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HomeMy WebLinkAbout2000 Kuparuk River PoolPHILLIPS Alaska, Inc. A Subsidiary of PHILLIPS PETROLEUM COMPANY John L. Hand Supervisor Greater Kuparuk Area Reservoir Planning AT0 1228 Phone 265-6036 Fax: 265-61 33 March 29, 2001 Ms. Julie Heusser, Commissioner Alaska Oil and Gas Conservation Commission 333 West 7'h Ave. Suite #I 00 Anchorage, Alaska 99501 -3539 Re: 2000 KRU Annual Surveillance Report Dear Ms. Heusser: 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 2000. The following is an outline of the information provided: a. A summary of the enhanced recovery project (Attachment 1). b. Voidage balance, by month, of produced and injected fluids, including low molecular weight hydrocarbons (Attachment 2, Attachment 3). c. Analysis of reservoir pressure surveys taken in 2000 (Attachment 4). d. A tabulation of both injection (Attachment 5) and production (Attachment 6) logs and surveys analyzed during 2000 from wells in the Kuparuk permit area. e. Composition of enriched gas injected during 2000 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) 265-1 694 x7535. Sincerely, ohn L. Hand 4KA Reservoir Planning Supervisor MAR 3 0 2001 Alaska Oii & Gas Cons. Commission Anchorage bcc: Central Files John Braden Bob Christensen John Hand Christine Lloyd Dan Kruse ATO-320 ATO-1276 NSK-69 ATO- 1228 ATO- 1230 ATO-1220 Attachment 1 Kuparuk River Unit Kuparuk River Oil Pool 2000 Annual Surveillance Report Summary of the Enhanced Recovery Project Attachment 1 Kuparuk River Oil Pool 2000 Annual Surveillance Report Summary of the Enhanced Recovery Project ENHANCEDRECOVERY Miscible water-alternating-gas (MWAG) is the predominant EOR process at the Kuparuk field. In March 2000, the Drill Site 1Y Miscible lnjectant (MI) jumper line was installed which allowed expansion of MI injection to Drill Sites 30, 3Q, and 1Q utilizing an incremental 35 MMSCFD of MI. Installation of the 1Y jumper also enabled (1) MI injection to increase to 20 MMSCFD at Drill Site 3F and (2) sufficient MI hole capacity in Kuparuk to utilize all Kuparuk lean gas production for MI manufacture. As a result, there is currently no Immiscible WAG (IWAG) injection at the Kuparuk field. In 2000, Kuparuk injected an average of 266 MMSCFD of MI. The Greater Kuparuk Area required an average 16 MBPD of indigenous NGLs and 30.7 MBPD of imported NGLs from Prudhoe Bay to manufacture 312 MMSCFD of MI. The incremental oil production resulting from MWAG at Kuparuk averaged 35 MBPD in 2000. MWAG Small Scale EOR (SSEOR and SSEORX) Drill Sites 1A, 1Y, 2X and 22 continued on MWAG during 2000. By year end 2000, over half of the ultimate incremental reserves attributed to MWAG had been recovered from these drill sites. Large Scale EOR (LSEOR) Since startup of LSEOR, Kuparuk's average MI injection rate has increased from 65 MMSCFD in 1996 to approximately 266 MMSCFD in 2000. The following drill sites are currently on MWAG injection: 2A, 28, 2C, 2D, 2F, 2G, 2H, 2K, 2M, 2T, 2U, 2V, 2W, 2X, 22, 1A, IF, 1G, 1Q, 1R, 1Y, 3F, 30, and 3Q. During 