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Home My WebLink About2001 Kuparuk River PoolPHILLIPS Alaska, Inc. A Subs~d~ary of PHILLIPS PETROLEUM COMPANY P. 0. BOX 100360 ANCHORAGE, ALASKA 99510-0360 John L. Hand Supervisor Greater Kuparuk Area Reservoir Planning AT0 1228 Phone 265-6036 Fax: 265-6133 March 28,2002 Ms. Camille Oechsli Taylor, Commissioner Alaska Oil and Gas Conservation Commission 333 West 7th Ave. Suite #I00 Anchorage, Alaska 99501 -3539 Re: 2001 KRU Annual Surveillance Report Dear Ms. Oechsli Taylor: In compliance with Rule 3, Conservation Order No. 198B, Phillips 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 2001. The following is an outline of the information provided: a. A summary of the enhanced recovery project (Attachment 1). Voidage balance, by month, of produced and injected fluids, including low molecular weight hydrocarbons (Attachment 2, Attachment 3). Analysis of reservoir pressure surveys taken in 2001 (Attachment 4). A tabulation of both injection (Attachment 5) and production (Attachment 6) logs and surveys analyzed during 2001 from wells in the Kuparuk permit area. Composition of enriched gas injected during 2001 and estimate of MMP (Attachment 7). Kuparuk LSEOR development plan (Attachment 8). If you have any questions concerning this data, please contact Robert Christensen at (907) 659-7535 or Mark Stevenson at (907) 263-491 7. Sincerely, , Sbhn L. Hand F &/ ' GKA Reservoir Planning Supervisor bcc: Central Files John Braden Bob Christensen Stephanie Dobson John Hand Dan Kruse Mark Stevenson Attachment 1 Kuparuk River Unit Kuparuk River Oil Pool 2001 Annual Surveillance Report Summary of the Enhanced Recovery Project Conservation Order 198B Rule 3. Kuparuk River Unit Reservoir Surveillance Proqram (a) Progress of enhanced recovery project(s) implementation and reservoir management summary including engineering and performance parameters. ENHANCEDRECOVERY Miscible water-alternating-gas (MWAG) continues as the predominant EOR process at the Kuparuk field. In the second half of 2001, four additional drill sites commenced MWAG operation, bringing the total number of MWAG drill sites in Kuparuk to 28. 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. Due to the superior petformance of the MWAG process over the Immiscible Water- Alternating Gas (IWAG) process, the Kuparuk EOR project continues to maximize the manufacture of MI by blending all available lean gas with NGLs. There was no IWAG injection at Kuparuk in 2001. The EOR project expanded to Drillsites 1 C, 1 E, 3B, and 3H in the second half of 2001. The 2001 annual average MI injection to these four drillsites was 20 MMSCFD. Total MI injection into Kuparuk averaged 252 MMSCFD for 2001. The incremental oil production resulting from MWAG at Kuparuk averaged 33 MBPD in 2001. The Greater Kuparuk Area utilized an average of 15 MBPD of indigenous NGLs and 29 MBPD of imported NGLs to manufacture 295 MMSCFD of MI, of which 43 MMSCFD was supplied to the GKA satellite fields Tarn and Meltwater. The priorities for gas management for the Kuparuk