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2004 Greater Kuparuk Area
Greater Kuparuk Area Annual Surveillance Reports for the Kuparuk, Meltwater, Tabasco, Tarn, and West Sak Oil Pools Reporting Period January 1 — December 31 2004 • • ConocoPhillips James R. Hand Supervisor - Drillsite Petroleum Engineering Greater Kuparuk Area ConocoPhillips Alaska Inc. ATO -1276 PO Box 100360 Anchorage AK 99510-0360 Phone (907)263-4027 Fax: (907)265-6133 April 1, 2005 Mr. Dan Seamount, Commissioner Alaska Oil and Gas Conservation Commission 333 West 7th Ave. Suite #100 Anchorage, Alaska 99501-3539 Re: 2004 KRU Annual Reservoir Surveillance Report Dear Mr. Seamount, In compliance with Rule 3, Conservation Order No. 1986, ConocoPhillips Alaska, Inc., operator of the Kuparuk River Unit, is hereby submitting the annual surveillance report on the Kuparuk River Oil Pool. This report documents the required information pertinent to the field development and enhanced recovery operations from January through December 2004. The following is an outline of the information provided: a. A summary of the enhanced recovery project (Attachment 1). b. Voidage balance, by month, for produced and injected fluids, including low molecular weight hydrocarbons (Attachment 2, Attachment 3). c. Analysis of reservoir pressure surveys taken in 2004 (Attachment 4). d. A tabulation of both injection (Attachment 5) and production (Attachment 6) logs and surveys analyzed during 2004 from wells in the Kuparuk permit area. e. Composition of enriched gas injected during 2004 and estimate of MMP (Attachment 7). f. Kuparuk LSEOR development plan (Attachment 8). If you have any questions concerning this data, please contact Robert Christensen at (907) 659- 7535 or Nick Pysz at (907) 265-6831. Sincerely, James R. Hand Supervisor - Drillsite Petroleum Engineering Greater Kuparuk Area bcc: GKA Files ATO -1220A • Attachment 1 Kuparuk River Unit Kuparuk River Oil Pool 2004 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 2004 solvent injection was expanded to 11 wells. All 11 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 2004. The total number of MWAG drill sites in Kuparuk is 33 and there are 282 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, however, a small volume of IWAG injection at Kuparuk in 2004 primarily due to a mechanical failure on the Oliktok Pipeline which prevented the import of NGL's from Prudhoe Bay. During the days when NGL import was curtailed, the lean gas injection rate averaged 166 MMscf/d. The annualized average rate was 14 MMscf/d Total MI injection into Kuparuk averaged 200 MMSCFD for 2004. The incremental oil production resulting from MWAG at Kuparuk averaged 35 MBPD in 2004. The Greater Kuparuk Area utilized an average of 14 MBPD of indigenous NGLs and 26 MBPD of imported NGLs to manufacture 273 MMSCFD of MI, of which 73 MMSCFD was supplied to the GKA satellite fields Tarn, Meltwater and West Sak. • The priority for gas management at the Kuparuk field during 2004 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 2004 was essentially equal to the 2003 rate: 343 and 348 MMscf/d, respectively. MWAG Small Scale EOR (SSEOR and SSEORX) Drill Sites 1A, 1Y, and 2Z continued MWAG during 2004. The 2004 average MI injection rate was 7 MMSCFD. To date, these drill sites recovered over half of the ultimate incremental reserves through the MWAG process. 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 113 MMSCFD in 2004. EOR Expansions Expansions to the original LSEOR now include DS 1 B, 1 C, 1 E, 1 L, 3B, 3G, 3H, 30, 3Q and 3S. During 2004, the average MI injection rate into these expansion drillsites was 80 MMSCFD. IWAG 0 The Kuparuk EOR project continues to maximize MWAG operation by blending all • available lean gas for MI. No IWAG operation was undertaken in 2004 except during the short period of NGL import curtailment as discussed above. In 2005, the KRU will pilot an IWAG-after-MWAG process to determine the efficiency with which NGL's trapped by the MWAG process can be recovered to surface. Modeling efforts suggest that the project is technically viable. • 0 L, '22 N Tarn 2004 EOR Program Status 0 GKA, Active EOR Patterns * '282W KRU * 17 Tani * 6 Melhviater SSE ORandSSEORX LSEOR and LSEORX EOR -,.l Expansion in X2001 EORXI Expan-:ion in 2002 — 4 V%fells GKA Satellites 1998-2002 E0P.XI Expansion in 2003 1 C'VV S a k EOR Pilot 2003 Potentia- Future Expansion- E0R)U GKA, Active EOR Patterns * '282W KRU * 17 Tani * 6 Melhviater 0 a O M • • Kuparuk EOR Drill Sites (SSEOR+LSEOR+3F) Incremental EOR Oil Rate (Data Available from Jan '93 through Dec '04) 45000 25000 20000 15000 10000 5000 L ■rad r r i■■ti ; ■■■r.■, a, van, +► ■■� rr a '■r, ;r �■■i, i■r■r � �r- a ■■r rrr■r ii.. � � � ' �t �■r r�r i rr. r � ,��r ► i ■i �ii �i ei rr rri,3r■r rr frr rr rr r / • w SIN~ ®DS1A ■DS113 22DS1C MDS1E 40000 IMDS1F MDS1G ■DS1L 0DS1Q - KIDS1R IIDS1Y mDS2A 0DS213 35000 - - ■ DS2C Ili DS2D ® DS2F M DS2G ��� - "Y���`-^^ 0 DS2H 0 DS2K © DS2M 0 DS2T W k�i ® DS2U 0 DS2V B DS2W 0 DS2X 30000 �`.y�^-��� El DS2Z N DS3B 0 DS3C Il DS3F �R^X��R�al ■ DS3G N DS3H 19 DS30 0 DS3Q I 01 DS3R 0 DS3S 25000 20000 15000 10000 5000 L ■rad r r i■■ti ; ■■■r.■, a, van, +► ■■� rr a '■r, ;r �■■i, i■r■r � �r- a ■■r rrr■r ii.. � � � ' �t �■r r�r i rr. r � ,��r ► i ■i �ii �i ei rr rri,3r■r rr frr rr rr r / • w SIN~ t�l(- �'^ - ;=(a� •yZ>'•'�tt^�i"f- ��� v 1'- ��� - "Y���`-^^ t} W k�i Y l R.. �`.y�^-��� �R^X��R�al >L;xY '�����a • Attachment 2 Kuparuk River Unit Kuparuk River Oil Pool 2004 Annual Reservoir Surveillance Report Produced Fluid Volumes • • iAttachment 2 Kuparuk River Oil Pool 2004 Annual Reservoir Surveillance Report Produced Fluid Volumes Produced Fluid Volumes (Reservoir Units) OIL GAS WATER CUM OIL CUM GAS CUM WATER MO YR MSTB MMSCF MSTB MSTB MMSCF MSTB 1 2004 4,673 9,583 15,288 1,923,304 1,178,837 2,293,828 2 2004 4,417 9,062 14,719 1,927,721 1,187,899 2,308,547 3 2004 4,726 9,805 15,997 1,932,447 1,197,704 2,324,544 4 2004 4,515 8,783 15,382 1,936,962 1,206,487 2,339,926 5 2004 4,567 8,408 15,759 1,941,529 1,214,895 2,355,685 6 2004 4,470 8,064 16,135 1,946,000 1,222,959 2,371,820 7 2004 4,223 7,574 14,940 1,950,223 1,230,533 2,386,760 8 2004 3,971 6,847 13,046 1,954,194 1,237,380 2,399,806 9 2004 4,427 8,030 15,798 1,958,620 1,245,410 2,415,604 10 2004 4,485 8,532 16,589 1,963,106 1,253,942 2,432,194 11 2004 4,248 8,070 16,665 1,967,354 1,262,012 2,448,859 12 2004 4,493 8,765 18,268 2004 TOTAL 53,215 101,523 188,587 • Cumulatives at Dec 31, 2003 1,918,631 1,169,254 2,278,539 Produced Fluid Volumes (Reservoir Units) OIL GAS WATER CUM OIL CUM GAS CUM WATER MO YR MRVB MRVB MRVB MRVB MRVB MRVB 1 2004 5,748 5,610 15,557 2,365,653 1,446,721 2,334,101 2 2004 5,433 5,306 14,977 2,371,086 1,452,028 2,349,078 3 2004 5,813 5,765 16,278 2,376,899 1,457,792 2,365,357 4 2004 5,554 5,039 15,652 2,382,453 1,462,832 2,381,009 5 2004 5,618 4,717 16,035 2,388,070 1,467,549 2,397,044 6 2004 5,499 4,484 16,418 2,393,569 1,472,033 2,413,462 7 2004 5,194 4,201 15,202 2,398,763 1,476,234 2,428,663 8 2004 4,884 3,730 13,273 2,403,647 1,479,965 2,441,937 9 2004 5,445 4,476 16,075 2,409,092 1,484,441 2,458,011 10 2004 5,517 4,852 16,880 2,414,609 1,489,293 2,474,891 11 2004 5,225 4,587 16,956 2,419,834 1,493,880 2,491,847 12 2004 5,526 5,036 18,587 2004 TOTAL 65,455 57,804 191,890 • Cumulatives at Dec 31, 2003 2,359,906 1,441,111 2,318,544 Attachment 3 Kuparuk River Oil Pool 2004 Annual Reservoir Surveillance Report Injected Fluid Volumes • • • Attachment 3 Kuparuk River Oil Pool 2004 Annual Reservoir Surveillance Report Injected Fluid Volumes Injected Fluid Volumes (Reservoir Units) WATER GAS MI CUM WATER CUM GAS CUM MI MO YR MSTB MMSCF MMSCF MSTB MMSCF MMSCF 1 2004 19,265 0 7,445 4,365,382 1,058,152 769,929 2 2004 18,574 0 7,021 4,383,957 1,058,152 776,949 3 2004 20,388 0 7,563 4,404,344 1,058,152 784,512 4 2004 20,690 0 6,557 4,425,034 1,058,152 791,069 5 2004 20,318 0 6,505 4,445,352 1,058,152 797,574 6 2004 18,376 0 6,788 4,463,728 1,058,152 804,362 7 2004 17,883 0 6,313 4,481,611 1,058,152 810,675 8 2004 16,697 0 4,579 4,498,308 1,058,152 815,254 9 2004 19,296 0 6,144 4,517,604 1,058,152 821,398 10 2004 20,499 0 6,498 4,538,103 1,058,152 827,896 11 2004 19,113 0 6,322 4,557,217 1,058,152 834,218 12 2004 21,864 0 6,628 2004 TOTAL 232,963 0 78,363 • Cumulatives at Dec 31, 2003 4,346,117 1,058,152 762,483 Injected Fluid Volumes (Reservoir Units) WATER GAS MI CUM WATER CUM GAS CUM MI MO YR MRVB MRVB MRVB MRVB MRVB MRVB 1 2004 19,602 0 5,584 4,441,667 931,165 577,446 2 2004 18,899 0 5,265 4,460,566 931,165 582,712 3 2004 20,744 0 5,672 4,481,310 931,165 588,384 4 2004 21,050 0 4,917 4,502,361 931,165 593,302 5 2004 20,670 0 4,879 4,523,031 931,165 598,181 6 2004 18,695 0 5,091 4,541,726 931,165 603,272 7 2004 18,192 0 4,735 4,559,919 931,165 608,006 8 2004 16,985 0 3,435 4,576,903 931,165 611,441 9 2004 19,632 0 4,608 4,596,535 931,165 616,049 10 2004 20,856 0 4,873 4,617,391 931,165 620,922 11 2004 19,446 0 4,742 4,636,837 931,165 625,664 12 2004 22,246 0 4,971 2004 TOTAL 237,017 0 58,773 Cumulatives at Dec 31, 2003 4,422,066 931,165 571,862 • Attachment 4 Kuparuk River Oil Pool 2004 Annual Reservoir Surveillance Report Reservoir Pressure Surveys • • • • • STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION 1 of 4 ANNUAL RESERVOIR PRESSURE REPORT - 2004 Name of Operator Address ConocoPhilli s Alaska Inc. P. 0. Box 100360, Anchorage, AK 99510-0360 Unit or Lease Name Field and Pool Kuparuk River Field Datum Reference Oil GravityGas Gravity Ku aruk River Unit Ku aruk River Oil Pool -6200' SS 0.91 0.71 Final Pressure Test Data Production and Test Data APIF0,G Shut-in Tool FinalProduction Rates Wtof Wt.ofPressure Numbero Date Shut-in Tubing Depth B. H. Observed Bbls/Da Mcfd Liquid Liquid Gas Casing at Well Name Sand WI Tested Time Press. MD Tem Pressure Oil Water Gas Gradient Column Column Press. Datum 1A-01 A+C 500292059000 0 08/04/04 288 1900 7180 156 2361 372 2728 1302 2399 1A-03 A+C 500292061500 0 08/05/04 432 2150 8020 156 2778 256 2944 896 2771 1A-05 A+C 500292062700 WI 09/05/04 768 577 6950 133 3141 0 3250 0 3214 1A-07 A 500292065800 WI 12/27/04 993 1750 8437 121 3235 0 1000 0 3262 1A-09 A+C 500292066900 WI 09/05/04 792 454 6970 132 3057 0 2300 0 3064 1A-10 A+C 500292067300 WI 09/07/04 840 750 9018 135 3160 0 2400 0 3290 1A-23 A 500292213100 0 04/27/04 24 550 7120 155 2904 168 5444 1179 2954 1A-26 A 500292211500 0 01/16/04 36 750 8000 159 1784 155 345 155 1825 1A-26 A 500292211500 O 11/06/04 1416 250 7992 158 .2406 200 200 120 2446 1A-27 A+C 500292212400 0 05/18/04 168 1600 8840 162 2921 144 3456 720 2973 1A-27 A+C 500292212400 0 11/07/04 264 2300 9130 161 3127 231 3069 1571 3091 1B-03 C 500292058800 0 08/12/04 248 2178 7430 157 2651 326 4337 1100 2644 1B-06 A+C 500292060300 O 07/31/04 86 1017 8066 158 2523 322 2365 406 2466 113-12 C 500292236500 WI 06/27/04 100 1917 8240 136 3431 0 2718 0 3320 1B-19 A+C 500292247500 0 01/19/04 125 146 8500 161 2418 25 11 85 2404 1B-19 A+C 500292247500 0 09/10/04 3817 922 8500 159 3109 167 78 182 3092 1C-01 C 500292052600 O 09/02/04 86 1200 7044 156 2990 1000 2333 600 2972 1C-02 C 500292053200 0 08/01/04 114 2413 7110 157 2852 500 1583 200 2825 1C-07 C 500292056900 O 07/30/04 64 1354 8862 160 2906 350 1050 60 2833 1C-12 C 500292271900 0 07/24/04 443 660 8662 96 2152 375 458 71 2912 1C-15 C 500292293200 O 01/29/04 30 1770 8840 155 2200 300 638 150 2188 1C-15 C 500292293200 0 05/07/04 144 2150 8845 155 2672 220 566 132 2656 1C-15 C 500292293200 0 05/08/04 166 1376 8840 153 2676 220 626 132 2662 1C-16 C 500292293400 0 01/07/04 129 95 11490 156 2213 530 149 318 2115 1C-22 C 500292312700 WI 02/09/04 135 570 14350 130 3366 0 5000 0 3213 1C-24 C 500292306300 0 11/02/04 142 2000 7145 152 2441 500 1352 2500 2439 1C-26 C 500292294400 WI 10/31/04 731 934 10452 140 3594 0 4000 0 3535 1D-01 C 500292039300 0 11/09/04 290 700 7820 148 2926 280 1194 693 2877 1D-11 C 500292294600 WI 10/06/04 582 770 10905 125 3353 0 500 0 3247 1D-11 C 500292294600 WI 10/11/04 702 1000 11030 140 3383 0 500 0 3272 1D-11 C 500292294600 WI 11/23/04 1730 950 10930 133 3300 0 500 0 3211 1D-12 C 500292294800 0 07/31/04 86 985 9090 158 3200 1200 2229 1080 3080 1D-30 C 500292296500 0 05/26/04 140 2210 11790 150 2670 320 0 640 2658 1D-30 C 500292296500 O 09/10/04 419 730 11460 145 3327 2500 0 5500 3295 1D-32 C 500292298200 WI 06/05/04 382 780 10466 100 2835 0 200 0 3333 1D-32 C 500292298200 WI 11/04/04 842 780 13750 134 3082 0 200 0 3011 1D-34 C 500292297500 0 06/22/04 102 1290 15088 152 3076 50 0 130 3068 1D-36 C 500292297300 0 08/02/04 127 936 11440 158 3264 180 249 216 3220 1D-37 C 