2000, MWAG injection commenced at Drill Sites 30, 3Q, and 1Q in March, Drill Site 2F in June, Drill Site 2D in August, and Drill Site 2G in October. CPFS EOR At year end 2000, three drill sites were on MWAG at CPF-3. Two additional CPF- 3 drill sites were converted to MWAG injection during 2000, 30 and 3Q, receiving a combined annual average 10 MMSCFD of MI. Drill Site 3F received an annual average 18 MMSCFD of MI. EOR Expansions The installation of the Drill Site 1Y MI jumper line in March 2000 enabled EOR expansions to Drill Sites 1Q, 30, and 3Q in 2Q00, averaging 30 MMSCFD of MI injection in 2000. Three additional LSEOR drill sites underwent EOR expansion starting 2Q00: 2D, 2F, and 2G at an average MI injection rate of 9 MMSCFD. IWAG After the installation of the Drill Site 1Y Jumper line in March 2000, there is no IWAG injection at the Kuparuk field. SSEOR and SSEORX a LSEOR and LSEORX 4 EOR Expansion DS in 2001 POTENTIAL FUTURE EXPANSION Kuparuk EOR Drillsites (SSEOR+LSEOR) Incremental EOR Oil Rate (Data Available from Jan 1993 through Dec 2000) Attachment 2 Kuparuk River Unit Kuparuk River Oil Pool 2000 Annual Surveillance Report Produced Fluid Volumes Attachment 2 Kuparuk Oil Pool 2000 Annual Reservoir Surveillance Report Produced Fluid Volumes OIL STB 6591 374 6272561 6324260 6273193 6243065 5778495 5981 652 61 04080 5883399 6245892 61 65866 6269371 GAS MSCF 10241 361 10189157 9697938 9747890 9430730 7875845 806531 3 8331 71 4 844791 9 91 89773 91 46207 9274038 WATER BBL 1741 3334 165351 67 16331383 161 841 46 15703056 14090409 14940088 15887877 15814712 17789393 1809901 9 1841 31 65 CUM OIL STB 1664932685 1671 205246 1677529506 1683802699 1690045764 1695824259 1701 80591 1 1707909991 1713793390 1720039282 17262051 48 1732474519 CUM GAS MSCF 18702371 47 1880426304 18901 24242 18998721 32 1909302862 19171 78707 1925244020 1933575734 1942023653 1951 21 3426 1960359633 1969633671 CUM WATER BBL 153201 6604 1548551 771 15648831 54 1581 067300 1596770356 161 0860765 1625800853 1641 688730 1657503442 1675292835 1693391 854 171 180501 9 2000 TOTAL 741 33208 Attachment 3 Kuparuk River Oil Pool 2000 Annual Surveillance Report Injected Fluid Volumes Attachment 3 Kuparuk Oil Pool 2000 Annual Reservoir Surveillance Report Injected Fluid Volumes WATER STB 24341334 21 422278 22597345 21 870639 21 41 01 40 19521316 2051 9055 21 61 401 1 21 229000 23469888 22464288 23638279 2000 TOTAL 264097573 GAS MSCF 0 0 0 0 0 0 0 0 0 0 0 0 0 NGLS MSCF 8043504 7795828 7325121 8350573 9097523 7788296 8298697 901 5747 8776075 7866173 7513917 7285680 971 571 34 CUM WATER MMSTB 8446.39 8467.81 8490.41 8512.28 8533.69 8553.21 8573.73 8595.34 861 6.57 8640.04 8662.51 8686.1 4 CUM GAS BCF 1528.24 1536.04 1543.36 1551.71 1560.81 1568.60 1576.90 1585.91 1594.69 1602.56 1610.07 1617.36 Attachment 4 Kuparuk River Oil Pool 2000 Annual Surveillance Report Reservoir Pressure Surveys STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION ANNUAL RESERVOIR PRESSURE REPORT - 2000 Phillips Alaska Inc. P. 0. Box 100360, Anchorage, AK 99510-0360 Kuparuk River