field in 2001 were 1) increased MI injection into A sand patterns within existing EOR areas and 2) MI injection into newly expanded MWAG patterns (A and C sands) Both A sand patterns and new MWAG patterns have higher gas storage efficiency than mature C sand patterns resulting in greater overall oil production due to the consequent suppression of gas production. This, combined with the less than expected gas production from the satellite fields in 2001, resulted a reduction in the total volume of lean gas available for MI manufacture in 2001 when compared to 2000. During 2001, an evaluation was undertaken to understand potential hydraulic limitations in the MI distribution pipeline system. A recommendation was made to install a 12" line loop between Central Processing Facility #2 and Drill Site 1Y during 2002. This project will assure adequate MI delivery pressure to the CPF1 and CPF3 area drill sites with continued EOR expansions. Conservation Order l98B Rule 3. Kuparuk River Unit Reservoir Surveillance Proqram MWAG Small Scale EOR (SSEOR and SSEORX) Drill Sites IA, 1Y, and 22 continued MWAG during 2001. The 2001 average MI injection rate was 30 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, IQ, 1 R, 2A, 2B, 2C, ZD, 2F, 2G, 2H, 2K, 2M, 2T, 2U, 2V, 2W, and 2X. The total MI injection rate into these drillsites averaged 177 MMSCFD in 2001. CPFS EOR DS3F was not part of the original LSEOR scope, but was approved shortly thereafter for MI injection. The 2001 average MI injection into DS3F was 16 MMSCFD. EOR Expansions CPF-3 has four additional drill sites on MWAG: DS3B, 3H, 30, and 3Q. CPF-1 has two additional drill sites 1 C and 1 E. The combined average MI injection into these expansion drillsites is 29 MMSCFD. IWAG The Kuparuk EOR project continues to maximize MWAG operation by blending all available lean gas for MI. No IWAG operation is currently undertaken. KUPARUK EOR DRILL SITE STATUS Alaska SSEOR and SSEORX LSEOR and LSEORX EOR Expansion in 2001 EOR Expansion in 2002 EOR Expansion in 2003 Potential Future Expansion Kuparuk EOR Drill Sites (SSEOR+LSEOR+SF) Incremental EOR Oil Rate (Data Available from Jan '93 through Dec '01) HDSIA ODSIF UDSlG fZIDS1Q BDSlR CllDSlY 61DS2A mDS2B BDS2C UDS2D ClDS2F BlDS2G UDS2H ODS2K ODS2M BDS2T QDS2U UDS2V WDS2W HDS2X ElDS2Z W DS3F Attachment 2 Kuparuk River Unit Kuparuk River Oil Pool 2001 Annual Surveillance Report Produced Fluid Volumes 2001 TOTAL OIL STB 6149701 5537857 607481 9 5835808 59091 31 5565949 56371 32 5607989 5364980 5460841 55491 32 5571 649 Attachment 2 Kuparuk River Oil Pool 2001 Annual Reservoir Surveillance Report Produced Fluid Volumes GAS MSCF 8926699 8437351 9550037 8976404 8861 960 81 71 407 7986041 81 26834 8081 821 9072633 9573320 9538587 WATER BBL 18240863 16457333 181 41 809 16822081 17351 026 171 971 56 17382203 17556329 16238764 172471 43 188401 18 18421013 CUM OIL STB 1738624220 17441 62077 1750236896 1756072704 1761 981835 1767547784 17731 8491 6 1778792905 17841 57885 178961 8726 17951 67858 1800739507 CUM GAS MSCF 1978560370 1986997721 1996547758 20055241 62 