500292299200 0 08/01/04 103 909 10705 158 3219 200 356 300 3147 1D-42 C 500292297900 0 07/31/04 80 1580 8460 154 2355 250 22 450 2368 1E-05 A+C 500292047900 0 02/28/04 67344 619 6974 153 2930 128 1999 150 2935 1E-16 A+C 500292077700 WI 10/06/04 40291 1449 7421 154 3777 0 0 0 3767 1E-17 A+C 500292079300 WI 10/06/04 57883 855 7610 155 3122 0 0 0 3119 1E-18 A+C 500292090400 0 08/01/04 110 718 7741 158 2809 617 3792 1235 2798 1E-20 A+C 500292089500 0 08/02/04 126 1471 7960 156 2886 273 1333 310 2915 1E-27 A 500292083700 WI 01/31/04 137 1997 6260 124 4517 0 0 0 4577 1E-29 A 500292082800 0 04/30/04 29172 1185 6422 156 3355 0 0 0 3379 1E-29 A+C 500292082800 0 05/01/04 29172 1185 6269 156 3355 0 0 0 3433 1E-30 A 500292081400 WI 10/02/04 57804 1223 10131 146 3783 0 0 0 3369 • • • STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION 2 Of 4 ANNUAL RESERVOIR PRESSURE REPORT - 2004 Name of Operator Address ConocoPhilli s Alaska Inc. P. O. Box 100360, Anchorage, AK 99510-0360 Unit or Lease Name Field and Pool Kuparuk River Field Datum Reference Oil Gravity Gas Gravity Ku aruk River Unit Ku amk River Oil Pool -6200' SS 0.91 0.71 Final Pressure Test Data Production and Test Data API O,G Shut-in Tool Final Production Rates Wt. of Wt. of Pressure Number or Date Shut-in Tubing Depth B. H. Observed (Bbls/Da (Mcfd) Liquid Liquid Gas Casing at Well Name Sand WI Tested Time Press. MD Temp. Pressure Oil Water Gas Gradient Column Column Press. Datum 1E-34 C 500292280500 0 08/22/04 275 726 10131 152 2796 287 4490 155 2896 1F-06 A+C 500292082000 0 07/31/04 86 1750 9220 163 2221 381 849 629 2250 1F-15 A+C 500292102500 WI 01/30/04 15372 860 6400 143 3311 0 0 0 3430 1F -16A A 500292102901 WI 09/06/04 225 1961 8650 139 4308 0 150 0 4431 11F-18 C 500292265400 0 08/19/04 5568 850 7530 156 3200 0 0 0 3259 1F -18A A+C 500292265401 0 10/02/04 9999 2475 7254 144 4012 990 3510 4950 4079 1G-04 A 500292083500 WI 05/20/04 264 2200 6830 117 5173 0 1000 0 4983 1G-08 A+C 500292084900 0 02/02/04 10548 350 7130 141 2515 0 0 0 2656 1G -08A A 500292084901 0 07/23/04 99999 1250 7732 165 3994 500 0 300 3829 1G -08A A+C 500292084901 0 08/25/04 99999 1500 7500 165 3830 500 0 300 3735 1G -10A A+C 500292100301 0 07/31/04 79 1139 7318 158 2163 396 54 139 2144 1G-15 A+C 500292102400 0 05/10/04 19 148 6490 156 2582 816 5984 2938 2662 1G-15 A+C 500292102400 0 06/25/04 144 1200 7080 167 2846 780 5220 1404 2740 1G-17 A+C 500292294500 0 08/02/04 126 1950 7070 155 2341 277 1454 609 2341 1H-01 A 500292233000 0 08/01/04 96 958 7670 161 2843 65 152 26 2713 1H-10 C 500292234600 0 08/23/04 720 1400 7160 157 2725 60 111 24 2631 1H-11 C 500292235100 0 02/25/04 42 198 9276 160 2557 136 1804 249 2496 1H-17 A+C 500292231400 0 01/09/04 240 197 8088 161 2617 77 779 11 2431 1J-03 C 500292300200 0 02/28/04 216 950 11720 157 3056 246 0 97 2976 11-09 C 500292300600 0 08/01/04 108 1624 9650 155 2727 465 791 581 2755 1J-10 A+C 500292301000 0 08/01/04 202 1482 10480 153 2834 298 997 2530 2915 1L-01 A 500292119600 0 05/31/04 49541 43 7055 132 3220 0 0 0 3383 1L-02 A 500292119300 0 08/02/04 128 1677 6454 159 2707 225 96 544 2786 1L-15 A+C 500292120400 0 08/03/04 148 2541 6400 152 3119 287 1760 1370 3212 1L-15 A 500292120400 0 09/11/04 113 1417 6405 156 2332 83 3 46 2430 1L-24 A+C 500292217000 O 05/25/04 2069 1169 8925 155 3319 131 804 135 3404 1L-25 A+C 500292217400 0 03/05/04 68021 1218 9000 152 3413 0 0 0 3494 1L -26A C 500292217301 0 11/11/04 13848 1146 9395 152 3152 0 0 0 3296 1M-17 C 500292305800 0 04/17/04 17500 1170 10606 152 3447 0 0 0 3360 1Q-03 A+C 500292124900 0 08/01/04 96 1820 10170 163 2677 146 79 57 2603 1Q-04 A 500292125000 0 01/02/04 240 179 9230 160 2710 98 44 141 2545 1Q-05 A 500292123300 O 07/31/04 72 1929 8300 152 2613 340 327 422 2739 1Q -07A A 500292123401 0 02/09/04 216 2350 7783 160 3895 0 240 0 3895 1Q -07A A 500292123401 0 03/04/04 792 2350 7224 160 3709 0 240 0 3851 1Q-10 A+C 500292121500 0 08/08/04 72 1775 7190 154 3013 307 3531 268 3030 1Q-12 A+C 500292121000 WI 09/12/04 912 1500 6789 133 3686 0 8261 0 3711 1Q-13 A+C 500292130600 WI 03/25/04 3672 2460 7350 160 3821 0 1400 0 3891 1Q-15 A+C 500292130800 0 05/26/04 312 195 8460 151 2141 6 294 31 2140 1Q-15 A+C 500292130800 0 08/27/04 912 1300 8590 150 3083 21 137 35 3052 1Q -20A A 500292258901 O 08/01/04 96 1169 7623 156 1376 534 160 1486 1388 10-23 C 500292259600 0 08/06/04 96 1441 9310 158 2598 226 2285 551 2583 1R-02 A 500292140500 0 07/31/04 48 1311 8900 158 1982 377 4 256 1876 1R-14 A 500292138600 0 07/31/04 72 1400 8980 163 2938 245 177 285 2766 1R -22A C 500292220601 0 01/19/04 3600 1600 9163 152 3950 265 563 190 3877 1Y-01 A 500292093300 WI 09/03/04 744 1125 6560 134 3667 0 2000 0 3740 1Y -06A A+C 500292095801 0 04/20/04 45 1000 7902 155 2642 152 483 77 2740 1Y -15A A+C 500292091901 0 08/01/04 101 1750 9877 155 2165 564 2402 2921 2250 1Y-17 A 500292236800 0 08/01/04 108 1500 7700 158 2680 54 109 344 2706 1Y-22 A+C 500292236900 0 08/01/04 104 1653 6300 156 2386 885 2963 1056 2450 • • • STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION ANNUAL RESERVOIR PRESSURE REPORT - 2004 3 of 4 Name of Operator Address ConocoPhilli s Alaska Inc. P. O. Box 100360, Anchorage, AK 99510-0360 Unit or Lease Name Field and Pool Kuparuk River Field Datum Reference Oil GravityGas Gravity Ku aruk River Unit Ku aruk River Oil Pool -6200' SS 0.91 0.71 Final re Test Data Production and Test Data API O,G Shut-in Final Production Rates Wt. of Wt. of Pressure Number or Date Shut-in Tubing LDe B.H. Observed Bbls/Da ) (Mcfd) Liquid Liquid Gas Casing at Well Name Sand WI Tested Time Press. Tem Pressure Oil Water Gas Gradient Column Column Press. Datum 1Y-23 A 500292237000 0 07/12/04 240 1450 7070 154 2277 111 189 322 2357 1Y-24 A 500292237100 0 02/22/04 13158 1420 8060 156 3087 140 260 56 3155 1Y-24 A 500292237100 O 07/14/04 18066 500 8061 156 2974 0 0 0 3044 1Y-25 A 500292185000 0 03/03/04 108 950 6963 158 2633 107 99 52 3493 1Y -26A A+C 500292185301 0 08/02/04 122 1632 7112 158 2773 555 3145 1499 2916 1Y-34 A 500292238200 0 08/01/04 99 1284 9040 158 1515 301 106 632 1522 2A-05 A+C 501032003000 0 01/11/04 352 266 8633 149 2122 900 2100 5400 2138 2A-06 A 501032002800 0 06/02/04 1056 1800 7933 112 3989 0 0 0 4113 2A-12 A 501032005800 0 01/16/04 97 550 6850 151 2495 0 0 0 2622 2A-15 A+C 501032004100 0 01/11/04 354 268 7649 153 2418 693 5607 4158 2441 2A-16 A+C 501032004200 0 01/09/04 161 212 8932 150 2451 900 2100 6300 2677 2A-18 A+C 501032022000 0 07/12/04 223 186 6420 159 2424 50 4950 165 2522 2A-18 A+C 501032022000 0 12/09/04 1240 1400 6484 150 2552 0 0 0 2638 2D-01 A 500292119400 0 05/17/04 96 141 6424 162 2992 236 944 354 3141 2D-03 A 500292117800 0 08/08/04 48 135 7559 156 1378 300 162 420 1472 2D-06 A 500292116800 0 09/14/04 336 1450 8100 149 2351 0 0 0 2591 2D-06 A 500292116800 0 12/02/04 318 1500 8750 157 2458 0 0 0 2551 2D-14 A+C 500292118300 0 12/09/04 39312 2400 7887 123 3399 0 0 0 3545 2D-15 A+C 500292118400 0 01/26/04 114 138 6290 162 3103 112 688 482 3228 2E-10 A 500292124600 0 09/23/04 600 1400 6344 160 2578 0 0 0 2666 2F-01 A 500292105800 WI 06/11/04 50 1975 6512 119 4412 0 900 0 4474 2F-06 A 500292107500 0 05/23/04 19416 2450 9038 157 3831 0 0 0 3935 2F-10 A+C 500292109400 0 01/26/04 124 121 8298 160 3578 117 413 198 3746 2F-11 A+C 500292109500 0 10/08/04 810 1500 9590 158 2718 0 0 0 2812 2F-17 A+C 500292273100 0 04/11/04 32300 1500 10551 149 4185 0 0 0 3930 2G-02 A 500292115300 O 01/24/04 85 131 6417 157 2945 162 418 487 3031 2G-04 A 500292116700 0 01/24/04 79 126 7418 157 2422 207 323 765 2507 2G-08 A 500292112500 0 01/25/04 103 138 7640 158 3174 128 623 255 3282 2G-09 A+C 500292113900 0 01/24/04 78 127 7787 156 2043 218 202 328 2128 2G-11 A+C 500292114900 0 01/24/04 83 123 8385 155 2425 239 212 262 2486 2G-13 A 500292116000 0 01/25/04 109 127 7595 159 3469 135 365 108 3539 2G-15 A 500292116200 0 04/19/04 9000 116 6698 153 4380 0 0 0 4489 21-1-06 A 501032004400 0 01/26/04 55 218 8290 156 2597 90 170 53 2708 2T-21 A+C 501032021200 0 04/20/04 7320 819 12425 152 3117 0 0 0 3309 2T-28 A+C 501032022500 0 01/15/04 72 1500 10551 117 3738 0 0 0 3971 2T-28 A+C 501032022500 0 04/11/04 1150 1500 10551 117 3633 0 0 0 3809 2T-29 A 501032022200 WI 04/18/04 7200 2100 10235 134 4029 0 0 0 4119 2T-32 A 501032021800 GI 07/27/04 15000 1800 13411 148 3513 0 0 0 3583 2U-07 A 500292128300 0 01/16/04 99 2500 7916 120 4369 0 0 0 4494 2U-14 A+C 500292126200 WI 06/27/04 555 1851 6868 120 2914 0 4750 0 3056 2V-13 A+C 500292129300 0 11/11/04 320 1250 8417 161 2456 0 0 0 2575 2V-15 A+C 500292129500 0 01/10/04 192 200 6100 158 2411 450 4050 3150 2445 2W-01 A+C 500292127300 0 07/12/04 70 2000 7857 154 2494 0 0 0 2580 2W-03 A+C 500292127400 O 07/12/04 70 1900 7910 150 2298 0 0 0 2435 2W-06 A+C 500292121100 0 01/09/04 193 304 7000 156 2443 1000 3348 7000 2565 2W-07 A+C 500292122000 O 07/12/04 60 2025 6150 155 2435 0 0 _0 2546 2W-11 A+C 500292123800 0 07/12/04 63 1000 6725 155 2668 2756 2W-12 A+C 500292124000 0 07/12/04 66 191 7870 155 2670 700 4685 630 2733 2W-15 A+C 500292125400 0 07/12/04 64 1850 7570 150 2377 2565 • i • STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION ANNUAL RESERVOIR PRESSURE REPORT - 2004 4of4 Name of Operator Address ConocoPhillips Alaska Inc. I P. O. Box 100360, Anchorage, AK 99510-0360 Unit or Lease Name Field and Pool Kuparuk River Field Datum Reference Oil Gravity Gas Gravity Kuparuk River Unit Kuparuk River Oil Pool 6200' SS 0.91 0.71 Final Pressure Test Data Production and Test Data API O,G Shut-in Tool Final Production Rates Wt. of Wt. of Pressure Number or Date Shut-in Tubing Depth B.H. Observed Bbls/Da ) (Mcfd) Liquid Liquid Gas Casing at Well Name Sand WI Tested Time Press. MD Temp. Pressure Oil Water Gas Gradient Column Column Press. Datum 2Z-05 A+C 500292095600 O 08/03/04 384 650 8225 152 2919 0 0 0 2979 2Z-13 A+C 500292136000 O 08/01/04 105 1950 8260 160 2975 0 0 0 3053 2Z-20 A+C 500292187600 O 07/31/04 161 850 7215 152 2861 0 0 0 3027 2Z-21 A+C 500292187700 O 08/01/04 105 750 7350 153 2837 0 0 0 2953 3C-01 A 500292141300 O 09/13/04 68 16 7886 151 952 133 85 323 976 3C-09 A 500292135500 WI 06/06/04 13386 1030 7995 160 3549 3455 3C-14 A 500292142500 WI 06/19/04 842 2500 8067 155 5044 4938 3F -19A A 500292268001 O 03/10/04 19848 1000 7992 160 3809 0 0 0 3883 3F-20 A 500292294700 WI 01/01/04 17160 2900 7277 149 3939 0 0 0 4001 31F-21 A+C 500292299100 WI 01/02/04 12456 1500 8853 150 3478 0 0 0 3537 3G-05 A 501032013200 O 04/12/04 72 1250 7914 158 3123 0 0 0 3244 3G -19A A 501032013601 O 07/23/04 18792 1600 8043 157 3698 0 0 0 3829 3H-04 A+C 501032007600 O 05/20/04 62 140 5865 169 2699 340 450 221 3270 3H-20 A 501032009300 O 02/26/04 76 1200 8735 155 2491 0 0 0 2549 31-01 A 500292151400 O 12/23/04 134 256 8766 157 3497 0 0 0 3470 31-10 A 500292193400 O 12/24/04 157 34 6774 156 2809 0 0 0 2810 31-11 A 500292193200 O 12/24/04 161 24 6470 159 3526 0 0 0 3526 31-13 A 500292192300 WI 06/06/04 142 2363 7429 160 5110 0 340 0 4965 31-17 A 500292192200 O 12/25/04 178 89 6962 157 3503 0 0 0 3530 3J-17 A+C 500292270000 O 04/01/04 18288 1500 7750 164 3766 0 0 0 3789 31K-05 A 500292161800 WI 10/18/04 456 2498 7860 105 5035 0 0 0 4879 3K-35 A 500292277500 O 01/30/04 419 50 8404 150 1800 0 0 0 1791 3M-03 A 500292169600 O 08/06/04 15456 -1 7624 149 4780 0 0 0 4840 3M-05 A 500292170600 O 06/15/04 42 1397 8668 154 3337 116 348 109 3338 3M-08 A+C 500292170900 O 12/25/04 143 138 9859 157 3041 0 0 0 3066 3M-09 A 500292171000 O 12/28/04 247 35 6594 155 1851 0 0 0 1822 3M-11 A 500292171800 O 12/25/04 116 146 7663 156 3457 0 0 0 3475 3M-18 A 500292173000 O 01/13/04 8760 1500 8192 154 3719 0 0 0 3719 3M-18 A 500292173000 O 10/12/04 16536 123 8158 152 4230 0 0 0 4242 3M-19 A 500292173700 O 12/25/04 171 515 8463 154 3062 3104 3M-27 A 500292263700 O 12/28/04 252 135 12741 158 3412 0 0 0 3427 3M-28 A 500292244200 O 12/29/04 260 14 12909 154 1630 0 0 0 1718 3M -29A A 500292264101 O 05/03/04 9864 1329 11320 145 2876 0 0 0 3034 30-03 A 500292183800 O 07/21/04 72 1280 8621 163 3008 261 982 218 2914 30-09 A 500292182500 O 08/02/04 72 1326 7587 162 2412 294 480 207 2287 30-12 A+C 500292180400 WI 11/25/04 336 2880 6671 115 4627 0 0 0 4433 30-20 A 500292275000 O 08/02/04 72 1179 10055 159 3065 169 599 82 2977 3S -24A C 501032045601 O 05/18/04 9999 750 12305 159 3166 0 0 0 3289 185 >> >> Total Pressure Count in 2004 I hereby c rti h �f a Ding is true and correct to the best of my knowledge. Signed Title GKA Voidage Management Coordinator Date 3 bs i C) --s roan IU -41Z v - - Submit in Duplicate Rev 7 1 80 • • ConocoPhillips April 1, 2005 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 -1276 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 2005 