Unit Unit or Lease Name 1 A-04 500292062100 WI 06/03/00 2000 1057 8185 155 3319 2700 0 3346 Well Name Field and Pool Kuparuk River Field l~atum Reference (011 Gravity /Gas Gravity Kuparuk River Oil Pool I -6200' SS Sand Date Tested 0.91 1 0.71 API Number Shut-in Time 0.G or WI Production and Test Data Final Shut-in Tubing Press. Production Rates (8blsIDay) (Mcfd) oil] water] Gas Pressure Test Data Liquid Gradient Tool Depth MD Wt. of Liquid Column Casing Press. Wt. of Gas Column Pressure at Datum B.H. Temp, Final Observed Pressure STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION ANNUAL RESERVOIR PRESSURE REPORT - 2000 IName of Operator (~ddress I Phillips Alaska Inc. P. 0. Box 100360, Anchorage, AK 9951 0-0360 Unit or Lease Name Kuparuk River Unit Well Name Field and Pool Kuparuk River Field Kuparuk River Oil Pool Sand Date Tested Datum Reference -6200' SS Production and Test Data Oil Gravity 0.91 API Number Shut-in Time Production Rates (BbisJDay) (Mcfd) oil1 water1 Gas Gas Gravlty 0.71 0.G or WI Liquid Gradient Final Shut-in Tubing Press. Pressure at Datum Pressure Test Data Wt. of Liquid Column Tool Depth MD Wt. of Gas Column 8.H. Temp. Casing Press. Final Observed Pressure STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION ANNUAL RESERVOIR PRESSURE REPORT - 2000 IName of Operator IAddress I Phillips Alaska Inc. i hereby certify that the foregoing is true and correct to the best of my knowledge. P. 0. Box 100360, Anchorage, AK 99510-0360 /signed Title GKA Reservoir Planning Supervisor Date Form 10-41 2 Submit In Duplicate Rev 7 1 80 Unit or Lease Name I Field and Pool KuDaruk River Field ]Datum Reference 1011 Gravitv Kuparuk River Unit 30-1 9 A 500292275300 Wi 0911 3/00 81 2900 9100 85 5350 0 1150 0 5241 30-22 A 500292262500 0 01/16/00 138 185 9833 160 1990 424 27 225 2286 Well Name Kuparuk River Oil Pool -6200' SS Sand Date Tested 0.91 1 0.71 API Number Shut-in Time 0. G or Wi Production and Test Data Final Shut-in Tubing Press. Production Rates (BbisIDay) (Mcfd) oil1 water1 Gas Casing Press. Pressure Test Data Pressure at Datum Tool Depth MD Wt. of Gas Column Liquid Gradient B.H. Temp. Wt. of Liquid Column Final Observed Pressure Attachment 5 Kuparuk River Oil Pool 2000 Annual Surveillance Report Injection Survey Data KUPARUK RIVER FIELD CONSERVATION ORDER 198B RULE 4 - INJECTIVITY PROFILES 2000 ANNUAL SUBMITTAL WELL API NUMBER 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 Follow up Sel. Single SZT SPINNER Sel. Single Sel. Single SZT Follow up SPINNER Follow up Sel. Single Follow up Sel. Single Sel. Single SZT SPINNER Follow up SPINNER Follow up Single Sel. Single Sel. Single Follow up SPINNER SZT Follow up SZT Follow up Sel. Single Sel. Single Single Follow up SZT SPINNER Follow up Follow up Sel. Single SZT SPINNER SPINNER Follow up Sel. Single Follow up Sel. Single KUPARUK RIVER FIELD CONSERVATION ORDER 198B RULE 4 - INJECTIVITY PROFILES 2000 ANNUAL SUBMITTAL WELL API DATE OF DATE OF INITIAL PROFILE/ INJECTION SURVEY DATA TYPE PROFILE/ SURVEY REASON FOR WELL ZONES PROFILE/ COMPLETION TAKING