201 43861 22 2022557529 2030543570 2038670404 2046752225 2055824858 20653981 78 2074936765 CUM WATER BBL 1730045882 174650321 5 1764645024 1781 4671 05 179881 81 31 181 601 5287 1833397490 1850953819 18671 92583 1884439726 1903279844 1921 700857 Cum's from Dec last report 173247451 9 1969633671 171 1805019 Attachment 3 Kuparuk River Oil Pool 2001 Annual Surveillance Report Injected Fluid Volumes Attachment 3 Kuparuk River Oil Pool 2001 Annual Reservoir Surveillance Report Injected Fluid Volumes WATER STB 23948093 20708821 231 44684 21 653437 22294958 21 186453 1907231 3 18784551 17409638 18290561 198651 74 201 51 530 GAS MSCF 0 0 0 0 0 0 0 0 0 0 0 0 NGLS MSCF 6844831 6431 539 74241 84 661 0768 6561771 6339421 7996506 8506979 8049599 88521 63 90521 58 91 53554 2001 TOTAL 246510213 0 91 823473 CUM WATER STB 8710092276 8730801 097 8753945781 877559921 8 87978941 76 8819080629 88381 52942 8856937493 8874347131 8892637692 8912502866 8932654396 CUM GAS MSCF 1 624201 653 16306331 92 1638057376 1 6446681 44 1651 22991 5 1657569336 1665565842 1674072821 16821 22420 1690974583 1700026741 17091 80295 Cum's from Dec last report 86861441 83 1617356822 Attachment 4 Kuparuk River Oil Pool 2001 Annual Surveillance Report Reservoir Pressure Surveys STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION ANNUAL RESERVOIR PRESSURE REPORT - 2001 Phillips Alaska Inc. I P. 0. Box 100360, Anchorage, AK 99510-0360 Unit or Lease Name I Field and Pool Kuparuk River Field 1 Datum Reference l0il Gravity l~as Gravity 1 A-02 1A-28 16-04 1 B-09 1B-12 18-14 1E-15 1 F-08 1 F-16A 1 H-01 1 H-02 1 H-02 1 H-03 1 H-03 1 H-08 1 H-08 1 H-09 1H-12 1H-12 1 H-20 1J-10 1 L-09 IL-10 1L-11 1L-18 1 L-21 DPN 1 R-20 1 R-29 1 Y-23 1 Y-24 1 Y-32 2A-13 2A-19A 28-03 28-04 28-05 28-07 2D-02 2D-04 2D-06B 2D-09 2D-11 2D-12 2D-14 2D-14 2F-07 2F-08 2F-12 2F-16 2F-17 Kuparuk River Unit Well Name API O,G Kuparuk River Oil Pool 1A-04 C 5002920621 00 WI 06/03/00 2000 1057 8185 155 3319 0 3346 0 2700 Sand -6200' SS Final Shut-in 0.91 1 0.71 Pressure Test Data Tool 1 I Final Number Production and Test Data Production Rates I Wt. of1 Wt. of I I Pressure or WI Date Tested Shut-in Time Tubing Press. Depth MD B.H. Temp. Observed Pressure (BbldDay) (Mcfd) oil1 water] Gas Liquid Gradient Liquid Column Gas Column Casing Press. at Datum STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION ANNUAL RESERVOIR PRESSURE REPORT - 2001 Phillips Alaska Inc. I P. 0. Box 100360, Anchorage, AK 99510-0360 Unit or Lease Name I Field and Pool Kuparuk River Field l0il Gravity l~as Gravity IDatum Reference Kuparuk River Unit 2G-03 A 5002921 16500 0 01/20/01 6768 2049 0 155 4347 0 0 6566 Well Name Kuparuk River Oil Pool -6200' SS Sand 0.91 1 0.71 Date Tested API Number Shut-in Time Final Shut-in Tubing Press. O,G or WI Production and Test Data Pressure Test Data Pressure at Datum Tool Depth MD Production Rates (BblslDay) (Mcfd) oil] water1 Gas B.H. Temp. Liquid Gradient Final Observed Pressure Wt. of Liquid Column Wt. of Gas Column Casing Press. STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION ANNUAL