m m m m m m m m m m m m m m m m m Y <'5 ❑ ❑ ❑ ❑ ❑ ❑ ❑ ❑ ❑ ❑ ❑ ❑ ❑ ❑ ❑ ❑ ❑ ❑ ❑ ❑ ❑ ❑ ❑ ❑ ❑ ❑ ❑ n u r o Z Z Z Z Z Z Z z Z z Z Z Z Z Z Z Z Z Z Z Z Z z Z Z Z Z a r a m H m F m H m H m F¢- m H m m m H m H m H m H m H m H m m H m m H m m m F m F m m m H m m H w OU Fa- la- Fa- la- Fa- I¢- Fa- F¢- la- ayi � 00 0 0 o 0 0 03: 3:1 3:1 ol o o o o o 0 o 0 0 0 0 0 3 0 o o o o� c ax Ec 0 Z 0 o 0 0 0 0 0 0 0 C. 0 0 0 p 0 0 0 0 0 0 0 0 0 C. 0 0 0 0 0 0 0 0 C. 0 0 0 Co 0 0 0 0 0 0 0 0 0 0 0 0 0 o E !� a Q 4 CO W 0 W 0 n h CD n CO M 6 co CO Cl) CO co A h N O N w 01 V• 6 w 61 O O r N v CO CO M V' 1ILCD Co O O r.- O C4 0 0 M CD r M m W C N N V• V' N 0 N 0 M 0 M 0 M C. N 0 N 0 M 0 M 0 M 0 N 0 N 0 N 0 M 0 N 0 M 0 N 00 N M 0 N 0 N C. N 0 N 0 M 0 O •O 3 m 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 N N C d C.1 p m m A c7 M co m m M m M m m M m C7 m m M m m m m m m m N C AC N 2. CO 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 r E CO L a) 0 ca a Y •O m a .L... N is o Q m w Z N .e N L: t -� M m z U) .3� c a O. o` C — at Z r r M O n n O M O v O �C> O O O M O co r` ao o N M N m N W N r- M W M V' y O O C D p M M M M M M M C7 CV M N M M M M M M M M M M ch 07 M M M M V' M CM N O co J J J J J J J J J J Z Z Z Z Z Z Z Z Z Z Z Z Z Z Z Z Z O L U M N N N N N N N N N Ni N N N N N N N N N N N N N N N N N N— W g U) w U) m LU w m Z O U) z O V Z Cl) O O N W aa) m N E 0 LL 1 ConocoPhillips 1 f Ll n March 31, 2006 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: Tarn Oil Pool — Proposed Pressure Survey Plan for 2006 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 27 pressure surveys reported for the Tarn Oil Pool to the AOGCC in 2005. In 2006, 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 Nick Pysz at (907) 265- 6831. Sincerely, James R. and Supervisor - Drillsite Petroleum Engineering Greater Kuparuk Area bcc: Central Files ATO -3 11 C� r_1 �I n Attachment 5 Kuparuk River Unit Tarn Oil Pool 2005 Annual Reservoir Surveillance Report Production Logs and Special Surveys One production profile survey and seven injection surveys were conducted at drill sites 2L and 2N. Results from the surveys indicate there are no casing or tubing leaks and all injection is within the Bermuda interval. Injection/Production rate, pressure, and temperature is summarized in the tables below. Tarn Production Profile Survey Data Tarn Injection Profile Survey Data Survey Date Well . Survey Date Fluid Rate (BWPD) (psig) (deg F) 21--305 9/19/2005 water 3450 3542 122.8 2N-306 9/19/2005 water 3180 3918 120 2N-309 9/11/2005 water 2198 3574 125 2N-325 9/15/2005 water 5368 3908 130 2N-331 9/12/2005 water 6420 3519 123 2N-343 9/13/2005 water 1 5380 3879 132 2N -349A 9/14/2005 water 1 2750 3953 122 Tarn Production Profile Survey Data Well Survey Date WC % iq. ate (BFPD) as ate (MCFD) (psig) (deg F) 2N-329 10/15/2005 1 17.7 1 2257 1 044 1 1022 130 .