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 2005. There were 185 pressure surveys reported for the Kuparuk River Oil Pool to the AOGCC in 2004. In 2005, we expect to conduct approximately 180 pressure surveys, including initial surveys for new wells prior to initial sustained production. If you have any questions concerning this data, please contact Robert Christensen at (907) 659-7535 or Paul Burtis at (907) 265-6314. Sincerely, t James R. Hand Supervisor - Drillsite Petroleum Engineering Greater Kuparuk Area • bcc: GKA Files ATO -1220A • Attachment 5 Kuparuk River Oil Pool 2004 Annual Reservoir Surveillance Report Injection Survey Data :7 KUPARUK RIVER UNIT 1 of 3 KUPARUK RIVER OIL POOL CONSERVATION ORDER 198B RULE 4 - INJECTIVITY PROFILES 2004 ANNUAL SUBMITTAL INJECTION BWPD / MSCFD WELL NUMBER API NUMBER 50- DATE OF INITIAL INJECTION DATE OF PROFILE/ SURVEY DATA TYPE PROFILE/ SURVEY REASON FOR PROFILE/ SURVEY WELL COMPLETION ZONES TAKING INJECTION 1A-05 02920627-00 12/19/91 07/22/04 SPINNER Follow up Sel. Single A+C 7800 A 1014 1A-06 02920638-00 03/09/92 12/21/04 SPINNER Follow up Sel. Single A+C 3960 A 990 1A-09 02920669-00 02/28/83 07/13/04 SPINNER Follow up Sel. Single A+C 1990 A 796 1A-12 02920688-00 01/27/83 07/13/04 SPINNER Follow up Sel. Single A+C 3787 A 705 1A-14 02920706-00 02/22/83 09/13/04 SPINNER Follow up Sel. Single A+C 3600 A 216 1A-15 02920711-00 02/15/83 10/18/04 SPINNER Follow up Sel. Single A+C 4800 A 192 1E-04 02920478-00 04/17/83 09/24/04 SPINNER Follow up Sel. Single A+C 4200 A 0 1E-11 02920787-00 05/31/96 09/25/04 SPINNER Follow up Sel. Single A+C 2344 A 819 1E-21 02920892-00 05/02/83 04/15/04 SPINNER Follow up Sel. Single A+C 4308 A 64 1F-02 02920881-00 10/15/85 12/14/04 SPINNER Follow up Sel. Single A+C 2237 A 1476 1F-05 02920807-00 10/28/85 01/27/04 SPINNER Follow up Sel. Single A+C 832 A 768 1G-01 02920805-00 11/23/93 07/16/04 SPINNER Follow up Sel. Single A+C 5061 A 0 1H-07 02920755-00 08/12/93 09/14/04 SPINNER Follow up Triple A+C 1400 A 0 1H-19 02922312-00 07/08/93 09/14/04 SPINNER Follow up Sel. Single A+C 2200 KUPARUK RIVER UNIT 2 of 3 KUPARUK RIVER OIL POOL CONSERVATION ORDER 198B RULE 4 - INJECTIVITY PROFILES 2004 ANNUAL SUBMITTAL INJECTION WELL API DATE OF DATE OF DATA TYPE REASON FOR WELL ZONES NUMBER NUMBER INITIAL PROFILE/ PROFILE/ PROFILE/ COMPLETION TAKING BWPD / 50- INJECTION SURVEY SURVEY SURVEY INJECTION MSCFD A 280 1Q-13 02921306-00 11/17/85 09/15/04 SPINNER Follow up Sel. Single A+C 1362 A 913 1R-08 02921333-00 09/01/85 06/19/04 SPINNER Follow up Sel. Single A+C 1146 A 86 1R-09 02921350-00 11/11/86 06/11/04 SPINNER Follow up Single A+C 532 A 532 1Y-02 02920941-00 03/30/85 09/16/04 SPINNER Follow up Sel. Single A+C 6860 A 0 1Y-13 02920903-00 10/28/85 01/27/04 SPINNER Follow up Single A+C 3125 A 1875 2B-10 02921084-00 11/09/86 08/28/04 SPINNER Follow up Sel. Single A+C 2335 A 350 2B-12 02921092-00 11/10/85 09/10/04 SPINNER Follow up Sel. Single A 2100 A 2100 2D-16 02921185-00 11/18/85 07/20/04 SPINNER Follow up Single A+C 840 A 780 2H-03 10320031-00 11/15/87 09/18/04 SPINNER Follow up Sel. Single A+C 3200 A 2368 2Z-02 02920960-00 11/04/85 05/22/04 SPINNER Follow up Sel. Single A+C 770 A 62 2Z-06 02920957-00 11/04/85 01/19/04 SPINNER Follow up Sel. Single A+C 2225 A 1139 2Z-06 02920957-00 11/04/85 06/04/04 SPINNER Follow up Sel. Single A+C 2233 A 1027 3A-07 02921444-00 01/09/91 10/01/04 SPINNER Follow up Sel. Single A+C 1370 A 822 • • KUPARUK RIVER UNIT KUPARUK RIVER OIL POOL CONSERVATION ORDER 198B RULE 4 - INJECTIVITY PROFILES 2004 ANNUAL SUBMITTAL • 3 of 3 WELL API DATE OF DATE OF DATA TYPE REASON FOR WELL ZONES INJECTION NUMBER NUMBER INITIAL PROFILE/ PROFILE/ PROFILE/ COMPLETION TAKING BWPD / 50- INJECTION SURVEY SURVEY SURVEY INJECTION MSCFD 3A-11 02921458-00 01/21/87 10/16/04 SPINNER Follow up Sel. Single A+C 2350 A 447 3A-15 02921491-00 01/16/88 10/16/04 SPINNER Follow up Sel. Single A+C 1470 A 353 3C-05 02921389-00 02/04/86 05/07/04 SPINNER Follow up Sel. Single A+C 1904 A 260 3C-12 02921354-00 01/09/86 10/19/04 SPINNER Follow up Sel. Single A+C 1290 A 516 3H-09 10320086-00 12/08/88 09/22/04 SPINNER Follow up Sel. Single A+C 5081 A 0 3K-13 02921630-00 11/05/87 07/01/04 SPINNER Follow up Sel. Single A+C 385 A 190 3K-15 02921632-00 11/05/87 06/03/04 SPINNER Follow up Sel. Single A+C 579 A 298 35-14 10320439-00 01/29/03 02/24/04 SPINNER Follow up Single C 8340 35-16 10320445-00 02/15/03 04/25/04 SPINNER Follow up Single C 8028 35-22 10320446-00 02/28/03 04/24/04 SPINNER Follow up Single C 4500 37 >> Total IPROF Count for 2004 • `� James R. Hand Supervisor - Drillsite Petroleum Engineering ConocoPhillips Greater Kuparuk Area ConocoPhillips Alaska Inc. ATO -1276 PO Box 100360 Anchorage AK 99510-0360 Phone (907)263-4027 Fax: (907)265-6133 April 1, 2005 Mr. Dan Seamount, Commissioner Alaska Oil and Gas Conservation Commission 333 West 7th Ave. Suite #100 Anchorage, Alaska 99501-3539 Re: Kuparuk River Oil Pool — Proposed Injection Profile Survey Plan for 2005 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 2005. In 2004, 37 injection profile surveys were reported for the Kuparuk River Oil Pool to the AOGCC. In 2005, we expect to conduct approximately 35 injection profile surveys, including initial surveys. If you have any questions concerning this data, please contact Robert Christensen at (907) 659-7535 or Paul Burtis at (907) 265-6314. Sincerely, James R. Hand Supervisor - Drillsite Petroleum Engineering Greater Kuparuk Area bcc: GKA Files 0 ATO -1220A • Attachment 6 Kuparuk River Oil Pool 2004 Annual Reservoir Surveillance Report Production Survey Data C • • WELL API NUMBER NUMBER 50- 1A-01 02920590-00 1A-20 02922112-00 1F-07 02920830-00 1F-09 02920983-00 1H-01 02922330-00 1L-24 02922170-00 1Q-05 02921233-00 1R-14 02921386-00 1Y-17 02922368-00 1Y-25 02921850-00 2A-12 10320058-00 ?A-18 10320220-00 ?E-11 02921242-00 !F-07 02921076-00 DATE OF INITIAL PRODUCTION 12/93 12/93 02/94 12/93 12/93 02/94 12/93 02/94 02/94 12/93 12/93 10/95 02/94 02/94 OIL BOPD 474 20 158 125 213 203 428 196 120 120 141 0 422 377 568 502 106 106 173 173 675 400 119 11 133 133 213 213 PRODUCTION WATER BWPD 2639 0 534 26 443 86 871 382 200 200 1029 978 4392 227 1095 383 261 261 162 162 1825 290 2603 234 109 109 377 377 • GAS MSCFD 2245 7 57 43 275 145 840 253 43 43 88 8 1810 451 382 270 90 90 43 43 2000 610 199 18 129 129 145 145 1 of 3 • KUPARUK RIVER UNIT KUPARUK RIVER OIL POOL CONSERVATION ORDER 432 RULE 9 — PRODUCTIVITY PROFILES ANNUAL 2004 SUBMITTAL DATE OF DATA TYPE REASON FOR WELL ZONES PROFILE/ PROFILE/ PROFILE/ COMPLETION PROD - SURVEY SURVEY SURVEY TYPE UCING 06/30/04 SPINNER A/C SPLITS Triple Pkr. A+C A 05/29/04 SPINNER A/C SPLITS Triple Pkr. A+C A 08/27/04 SPINNER A/C SPLITS Sel. Single A+C A 06/27/04 SPINNER A/C SPLITS Sel. Single A+C A 04/29/04 SZT CLOSE C SANDS Sel. Single A+C A 07/25/04 SPINNER A/C SPLITS Sel. Single A+C A 02/05/04 SZT CLOSE C SANDS Sel. Single A+C A 02/10/04 SZT CLOSE C SANDS Sel. Single A+C A 03/12/04 SZT CLOSE C SANDS Sel. Single A+C A 04/14/04 SPINNER FOLLOW-UP Sel. Single A+C A 01/27/04 SZT OPEN C SANDS Sel. Single A+C A 09/12/04 SPINNER A/C SPLITS Single A+C A 08/31/04 SPINNER A/C SPLITS Sel. Single A+C A 08/29/04 SPINNER A/C SPLITS Single A+C A OIL BOPD 474 20 158 125 213 203 428 196 120 120 141 0 422 377 568 502 106 106 173 173 675 400 119 11 133 133 213 213 PRODUCTION WATER BWPD 2639 0 534 26 443 86 871 382 200 200 1029 978 4392 227 1095 383 261 261 162 162 1825 290 2603 234 109 109 377 377 • GAS MSCFD 2245 7 57 43 275 145 840 253 43 43 88 8 1810 451 382 270 90 90 43 43 2000 610 199 18 129 129 145 145 1 of 3 KUPARUK RIVER UNIT 2of3 KUPARUK RIVER OIL POOL CONSERVATION ORDER 432 RULE 9 - PRODUCTIVITY PROFILES ANNUAL 2004 SUBMITTAL WELL API DATE OF DATE OF DATA TYPE REASON FOR WELL ZONES PRODUCTION NUMBER NUMBER INITIAL PROFILE/ PROFILE/ PROFILE/ COMPLETION PROD- OIL WATER GAS 50- PRODUCTION SURVEY SURVEY SURVEY TYPE UCING BOPD BWPD MSCFD 2F-08 02921077-00 12/93 09/20/04 SPINNER A/C SPLITS Single A+C 208 544 613 A 208 544 613 2G-09 02921139-00 02/94 09/01/04 SPINNER A/C SPLITS Single A+C 245 243 263 A 245 243 263 2G-11 02921149-00 02/94 09/08/04 SPINNER A/C SPLITS Single A+C 238 227 233 A 238 227 233 2H-12 10320053-00 02/94 09/23/04 SPINNER A/C SPLITS Sel. Single A+C 287 674 152 A 34 85 18 2K-02 10320101-00 12/93 09/28/04 SPINNER A/C SPLITS Single A+C 548 2317 1271 A 66 278 152 2K-04 10320099-00 02/94 03/25/04 SPINNER PERF C SANDS Single A+C 189 169 164 A 189 169 164 2M-20 10320169-00 02/94 09/02/04 SPINNER A/C SPLITS Single A+C 851 2355 2599 A 0 0 0 2M-21 10320156-00 02/94 09/07/04 SPINNER A/C SPLITS Single A+C 125 1107 429 A 1 11 4 2T-19 10320214-00 06/95 03/11/04 SPINNER A/C SPLITS Single A+C 229 248 374 A 163 150 293 2W-06 02921211-00 12/93 05/02/04 SPINNER A/C SPLITS Sel. Single A+C 1290 3870 8272 A 129 387 827 2W-12 02921240-00 12/93 12/15/04 SPINNER A/C SPLITS Sel. Single A+C 450 4492 337 A 318 875 266 2X-11 02921188-00 12/93 09/09/04 SPINNER A/C SPLITS Sel. Single A+C 683 2178 696 A 180 183 250 2X-15 02921199-00 02/94 05/31/04 SPINNER A/C SPLITS Sel. Single A+C 317 2956 693 A 250 50 150 2Z-10 02921378-00 12/93 02/26/04 SPINNER A/C SPLITS Sel. Single A+C 547 4390 3007 A 44 351 241 3F-02 02921447-00 02/94 12/02/04 SPINNER A/C SPLITS Sel. Single A+C 1721 2705 407 • • KUPARUK RIVER UNIT KUPARUK RIVER OIL POOL CONSERVATION ORDER 432 RULE 9 - PRODUCTIVITY PROFILES ANNUAL 2004 SUBMITTAL 3of3 WELL NUMBER API NUMBER 50- DATE OF INITIAL PRODUCTION DATE OF PROFILE/ SURVEY DATA TYPE PROFILE/ SURVEY REASON FOR PROFILE/ SURVEY WELL COMPLETION TYPE ZONES PROD- UCING OIL BOPD PRODUCTION WATER BWPD GAS MSCFD A 173 32 40 3F-06 02921462-00 02/94 11/09/04 SPINNER A/C SPLITS Sel. Single A+C 766 2444 2808 A 70 47 426 3F-09 02921480-00 12/93 11/10/04 SPINNER A/C SPLITS Sel. Single A+C 822 2534 465 A 0 0 0 3F-14 02921500-00 12/93 12/03/04 SPINNER A/C SPLITS Sel. Single A+C 765 7248 1151 A 51 0 27 3F -19A 02922680-01 01/04 07/04/04 SPINNER A/C SPLITS Single A+C 596 3172 1197 A 131 5 69 3G-08 10320128-00 02/94 09/11/04 SPINNER A/C SPLITS Sel. Single A+C 314 366 523 A 314 366 523 3G-22 10320147-00 02/94 04/06/04 SPINNER A/C SPLITS Single A+C 220 250 538 A 220 250 538 3H-03 10320085-00 02/94 01/30/04 SPINNER A/C SPLITS Sel. Single A+C 200 54 1000 A 136 6 700 3H -10B 10320087-02 06/04 06/19/04 SPINNER A/C SPLITS Single A+C 919 1902 777 A 37 19 31 3J-14 02921496-00 02/94 01/18/04 SPINNER A/C SPLITS Sel. Single A+C 200 600 700 A 200 600 700 3J-18 02922701-00 12/96 05/20/04 SPINNER A/C SPLITS Single A+C 591 1037 132 A 449 595 57 3J-18 02922701-00 12/96 06/02/04 SPINNER A/C SPLITS Single A+C 591 1037 132 A 449 595 57 40 >> Total PPROP Count in 2004 • Attachment 7 Kuparuk River Oil Pool 2004 Annual Reservoir Surveillance Report Miscible Injectant Composition • • Conservation Order 198B Rule 3. Kuparuk River Unit Reservoir Surveillance Program 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 2004 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 -31F. 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 -31F 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 Attachments of individual CPF MI compositions follow. CPF1 CPF2 CPF3* CPF3 MI Source Month CALC MMP** (psia) CPF1(%) CPF2(%) Jan -04 3823 3372 3446 16 84 Feb -04 3301 3418 3403 12 88 Mar -04 3307 3165 3165 1 0 100 Apr -04 3254 3381 3381 0 100 May -04 3247 3264 3264 0 100 Jun -04 3123 3263 3263 0 100 Jul -04 3281 3529 3529, 0 100 Aug -04*** 5885 4875 4875 0 100 Sep -04 3354 3402 3397 10 90 Oct -04 3304 3353 3350 7 93 Nov -04 3365 3382 3382 1 99 Dec -04 3736 4091 3868 1 63 37 Average 3582 1 3541 1 3527 1 0 100 * Calculated **Considers NGL pump downtime & gas compressor downtime ***MI curtailment due to mechanical failure Attachments of individual CPF MI compositions follow. • ATTACHMENT 7 KUPARUK RIVER UNIT MI COMPOSITION - CPF-1 Date Facility CO2 N2 C1 C2 C3 I -C4 N -C4 I-05 N-05 C6 C7 C8 C9 C10 C11 C12 C13 1/17/2004 CPF1 0.816 0.342 68.354 7.270 6.251 2.519 6.723 1.801 2.164 1.093 1.647 0.802 0.202 0.016 0.000 0.000 0.000 2/14/2004 CPF1 0.843 0.315 69.544 6.810 5.330 2.438 6.601 1.823 2.218 1.197 1.762 0.868 0.231 0.020 0.000 0.000 0.000 2/29/2004 CPF1 0.880 0.303 69.034 6.899 5.468 2.507 6.710 1.863 2.270 1.168 1.739 0.892 0.244 0.023 0.000 0.000 0.000 3/12/2004 CPF1 0.871 0.314 68.951 6.986 5.631 2.525 6.803 1.836 2.223 1.099 1.671 0.837 0.232 0.021 0.000 0.000 0.000 3/27/2004 CPF1 0.852 0.321 69.575 6.871 5.295 2.447 6.618 1.805 2.212 1.118 1.739 0.881 0.244 0.022 0.000 0.000 0.000 4/10/2004 CPF1 0.865 0.329 69.333 6.963 5.446 2.539 6.675 1.784 2.166 1.100 1.696 0.858 0.228 0.018 0.000 0.000 0.000 4/25/2004 CPF1 0.849 0.346 67.963 7.038 5.794 2.685 7.021 1.881 2.286 1.165 1.811 0.911 0.232 0.018 0.000 0.000 0.000 5/9/2004 CPF1 0.849 0.320 68.777 6.801 5.265 2.601 7.017 1.881 2.311 1.176 1.828 0.917 0.238 0.019 0.000 0.000 0.000 6/5/2004 CPF1 0.853 0.320 67.905 6.712 5.275 2.697 7.398 2.047 2.530 1.264 1.905 0.879 0.200 0.015 0.000 0.000 0.000 6/19/2004 CPF1 0.884 0.309 69.613 6.766 5.090 2.420 6.488 1.864 2.278 1.162 1.861 0.978 0.265 0.022 0.000 0.000 0.000 7/3/2004 CPF1 0.730 0.324 65.010 6.513 5.230 2.700 7.517 2.462 3.155 1.612 2.771 1.525 0.415 0.036 0.000 0.000 0.000 7/17/2004 CPF1 0.811 0.311 68.663 6.752 5.423 2.494 6.846 1.923 2.364 1.239 1.946 0.964 0.245 0.019 0.000 0.000 0.000 9/12/2004 CPF1 0.814 0.301 69.921 6.630 5.235 2.373 6.468 1.889 2.294 1.175 1.798 0.870 0.215 0.017 0.000 0.000 0.000 10/19/2004 CPF1 0.756 0.288 70.360 6.032 4.795 2.541 6.890 1.855 2.246 1.198 1.855 0.930 0.236 0.018 0.000 0.000 0.000 11/21/2004 CPF1 0.743 0.262 70.904 6.103 4.849 2.473 6.538 1.845 2.163 1.922 1.385 0.692 0.103 0.018 0.000 0.000 0.000 • • • Facility CPF-1 EOR ANALYTICAL REPORT KUPARUKLABORATORY CONOCOPHILLIPS ALASKA INC. Distribution: 63.45 Solvent (Lab) Lean Gas (Lab) Date/Time 2/29/04 3:38 PM 2/29/04 4:04 PM _ 3.55 PM 2-M-. Rate (Mol/d) NGL Anal sis Sample BlendingGas Sample -- Mi Gas Sam le LIMS # AA89506 AA89505 AA89507 Line Pressure 400 1440 3700 Line Temp. NA 0 0 SETCIM Tag FI-20GC F1-21GC Calculated Flow (MSCFD) , 15662. :'6175'. 