RESERVOIR PRESSURE REPORT - 2001 Name of Operator Phillips Alaska Inc. Address P. 0. Box 100360, Anchorage, AK 99510-0360 Kuparuk River Unit Unit or Lease Name 3H-20 A 501032009300 0 1 011 7/01 87 106 8735 155 2476 284 43 232 2548 Well Name F~eld and Pool Kuparuk River Field l~atum Reference l0il Gravity l~as Gravity Kuparuk River Oil Pool Sand Date Tested -6200 SS I 0.91 1 0.71 Production and Test Data API Number Shut-in Time Pressure at Datum O,G or WI Production Rates (Bbls/Day) (Mcfdl oil1 water( Gas Final Shut-in Tubing Press. Wt. of Liquid Column Liquid Gradient Wt. of Gas Column Pressure Test Data Casing Press. Tool Depth MD B.H. Temp. Final Observed Pressure Attachment 5 Kuparuk River Oil Pool 2001 Annual Surveillance Report Injection Survey Data KUPARUK RIVER UNIT KUPARUK RIVER OIL POOL CONSERVATION ORDER 198B RULE 4 - INJECTIVITY PROFILES 2001 ANNUAL SUBMITTAL WELL API DATE OF DATE OF DATA TYPE REASON FOR WELL ZONES INJECTION NUMBER NUMBER INITIAL PROFILE/ PROFILE/ PROFILE/ COMPLETION TAKING BWPD / 50- INJECTION SURVEY SURVEY SURVEY INJECTION MSCFD SPINNER SZT SZT SZT SPINNER SPINNER SZT SPINNER SPINNER SPINNER S ZT SPINNER SPINNER SPINNER SPINNER Follow up Follow up Follow up Follow up Follow up Follow up Follow up Follow up Follow up Follow up Sel. Single Sel. Single Sel. Single Sel. Single Sel. Single Sel. Single Sel. Single Sel. Single Sel. Single Sel. Single New ST Well Single Follow up Sel. Single Follow up Sel. Single Follow up Sel. Single Follow up Sel. Single KUPARUK RIVER UNIT KUPARUK RIVER OIL POOL CONSERVATION ORDER 198B RULE 4 - INJECTIVITY PROFILES 2001 ANNUAL SUBMITTAL WELL API DATE OF DATE OF DATA TYPE REASON FOR WELL ZONES INJECTION NUMBER NUMBER INITIAL PROFILE/ PROFILE/ PROFILE/ COMPLETION TAKING BWPD / 50- INJECTION SURVEY SURVEY SURVEY INJECTION MSCFD SPINNER SPINNER SZT SPINNER SPINNER SPINNER SPINNER SPINNER SPINNER SZT SZT SZT SPINNER SPINNER Follow up Follow up Follow up Follow up Follow up Follow up Follow up Follow up Follow up Follow up Sel. Single Sel. Single Sel. Single Sel. Single Sel. Single Sel. Single Sel. Single Single Single Sel. Single Follow up Sel. Single Follow up Sel. Single Follow up Single Follow up Sel. Single KUPARUK RIVER UNIT KUPARUK RIVER OIL POOL CONSERVATION ORDER 198B RULE 4 - INJECTIVITY PROFILES 2001 ANNUAL SUBMITTAL WELL API DATE OF DATE OF DATA TYPE REASON FOR WELL ZONES INJECTION NUMBER NUMBER INITIAL PROFILE/ PROFILE/ PROFILE/ COMPLETION TAKING BWPD / 50- INJECTION SURVEY SURVEY SURVEY INJECTION MSCFD 2U-14 02921262-00 01/86 01/03/01 SPINNER 01/86 05/30/01 SPINNER 11/84 05/05/01 SPINNER 01/86 09/05/01 SPINNER 11/85 09/05/01 SPINNER SPINNER SPINNER SPINNER SPINNER SPINNER SZT SPINNER SPINNER SPINNER SPINNER Follow up Follow up Follow up Follow up Follow up Follow up Follow up Follow up Follow up Follow up Follow up Follow up Follow up Follow up Follow up Sel. Single Sel. Single Sel. Single Sel. Single Sel. Single Sel. Single Sel. Single Sel. Single Sel. Single Sel. Single Sel. Single Sel. Single Sel. Single Sel. Single Sel. Single KUPARUK RIVER UNIT KUPARUK RIVER OIL POOL