SURVEY INJECTION INJECTION BWPD / MSCFD NLJMBER NUMBER 50- Follow up Sel. Single A+C A SPINNER SPINNER Follow up Sel. Single A+C A SPINNER Follow up Single A+C A Follow up Sel. Single A+C A SPINNER Initial Single A+C A SPINNER SPINNER SPINNER SPINNER SPINNER SPINNER SPINNER SPINNER SPINNER SPINNER SPINNER Follow up Single A+C A Follow up Single A+C A Follow up Single AtC A Follow up Single A+C A Follow up Single A+C A Follow up Single AtC A Follow up Single A+C A Follow up Single A+C A Follow up Single A+C A Follow up Single A+C KUPARUK RIVER FIELD CONSERVATION ORDER 198B RULE 4 - INJECTIVITY PROFILES 2000 ANNUAL SUBMITTAL WELL API NUMBER NUMBER 50- DATE OF DATE OF INITIAL PROFILE/ INJECTION SURVEY DATA TYPE PROFILE/ SURVEY REASON FOR PROFILE/ SURVEY WELL COMPLETION ZONES TAKING INJECTION INJECTION BWPD / MSCFD SZT SZT SZT SZT SPINNER SZT SPINNER SPINNER SZT 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 Follow up Follow up Follow up Follow up Follow up Follow up Follow up Follow up Follow up Follow up SZT SZT SPINNER SPINNER SPINNER Follow up Follow up Follow up Follow up KUPARUK RIVER FIELD CONSERVATION ORDER 198B RULE 4 - INJECTIVITY PROFILES 2000 ANNUAL SUBMITTAL WELL API NUMBER NUMBER 50- DATE OF DATE OF INITIAL PROFILE/ INJECTION SURVEY DATA TYPE PROFILE/ SURVEY REASON FOR PROFILE/ SURVEY WELL COMPLETION ZONES TAKING INJECTION INJECTION BWPD / MSCFD SPINNER Follow up Sel. Single SZT Follow up Sel. Single Follow up Sel. Single Sel. Single Sel. Single SPINNER SPINNER SPINNER SZT SZT SPINNER SZT SPINNER SPINNER SPINNER Follow up Follow up Sel. Single Sel. Single Follow up Follow up Follow up Sel. Single Sel. Single Sel. Single Follow up Follow up Follow up Single Follow up Single Attachment 6 Kuparuk River Oil Pool 2000 Annual Surveillance Report Production Survey Data KUPARUK RIVER FIELD CONSERVATION ORDER 432 RULE 9 - PRODUCTIVITY PROFILES ANNUAL 2000 SUBMITTAL WELL API DATE OF NUMBER NUMBER INITIAL 50- PRODUCTION DATE OF PROFILE/ SURVEY 07/07/00 10/22/00 DATA TYPE REASON FOR PROFILE/ PROFILE/ SURVEY SURVEY SZT POST FRAC SPINNER POST PERF SPINNER SPINNER SPINNER SPINNER SPINNER SPINNER SPINNER SPINNER SPINNER SPINNER SZT OPEN C SAND A/C SPLITS A/C SPLITS A/C SPLITS A/C SPLITS POST FRAC A/C SPLITS A/C SPLITS A/C SPLITS A/C SPLITS OPEN C SAND WELL COMPLETION TYPE SEL SINGLE SINGLE SEL SINGLE SINGLE SEL SINGLE SINGLE SINGLE SEL SINGLE SEL SINGLE SEL SINGLE SEL SINGLE SEL SINGLE SEL SINGLE ZONES PROD- UCING A+C A A+C A A+C A A+C A A+C A A+C A A+C A A+C A A+C A A+C A A+C A A+C A A+C A PRODUCTION OIL BOPD 543 3 8 6 1019 10 277 277 306 306 517 207 212 3 4 6 5 6 5 590 590 1400 1000 646 200 7 5 7 5 1025 10 778 233 WATEE BWPD 887 372 985 0 616 616 1216 1216 690 276 787 126 1390 1390 3 15 3 15 4400 300 1600 496 2750 2750 3274 3 2 5552 3 12 GAS MSCFD 4310 1178 1021 10 298 298 1188 1188 1105 442 150 2 4 183 183 1325 1325 3000 1264 2020 626 1500 1500 1470 15 2427 145 SZT OPEN C SAND SEL SINGLE CLOSE C SAND SEL SINGLE OPEN C SAND SEL SINGLE A/C SPLITS SEL SINGLE A/C SPLITS SEL SINGLE A/C SPLITS SEL SINGLE SZT SZT SPINNER SPINNER