• ' Attachment 6 ' Tarn Oil Pool 2005 Annual Reservoir Surveillance Report Production Allocation Factors ' Aug -05 0.9410 0.9216 1.1813 Sep -05 0.9274 0.9095 Oil Gas Water 0.8793 Jan -05 0.9346 0.9741 1.1696 ' Feb -05 0.9273 0.9561 1.1692 Mar -05 0.9366 0.9375 1.1674 ' Apr -05 May -05 0.9644 0.9618 0.9617 0.9498 1.2042 1.1878 Jun -05 0.9526 0.9543 1.1858 Jul -05 0.9019 0.9380 1.1435 ' Aug -05 0.9410 0.9216 1.1813 Sep -05 0.9274 0.9095 1.1758 Oct -05 0.9398 0.8793 1.1738 ' Nov -05 0.9159 0.8546 1.0441 Dec -05 0.9115 0.8383 1.0426 r U - IL 11 C� Attachment 7 Kuparuk River Unit Tarn Oil Pool 2005 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 2006 include a minimum of one new development well on each of the two Tarn drillsites, 2L and 2N. Depending on ' rig availability and timing, an additional 1-6 wells may be drilled in the Tarn field during 2006. Currently, approximately 20 potential drilling opportunities are being evaluated. These opportunities include wells that may be drilled in 2006 in addition to a development program that would include 2007 and 2008. A portion of these penetrations would test the productivity of the peripheral edges of the field. An update of the full -field reservoir model is being considered for ' use in development planning and flood optimization. ' Producer to Injector Conversions — There are plans to convert one producer (2N-332) to an injector in 2006 at Tarn. E 0 1 71 P u 0 D u u F1 t D ConocoPhillips March 31, 2006 Mr. Dan Seamount, Commissioner Alaska Oil and Gas Conservation Commission 333 West 7t" Ave. Suite #100 Anchorage, Alaska 99501-3539 Jeffrey A. Spencer Supervisor — Heavy Oil Development Greater Kuparuk Area ConocoPhillips Alaska Inc. ATO -1170 PO Box 100360 Anchorage AK 99510-0360 Phone (907)263-4171 Fax: (907)263-4486 Re: 2005 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 2005. The following is an outline of the information provided: a. A summary of the enhanced recovery project (Attachment 1, page 73). b. Voidage balance, by month, for produced and injected fluids (Attachment 20, page 75-76). c. Analysis of reservoir pressure surveys taken in 2005 (Attachment 4, page 77). d. Results of production surveys, and any special surveys, taken on the West Sak Oil Pool in 2005 (Attachment 5, page 80-82). e. Results of well allocation and test evaluation for Rule 7, and any other special monitoring (Attachment 6, page 84). f. Future development plans (Attachment 7, page 85). If you have any questions concerning this data, please call Nick Pysz at (907) 265-6831. Sincerely, Jeffrey A. Spencer Supervisor — Heavy Oil Development Greater Kuparuk Area bcc: Central Files ATO -3 72 IAttachment 1 Kuparuk River Unit West Sak Oil Pool 2005 Annual Reservoir Surveillance Report Summary of the Enhanced Recovery Project West Sak development activities in 2005 included drilling five horizontal wells at the 1 E West Sak development; two producers and three injectors. In 2005 development drilling commenced on the 1 J West Sak Program. One producer and two injectors were drilled at 1 J in 2005. At the end of 2005 there were 25 water injectors and 33 producers in service in the West Sak oil pool. The following wells were drilled in 2005 in the West Sak oil pool: Name Well Type Target Inj/Prod 1E-102 Multilateral B/D Sand Injector 1E-121 Multilateral