CONSERVATION ORDER 198B RULE 4 - INJECTIVITY PROFILES 2001 ANNUAL SUBMITTAL WELL API DATE OF DATE OF DATA TYPE REASON FOR WELL ZONES INJECTION NUMBER NUMBER INITIAL PROFILE/ PROFILE/ PROFILE/ COMPLETION TAKING BWPD / 50- INJECTION SURVEY SURVEY SURVEY INJECTION MSCFD SPINNER SZT SZT SZT SZT SPINNER SPINNER SPINNER SPINNER SPINNER SPINNER SPINNER Follow up Follow up Follow up Follow up Follow up Follow up Follow up Follow up Follow up Follow up Follow up Follow up Sel. Single Sel. Single Sel. Single Sel. Single Sel. Single Sel. Single Single Single Single Single Sel. Single Single Attachment 6 Kuparuk River Oil Pool 2001 Annual Surveillance Report Production Survey Data KUPARUK RIVER UNIT KUPARUK RIVER OIL POOL CONSERVATION ORDER 432 RULE 9 - PRODUCTIVITY PROFILES ANNUAL 2001 SUBMITTAL Sel. Single Single 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 SPINNER SZT SZT Spinner Spinner Spinner SPINNER SZT SZT OPEN C SANDS SZT OPEN C SANDS SZT CLOSE C SANDS SPINNER A/C SPLITS S ZT CLOSE C SANDS SZT OPEN A SANDS FOLLOW-UP OPEN C SANDS OPEN C SANDS A/C SPLITS A/C SPLITS A/C SPLITS A/C SPLITS CLOSE C SANDS Sel. Single Sel. Single Sel. Single Single Sel. Single Sel. Single Sel. Single Sel. Single Sel. Single Sel. Single Sel. Single Sel. Single Sel. Single Single Sel. Single KUPARUK RIVER UNIT KUPARUK RIVER OIL POOL CONSERVATION ORDER 432 RULE 9 - PRODUCTIVITY PROFILES ANNUAL 2001 SUBMITTAL Sel. Single Single 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 SZT SPINNER SZT SZT SPINNER SZT SZT SPINNER SPINNER 07/16/01 SPINNER 07/14/01 SPINNER 08/04/01 SPINNER 07/15/01 SPINNER 01/14/01 SZT OPEN A SANDS A/C SPLITS OPEN C SANDS OPEN C SANDS A/C SPLITS OPEN C SANDS CLOSE C SANDS A/C SPLITS A/C SPLITS A/C SPLITS A/C SPLITS A/C SPLITS A/C SPLITS OPEN C SANDS Sel. Single Single Sel. Single Sel. Single Single Sel. Single Sel. Single Single Single Single Single Sel. Single Single Sel. Single KUPARUK RIVER UNIT KUPARUK RIVER OIL POOL CONSERVATION ORDER 432 RULE 9 - PRODUCTIVITY PROFILES ANNUAL 2001 SUBMITTAL Sel. Single Single 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 SPINNER SPINNER SZT SPINNER SZT SPINNER S ZT SPINNER SPINNER 10/23/01 SPINNER 12/02/01 SZT 10/22/01 SPINNER A/C SPLITS FOLLOW-UP OPEN C SANDS A/C SPLITS CLOSE C SANDS A/C SPLITS OPEN C SANDS OPEN C SANDS A/C SPLITS A/C SPLITS CLOSE C SANDS A/C SPLITS Sel. Single Sel. Single Sel. Single Sel. Single Sel. Single Sel. Single Sel. Single Sel. Single Sel. Single Sel. Single Sel. Single Single Attachment 7 Kuparuk River Oil Pool 2001 Annual Surveillance Report Miscible lnjectant Composition Conservation Order 198B Rule 3. Kuparuk River Unit Reservoir Surveillance Proqram Attachment 7: MI Composition and MMP Miscible lnjectant (MI) compositions and corresponding Minimum Miscible Pressures (MMP) for the three CPF's are presented in the attached tables. No MI composition data is reported for CPF-3 for 2001 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 1 Q, 30 and 3Q, as well as continued MI supply to DS-3F. MI is now supplied to the CPF-3 drillsites from both CPF-1 and CPF-2. The