77035 Component 63.45 Solvent (Lab) Lean Gas (Lab) MI (Target) MI (Lab) MI (Calc) 2615010.53 Rate (Mol/d) (Mo e % Mole % Mole % Mole % Mole CO2 :.: ' ',0"3'4 ". , ,; .:, .° 1`218 1.037 , 0.880'' .. ` ; ` 1.040 N2 0.18..0,3 "%. 0.341 30 0.341 C1 "6 X66 .. ' : 686 68.561 59:034:... 68.780 C25.925 „- ,x-;192 "�,. � 6.931 6,895,. `_ 6.934 C3 j1:29b 3.19,", 5.280 5468; - 5.258 iC4 8.824 ,. 0;52 ;:.> % 2.416 ,2 6A7, . < :. 2.393 nC4 . 26,0612 4A72 ; 6.541 .6ri (0 - 6.471 iC5 $.8.. 0.251 ". ,;., 1.906 ,. ` ,:1:863., 1.883 nC5 10:208 -,0.260 : - 2.311 .2;270.' 2.283 C6 10;064 = 0.15$ 2.201 ,1:168 :` 2.173 C7 7:937." � 0: 1T=� 1.650 �"_1.739,.=� . " 1.627 C8+ :4.016 0.000": , ":." 0.828 :1.159 0.816 Total Moles 100.00 100.00 100.00 100.00 100.00 MW 63.45 Density (Ibs/scf 37.48 Actual ENFL Rate Rate (Ib/d) 2615010.53 Rate (Mol/d) 41215.79 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) 19.83 28.82 28.60 Ideal BG Rate Actual Gas Rate 3147674.566 3202595.35 158738.2224 60320524.52 1.20 1.22 3300.00 3370 3338 0 ATTACHMENT KUPARUK RIVER UNIT MI COMPOSITION - CPF-2 Date Facility CO2 N2 C1 C2 C3 I -C4 N -C4 I -Cs N-05 C6 C7 C8 C9 C70 C11 C12 C13 1/17/2004 CPF2 0.661 0.257 70.405 7.370 5.338 2.343 6.550 1.614 2.048 0.955 1.511 0.753 0.179 0.016 0.000 0.000 0.000 2/14/2004 CPF2 0.646 0.269 69.854 6.989 4.839 2.478 6.961 1.707 2.221 1.217 1.766 0.839 0.198 0.016 0.000 0.000 0.000 2/29/2004 CPF2 0.655 0.256 69.642 7.125 5.032 2.500 6.910 1.702 2.177 1.333 1.667 0.792 0.192 0.017 0.000 0.000 0.000 3/12/2004 CPF2 0.629 0.268 68.463 7.234 5.354 2.695 7.443 1.777 2.263 1.069 1.728 0.847 0.212 0.018 0.000 0.000 0.000 3/15/2004 CPF2 0.664 0.244 69.227 7.224 5.146 2.438 7.033 1.792 2.281 1.093 1.755 0.867 0.216 0.020 0.000 0.000 0.000 3/27/2004 CPF2 0.635 0.262 69.744 7.136 5.166 2.537 7.056 1.678 2.131 1.018 1.632 0.795 0.193 0.017 0.000 0.000 0.000 4/10/2004 CPF2 0.669 0.261 69.579 7.271 5.275 2.600 7.005 1.646 2.093 0.999 1.610 0.785 0.190 0.017 0.000 0.000 0.000 4/25/2004 CPF2 0.643 0.274 69.245 7.385 5.576 2.582 7.004 1.662 2.105 0.992 1.580 0.759 0.178 0.015 0.000 0.000 0.000 5/9/2004 CPF2 0.649 0.262 69.350 7.262 5.272 2.599 7.093 1.698 2.164 1.019 1.637 0.786 0.192 0.017 0.000 0.000 0.000 6/5/2004 CPF2 0.680 0.415 68.560 7.051 5.292 2.673 7.429 1.794 2.283 1.086 1.731 0.807 0.184 0.015 0.000 0.000 0.000 6/19/2004 CPF2 0.668 0.459 68.546 6.913 5.005 2.404 6.726 1.915 2.465 1.290 2.153 1.139 0.291 0.026 0.000 0.000 0.000 7/3/2004 CPF2 0.658 0.284 68.795 6.931 5.281 2.490 6.834 1.963 2.472 1.178 1.925 0.941 0.229 0.019 0.000 0.000 0.000 7/17/2004 CPF2 0.654 0.258 70.189 7.101 5.264 2.333 6.581 1.693 2.156 1.064 1.699 0.805 0.187 0.016 0.000 0.000 0.000 9/12/2004 CPF2 0.646 0.244 69.996 7.195 5.414 2.340 6.589 1.699 2.147 1.035 1.673 0.811 0.194 0.017 0.000 0.000 0.000 10/19/2004 CPF2 0.636 0.245 69.903 6.967 5.298 2.573 7.105 1.662 2.090 0.998 1.583 0.749 0.176 0.015 0.000 0.000 0.000 11/21/2004 CPF2 0.647 0.234 70.490 7.000 5.169 2.506 6.775 1.591 1.991 1.652 1.241 0.609 0.079 0.016 0.000 0.000 0.000 EOR ANALYTICAL REPORT KUPARUKLABORATORY CONOCOPHILLIPS ALASKA INC. Facility CPF-2 Distribution: Date/Time 7/3/04 12:50 PM 7/3/04 12:57 PM 7/3/04 12:45 PM 7/3/04 3.13 PM LIMS# AA92515 AA92514 Density (lbs/scf) AA92516 AA92538 300 1400 Actual Gas Rate 3500 3500 Line Pressure Line Temp. NA 83 180803195 83 83 1.72 SETCIM Tag Flow (MSCFD) Gas blend % FI-NGL-MSCFD 32801" . '�ft�'� FI -P2-1071 TOT 0.78 ORION CALCULATED FI-GD407 37804175680 0.22 1.00 3300.00 FI-P2-NGLVSUM CALCULATED 208281 (Using Lab MI Composition) 3269 Componenttoo ,, _ `} Mo►e % �� `. i`��G � Moie % MI (Target) Mole % 285 MMP (a) MI:' �.;; Mole % MI (Calc) Mole % "GHPGx »_ i Mole 4/0 1GIi'ta�o Mole °Ia ' Mixed BG (Lab) Mole ) CO2 0:129 0.863 0.751 0.658 1.251 0.946 No sample - N2 0.013 0.300 0.256 0:284 1:140 0.481 No sample C1 7:426 79.788 68.734 68:795 81631 80.400 No sample C2 C3 iC4 nC4 iC5 nC5 C6 1:500 4.744 8.509 26.726 9.405 12:494 12:155 8.362 6.480 1.184 2.733 0.498 0.526 0.138 7.314 5.368 2.303 6.398 1.859 2.354 1.974 6:931 5:281 2.490 6.834 1:963 2:472 1.178 6.972 3.889 '0.941 1.985 0.439 0.431 0.152 8.063 5.138 1.132 2.572 0.485 0.506 0.141 ' No sample No sample No sample No sample No sample No sample No sample C7 10.628 0.128 1.732 1:925 0:148 0.132 No sample C8+ 6;271 0.000 0.958 1:189 0.021 0.005 No sample Total Moles 100.000 100.00 100.00 100.000 100.000 100.000 100.000 MW 69.23 21.46 28.76 28.90 Density (lbs/scf) 38.92 Actual ENFL Rate Ideal BG Rate Actual Gas Rate Rate (Ib/d) 5939037.62 Rate (Mol/d) 85792.11 475797.8817 Rate (MMSCFD) 180803195 Target Blend Ratio w/ CPF2 gas only (lb BG/Ib EF) 1.72 Actual Blend Ratio (From measured flow rates) 1.66 Youngren MMP 3300.00 Actual MMP (Using Lab MI Composition) 3269 Calc MMP (Using Lab BG/ENFL comp and rates) EMANAWNW, MWC7+ in Oil 285 MMP (a) -0.0017054 MMP (b) -26618.5 MMP (C) 1.6 21.27 Note: Shaded areas are lab analysis values Non -shaded are calculated values • Attachment 8 Kuparuk River Unit Kuparuk River Oil Pool 2004 Annual Reservoir Surveillance Report Development Plan for LSEOR • • 0 Attachment 8 Kuparuk River Oil Pool 2004 Annual Surveillance Report LSEOR Development Plan During 2004, the Greater Kuparuk Area (GKA) averaged 26 MBPD of PBU NGL imports and 14 MBPD of indigenous NGLs for an annual average of 273 MMSCFD of Miscible Injectant (MI) manufacture. Of the GKA manufactured MI volume, 200 MMSCFD was distributed to Kuparuk: 113 MMSCFD to LSEOR drillsites (including 3F), 7 MMSCFD to SSEOR and SSEORX drillsites, and 80 MMSCFD to LSEOR expansion drillsites. The remaining 73 MMSCFD was distributed to the GKA satellites. LSEOR expansion drillsites include drillsites: 1 B, 1 C, 1 E, 1 L, 313, 3G, 3H, 30, 3Q and 3S. Currently MI is injected into all of the 21 drillsites sanctioned under the SSEOR/SSEORX/LSEOR project and the CPF-3 EOR expansion drill site 3F. A West Sak (DS1 C) EOR pilot was performed in 2004 and additional pilot work will continue in 2005. • 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. During 2005, a pilot of a new process, IWAG-after-MWAG will be piloted to test the ability to recover NGL's trapped in mature EOR patterns by the MWAG process. Modeling suggests the process is technically viable. 0 • • • ConocoPhillips April 1, 2005 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 -1276 PO Box 100360 Anchorage AK 99510-0360 Phone (907)263-4027 Fax: (907)265-6133 Re: Kuparuk River Oil Pool — 365+ Days Shut In Well Report Dear Mr. Seamount, 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 Robert Christensen at (907) 659-7535 or Paul Burtis at (907) 265-6314. Sincerely, James R. Hand Supervisor - Drillsite Petroleum Engineering Greater Kuparuk Area bcc: GKA Files ATO -1220A • Greater Kuparuk Area 365 -Day Shut -In Well Report 2004 Annual Submittal • 1 of 4 Reason Well Current Mechanical Condition Future Utility3 Plans Well Name Date Shut -In Shut -In' of the We112 & Possibilities Comments 1D -105A 1D-111 Sep -03 Jun D Failed ESP 6 Attempted Gaslift but well froze -03 D Annulus x Conductor Leak 2 IA patch planned 2005 No known problems; MITIA 1 D-119 1D-121 Mar -02 Oct -03 E E 07/11/02 6 Reservoir Management 1D-127 Apr -03 E Failed ESP on Gaslift 6 Returned to production 02/16/05 1 E-08 Jun -00 E Failed ESP Flowline corrosion; MITIA 07/11/02 1 1 Sidetrack/WO Candidate 1 E-09 Feb -01 E Flowline corrosion; MITIA 06/29/02 3 Flowline repair under evaluation No immediate plans to fix flow line IE -10 Nov -93 D Plug Stuck in Tbg 3 Flowline removed 1 E-13 Oct -01 E Flowline corrosion; MITIA 07/11/02 3 No immediate plans to fix flow line 1E-14 Oct -90 E No known problems 3 Unable to inject or flow / Flowline IE -16 Mar -00 E Flowline corrosion 3 removed Low priority to fix flow line 1E-17 Jul -97 D Flow cut C sand mandrels 3 Flowline removed IE -19 Feb -98 D Flow cut C sand mandrels 3 Not injecting, downhole trouble No known problems; MITIA 1 E-25 1 E-26 Sep -94 E 05/30/04 3 Low Injectivity / Flowline removed Dec -97 D T x IA comm 1 Sidetrack/WO Candidate 1 E-30 Aug -96 D Fish in Tubing Tail 3 Low Injectivity past fish / Flowline 1 F-01 Jun -03 D T x IA comm 1 removed 2005 CTD Sidetrack sundry 10-403 approved for casing 1 F-11 May -01 D OA x OOA Comm; MITIA 06/05/04 3 repair Well is SI with TTP in SBR and DV is pulled. 1 H-401 Aug -02 D Failed ESP 2 Waiting on pump redesign No known problems; MITIA 1L-01 1L-16 Oct -98 E 06/14/04 1 Sidetrack & flowline repair Jun -03 E Flowline corrosion; MITIA 06/14/04 6 Flowline repair planned for 2005 1 L-25 May -96 E No known problems; MITIA Reservoir Management. Evaluating 1 L -26A Apr -03 C 06/14/04 Possible T x IA Comm 1 2 possible sidetrack. 1M-17 May -02 E No known problems 3 Convert to Jet pump Appraisal Well 1Q_01 1 Q-21 Dec -99 Oct E No known problems 6 Reservoir Management 2D-14 -03 Jun -00 D E T x IA comm Tbg x IA Communication 1 6 Sidetrack Candidate 2E-05 I Apr -94 E Never Completed 1 Reservoir Management Sidetrack Candidate 2E-06 I Apr -94 E Never Completed 1 Sidetrack Candidate 1 of 4 • • Greater Kuparuk Area 365 -Day Shut -In Well Report 2004 Annual Submittal • Well Name Date Shut -In Reason Well Shut -In' Current Mechanical Condition of the We112 Future Utility3 Plans & Possibilities Comments 2E-07 Oct -94 C No known problems 3 Ice Plug In Tubing / Low Volume Cold A Sand Oil 2E-09 Nov -93 D Ice Plug In Tubing/ Hole In Tubing 1 May Make It A 2F Injector 2E-17 Apr -94 C No known problems 4 No future plans 2F-06 Mar -02 D Casing Damage 1 Sidetrack Candidate 2F-20 Jun -98 B No known problems 2 Watered Out Lisburne Test / Ready to Complete In Kuparuk Zone 2G-06 Mar -01 C No known problems 6 Returned to production 01/20/05 2G-17 Mar -03 C No known problems 3 Uneconomic To Produce/Freezes 2H-02 Jun -02 E No known problems; MITIA 06/24/04 6 Returned to Injection 02/12/05 2L-03 Apr -02 C No known problems; MITIA 03/24/02 3 No Future Plans 2L -329A Feb -03 E No known problems 3 Reservoir Management 2M-18 Dec -99 D Hole In 7" Casing at 7041' 1 WO Candidate 2M-23 Sep -97 E IA x OA Comm; MITIA 06/28/04 3 Disposal 2T-21 Jun -03 D T x IA comm 1 WO Candidate 2T-32 Dec -02 E No known problems; MITIA 11/01/03 6 Reservoir Management 2T -38A Jan -01 C No known problems 6 Convert to Jet pump 2T-210 Jun -00 D Tubing Damage; MITIA 11/01/03 1 Tabasco Water Injection Well 2U-09 Jan -00 C IA x OA Comm; 1 Producer to Injector Conversion 2X-19 Nov -01 C No known problems 3 Uneconomic To Produce/Freezes 2Z-03 Apr -02 E No known problems; MITIA 06/24/01 6 Reservoir Management 2Z-16 Jun -97 D C Sand CSM Broken (Leaks) and Possible Packer Leak 6 Returned to Injection 02/20/05 2Z -WS -1 Oct -86 C No known problems 3 West Sak Test Producer 3A -03A Jun -01 D&E Tbg x IA Communication 1 A sand won't flow post CTD ST 3C-07 Jun -01 E No known problems; MITIA 07/15/01 6 Waiting on meter install 3C-15 Jan -02 D Flowline corrosion; MITIA 06/21/03 3 Uneconomic to repair 3G -14A Oct -03 E Well produces rocks 2 Thru-tubing gravel pack candidate 3G -19A Jun -02 D No known problems 6 Returned to production 02/06/05 3G-23 Feb -03 E No known problems; MITIA 09/18/03 1 6 Reservoir Management 3H -14A Oct -00 D CTD lost BHA in hole lNo 1 ST planned 3H -25A Jun -99 