B/D Sand Producer 1 E-105 Multilateral D/B/A Sand Injector 1 E-117 Multilateral B/D/A Sand Injector 1 E-170 Multilateral D/B/A Sand Producer 1J-168 Multilateral D/B/A Sand Producer 1J-154 Multilateral B/D/A Sand Injector 1J-164 Multilateral B/D/A Sand Injector 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 2005. These events created high conductive pathways between an injector and a producer. A list of the breakthrough events in 2005 are shown below: Injector Producer Event Date Breakthrough Zone 1 E-112 1E-166 February 2005 B Sand 1 E-105 1E-126 December 2005 B Sand 1 73 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 the 1 E-112 to 1 E-166 failure has naturally healed and the 1 E-105 to 1 E-126 breakthrough is being investigated. 1 73 During 2003 ConocoPhi(lips 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 II : 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 1 C-135. Injection was continued for approximately two months. 1 C-135 was returned to long-term production in April 2004. Production from the well indicated that slotted liner wells are suitable for gas production. 1 74 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 are scheduled to be made in mid -2006 as soon as weather conditions permit. ■ Phase III of the Pilot Project was also initiated on March 2004 with gas injection into 1C-121. Well 1C-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 1C-102 as subsequent WAG cycles in 1C-119 and 1C-121 were suspended as a result of failed surface casing which was detected early in 2005 in 1 C-121 and mid year in 1C-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. Additional WAG cycles are planned in 1 C-174 to further observe WAG cycle performance and establish gas breakthrough levels in offset producers in 2006. This will complete the West Sak Small Scale EOR (SSEOR) Pilot Project. 1 74 11 Attachment 2 West Sak Oil Pool 2005 Annual Reservoir Surveillance Report Produced Fluid Volumes Cumulatives at Dec 31, 2004 14879781 4961826 3051364 Produced Fluid Volumes (Reservoir Units) OIL GAS WATER CUM OIL CUM GAS CUM WATER MO YR STB MSCF STB STB MSCF STB 1 2005 464373 394362 119451 15344154 5356188 3170815 2 2005 419065 289721 103578 15763219 5645909 3274393 3 2005 420195 277256 132172 16183414 5923165 3406565 4 2005 354063 264626 116385 16537477 6187791 3522950 5 2005 289012 203057 125421 16826489 6390848 3648371 6 2005 274198 171478 102997 17100687 6562326 3751368 7 2005 289478 150318 97215 17390165 6712644 3848582 8 2005 291338 163817 75603 17681503 6876461 3924185 9 2005 270352 131914 91558 17951855 7008375 4015743 10 2005 343304 181149 101789 18295159 7189524 4117532 11 2005 370133 237776 93523 18665292 7427300 4211055 12 2005 389158 277465 7533119D45D 01 03 2005 TOTAL 4174669 2742939 1235022 1235022 Cumulatives at Dec 31, 2004 14879781 4961826 3051364 Produced Fluid Volumes (Reservoir Units) Cumulatives at Dec 31, 2004 15921366 4110108 3051364 75 OIL GAS WATER CUM OIL CUM GAS CUM WATER MO YR RVB RVB RVB RVB RVB RVB 1 2005 496879 292617 119451 16418245 4402725 3170815 2 2005 448400 150061 103578 