SPINNER SPINNER SPINNER A/C SPLITS SINGLE A/C SPLITS SINGLE SPINNER SPINNER SZT SPINNER SPINNER A/C SPLITS SEL SINGLE POST FRAC SEL SINGLE OPEN C SAND SEL SINGLE A/C SPLITS SEL SINGLE A/C SPLITS SINGLE SPINNER A/C SPLITS SINGLE Attachment 7 Kuparuk River Oil Pool 2000 Annual Surveillance Report Miscible lnjectant Composition Date Facility 1/6/00 CPFl 1/21/00 CPFl 1/28/00 CPFl 2/9/00 CPFl 2/22/00 CPFl 3/22/00 CPFl 4/12/00 CPFl 4/12/00 CPFl 5/3/00 CPFl 6/2/00 CPFl 6/18/00 CPFl 7/9/00 CPFl 7/20/00 CPFl 8/13/00 CPFl 8/29/00 CPFl 9/30/00 CPFl 10/27/00 CPFl 11/19/00 CPFl 12/3/00 CPFl 12/16/00 CPFl 12/29/00 CPFl ATTACHMENT 7 KUPARUK RIVER UNIT MI COMPOSITION C13 MMPm 0.000 3029 0.000 3583 0.000 3651 0.000 2363 0.000 2997 0.000 3227 0.000 3750 0.000 3742 0.000 4021 0.000 3517 0.034 3212 0.013 3277 0.015 3369 0.013 3108 0.031 3220 0.017 3396 0.000 3271 0.000 3391 0.01 5 31 97 0.000 2929 0.000 3403 EOR ANALYTICAL REPORT KUPARUK LABORATORY PHILLIPS ALASKA INC. Facility CPF-1 Sample Date 9/30/00 Distribution: Sample Time. Line Pressure Line Temp. SETCIM Tag Flow (MSCFD) Component C02 N2 C1 C2 C3 iC4 nC4 iC5 nC5 C6 C7 C8+ 'otal Moles MW Density (Ibslscf) Rate (lbld) Rate (Molfd) 15:40 3800 N A Calculated 81901 Solvent (Lab) 1 Lean Gas (Lab) ) MI (Target) 1 MI (Lab) 1 MI (Calc) 61.96 19.75 28.75 28.51 37.00 Actual ENFL Rate Ideal BG Rate Actual Gas Rate 2870796.1 0 33751 03.658 3341 041.26 4633 1.58 1 70922.3601 (Mole %) Rate (MMSCFD) 64950496.83 Target Blend Gas Ratio (Ib BG/lb EF) 1.18 Actual Blend Ral (From measured flow rates) 1 .16 Youngren MMP 3300.00 Actual MMP (Using Lab MI Composition) 3397 Calc MMP (Using Lab BGIENFL comp and rates) 3277 0.357 1.225 1.040 0.668 1.038 (Mole %) (Mole %) I (Mole %) I (Mole %) Date Facility 1/6/00 CPF2 1/21/00 CPF2 2/10/00 CPF2 2/22/00 CPF2 3/22/00 CPF2 4/12/00 CPF2 5/3/00 CPF2 5/17/00 CPF2 6/2/00 CPF2 6/17/00 CPF2 7/9/00 CPF2 7/20/00 CPF2 8/13/00 CPF2 8/29/00 CPF2 9/10/00 CPF2 9/30/00 CPF2 1 O/27/OO CPF2 11/19/00 CPF2 1211 1/00 CPF2 12/29/00 CPF2 ATTACHMENT 7 KUPARUK RIVER UNIT MI COMPOSITION MMPm 2987 3544 3330 2793 2840 3628 31 97 3557 3480 31 62 3654 3518 2836 3560 3295 3639 3058 3306 3457 3386 EOR ANALYTICAL REPORT KUPARUK LABORATORY PHILLIPS ALASKA INC. Facility CPF-2 Sample Date 11/19/00 Distribution: Flow (MSCFD) Sample Time. Line Pressure Line Temp. (Mole %) 0.1 62 0.022 8.294 2.800 6.970 9.193 29.799 9.176 11.856 10.102 7.772 (Mole 8) 0.941 0.310 81.992 8.725 4.906 0.832 1.773 0.24.4 0.224 0.053 0.000 13:28 290 N A 1 (Mole %) 0.795 0.256 68.152 7.612 5.294 2.402 7.036 1.921 2.408 1.940 1.460 13:35 1460 84 MW 64.59 20.34 28.65 Density (ibslscf) 37.88 Actual ENFL Rate Ideal BG Rcte Actual Gps_Rate_ Rate (ib/d) 8059231 39 ail#$i%F!@ ~-~-s:.~?