E known problems 4 Suspended Sidetrack of 4 • • • Greater Kuparuk Area 365 -Day Shut -In Well Report 2004 Annual Submittal Well Name Date Shut -In Reason Well Shut -In' Current Mechanical Condition of the We112 Future Utility3 Plans & Possibilities Comments 3M-03 Nov -02 D T x IA comm 1 Thru-tubing gravel pack candidate 3M-18 Nov -02 D Tx IA x OA comm 1 WO Candidate 3M-26 Jun -01 E No known problems; MITIA 08/03/04 6 Reservoir Management; ST candidate 3N-14 Dec -03 D Casing Failure 1 WO Candidate 30-19 Jan -01 D Hole in casing 2 Troubleshooting leaking csg patch 313-11 D Sep -00 E No known problems; MITIA 06/20/03 3 Disposal CPF2-WDW Aug -89 E No known problems; MITIA 01/22/04 5 P&A wellbore and remove for facility expansion WSW -01 Apr -83 D T x IA Comm 3 Will not be used for injection WSW -02 Mar -94 E No known problems; MITIA 10/05/97 3 Will not be used for injection WSW -03 Jul -01 E No known problems; MITIA 10/05/97 3 Will not be used for injection WSW -04 Aug -96 E Failed MITIA 04/27/96 3 Will not be used for injection WSW -05 Jul -01 E No known problems; MITIA 08/15/04 3 Will not be used for injection WSW -06 Jul -94 E No known problems; MITIA 10/05/97 3 Will not be used for injection WSW -07 Jul -01 E No known problems; MITIA 10/05/97 3 Will not be used for injection WSW -08 Oct -96 E Failed MITIA 05/24/93 3 Will not be used for injection WSW -09 Oct -96 E No known problems; MITIA 08/15/04 3 Will not be used for injection WSW -10 Apr -83 D Failed MITIA 3 Will not be used for injection WSVT-Tl-- Aug -92 E T x IA Comm; MITIA 10/05/97 3 Will not be used for injection 3 of 4 • Greater Kuparuk Area 365 -Day Shut-in Well Report 2004 Annual Submittal EWellame Reason Well Current Mechanical Condition Future Utility3 Plans Date Shut -In Shut -In' of the We112 & Possibilities Comments Reasons for Well Shut -In High GOR, currently uncompetitive to produce due to facility constraints, no known mechanical problems High water, currently uneconomic to produce, no known mechanical problems Low production rate, no known mechanical problems Mechanical Problem Other (Specify under comments) Current Mechanical Condition sfly describe the current mechanical condition including the condition of installed tubing and casing strings. Future Utility Evaluating remedial, sidetrack and/or re -drill opportunities Remedial well work planned Long term Shut-in well/ No immediate plans Suspended well P&A planned Other (Specify under comments) 4of4 • 9 • .7 0 )P --,O" ConocoPhillips • April 1, 2005 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 -1276 PO Box 100360 Anchorage AK 99510-0360 Phone (907)263-4027 Fax: (907)265-6133 Re: 2004 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 2004. The following is an outline of the information provided: a. Progress of EOR project and reservoir management summary (Attachment 1). b. Voidage balance, by month, for produced and injected fluids (Attachment 2, Attachment 3). c. Analysis of reservoir pressure surveys taken in 2004 (Attachment 4). d. Results of production surveys, and any special surveys, taken on the Meltwater Oil Pool in 2004 (Attachment 5). e. Results of well allocation and test evaluation for Rule 7, and any other special monitoring (Attachment 6). f. Development Plan and Operation Review (Attachment 7). If you have any questions concerning this data, please contact Bob Christensen at (907) 659- 7535 or Darron Jackson at (907) 263-4526. Sincerely, aures R. Hand Supervisor -Drillsite Petroleum Engineering Greater Kuparuk Area . is bcc: GKA Files ATO -1220A • Attachment 1 Kuparuk River Unit Meltwater Oil Pool 2004 Annual Reservoir Surveillance Report Progress of EOR Project and Reservoir Management Summary Background In 2001, CPAI received approvals for formation of the Meltwater Oil Pool in the Kuparuk River Unit, an Area Injection Order for Meltwater, expansion of the Kuparuk River Unit, and formation of the Meltwater Participating Area. The Meltwater Pool Rules and Area Injection Order were approved on August 1, 2001. The Unit Expansion and Participating area were approved effective June 1, 2001. Injection of miscible injectant (MI) began in January 2002 and the MWAG (miscible water alternating gas) process was implemented during May 2003. Eleven wells were online and producing (injecting) at the end of 2003. The Meltwater Phase II drilling program began in October of 2003 and was completed during May 2004. A total of 8 additional wells (4 producers and 4 MWAG injectors) were completed and brought into service during the 1St half of 2004. The Meltwater field now has 19 total wells (13 producers and 6 injectors). Progress of EOR Project Development activities in 2004 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 2004: 1. Three injection wells drilled during 2003 were put on in ection during 2004 (2P-432, 2P-434 and 2P-447). These wells were put on injection during the 1s quarter of 2004. • 2. Continued the Phase II development program by drilling and completing 5 additional wells (2P - 424A, 2P-406, 2P-443, 2P-449, and 2P-419). The last well in the phase II program was completed during May 2004. 3. The original wellbore of the 2P-424 was drilled into southeastern portion of the field; but, the well found insufficient amount of pay to warrant a completion. The well was subsequently sidetracked to a location south of the 1St bottomhole location which found adequate pay. 4. All four (4) of the producing wells (2P-406; 2P -424A, 2P-443, and 2P-449) were fracture stimulated to maximize production from the Bermuda interval. 5. Began injection into the 2P-419 during March 2004. 6. During January 2004, returned 2P-451 to service after beginning injection in the offsetting MWAG injection well (2P-434). 7. After finishing phase II drilling program, returned 2P-420 to injection (May 2004). 8. Returned 2P -448A to production during December 2004 after performing a fracture stimulation on the well (re -frac). 9. Performed a fracture stimulation on 2P-441 during May 2004 (re -frac treatment). 10. Performed high pressure breakdowns on 2P-419 and 2P-447 to increase injection rates. Below is a listing of the most important new findings derived from the 2004 Meltwater development efforts: 1. Data from the organic tracer study indicates that the producing well 2P-417 has good communication with the 2P-420 injection well. Further testing shows some communication exists between the producer 2P-422 and 2P-420. The expanded testing also showed some communication between the injector 2P-429 and the producers 2P-427 and 2P-441. 2. The producing well 2P-438 showed response to the new injectors drilled during the 1St half of 2004. 3. 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. 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 4. Outer annuli pressures in 2P-431, 2P-438, and 2P-451 remained at elevated levels in 2004. Outer annuli pressures at 2P-441 and 2P -448A increased to elevated levels after injection began in the new Phase II injection wells. 5. Outer annuli pressures at the three wells which encountered shallow, high pressure gas intervals have been at elevated levels since injection began (2P-432, 2P-434, and 2P-447). 6. 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. Reservoir Management Summary Meltwater came on-line in November of 2001 and has cumulatively produced 7.65 MMSTBO, 214 MBW, and 17.18 BCF of gas by year-end 2004. Miscible gas injection began in 2002 with water injection beginning in 2003 (MWAG cycles). Cumulative injection through year-end 2004 at Meltwater has been 5.36 MMBW and 23.5 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 and 2P-438 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, 2P-447 and 2P -448A also show that they are receiving support from the new injection wells drilled in the field. 2P-451 still appears to be receiving only limited support from the • injection wells. 2PA15A 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. 0 0 0 0 Meltwater Phase 11 Development Drilling 2003-04 Injectors 2003-04 Producers 2F-4 15 P 47 All P-41 P-424 AL 2P-41 SLP -424A -ST 3124098 StATUTE MILES 0 A STATUM MILES Mafmsam 1,0KILOMETtItS %.AM IVIC&N-1 W • • • Da to 2004 Meltwater Elevated OA Pressures 2P-432 2P-434 2P-438 2P-441 2P -448A 2P-451 2P-447* Surf. Press Press @ C- Surf. Press Press @ C- ::::Press Press @ C- Surf. Press Press @ C- Surf. Press Press@ C- Surf. Press Press @ C- Surf. Press (psi g) 80 Top (psig) 80 Top 80 Top (psig) 80 Top (psig) 80 Top p (psi9) 80 Top (psig) 910 1301 845 1096 920 1327 580 1024 1275 1468 958 1493 750 1 1400 1792 1050 315 1438 1000 890 1356 1241 740 1082 1250 1460 1500 1550 1785 1440 1622 980 1315 910 1379 860 1226 1220 1361 1600 1832 1370 1565 1064 1080 1386 1396 920 918 1385 1357 900 124 12 -1380 1L 1644 1650 1794 17 91 1320 1488 1120 1427 900 -1328 985 1040 1337 1392 1222 1220 1354 1347 9 1639 1785 1380 1380 1572 1556 1160 1180 1460 1456 890 900 1309 1100 1449 1234 1395 11 1620 1767 1400 1576 1210 1479 910 1314 1313 1160 1150 1589 1586 1280 1432 9 1620 12501 1764 1348 1400 1302 1580 1445 810 1150 1170 900 1296 11431579 1320 1326 1454 4 1456 10 -447 OA is cemented off, can only get surface pressure readings 1479 920 1156 1130 1410 1250 1381 10 0 Attachment 2 • Meltwater Oil Pool 2004 Annual Reservoir Surveillance Report Produced Fluid Volumes MO YR OIL GAS WATER CUM OIL CUM GAS CUM WATER STB MSCF STB STB MSCF STB 1 2004 176944 526944 6014 5352649 10380545 86573 2 2004 160297 551335 4648 5512946 10931880 91221 3 2004 183113 633813 13323 5696059 11565693 104544 4 2004 177480 596992 6871 5873539 12162685 111415 5 2004 190855 575193 10290 6064394 12737878 121705 6 2004 211225 591920 13311 6275619 13329798 135016 7 2004 194289 548816 6020 6469908 13878614 141036 8 2004 219626 680485 9156 6689534 14559099 150192 9 2004 233104 791030 11366 6922638 15350129 161558 10 2004 266237 649301 11097 7188875 15999430 172655 11 2004 222984 548456 20138 7411859 16547886 192793 12 2004 241476 627869 21235 2004 TOTAL 2477630 7322154 133469 Cumulatives at Dec 31, 2003 5175705 9853601 80559 • Produced Fluid Volumes (Reservoir Units) MO OIL GAS WATER CUM OIL CUM GAS CUM WATER YR RVB RVB RVB RVB RVB RVB 1 2004 236928 369152 6098 7086858 7934047 82042 2 2004 214638 399808 4713 7301496 8333855 86755 3 2004 245188 460254 13510 7546684 8794109 100264 4 2004 237646 430781 6967 7784330 9224891 107231 5 2004 255555 404204 10434 8039884 9629095 117666 6 2004 282830 407863 13497 8322715 10036957 131163 7 2004 260153 379011 6104 8582868 10415968 137267 8 2004 294079 481564 9284 8876947 10897533 146551 9 2004 312126 571923 11525 9189073 11469456 158076 10 2004 356491 428534 11252 9545564 11897989 169329 11 2004 298576 363016 20420 9844140 12261006 189749 12 2004 323336 423115 21532 4 2004 TOTAL 3317547 5119225 135338 Cumulatives at Dec 31, 2003 6849930 7564895 75943 0 • Attachment 3 Meltwater Oil Pool 2004 Annual Reservoir Surveillance Report Injected Fluid Volumes WATER GAS MI CUM WATER CUM GAS MI MO YR STB MSCF MSCF STB MSCF MSCF 1 2004 0 0 624948 1737460 0 12531361 2 2004 0 0 648582 1737460 0 13179943 3 2004 80358 0 1019245 1817818 0 14199188 4 2004 152980 0 1238079 1970798 0 15437267 5 2004 509759 0 1126698 2480557 0 16563965 6 2004 423744 0 1108633 2904301 0 17672598 7 2004 294967 0 1013750 3199268 0 18686348 8 2004 375532 0 1021912 3574800 0 19708260 9 2004 344022 0 1107087 3918822 0 20815347 10 2004 348868 0 1134463 4267690 0 21949810 11 2004 522965 0 850904 4790655 0 22800714 12 2004 573835 0 7018424A> 2004 TOTAL 3627030 0 11596143 Cumulatives at Dec 31, 2003 1737460 0 11906413 Injected Fluid Volumes (Reservoir Units) WATER GAS MI CUM WATER CUM GAS CUM MI MO YR RVB RVB RVB RVB RVB RVB 1 2004 0 0 552454 1761784 0 11160204 2 2004 0 0 573346 1761784 0 11733551 3 2004 81483 0 901013 1843267 0 12634563 4 2004 155122 0 1094462 1998389 0 13729025 5 2004 516896 0 996001 2515285 0 14725026 6 2004 429676 0 980032 2944961 0 15705058 7 2004 299097 0 896155 3244058 0 16601213 8 2004 380789 0 903370 3624847 0 17504583 9 2004 348838 0 978665 3973686 0 18483248 10 2004 353752 0 1002865 4327438 0 19486113 11 2004 530287 0 752199 4857724 0 20238312 12 2004 581869 0 620428 � 2004 TOTAL 3677808 0 10250990 Cumulatives at Dec 31, 2003 1761784 0 10607750 • • • STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION ANNUAL RESERVOIR PRESSURE REPORT -2004 Attachment 4 Phillips Alaska Inc. Name of Operator Form Address Phillips Alaska Inc. I P. O. Box 100360, Anchorage, AK 99510-0360 Unit or Lease Name Field and Pool Kuparuk River Field Datum Reference Oil Gravity Gas Gravity Ku aruk River Unit Meltwater Oil Pool -5400' SS 34.9 0.74 Final Pressure Test Data