16866644 4552786 3274393 3 2005 449609 160612 132172 17316253 4713398 3406565 4 2005 378847 195993 116385 17695100 4909391 3522950 5 2005 309243 145009 125421 18004343 5054401 3648371 6 2005 293392 91852 102997 18297735 5146252 3751368 7 2005 309741 25716 97215 18607477 5171968 3848582 8 2005 311732 34685 75603 18919208 5206652 3924185 9 2005 289277 12206 91558 19208485 5218858 4015743 10 2005 367335 25646 101789 19575820 5244505 4117532 11 2005 396042 131889 93523 19971862 5376393 4211055 12 2005 416399 177130 75331 01 03 2005 TOTAL 4466896 1443415 1235022 Cumulatives at Dec 31, 2004 15921366 4110108 3051364 75 Attachment 3 West Sak Oil Pool 2005 Annual Reservoir Surveillance Report Injected Fluid Volumes Cumulatives at Dec 31, 2004 25581140 0 291982 Injected Fluid Volumes (Reservoir Units) WATER GAS MI CUM WATER CUM GAS MI MO YR STB MSCF MSCF STB MSCF MSCF 1 2005 701903 0 0 26283043 0 291982 2 2005 627575 0 0 26910618 0 291982 3 2005 372264 0 0 27282882 0 291982 4 2005 377346 0 0 27660228 0 291982 5 2005 540546 0 0 28200774 0 291982 6 2005 515141 0 0 28715915 0 291982 7 2005 440811 0 0 29156726 0 291982 8 2005 338281 0 0 29495007 0 291982 9 2005 408077 0 0 29903084 0 291982 10 2005 533046 0 0 30436130 0 291982 11 2005 485603 0 14276 30921733 0 306258 12 2005 520898 0 52507 ," ` 31111"'', 6� 2005 TOTAL 5861491 0 66783 Cumulatives at Dec 31, 2004 25581140 0 291982 Injected Fluid Volumes (Reservoir Units) Cumulatives at Dec 31, 2004 25581140 0 218695 76 WATER GAS MI CUM WATER CUM GAS CUM MI MO YR RVB RVB RVB RVB RVB RVB 1 2005 701903 0 0 26283043 0 218695 2 2005 627575 0 0 26910618 0 218695 3 2005 372264 0 0 27282882 0 218695 4 2005 377346 0 0 27660228 0 218695 5 2005 540546 0 0 28200774 0 218695 6 2005 515141 0 0 28715915 0 218695 7 2005 440811 0 0 29156726 0 218695 8 2005 338281 0 0 29495007 0 218695 9 2005 408077 0 0 29903084 0 218695 10 2005 533046 0 0 30436130 0 218695 11 2005 485603 0 10693 30921733 0 229387 12 2005 520898 0 393283463'1 6137 " 2005 TOTAL 5861491 0 50020 Cumulatives at Dec 31, 2004 25581140 0 218695 76 1 Attachment 4 West Sak Oil Pool 2005 Annual Reservoir Surveillance Report Reservoir Pressure Surveys 1 L I,n O N Z rO'^� 'v�J1 O vCJ 1L tG W O Z W�/ O w C5 w mWUJ u— Z 0z W°a N U)C)O ' Q J_ W O `� W S QJ Z Q 1� CO O O N CA N N 0 E O LL I- o -�6^ m N CA V M O M n op o CC) CA O Cd O CO N o N O M CO m M w C W V O (A O CC) o 0 o V CA I!) 1-'- n 1-'- r ti n M O N Cn C N r N r N r r r r NN r r r r r r r r r w N � N M O M V M V ITeY M N M W o M M 0) V M O O M M O 10 M M m M O M O M CA M CA •� W C O co O O O C O M6 M O M O M O M O O M M M M W W F d C 0 0 0 0 0 O C C C W W a sz 0 of r` 0 W 00 O o 0 0 0 0 0 0 0 0 0 0 0 0 0 C. 