~+~~ Rate (Moltd) 124778 95 539653.947 Rate (MMS~FD) 205068499 Target Blend Ratio w/ CPF2 gas only (Ib BG/lb EF) 1.36 Target Bid Rotb cmecied for CPFl gas Actual Blend Ratio (From measured flow rates) Youngren MMP Actual MMP (Using Lab MI Composition) Calc MMP (Using Lab BGIENFL comp and MWC7+ in Oil MMP (a) MMP (b) MMP (c) 1.33 1.34 3300.00 3319 rates) %&3mg SX;SW---"+- -w- *+yggg~&& v -+" 285 -0 001 7054 -2661 8.5 16 Aixed BG (Lab) 13.20 3800 114 ole- %) No sample CPF-1 11-19-00 No sample No sample No sample No sample No sample No sample No sample No sample No sample No sample No sample Note: Shaded areas are lab analysis values Non-shaded are calculated values I FI-GD407 203596 1 00 :.I :* * ': ' Mixed BG (Calc) (Mole %) 1.014 0.336 82.751 8.363 4.555 0.661 0.786 6.930 : 5 6.970 '* 1.324 1.653 1.987 7;-;:l$qyc 0.249 0.245 2.459 ;: .2;023 , 0.233 0.226 1.911 - ' * ? 1,961 % 0.098 0.065 1.549 x;2c1A722d' 0.016 0.004 0.964 " , 8,728 0.000 0.000 100.000 100.000 1 100.000 100.000 CALCULATED 54243 0 27 , 0.22.~ .", : CPFl HPG (Mole %) FI-P2-NGLV-SUM CALCULATED 251 002 251012 - :. : 1 ,op A. MI (Lab) (Mole %) .-- .s3 I' MI (Calc) (Mole %) ATTACHMENT 7 KUPARUK RIVER UNIT MI COMPOSITION Date Facility C02 N2 C1 C2 C3 I-C4 N-C4 I-C5 N-C5 C6 C7 C8 C9 C10 C11 C12 C13 MMPm 1/6/00 CPF3 0.606 0.289 66.514 6.687 6.003 2.436 6.754 2.279 2.696 2.419 2.042 0.989 0.072 0.207 0.007 0.000 0.000 2818 1/21/00 CPF3 0.646 0.329 72.062 6.466 5.342 1.503 3.760 1.589 1.885 2.451 2.417 1.238 0.085 0.219 0.008 0.000 0.000 3546 2/3/00 CPF3 0.638 0.322 70.402 6.481 5.569 1.663 4.225 1.815 2.144 2.635 2.537 1.260 0.085 0.217 0.007 0.000 0.000 3275 2/17/00 CPF3 0.632 0.316 70.942 6.693 5.597 1.624 4.078 1.715 2.018 2.493 2.432 1.202 0.073 0.181 0.004 0.000 0.000 3410 Facility Sample Date Distribution: Sample Time. Line Pressure Line Temp. Flow (MSCFD) KDGS MW Corrected Flow Component Total Moles L EOR ANALYTICAL REPORT KUPARUK LABORATORY ARC0 ALASKA INC. CPF-3 2/2/00 Density (Ibslscf) 37.87 Actual ENFL Rate Ideal BG Rate Actual Gas Rate Rate (Ib/d) 559709.05 648246.3805 596101.79 Rate (Mol/d) 8602.63 3292 1.90463 Rate (MMSCFD) 12510323.76 Target Blend Gas Ratio (Ib BGIlb EF) 1.16 Actual Blend Rai (From measured flow rates) 1.07 Youngren MMP 3300.00 Actual MMP (Using Lab Mi Composition) 3274 Calc MMP (Using Lab BGIENFL compand rates) 31 06 0.465 1.116 0.981 0.638 0.972 MI (Lab) (Mole %) MI (Target) (Mole %) Solvent (Lab) (Mole %) MI (Calc) (Mole %) Lean Gas (Lab) (Mole %) Attachment 8 Kuparuk River Unit Kuparuk River Oil Pool 2000 Annual Surveillance Report Development Plan for LSEOR Attachment 8 Kuparuk River Oil Pool 2000Annual Surveillance Report LSEOR Development Plan The Greater Kuparuk Area (GKA) averaged 30.7 MBPD of PBU NGL imports and 16 MBPD of indigenous NGLs for an annual average of 31 2 MMSCFD of MI (miscible injectant). Of the GKA MI volume, 266 MMSCFD was distributed to Kuparuk: 215 MMSCFD to LSEOR drill sites and 51 MMSCFD to SSEORISSEORX drill sites. Currently, MI is injected into all of the 18 drill sites, including 3F, the CPF3 Expansion, sanctioned under the LSEOR project. The installation of the Drill Site 1Y MI jumper line in March 2000 allowed EOR expansion to DS IQ, 30 and 3Q in 2Q00. The three drill sites averaged 30 MMSCFD of MI injection in 2000. Three additional LSEOR drill sites underwent EOR expansion starting 2Q00: 2D, 2F, and 2G at an average MI injection rate of 9 MMSCFD.