Production and Test Data Tool Final Production Rates Wt. of M.of Pressure API O,G Shut-in Number or Date Shut-in Tubing Depth B.H. Observed Bbls/Day) (Mcfd) Liquid Liquid Gas Casing at Well Name Sand WI Tested Time Press. MD Temp. Pressure Oil Water Gas Gradient Column Column Press. Datum 21P-406 A 501032048400 O 05/09/04 99999 680 6932 144 2871 0 0 0 2888 2P -415A A 501032038301 O 04/15/04 242 258 8645 141 1016 75 75 75 1005 2P-419 A 501032048300 GI 03/09/04 99999 0 10053 133 2168 0 0 0 2290 2P-420 A 501032039100 GI 04/19/04 3048 2080 6330 130 2963 0 0 0 3009 2P -424A A 501032047501 O 02/24/04 99999 538 10856 139 2780 0 0 0 2784 21P-432 A 501032042000 GI 01/03/04 99999 500 5844 133 2972 0 0 0 3025 21P-434 A 501032046700 GI 01/05/04 99999 952 5754 133 2881 0 0 0 2983 2P-443 A 501032048700 O 04/06/04 99999 500 5450 141 2675 0 0 0 2913 2P-447 A 501032046800 GI 03/09/04 99999 30 7620 133 1715 0 0 0 1816 2P-448 A 501032039600 O 08/30/04 8016 1320 7202 132 1604 0 0 0 1916 2P-448 A 501032039600 O 11/05/04 9576 1250 7202 132 1726 0 0 0 2038 2P -448A A 501032039601 O 01/30/04 3024 1250 7202 128 1433 0 0 0 1501 2P -448A A 501032039601 O 04/04/04 4400 1050 7202 132 1435 0 0 0 1500 2P-449 501032 600 O 03/05/04 99999 0 9397 138 2014 0 0 0 2102 14 » > Total r ssure Count in 2004 I hereby certify Signed �eX•fore in true U!L correct to the best of my knowledge. L -Title Meltwater Coordinator Date � / Ing - b Form 10-412 I�7`/—� Submit in Duplicate Rev 7 1 60 J • ConocoPhillips April 1, 2005 Mr. Dan Seamount, Commissioner Alaska Oil and Gas Conservation Commission 333 West 7'h Ave. Suite #100 Anchorage, Alaska 99501-3539 James R. Hand Supervisor - Drillsite Petroleum Engineering Greater Kuparuk Area ConocoPhillips Alaska Inc. ATO -1276 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 2005 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 2005. There were 14 pressure surveys reported for the Meltwater Oil Pool to the AOGCC in 2004. In 2005, 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 Robert Christensen at (907) 659-7535 or Darron Jackson at (907) 263-4526. Sincerely, L.. James R. Hand Supervisor- Drillsite Petroleum Engineering Greater Kuparuk Area • bcc: GKA Files ATO -1220A 10 10 0 Attachment 5 Meltwater Oil Pool 2004 Annual Reservoir Surveillance Report Production/Special Surveys • Two injection surveys were run during 2004. Injection surveys were run on 2P- 447 and 2P-432 while they were injecting MI. 0 2P-432 - An injection survey was performed on this well during September 2004. The well was injecting at an average rate of 6.7 MMSCFD while the survey was being performed. The average bottomhole injection temperature was 109°F at a bottomhole injection pressure of 3522 psig. There was no apparent out of zone injection. 0 2P-447 — An injection survey was performed on this well during September 2004. The well was injecting at an average rate of 16.7 MMSCFD while the survey was being performed. The average bottomhole injection temperature was 113°F at a bottomhole injection pressure of 3120 psig. There was no apparent out of zone injection. • Cement bond logs were run on the new 2P-419 Meltwater injector in 2004. Logs indicated adequate cement bond above the perforations. • MWD logs, consisting of CNL, density, and induction logs, were run on each of the wells drilled during 2004 (2P-406, 2P-419, 2P-424 and 424A, 2P-443, and 2P-449). • Attachment 6 Meltwater Oil Pool 2004 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 is 2004 Meltwater allocation factors by month are listed below. ..roti. (Meltwater Oil Pool 2004 Production Allocation Factorsk Oil Gas Water Jan 04 1 0.9477 1 0.9208 1.0025 Feb -04 0.9642 0 9276 x 1.0139 Mar -04 ..��.._.n......�....tio.,��...,.v..u.�.-..�...�.�.anti.��,�.�.,u....,.�..w..w��...�x i 0.9688 1 0.9484 � 1.0229 g Apr -04 1 0.9549 0.9585 1.0198 I May-04 ` 1 0.9550 ' 0.9833 1 0539 % t Jun 04 9605 0.9606 1 1.0632 I r Jul 04 1 ^0 0.9538 1 0.9755 1 1.0634 k Aug 04 1 0 9482 0 9672 ..1 0913.......w. ,..�. Sep 04 1 0.9418 0.9326 I 1.0469 v,. Oct -04 .v� a. 0.9381 u .0 0.9435 1.0509 .r. -ti -wan.... r I Nov 04 u_......__..... f ._m_A,.�u.�.ray.. 0.9453 � 0.9246 . r..._.... .....�..... 1.1212 I Dec 04 0 9487 0 9510 i 1.1775 0 • Shallow Gas Special Monitoring 2P-431, 2P-438 and 2P-451 have elevated outer annuli (OA) pressures that rebuild pressure after bleeding. During 2004, two (2) additional original wells (2P-441 and 2P - 448A) had OA pressures that increased to anomalous levels (>_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. 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 2005. • • • Attachment 7 Meltwater Oil Pool 2004 Annual Reservoir Surveillance Report Meltwater Development Plan and Operational Review Following are summaries of key activities that are planned for 2005 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 2006. 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. MI/Water 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. New injection wells drilled in the Phase II Drilling program (2P-419, 2P-432, 2P-434, and 2P-447) were brought on line during the first half of 2004. These wells were initially put on MI injection. Once the initial slug of MI is injected, the MWAG process will be implemented in these wells. • The 2P-427 will be converted to injection during the 1St quarter of 2005. Conversion of this well is 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. The metered oil rates of 2P -415A fluctuate with the variance in water injection header pressure. Three (3) additional surface powered jet pumps are scheduled to be installed during the 1St half of 2005. These pumps will be 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). 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 drillsite 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 2004 the 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. • 0 L' • • • ConocoPhillips April 1, 2005 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 -1276 PO Box 100360 Anchorage AK 99510-0360 Phone (907)263-4027 Fax: (907)265-6133 Re: 2004 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 2004. The following is an outline of the information provided: a. A summary of the enhanced recovery project (Attachment 1). b. Voidage balance, by month, for produced and injected fluids (Attachment 2, Attachment 3). c. Analysis of reservoir pressure surveys taken in 2004 (Attachment 4). d. Results of production surveys, and any special surveys, taken on the Tabasco Oil Pool in 2004 (Attachment 5). e. Results of well allocation and test evaluation for Rule 7, and any other special monitoring (Attachment 6). f. Future development plans (Attachment 7). If you have any questions concerning this data, please contact Martin Walters at (907) 263-4194. Sincerely, ames R. Hand Supervisor - Drillsite Petroleum Engineering Greater Kuparuk Area bcc: GKA Files 0 ATO -1220A • Attachment 1 Kuparuk River Unit Tabasco Oil Pool 2004 Annual Reservoir Surveillance Report Summary of the Enhanced Recovery Project Tabasco produced 1471 MSTB of crude, 183 MMSCF of formation gas, and 5745 MB of water during 2004. Water injection was 5975 MBW over the same period. Cumulative oil, gas, and water production and water injection through year end 2004 were 9732 MSTBO, 1332 MMSCF, 26180 MBW, and 30420 MBWI, respectively. The cumulative injection/withdrawal ratio was 0.84 on a reservoir barrel basis through year end 2004. Reservoir pressure decreased slightly from 1050 psi to approximately 1030 psi during 2004. Two producers (2T-202 and 2T-220), which previously experienced ESP downhole failures, were serviced to replace these failed pumps. One producer (2T-204), which experienced ESP downhole failure in early 2004, was serviced to replace the failed pump during 2004. Injector 2T-210 remained shut-in with mechanical problems which continue to prevent water injection. Year end 2004 • 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 4.2 bbl water per STBO as compared to 2.9 at year end 2003. This increase is due to the higher WOR of the new producer as well as returning the two failed wells back to production. 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. • • OIL GAS Attachment 2 Tabasco Oil Pool CUM OIL CUM GAS CUM WATER MO YR 2004 Annual Reservoir Surveillance Report RVB RVB RVB RVB 1 Produced Fluid Volumes 87872 404 320514 8828543 OIL GAS WATER CUM OIL CUM GAS CUM WATER MO YR STB MSCF STB STB MSCF STB 1 2004 83055 15343 320514 8344558 1164372 20754782 2 2004 70134 10408 268703 8414692 1174780 21023485 3 2004 71673 9059 288513 8486365 1183839 21311998 4 2004 63466 8637 298185 8549831 1192476 21610183 5 2004 75656 10016 329437 8625487 1202492 21939620 6 2004 128340 14647 482214 8753827 1217139 22421834 7 2004 159621 17781 611556 8913448 1234920 23033390 8 2004 153842 16891 647170 9067290 1251811 23680560 9 2004 164456 13569 587072 9231746 1265380 24267632 10 2004 176639 17670 617734 9408385 1283050 24885366 11 2004 163389 24195 627464 9571774 1307245 25512830 12 2004 160457 24422 666828 5745390 .� 2004 TOTAL 1470728 182638 5745390 at Dec 31, 2003 Cumulatives at Dec 31, 2003 8261503 1149029 20434268 Produced Fluid Volumes (Reservoir Units) OIL GAS WATER CUM OIL CUM GAS CUM WATER MO YR RVB RVB RVB RVB RVB RVB 1 2004 87872 404 320514 8828543 404 20754782 2 2004 74202 0 268703 8902745 404 21023485 3 2004 75830 0 288513 8978575 404 21311998 4 2004 67147 0 298185 9045722 404 21610183 5 2004 80044 0 329437 9125766 404 21939620 6 2004 135784 0 482214 9261549 404 22421834 7 2004 168879 0 611556 9430428 404 23033390 8 2004 162765 0 647170 9593193 404 23680560 9 2004 173994 0 587072 9767188 404 24267632 10 2004 186884 0 617734 9954072 404 24885366 11 2004 172866 0 627464 10126937 404 25512830 12 2004 169764 0 666828 2004 TOTAL 1556030 404 5745390 Cumulatives at Dec 31, 2003 8740671 0 20434268 • Attachment 3 Tabasco Oil Pool 2004 Annual Reservoir Surveillance Report Injected Fluid Volumes r • Cumulatives at Dec 31, 2003 24445145 Injected Fluid Volumes (Reservoir Units) 0 0 WATER GAS MI CUM WATER CUM GAS MI MO YR STB MSCF MSCF STB MSCF MSCF 1 2004 470520 0 0 24915665 0 0 2 2004 409417 0 0 25325082 0 0 3 2004 418090 0 0 25743172 0 0 4 2004 389006 0 0 26132178 0 0 5 2004 421183 0 0 26553361 0 0 6 2004 443645 0 0 26997006 0 0 7 2004 548515 0 0 27545521 0 0 8 2004 568118 0 0 28113639 0 0 9 2004 527260 0 0 28640899 0 0 10 2004 601938 0 0 29242837 0 0 11 2004 575615 0 0 29818452 0 0 12 2004 601984 0 0 2004 TOTAL 5975291 0 0 Cumulatives at Dec 31, 2003 24445145 Injected Fluid Volumes (Reservoir Units) 0 0 WATER GAS MI CUM WATER CUM GAS CUM MI MO YR RVB RVB RVB RVB RVB RVB 1 2004 470520 0 0 24915665 0 0 2 2004 409417 0 0 25325082 0 0 3 2004 418090 0 0 25743172 0 0 4 2004 389006 0 0 26132178 0 0 5 2004 421183 0 0 26553361 0 0 6 2004 443645 0 0 26997006 0 0 7 2004 548515 0 0 27545521 0 0 8 2004 568118 0 0 28113639 0 0 9 2004 527260 0 0 28640899 0 0 10 2004 601938 0 0 29242837 0 0 11 2004 575615 0 0 29818452 0 0 12 2004 601984 0 0 2004 TOTAL 5975291 0 0 Cumulatives at Dec 31, 2003 24445145 0 0 • • • STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION ANNUAL RESERVOIR PRESSURE REPORT - 2004 Attachment 4 Name of Operator Address ConocoPhilli s Alaska Inc. P. O. Box 100360, Anchorage, AK 99510-0360 Unit or Lease Name Field and Pool Kuparuk River Field Datum Reference Oil Gravity Gas Gravity Kuparuk River Unit Tabasco Oil Pool -3000' SS 1.04 0.572 Final Pressure Test Data Production and Test Data API O,G Shut-in Tool Final Production Rates Wt. of Wt. of Pressure Number or Date Shut-in Tubing Depth B.H. Observed Bbls/Day Mcfd Liquid Liquid Gas Casing at Well Name Sand WI Tested Time Press. MD Temp. Pressure Oil Water Gas Gradient Column Column Press. Datum 2T-202 T 501032025400 O 03/05/04 1100 600 3237 60 879 0 0 0 1179 2T-204 A 501032032700 O 09/07/04 3024 1100 3315 67 1104 0 0 0 1176 2T-218 T 501032044900 O 02/19/04 1000 200 5038 72 1018 0 0 0 1083 2T-218 T 501032044900 O 03/23/04 2000 32 5205 65 1083 0 0 0 1137 2T-220 T 501032028300 O 04/22/04 3300 300 4677 55 1008 0 0 0 1098 2T-220 T 501032028300 O 04/25/04 3408 32 4792 67 1088 0 0 0 1155 2T-220 T 501032028300 O 06/10/04 4248 0 4671 63 1061 0 0 0 1141 7 >> >> Total Pressure Count in 2004 I hereby certif at for tel; dcorrect to the best of my knowledge. Signed ° h/� !