MMP of the blended CPF-1 and CPF-2 MI is estimated on a monthly average basis and is reported in the attached Table in the column for CPF-3. Prior to 2001, CPF-3 manufactured a small amount of MI for DS-3F with indigenous NGL's. Now, these CPF-3 indigenous NGL's are routed to the wet oil line for transport to CPF-1 and 2 for stabilization in the GKA sales oil, or else recovery as indigenous NGL for reuse within the EOR project. Date 1/10/2001 2/3/2001 2/17/2001 311 712001 4/21/2001 5/2/2001 511 712001 5/30/2001 611 612001 6/24/2001 711 1/2001 7/22/2001 8/6/2001 811 8/2OOl 9/7/2001 9/29/2001 1011 912001 1 0/29/2001 11/11/2001 11/23/2001 12/28/2001 Facility CPF-I CPF-1 CPF-1 CPF-1 CPF-1 CPF-1 CPF-1 CPF-1 CPF-I CPF-1 CPF-1 CPF-1 CPF-1 CPF-1 CPF-1 CPF-I CPF-I CPF-1 CPF-1 CPF-1 CPF-1 ATTACHMENT 7 KUPARUK RIVER UNIT MI COMPOSITION - CPF-1 Facility CPF-1 Sample Date 5/2/2001 Distribution: EOR ANALYTICAL REPORT KUPARUK LABORATORY PHILLIPS ALASKA INC. Sample Time. 15:52 16:13 Line Pressure 400 1400 Line Temp. N A N A SETCIM Tag FI-20GC F1-2lGC Flow (MSCFD) 17221 62999 16:OO 3800 N A Calculated 80220 Component MW 62.76 19.82 Density (Ibslscf) 37.22 Actual ENFL Rate Ideal BG Rate Rate (Ibld) 2844223.95 3408799.51 3 Rate (Molld) 4531 8.42 172005.7897 Rate (MMSCFD) 65362200.1 Target Blend Gas Ratio (lb BGRb EF) Actual Blend Ratio (From measured flow rates) Youngren MMP Actual MMP (Using Lab MI Composition) Calc MMP (Using Lab BGlENFL camp and rates) N2 C1 C2 C3 iC4 nC4 iC5 nC5 C6 C7 C8+ Total Moles Actual Gas Rate 3285552.81 C02 I 0.349 1.142 0.977 0.692 0.972 Solvent (Lab) (Mole %) 0.013 0.401 0.320 0.309 0.31 8 7.092 84.366 68.252 68.929 67.777 6.853 7.416 7.299 6.788 7.295 12.267 3.792 5.559 5.580 5.61 1 8.441 0.766 2.366 2.41 5 2.41 4 25.467 1.547 6.535 6.588 6.682 8.334 0.259 1.943 1.978 1.992 10.284 0.237 2.332 2.341 2.394 9.234 0.074 1.984 1.91 9 2.040 7.323 0.000 1.527 1.588 1.572 4.343 0.000 0.906 0.873 0.932 100.00 100.00 100.00 100.00 100.00 Lean Gas (Lab) (Mole %) MI (Target) (Mole %) MI (Lab) (Mole %) MI (Calc) (Mole %) ATTACHMENT 7 KUPARUK RIVER UNIT MI COMPOSITION - CPF-2 Date 1/9/2001 2/2/2001 2/17/2001 3/5/2001 3/17/2001 4/6/2001 4/21/2001 5/2/2001 511 712001 5/30/2001 611 612001 6/24/2001 711 1/2001 7/22/2001 8/6/2001 811 812001 9/7/2001 9/29/2001 1011 912001 1 0/29/2001 1111 112001 1 1 /23/2001 1 2/28/2001 Facility CPF-2 CPF-2 CPF-2 CPF-2 CPF-2 CPF-2 CPF-2 CPF-2 CPF-2 CPF-2 CPF-2 CPF-2 CPF-2 CPFB CPF-2 CPF-2 CPF-2 CPF-2 CPF-2 CPF-2 CPF-2 GPF-2 CPF-2 EOR ANALYTICAL REPORT KUPARUK LABORATORY PHILLIPS ALASKA INC. Facility Sample Date Distribution: Sample Time. Line Pressure Line Temp. SETCIM Tag Flow (MSCFD) Gas blend % FI-NGL-MSCFD Fl-P2-I 071 TOT 44898 153793 0.77 (Mole %) 0.1 54 0.01 9 8.338 2.499 5.31 7 8.886 29.769 9.530 12333 10.599 8.295 (Mole %) 0.889 0.282 82.163 8.422 4.792 0.867 1.871 0.291 0.277 0.091 0.055 C8+ 4.261 0.000 otal Moles 100.000 100.000 MW 65.65 20.43 Densitv (Ibslscf) 38.14 FI-P2-NGLV-SUM CALCULATED CALCULATED 243792 243784 45093 9 0.23 o ole YO) No sarnole No sample No sample No sample No sample No sample