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 r II co o M 0 M o M 0 M o0 M M 0 M 0 M 00 M M o M 0 M 0 M 0 M 0 M 0 M 0 M 0 M 0 M o M o M ul) M G) O O c co o CA N N V M CO O CC) N O M O O O O O O CC) M O V o I- V o M N P CC) M r CC) O W M O N COp C6 ycc W n 0 r N N N (A CC) o o N CA V o o n N Q) r - V O c N I1 y p 0 J c , o o y r0 ELI E -4 CD °' E O p CA V; o n V r M N N N M CA O o O CO M M co O cp C o o N C M r m N m N V V M V Y Q W N p o N N o C co V O to m N o o O O V O C (n s W O M CC) M W M r M o m CA o N N M N M M O o M h CD CO M � M a0 O O N V1 Q M M M Cl) M m M 0V7 V cc ) co CM' Cc U O O N Q M Ci - 6 W O p W w O) O I` to CC) r co 1` n u) N CC) 0) O O V M o u') o O NU CID o 11- o r- I%- I n Co o Co co co 0 o ti 1- 11 co Co ti r- co h W a cc o = CL ~ a pLL d o ~ cc m - � co a Y co Y v 2 $ 0_ d m n. m d a m m d d d d d d d LL LL LL LW. d: 2 2 2 2 2 2 2 2 2 2 2== 2 2 2== 5 2 O S o C m m m m m m m m m m m m m m m m m m m m LL m N O CL a. — O O U) U) U) U) U) U) CO.) U) U) co U) U) U) U) 0 U) 0 U) co LL co W p C O O N o V o O N w o O O o CC') 0 W o o O o V V O N N M O co A O O O O O O O ao O aD Co ao O O c C6 p j 0 V o CO CC) tt) o M O V o o I- M r m O V o o N o M r Cl) 0) O V V N O U ` p co L CO m C d ii N cj E_ p d r ~ to W 0 ON 0 0 0 Or 0 to Or 0 OOO 0 OO 0 0 Or to OO 0 0 to ON o Or 0 ON 0 0 ON 0 Or 0 OM 0 ON o ON W H_t6 co N 73) V OO `M `r o `N h o t as M O V M CD OOO OOO O d' N N h N OO M M N �C p C W M O co O CA O r r O O) O r O r r O N O O h O O CO O N O 3 - CV 1 N 16 N � U (D d c U c Y O U >+ a p n ra Y a Y a Y Q Y a Y a Y a Y Q Y a Y a Y Y Y Y Y Y Y Y Y Y Y Y Y \^ r U V) V) U U CO U) V) U Ua U) U) V) V) V) V) V) V) U) U U) U) 0) y O co (7 Z Z Z Z Z > Z > Z Z Z I-)cisj 0 0 0�� 3 _Z 0 0 0 � 0 0 0 0�� 0 0 0 � P U U X X � a a) )C c m — E I v 2� 'C 3 Z 0 O 0 O 0 O 0 O 0 O 0 O 0 O O 0 O 0 O 0 O 0 O 0 O 0 O 0 O 0 O 0 O 0 O 0 O 0 O 0 O 0 O E E N a o o i i M O i o O i M f- . i 10 V i i N i o � o co N i M ' r i o N CA N Q r- O O a N N O r O V M o V CC) O O 0 O O r o (A r o o O CA CylN o O M M N V N r N CM N y C p > Cyj X Cl) M M M M M N N N N N N N N N N N N Co N N N M M Cl) M 3 CA x N N N N N N N N N N N N N N N N N N N N N N c y U C Y p (A N W N (A N m N W N m N m N m N m N O) N m N m N m N m N m N m N m N m N C6 N O N CA N c6 N W p w - N N 2 E ccL o O O O O O O O O O O O O O O O O O O O O O O N N Q ZE Y cc ccc@ W a (D R E Z a rn v r L: - L J a ZE U) a? Y U O. 00 C Z O O N M T O O CO N N N M M M M V O O W C .r 'L d O CO r i r i i r r i i i i r i i i i r i i i CU r Q LD U M o U U U U U U N L CO O O N CA N N 0 E O LL 1 ConocoPhillips March 31, 2006 Mr. Dan Seamount, Commissioner Alaska Oil and Gas Conservation Commission 333 West 7t" Ave. Suite #100 Anchorage, Alaska 99501-3539 Jeffrey A. Spencer Supervisor — Heavy Oil Development Greater Kuparuk Area ConocoPhillips Alaska Inc. ATO -1170 PO Box 100360 Anchorage AK 99510-0360 Phone (907)263-4171 Fax: (907)263-4486 Re: West Sak Oil Pool — Proposed Pressure Survey Plan for 2006 Dear Mr. Seamount, In compliance with Rule 8, Conservation Order No. 406A, ConocoPhillips Alaska, Inc., operator of the West Sak Oil Pool, is hereby submitting the proposed pressure survey plan for 2006. There were 22 pressure surveys reported for the West Sak River Oil Pool to the AOGCC in 2005. In 2006, we expect to conduct approximately 25 pressure surveys, including initial surveys for new wells prior to initial sustained production. If you have any questions concerning this data, please contact Nick Pysz at (907) 