✓ Title Tabasco Coordinator Date _ Form 10-412 Submit in Duplicate Rev 7 1 80 • IP -10' ConocoPhillips April 1, 2005 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 -1276 PO Box 100360 Anchorage AK 99510-0360 Phone (907)263-4027 Fax: (907)265-6133 Re: Tabasco Oil Pool — Proposed Pressure Survey Plan for 2005 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 2005. There were 7 pressure surveys reported for the Tabasco Oil Pool to the AOGCC in 2004. In 2005, we expect to conduct approximately 5 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 Robert Christensen at (907) 659-7535 or Martin Walters at (907) 263-4194. Sincerely, ames R. Hand Supervisor - Drillsite Petroleum Engineering Greater Kuparuk Area • bcc: GKA Files ATO -1220A I* I* 10 Attachment 5 Kuparuk River Unit Tabasco Oil Pool 2004 Annual Reservoir Surveillance Report Production Logs and Special Surveys Well Date Type Comments 2T-02 9/18/2004 Temperature Logged cased hole across Tabasco after 72 hr SI. No clear indication of warm injection water in Tabasco interval. • Attachment 6 Kuparuk River Unit Tabasco Oil Pool 2004 Annual Reservoir Surveillance Report Wells 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 2004 production allocation factors were as follows: Tabasco Oil Pool 2004 Production Allocation Factors • Oil Gas Water Jan -04 0.9478 0.9209 1.0019 Feb -04 0.9642 0.9275 1.0139 Mar -04 0.9687 0.9486 1.0231 Apr -04 0.9549 0.9584 1.0198 May -04 0.9550 0.9834 1.0538 Jun -04 0.9605 0.9607 1.0631 Jul -04 0.9538 0.9754 1.0633 Aug -04 0.9482 0.9672 1.0912 Sep -04 0.9418 0.9326 1.0468 Oct -04 0.9381 0.9437 1.0511 Nov -04 0.9453 0.9245 1.1213 Dec -04 0.9488 0.9510 1.1774 Attachment 7 Kuparuk River Unit Tabasco Oil Pool 2004 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 being considered. 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 Site 2T continues to prove challenging due to smaller accumulations, lower quality reservoir, and higher viscosity oil. 1�1 0 ConocoPhillips April 1, 2005 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 -1276 PO Box 100360 Anchorage AK 99510-0360 Phone (907)263-4027 Fax: (907)265-6133 Re: 2004 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 2004. The following is an outline of the information provided: a. A summary of the enhanced recovery project (Attachment 1). b. Voidage balance, by month, for produced and injected fluids (Attachment 2, Attachment 3). c. Analysis of reservoir pressure surveys taken in 2004 (Attachment 4). d. Results of production surveys, and any special surveys, taken on the Tarn Oil Pool in 2004 (Attachment 5). e. Results of well allocation and test evaluation for Rule 7, and any other special monitoring (Attachment 6). f. Development Plan and Operation Review (Attachment 7) If you have any questions concerning this data, please contact Bob Christensen at (907) 659-7535 or Eric Dahlgren at (907) 265-6847. Sincerely, f James R. Hand Supervisor - Drillsite Petroleum Engineering Greater Kuparuk Area bcc: GKA Files ATO -1220 • Attachment 1 Kuparuk River Unit Tarn Oil Pool 2004 Annual Reservoir Surveillance Report Background In 1998 Arco Alaska, Inc received approvals for formation of the Tarn Oil Pool in the Kuparuk River Unit, an Area Injection Order for Tarn, expansion of the Kuparuk River Unit, and formation of the Tarn Participating. Area. The Tarn Pool Rules and Area Injection Order were approved on July 21st and July 20th respectively. The Unit Expansion and Participating area were approved effective July 1, 1998. Construction of the Tarn road, pads, powerlines, and pipelines took place in the 1998/1999 winter construction season. Tarn development drilling commenced in April of 1998. Tarn production began on July 8, 1998. Injection of miscible injectant (MI) began in November 1998. Tarn switched to a miscible water alternating gas (MWAG) recovery process in July 2001. Progress of EOR Project Three development wells and one producer sidetrack were drilled at Tarn in 2004; the total well count has increased to 44. 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 after 42 months of continuous water injection 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 2004, Tarn produced 10.34 MMSTB oil, 3.39 MMBW water, and 14,284 MMSCF gas. The injection totals for 2004 were 17,357 MMSCF of MI and 13.25 MMBW water. The cumulative year-end 2004 INV ratio for Drill Site 2N is estimated at 0.97, while the estimated cumulative INV for Drill Site 2L is 1.23. The average annual 2004 INV ratios for Drill Sites 2N and 2L were 1.05 and 1.15, 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. 40 :7 Attachment 2 Tarn River Oil Pool 2004 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 2004 954324 1124059 236921 55129050 78111493 4197789 2 2004 880005 1033265 211879 56009055 79144758 4409668 3 2004 893820 1047864 268971 56902875 80192622 4678639 4 2004 834440 1159995 225414 57737315 81352617 4904053 5 2004 897623 1441028 187612 58634938 82793645 5091665 6 2004 862299 1203495 227530 59497237 83997140 5319195 7 2004 899649 1220638 340512 60396886 85217778 5659707 8 2004 866178 1195810 408712 61263064 86413588 6068419 9 2004 847873 1218947 328049 62110937 87632535 6396468 10 2004 854914 1372708 313484 62965851 89005243 6709952 11 2004 797015 1222419 285836 63762866 90227662 6995788 12 2004 749127 1043469 360061 2004 TOTAL 10337267 14283697 3394981 Cumulatives at Dec 31, 2003 54174726 76987434 3960868 Produced Fluid Volumes (Reservoir Units) OIL GAS WATER CUM OIL CUM GAS CUM WATER MO YR RVB RVB RVB RVB RVB RVB 1 2004 1278033 609217 240238 73874259 80054664 4256558 2 2004 1178662 558275 214845 75052922 80612939 4471403 3 2004 1197028 564676 272737 76249950 81177615 4744140 4 2004 1118280 734318 228570 77368229 81911933 4972709 5 2004 1203412 1012313 190239 78571641 82924246 5162948 6 2004 1157041 760103 230715 79728682 83684348 5393663 7 2004 1207367 750498 345279 80936050 84434847 5738942 8 2004 1162349 745788 414434 82098398 85180634 6153376 9 2004 1137250 787716 332642 83235648 85968351 6486018 10 2004 1146460 960262 317873 84382108 86928612 6803891 11 2004 1068755 830140 289838 85450863 87758752 7093729 12 2004 1004935 657209 365102 2004 TOTAL 13859571 8970515 3442511 Cumulatives at Dec 31, 2003 72596227 79445447 4016320 :7 • Attachment 3 Tarn River Oil Pool 2004 Annual Reservoir Surveillance Report Injected Fluid Volumes 40 WATER GAS MI CUM WATER CUM GAS MI MO YR STB MSCF MSCF STB MSCF MSCF 1 2004 877445 0 1772959 54695326 0 86246416 2 2004 896044 0 1776875 55591370 0 88023291 3 2004 927815 0 1539574 56519185 0 89562865 4 2004 1180039 0 1374292 57699224 0 90937157 5 2004 1076929 0 1578131 58776153 0 92515288 6 2004 1099205 0 864521 59875358 0 93379809 7 2004 1565515 0 756600 61440873 0 94136409 8 2004 1314536 0 1246362 62755409 0 95382771 9 2004 1093218 0 1643422 63848627 0 97026193 10 2004 1037312 0 1699126 64885939 0 98725319 11 2004 865099 0 1629691 65751038 0 100355010 12 2004 1316928 0 1475353 2004 TOTAL 13250085 0 17356906 Cumulatives at Dec 31, 2003 53817881 0 84473457 Injected Fluid Volumes (Reservoir Units) WATER GAS MI CUM WATER CUM GAS CUM MI MO YR RVB RVB RVB RVB RVB RVB 1 2004 889729 0 1449581 55461064 0 70551596 2 2004 908589 0 1454342 56369653 0 72005938 3 2004 940804 0 1258575 57310457 0 73264513 4 2004 1196560 0 1122040 58507017 0 74386553 5 2004 1092006 0 1289115 59599023 0 75675668 6 2004 1114594 0 702142 60713617 0 76377810 7 2004 1587432 0 619294 62301049 0 76997104 8 2004 1332940 0 1022524 63633988 0 78019628 9 2004 1108523 0 1348399 64742512 0 79368026 10 2004 1051834 0 1389645 65794346 0 80757671 11 2004 877210 0 1330866 66671556 0 82088537 12 2004 1335365 0 11953331Yt 2004 TOTAL 13435586 0 14181854 Cumulatives at Dec 31, 2003 54571335 0 69102015 40 • • • STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION ANNUAL RESERVOIR PRESSURE REPORT - 2004 Attachment 4 Name of Operator Address ConocoPhillips Alaska Inc. P. O. Box 100360, Anchorage, AK 99510-0360 Unit or Lease Name Field and Pool Kuparuk River Field Datum Reference Oil Gravity Gas Gravity Ku aruk River Unit Tarn Oil Pool -5200' SS 1.2 0.74 Final t Data Production and Test Data API O,G Shut-in "MDT. Final Production Rates Wt. of Wt. of Pressure Number or Date Shut-in Tubing B. H. Observed (Bbls/Da (Mcfd) Liquid Liquid Gas Casing at Well Name Sand WI Tested Time Press. -. Pressure Oil Water Gas Gradient Column Column Press. Datum 2L-305 A 501032027900 O 11/19/04 792 100 8500 136 1817 0 0 0 1828 2L-311 A 501032046900 O 06/07/04 240 520 10885 140 2414 434 576 298 2445 2L-311 A 501032046900 O 07/05/04 72 126 10951 137 1631 1303 0 1467 2050 2L-329 A 501032027200 O 11/11/04 15288 850 5797 119 2752 0 0 0 3007 2L -329A A 501032027201 VVI 05/14/04 11000 0 5797 126 2741 0 0 0 2801 2L -329A A 501032027201 WI 11/11/04 15336 0 5797 117 2752 0 0 0 2800 2N-302 A 501032038000 O 01/28/04 84 1516 9754 112 3758 0 0 0 3695 2N-302 A 501032038000 WI 04/11/04 37 1191 9564 112 3571 0 0 0 3552 2N-306 A 501032049000 O 06/26/04 9999 3167 7280 148 2575 4935 0 0 2549 2N-307 A 501032029000 GI 01/28/04 95 2814 8470 121 3680 0 0 0 3685 2N-325 A 501032026900 VVI 01/09/04 207 1845 7827 125 3208 0 7000 0 3235 2N-325 B 501032026900 O 07/04/04 3360 1250 7827 120 2738 0 0 0 2765 2N-332 B 501032034000 O 05/03/04 240 300 11615 128 3067 100 400 300 3208 2N -337A A 501032026201 O 01/09/04 744 280 9980 136 2971 90 110 18 2991 2N -337A B 501032026201 O 05/20/04 3912 950 9980 137 3046 0 0 0 3066 2N-341 A 501032026300 O 07/11/04 28 1600 12030 130 1967 3352 104 5434 2035 2N -345A A 501032026401 O 06/13/04 9999 270 8128 141 2374 48 1 0 2421 17 >> >> Total Pressure Count in 2004 I hereby certify that t ore oing is true and correct to the best of my knowledge. Signed itle Tarn Coordinator Date l 36),l rorm io-w-it i Submit in Duplicate Rev 7 1 80 ConocoPhillips April 1, 2005 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 -1276 PO Box 100360 Anchorage AK 99510-0360 Phone (907)263-4027 Fax: (907)265-6133 Re: Tarn Oil Pool — Proposed Pressure Survey Plan for 2005 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 2005. There were 17 pressure surveys reported for the Tarn Oil Pool to the AOGCC in 2004. In 2005, we expect to conduct approximately 15 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 Robert Christensen at (907) 659-7535 or Eric Dahlgren at (907) 265-6847. Sincerely, ames R. Hand 4Z Supervisor - Drillsite Petroleum Engineering Greater Kuparuk Area • bcc: GKA Files ATO -1220A 0 • • Attachment 5 Kuparuk River Unit Tarn Oil Pool 2004 Annual Reservoir Surveillance Report Production Logs and Special Surveys One injection survey was conducted at drill site 2N to evaluate vertical conformance while injecting miscible gas. Results from the surveys indicate there are no casing or tubing leaks and all injection is within the Bermuda interval. Injection rate, pressure, and temperature are summarized in the table below. WELL RATE SVY DATE FLUID (MMCFPD) BHIP (psi) BHT (deg F) 2N -321A 2/25/2004 Mi 11.4 3360 103 10 t: 16 Attachment 6 Tarn Oil Pool 2004 Production Allocation Factors Oil Gas Water Jan -04 0.9478 0.9208 1.0019 Feb -04 0.9641 0.9275 1.0139 Mar -04 0.9687 0.9484 1.0231 Apr -04 0.9549 0.9585 1.0198 May -04 0.9550 0.9833 1.0539 Jun -04 0.9605 0.9606 1.0631 Jul -04 0.9538 0.9755 1.0633 Aug -04 0.9482 0.9672 1.0912 Sep -04 0.9418 0.9326 1.0468 Oct -04 0.9380 0.9435 1.0511 Nov -04 0.9452 0.9247 1.1214 Dec -04 0.9487 0.9510 1.1774 • Attachment 7 Kuparuk River Unit Tarn Oil Pool 2004 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. Three development wells and one producer sidetrack were drilled at Tarn in 2004. 2N-311 did not find adequate pay to warrant completion. The wellbore was suspended and may be used for future sidetrack. 