No sample No sample No sample No sample No sample Actual ENFL Rate Ideal BG Rate Actual Gas Rate Rate (Ibld) 7756525 58 10789872.42 10619376.77 Rate (Molld) 118152 63 528076.2904 Rate (MMSCFD) 200668990.4 sry Target Blend Ratio wl CPF2 gas only (Ib BGIlb EF) 1.39 Target Blend Ratlo corrected tor CPFI gas 1.37 Actual Blend Ratio (From measured flow rates) 1.37 Youngren MMP 3300.00 Actual MMP (Usma Lab MI Comoos~t~on) 3435 . - Cak MMP (Using Lab BGJENFL comp and rates) MWC7+ in Oil MMP (a) MMP (b) MMP (c) Note: Shaded areas are lab analysis values Non-shaded are calculated values I EOR ANALYTICAL REPORT KUPARUK LABORATORY PHILLIPS ALASKA INC. Facility Sample Date Distribution: Sample Time. Line Pressure Line Temp. SETCIM Tag Flow (MSCFD) Gas blend % FI-NGL-MSCFD Fl-P2-I 071 TOT 44898 153793 0.77 (Mole %) 0.1 54 0.01 9 8.338 2.499 5.31 7 8.886 29.769 9.530 12333 10.599 8.295 (Mole %) 0.889 0.282 82.163 8.422 4.792 0.867 1.871 0.291 0.277 0.091 0.055 C8+ 4.261 0.000 otal Moles 100.000 100.000 MW 65.65 20.43 Densitv (Ibslscf) 38.14 FI-P2-NGLV-SUM CALCULATED CALCULATED 243792 243784 45093 9 0.23 o ole YO) No sarnole No sample No sample No sample No sample No sample No sample No sample No sample No sample No sample Actual ENFL Rate Ideal BG Rate Actual Gas Rate Rate (Ibld) 7756525 58 10789872.42 10619376.77 Rate (Molld) 118152 63 528076.2904 Rate (MMSCFD) 200668990.4 sry Target Blend Ratio wl CPF2 gas only (Ib BGIlb EF) 1.39 Target Blend Ratlo corrected tor CPFI gas 1.37 Actual Blend Ratio (From measured flow rates) 1.37 Youngren MMP 3300.00 Actual MMP (Usma Lab MI Comoos~t~on) 3435 . - Cak MMP (Using Lab BGJENFL comp and rates) MWC7+ in Oil MMP (a) MMP (b) MMP (c) Note: Shaded areas are lab analysis values Non-shaded are calculated values I Attachment 8 Kuparuk River Unit Kuparuk River Oil Pool 2001 Annual Surveillance Report Development Plan for LSEOR Attachment 8 Kuparuk River Oil Pool 2001 Annual Surveillance Report LSEOR Development Plan During 2001, the Greater Kuparuk Area (GKA) averaged 29 MBPD of PBU NGL imports and 15 MBPD of indigenous NGLs for an annual average of 295 MMSCFD of Miscible lnjectant (MI) manufacture. Of the GKA manufactured MI volume, 252 MMSCFD was distributed to Kuparuk: 193 MMSCFD to LSEOR drillsites (including 3F), 30 MMSCFD to SSEOR and SSEORX drillsites, and 29 MMSCFD to LSEOR expansion drillsites. The remaining 43 MMSCFD was distributed to the GKA satellites. LSEOR expansion drillsites include drillsites: lC, 1 E, 3B, 3H, 30, and 3Q. Currently MI is injected into all of the 18 drillsites sanctioned under the LSEOR project and the CPF-3 EOR expansion drill site 3F. Further development of LSEOR expansion drillsites includes the installation a 12" pipeline loop to eliminate the existing MI pipeline hydraulic limitations which would delay future EOR Drill Site expansion pace to CPF-1 and CPF-3. This project will maintain adequate MI delivery pressure to CPF1 and CPF3 area drill sites. In 2002, plans are being developed to expand the Kuparuk EOR project to drill sites 3S, 3G, 1 B and the remaining patterns at 1 E.