265- 6831. r bcc: Central Files ATO -3 79 Sincerely, 77 r Jeffrey A. Spencer Supervisor — Heavy Oil Development Greater Kuparuk Area r bcc: Central Files ATO -3 79 Attachment 5 ' West Sak Oil Pool 2005 Annual Reservoir Surveillance Report Injection Survey Data 1 fl 1 1 80 d w O z d w x F J � a wwz W 0 F J Q 7 ¢ ? Z a�w Q YaZ�0 Y 0 j N Q. i z x X H E a o �Lo 0 W �! N r Lo r c� N r z ° "m OH O E E. A W U z H Z 100 p z0 Y 0 m m N H Z Q z O J W W J ao 2 N 0 U O W n O "' � o bay U. It a�� cr �E> z ¢0X z oar w LLu3>- uo 0=,w o F 0 N CCQ 0: O LL., z 0 J 0 W 0 Q W W F- U M Z 2 � �o W� _ � N W Q z 0 O LU LU m W m cli �z � L 11 I 11 0 0 11 Attachment 5 Kuparuk River Unit West Sak Oil Pool 2005 Annual Reservoir Surveillance Report Production Logs and Special Surveys Geochemical Oil Production Splits: 82 LI G 1 Geochemical Oil Production Splits: 1 83 Attachment 6 West Sak Oil Pool 2005 Annual Reservoir Surveillance Report Production Allocation Factors 84 Oil Gas Water Jan -05 0.9346 0.9741 1.1696 Feb -05 0.9273 0.9561 1.1692 Mar -05 0.9366 0.9375 1.1674 Apr -05 0.9644 0.9617 1.2042 May -05 0.9618 0.9498 1.1878 Jun -05 0.9526 0.9543 1.1858 Jul -05 0.9019 0.9380 1.1435 Aug -05 0.9410 0.9216 1.1813 Sep -05 0.9274 0.9095 1.1758 Oct -05 0.9398 0.8793 1.1738 Nov -05 0.9159 0.8546 1.0441 Dec -05 0.9115 0.8383 1.0426 84 r Attachment 7 Kuparuk River Unit West Sak Oil Pool 2005 Annual Reservoir Surveillance Report Future Development Plans • DRILL SITE 1J DEVELOPMENT The KRU working interest owners intend to complete 17 wells from Drill Site 1J in 2006. The West Sak Wells 1J-101, 1J-166 and 1J-159 have been drilled and completed with Doyon 141 in early 2005 and are either currently on production or in the process of being hooked up. Doyon 15 is scheduled to arrive and spud the 1J-127 well starting in April, 2006. The Drill Site 1J drilling program should be complete in March, 2008. Information regarding the wells is listed below: Name Well Type Target Inj/Prod 1J-101 Multilateral D/B/A2 Sand Producer 1J-166 Multilateral D/B/A2 Sand Producer 11-159 Multilateral D/B/A2 Sand Producer 1J-152 Multilateral D/B/A2 Sand Producer 1J-184 Multilateral D/B Sand Producer 1J-127 Multilateral D/B/A2 Sand Injector 1J-109 Multilateral D/B/A2 Sand Producer 1J-170 Multilateral D/B/A2 Sand Injector 1J-133 Multilateral Intermediate N/A 1J-102 Multilateral D/B/A2 Sand Injector 1J-156 Multilateral D/B/A2 Sand Injector 1J-137 Multilateral D/B Sand Producer 1J-115 Multilateral D/B/A2 Sand Producer 1J-182 Multilateral D/B Sand Injector 1J-103 Multilateral D/B/A2 Sand Producer 1J-136 Multilateral DIB Sand Injector 1J-118 Multilateral D/B/A2 Sand Injector • WEST SAK EOR PILOT PROJECT PLANS An enriched hydrocarbon miscible gas EOR pilot is underway at Drill Site 1C. The enriched hydrocarbon miscible gas for this project comes from the existing Kuparuk River Unit ("KRU") enriched hydrocarbon miscible gas supply. Miscible ' gas injection began in late 2003. Facility modifications have been made to Drill Site 1C to accommodate West Sak EOR. The pilot is scheduled for completion in mid -2006. 1 85