2N-345 was successfully sidetracked away from short-circuit with offset injector. The total well count at Tarn has increased to 44. Plans for 2005 include one new development well on 2L Pad and one sidetrack on 2N Pad. An update of the full -field reservoir model is being considered for use in development planning and flood optimization. • Producer to Injector Conversions — The 2L-305 was converted to injection service during 2004. Future conversions are being evaluated in order to continue to improve sweep efficiency and help to maximize recovery from the Tarn field. There are no plans in 2005 to convert a producer to an injector or vise versa at Tarn. C: • El CD W r+ 0 0 ConocoPhillips April 1, 2005 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 -1276 PO Box 100360 Anchorage AK 99510-0360 Phone (907)263-4027 Fax: (907)265-6133 Re: 2004 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 2004. The following is an outline of the information provided: a. A summary of the enhanced recovery project (Attachment 1). b. Voidage balance, by month, for produced and injected fluids (Attachment 2, • Attachment 3). c. Analysis of reservoir pressure surveys taken in 2004 (Attachment 4). d. Results of production surveys, and any special surveys, taken on the West Sak Oil Pool in 2004 (Attachment 5). e. Results of well allocation and test evaluation for Rule 7, and any other special monitoring (Attachment 6). f. Future development plans (Attachment 7). If you have any questions concerning this data, please call Hai Hunt at (907) 265-6912 or Bob Christensen at (907) 659-7535. Sincerely, _ ames R. Hand Supervisor - Drillsite Petroleum Engineering Greater Kuparuk Area bcc: GKA Files 0 ATO — 1220A • Attachment 1 Kuparuk River Unit West Sak Oil Pool 2004 Annual Reservoir Surveillance Report Summary of the Enhanced Recovery Project West Sak development activities in 2004 included drilling eight horizontal wells; four producers and four injectors. The 2004 development drilling program led to expansion of the West Sak development area to a new surface pad location, Drillsite 1 E. Both a water injector and a producer were drilled from Drillsite 1 E. At the end of 2004, there were 33 water injectors and 33 producers in service in the West Sak oil pool. The following wells were drilled in 2004 in the West Sak oil pool: Name Well Type Target Inj/Prod 1E-104 Vertical B/D/A Sand Injector 1 E-119 Vertical B/D/A Sand Injector 1 E-112 Multilateral D/B/A Sand Injector 1 E-114 Multilateral B/D/A Sand Injector 1E-123 • 1E-126 Multilateral Multilateral D/B Sand D/B/A Sand Producer Producer 1E-166 Multilateral B/D/A Sand Producer 1E-168 Multilateral B/D/A Sand Producer 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, three rapid water breakthrough events occurred in 2004. These events created high conductive pathways between an injector and a producer. A list of the breakthrough events in 2004 are shown below: Injector Producer Event Date Breakthrough Zone 1D-139 1D-102 April 2004 B Sand 1C-125 1C-104 Sept 2004 B Sand 1B-102 1C-178 Nov 2004 Unknown We are currently studying these rapid water breakthrough events to understand the failure mechanism. This study will then be used to make recommendations to minimize future events and to develop a remediation strategy for the events that have occurred. 0 • During 2003, ConocoPhillips Alaska, Inc. received approval to commence a West Sak Small Scale EOR (SSEOR) Pilot Project using Kuparuk MI in a water - alternating gas (WAG) pilot. The SSEOR Pilot Project consists of three phases in two permitted areas: Phase I : WAG wellbore completion integrity test; Phase 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. 1C-135 was returned to long-term production in April 2004. Production from the well indicated that slotted liner wells are suitable for gas production. Phase II of the Pilot Project was initiated on March 2004 with injection into 1 C- 119 and 1 C-121. 1 C-119 received a 1 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 recovered to the pre -gas injection levels. Several more wag cycles are planned for these wells in 2004. • Phase III of the Pilot Project was also initiated on March 2004 with gas injection into 1 C-121. Well 1 C-121 was on continuous gas injection for 5 months and resulted in an increase in the GOR of offset producer 1C-102. Once 1C-121 was switched to water injection, the GOR in 1 C-102 reduced back to its pre -gas injection level. Gas breakthrough will continued to be monitored in 1C-102 and 1C-104 as additional WAG cycles are injected into 1C-119 and 1C-121. Later in 2004, we plan to convert 1 C-174, which is a horizontal undulating injector, to gas injection for the beginning of several WAG cycles. 0 • Attachment 2 West Sak Oil Pool 2004 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 2004 286724 131156 73873 10885864 3023626 2090437 2 2004 270466 130186 87317 11156330 3153812 2177754 3 2004 319754 115164 89425 11476084 3268976 2267179 4 2004 285943 100672 75813 11762027 3369648 2342992 5 2004 267971 122477 70587 12029998 3492125 2413579 6 2004 264484 65927 75827 12294482 3558052 2489406 7 2004 306715 85131 83547 12601197 3643183 2572953 8 2004 265587 95708 64701 12866784 3738891 2637654 9 2004 426814 193853 69158 13293598 3932744 2706812 10 2004 529306 270626 110282 13822904 4203370 2817094 11 2004 532643 394548 129768 14355547 4597918 2946862 12 2004 524234 363908 104502`4$7>3 2004 TOTAL 4280641 2069356 1034800 Cumulatives at Dec 31, 2003 10599140 2892470 2016564 • Produced Fluid Volumes (Reservoir Units) OIL GAS WATER CUM OIL CUM GAS CUM WATER MO YR RVB RVB RVB RVB RVB RVB 1 2004 306795 42520 73873 11647874 3241606 2090437 2 2004 289399 46629 87317 11937273 3288235 2177754 3 2004 342137 17244 89425 12279410 3305479 2267179 4 2004 305959 39468 75813 12585369 3344947 2342992 5 2004 286729 52661 70587 12872098 3397607 2413579 6 2004 282998 13405 75827 13155096 3411013 2489406 7 2004 328185 26588 83547 13483281 3437601 2572953 8 2004 284178 34167 64701 13767459 3471768 2637654 9 2004 456691 58428 69158 14224150 3530197 2706812 10 2004 566357 82501 110282 14790507 3612697 2817094 11 2004 569928 277212 129768 15360435 3889909 2946862 12 2004 560930 220199 104502 2004 TOTAL 4580286 911023 1034800 Cumulatives at Dec 31, 2003 11341080 3199085 2016564 • • Attachment 3 West Sak Oil Pool 2004 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 2004 697461 0 0 19077116 0 170839 2 2004 623285 0 2789 19700401 0 173628 3 2004 548147 0 28035 20248548 0 201663 4 2004 571599 0 21506 20820147 0 223169 5 2004 572023 0 20976 21392170 0 244145 6 2004 549294 0 18213 21941464 0 262358 7 2004 506958 0 16072 22448422 0 278430 8 2004 541124 0 13552 22989546 0 291982 9 2004 749440 0 0 23738986 0 291982 10 2004 716899 0 0 24455885 0 291982 11 2004 572788 0 0 25028673 0 291982 12 2004 552467 0 0 2004 TOTAL 7201485 0 121143 Cumulatives at Dec 31, 2003 18379655 0 170839 • Injected Fluid Volumes (Reservoir Units) WATER GAS MI CUM WATER CUM GAS CUM MI MO YR RVB RVB RVB RVB RVB RVB 1 2004 697461 0 0 19077116 0 127958 2 2004 623285 0 2089 19700401 0 130047 3 2004 548147 0 20998 20248548 0 151046 4 2004 571599 0 16108 20820147 0 167154 5 2004 572023 0 15711 21392170 0 182865 6 2004 549294 0 13642 21941464 0 196506 7 2004 506958 0 12038 22448422 0 208544 8 2004 541124 0 10150 22989546 0 218695 9 2004 749440 0 0 23738986 0 218695 10 2004 716899 0 0 24455885 0 218695 11 2004 572788 0 0 25028673 0 218695 12 2004 552467 0 0 2004 TOTAL 7201485 0 90736 Cumulatives at Dec 31, 2003 18379655 0 127968 • • • STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION ANNUAL RESERVOIR PRESSURE REPORT - 2004 Attachment 4 Name of Operator Address ConocoPhilli s Alaska Inc. I P. O. Box 100360, Anchorage, AK 99510-0360 Unit or Lease Name Field and Pool Kuparuk River Field Datum Reference Oil Gravity Gas Gravity Ku aruk River Unit West Sak Oil Pool -3500' SS 1.06 0.57 Final re Test Data Production and Test Data API O,G Shut-in rDh Final Production Rates Wt. of Wt. of Pressure Number or Date Shut-in Tubing B.H. Observed (Bbls/Da (Mcfd) Liquid Liquid Gas Casing at Well Name Sand WI Tested Time Press. Temp. Pressure Oil Water Gas Gradient Column Column Press. Datum 1C-104 B+D 500292307600 O 06/16/04 400 0 6166 69 1096 0 0 0 1172 1C-172 A 500292315900 O 04/08/04 2600 0 6367 69 1556 0 0 0 1498 1C-172 A 500292315900 O 12/15/04 5060 0 6367 69 1507 0 0 0 1449 1C-190 D 500292313600 WI 10/13/04 168 710 4950 93 2273 0 2500 0 2188 1D -105A D 500292284301 O 01/16/04 3000 0 5134 69 1644 0 0 0 1670 1D-121 A+B+D 500292281400 O 02/12/04 2500 0 3636 70 1879 0 0 0 1908 1D-127 A+B+D 500292289000 O 04/22/04 8700 0 6567 70 1650 0 0 0 1726 1D-140 B+D 500292297400 O 01/23/04 1000 0 3589 70 2022 0 0 0 2067 1D-141 B+D 500292296700 O 02/26/04 3000 0 5460 69 1616 0 0 0 1628 1D-141 B+D 500292296700 O 10/05/04 5064 0 5460 68 1615 0 0 0 1627 1E-104 A 500292323400 O 12/30/04 9999 0 6385 80 1560 0 0 0 1499 11 >> >> Tota! Pressure Count in 2004 I hereby certify hat th f egoing is true and correct to the best of my knowledge. Signe Title West Sak Surveillance Engineer Date 3 rorm iu-ver-0 U Submit in Duplicate Rev 7 1 80 • 0 ConocoPhillips April 1, 2005 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 -1276 PO Box 100360 Anchorage AK 99510-0360 Phone (907)263-4027 Fax: (907)265-6133 Re: West Sak Oil Pool — Proposed Pressure Survey Plan for 2005 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 2005. There were 11 pressure surveys reported for the West Sak River Oil Pool to the AOGCC in 2004. In 2005, we expect to conduct approximately 15 pressure surveys, including initial surveys for new wells prior to initial sustained production. If you have any questions concerning this data, please contact Robert Christensen at (907) 659-7535 or Paul Burtis at (907) 265-6314. Sincerely, ames R. Hand Supervisor - Drillsite Petroleum Engineering Greater Kuparuk Area • bcc: GKA Files ATO -1220A • KUPARUK RIVER UNIT WEST SAK OIL POOL CONSERVATION ORDER 406 RULE 11 - INJECTIVITY PROFILES 2004 ANNUAL SUBMITTAL • WELL NUMBER API NUMBER 50- DATE OF INITIAL INJECTION DATE OF PROFILE/ SURVEY DATA TYPE PROFILE/ SURVEY REASON FOR PROFILE/ SURVEY WELL COMPLETION ZONES TAKING INJECTION INJECTION BWPD / MSCFD iC-111 02923029-00 12/12/01 12/06/04 SPINNER Initial Monobore D+B 1460 B 0 1C-117 02923027-00 01/04/02 09/01/04 SPINNER Initial Monobore A+B+D 1600 B 0 A 0 1C-119 02923034-00 12/08/01 12/28/04 SPINNER Follow-up Monobore B+D 1064 B 0 3 >> TotaI IPROF Count for 2004 I* 10 16 Attachment 5 Kuparuk River Unit West Sak Oil Pool 2004 Annual Reservoir Surveillance Report Production Logs and Special Surveys Geochemical Oil Production Splits: Well Name Sample Date I A Sand B Sand D Sand 1C-102 08/28/04 1 C-102 12/03/04 1 C-109 04/17/04 1 C-109 04/19/04 1 C-109 08/28/04 1 C-109 wagEMEREMM 12/03/04 1C-178 04/17/04 1C-178 08/28/04 1C-178 12/03/04 1D-108 01/03/04 17% 1D-108 04/19/04 25% 1D-108 08/24/04 31% 1D-108 12/04/04 37% 1 D-112 01/04/04 31% 50% 19% 1D-112 04/19/04 31% 50% 19% 1 D-112 08/28/04 38% 41% 21% 1 D-112 12/04/04 38% 39% 23% 1D-115 01/12/04 52% MOM 39% 9% 1 D-115 04/19/04 41 % 47% 12% 1D-115 08/28/04 41 % 41% 18% 1D-115 12/04/04 48% 35% 17% 1 of 2 140 I* I* Geochemical Oil Production Splits: Well Name Sample Date I A Sand B Sand D Sand 1D-118 01/12/04 77% 1D-118 04/19/04 83% 1D-118 08/28/04 70% 1 D-118 12/04/04 65% 1D-124 iv 01/12/04 39% 1D-124 04/19/04 44% 1D-124 08/28/04 45% 1D-124 12/04/04 49% IM 26 :w w �1. 1D-129 01 /12/04 61 % 1 D-129 04/19/04 52% 1 D-129 08/30/04 49% 1D-129 12/04/04 50% 9/ti4/ =30'1 ��1D-13/12/0458% 1D-133 04/19/04 49% 1D-133 08/30/04 47% 1D-133 12/04/04 54% 0 1D-135 01/12/0404 1 D-135 04/19/04 4% 1D-135 08/30/04 5% 1D-135 12/04/04 8% !1E 12 09/09/04 38% 12 12/02/04 23% 1E-123 08/12/04 0% 1E-123 WOMBINAWMEWAYMOMMMEM 12/02/04 0% 1E-166 12/02/04 7% 2 of 2 I* 10 19 Attachment 6 Wsak Oil Pool 2004 Production Allocation Factors Oil Gas Water Jan -04 0.9477 0.9208 1.0019 Feb -04 0.9641 0.9275 1.0139 Mar -04 0.9687 0.9484 1.0231 Apr -04 0.9548 0.9585 1.0198 May -04 0.9550 0.9833 1.0538 Jun -04 0.9605 0.9605 1.0631 Jul -04 0.9538 0.9755 1.0633 Aug -04 0.9482 0.9672 1.0912 Sep -04 0.9418 0.9327 1.0469 Oct -04 0.9380 0.9435 1.0510 Nov -04 0.9452 0.9247 1.1213 Dec -04 0.9487 0.9510 1.1774 • Attachment 7 Kuparuk River Unit West Sak Oil Pool 2004 Annual Reservoir Surveillance Report Future Development Plans • DRILL SITE 1 E DEVELOPMENT DRILLING The KRU working interest owners intend to drill six wells from Drill Site 1 E in 2005. The West Sak Wells 1E-102 and 1E-121 have been drilled and completed with Doyon 141 in early 2005 and are currently on injection/production, respectively. Doyon 15 is scheduled to arrive and spud the 1 E-117 well starting in May, 2005. The Drill Site 1 E drilling program should be complete in September, 2005. Information regarding the wells is listed below: Name Well Type Target Inj/Prod 111-102 • 1E-121 Multilateral Multilateral D/B Sand D/B Sand Injector Producer 1 E-117 Multilateral D/B/A2 Sand Injector 1E-105 Multilateral D/B/A2 Sand Injector 1E-170 Multilateral D/B/A2 Sand Producer 1E-108 Vertical D/B/A2 Sand Injector DRILL SITE 1.1 DEVELOPMENT ConocoPhillips and its working interest owners approved an AFE for a 31 well West Sak development at Drill Site 1J. The estimated spud date for the 1St Drill Site 1J well is approximately May 1, 2005 with Doyon 141. A total of 7 wells are planned to be drilled and completed in 2005. Information regarding the wells is listed below: Name Well Type Target Inj/Prod 1J-154 Multilateral D/B/A2 Sand Injector 1J-168 Multilateral D/B/A2 Sand Producer 1J-184 Multilateral D/B Sand Injector 1J-164 Multilateral D/B/A2 Sand Injector 1J-152 Multilateral D/B/A2 Sand Producer 1J-133 Multilateral D/B Sand Injector 1J-159 Multilateral D/B/A2 Sand Producer 0 • 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. LI C,
