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Home My WebLink AboutPoint McIntyre/Arco:Revised 1 993 Pfloduc:tioN eepol2ts POLttb mcintyQe Œl2cO aLas~a INC- , 0 If¿ Memorandum State of Alaska Oil and Gas Conservation Commission 3001 Porcupine Dr. Anchorage, AK 99501 Tel. 907-279- 1433 Fax 907 276-7542 January 21, 1998 To: File Jack Hartz ~ Fro: Subject: GPMA Water Cut Correction Revisions 4/93-4/95 The attached supporting documents show AOGCC reallocated oil and water production to the well s in the GPMA caused by water cut measurement errors during the period April 1993 through April 1995. The operators proposed a fiscal settlement of tax and royalty differences based on a one- month volumetric shift between pools producing to the Lisburne Production Center. The fiscal settlement method did not address individual wells nor were monthly adjustments made. The settlement entailed reporting the adjustment volume to a bogus API number during the month of January 1995. The volumes were both positive and negative depending on the type and magnitude of former allocation error. This type of revision is not appropriate for volumetric revisions and would have distorted well and pool production records without any supporting justification. The AOGCC reallocation was agreed by the parties and is documented in the October 2, 1996 letter from Kris Fuhr, ARCO Alaska, Inc. to Mister's Pilkinton, Johnston and Boyd of the DOR, AOGCC and DNR. Correction factor information was included in a letter dated October 23, 1996, Fuhr to Misters Pilkinton, Johnston and Boyd. Reallocation was done for each well as required in each pool. Original oil and water data were corrected using the ratio of monthly reported volume for the pool to monthly-corrected volume for the pool over each month of the affected period. Gas volumes remained unchanged and were transferred to the sheets to make a complete set of data for oil, water and gas volumes. The corrected volumes of oil and water w"ere placed into the AOGCC database on January 13, 1998. A sheet showing corrected mont1fly oil and water volumes are in each pool production file. The operator 10-405 forms have been replaced with the revision sheets. The reallocation was done by 1. Hartz and finalized in January 1998. Copy: Kris Fuhr, ARCO Alaska Kim Kerns, ARCO Alaska Bob Wilks, BP Exploration Mike Kotowski, DNR Dudley Platt, DOR ARCO Alaska, Inc. Post Office Box 100360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 ~~ ~~ Kris J. Fuhr S u perv isor GPMA Field Operations October 23 1996 J. E. Pilkinton Director, Oil & Gas Audit Division Alaska Department of Revenue 550 West 7th Avenue, Suite 570 Anchorage, AK 99501 D. W. Johnston Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 K.Boyd Alaska Department of Natural Resources 3601 C Street, Suite 1380 Anchorage, AK 99510 RECEIYED OC1 ~ \ \99b Dear Sirs: co(n\Ì1\~S\on '\ & Gas Cons. ' l\\asKa 01 J\nd'IOr2.ge AAI has continued to meet with representatives of the DOR, DNR and AOGCC to develop a settlement methodology with respect to the mis-allocations which occurred between April 1993 and April 1995. The errors stemmed from a watercut calculation error at Lisburne Drillsites L1 and L5 (April 1993 through April 1995) and an early time Point McIntyre watercut measurement error (October 1993 through December 1993). As we indicated in our October 2, 1996 correspondence we made excellent headway addressing these issues with the help of Mssrs. Kotowski, Platt and Hartz. Following the issuing of the October 2nd memo it became clear that some additional work was required with regard to the mis-allocation estimate developed for the Point McIntyre error. In the October 2, 1996 memo it was proposed to estimate the error by linearly increasing the watercut from 0.0% on October 14th to .2% field watercut at the end of November 1993. In subsequent conversations with Mr. Platt we re- evaluated this proposed algorithm to account for some anomalies which occurred in December 1993. A comprehensive review of the field notes during this period of time indicate that the problems with the Phase Dynamics watercut meters were corrected by November 26th. AAI also had a limited amount of Fisher titration data available through the November time frame. The Fisher titration data indicates that a minor amount of water was being produced on November 12th. Unfortunately we do not have Fisher titration data on well P1- ARCO Alaska. Inc. is a Subsidiary of AtlanticRichfieldCompany 04 which was perforated closer to the oil/water contact. Production data at the end of November indicates that PI-04 had a watercut of 2% which yields a daily water production rate of approximately 280 BWPD. It is clear that from a Point McIntyre field watercut perspective that P1-04 dominates the early time data. It is also evident that PI-04 produced a significant amount of water in November. The anomalies which occurred in December appear to be the result of bad tests which were not caught during the allocation process. Five wells exhibited a spike in water production in mid-December before re-establishing a normal trend. An assessment performed by an AAI allocations engineer indicate that the magnitude of the raw unallocated error is approximately 780 bbls; Based on the above information the following correction methodology was developed: 1) The field watercut for Point McIntyre during the month of October was held at 0 %. We used this approach/rationale to account for the anomalies in December. 2) The field watercut was then linearly ramped from 0.0% to .24% at the end of November. We believe that the field watercut data was correct at the end of this month. In our opinion the water production from PI-04 would closely approximate the water volume calculated using this approach. Attachment 1 is the new Point McIntyre corrected theoretical production for October and November 1993 utilizing the above methodology. This refined estimate of Point McIntyre production was then input into our field allocation model which contained the correction methodology for the Lisburne Drillsite L1 and L5 error correction. Attachment 2 is a summary of the corrected allocated production data for each field (oil and water). Finally, Attachment 3 represents the differential volumes of oil and water which resulted from our correction analysis. The volumes shown on Attachment 3 will be used to prepare schedular spreadsheets to calculate the Severance and Royalty implications of these corrections. The dollar values calculated in the spreadsheets, including 11% compounded interest, win be AAI's settlement amount with respect to the subject errors. As noted in the October 2, 1996 memo AAI intends to prepare a settlement payment based on the incremental volumes identified in Attachment 3. Templates of our schedulars have also been sent to BPX and Exxon for their use. AAI has passed on to both BPX and Exxon the States desire for the owners to use a consistent means to resolve our Royalty and Severance obligations. This infomation has been passed on to BPX and Exxon for their consideration. We are still planning to correct one historical monthly tape to correct the reservoir volume issue and to correctly re-allocate the owners volumes within the AAI database. As requested by the AOGCC Attachment 4 has been created to document a monthly reservoir correction factor (both oil and water) to be used by the AOGCC. These correction factors can be used to correct individual well production volumes on a monthly basis within the AOGCC database. ARca Alaska. Inc. is a Subsidiary of AtlanticRichfieldCompany It is my understanding that Mssrs. Kotowski, Platt and Hartz support the settlement methodology outlined in the October 2, 1996 memo utilizing the Point McIntyre correction presented above. Please indicate your acceptance of our resolution strategy by signing and returning a copy of this memo. Once AAI receives concurrence from the DaRt DNR and the AOGCC we will notify BPX and Exxon. We will then proceed with finalizing the settlement of this issue. since~lY;/,)' . '.,J/ '" - ~... / '(....... I Kris Fuhr Operations Support Supervisor GPMA Area, ARCO Alaska Ine J.E. Pilkinton DOR cc: J. Leone D. Coleman J. Hartz R. W. Janes M. Kotowski R. Provan D. Platt M. Hay M. Bandy D.W. Johnston AOGCC K.Boyd DNR AAI Exxon AOGCC BPX DNR BPX OOR AAI AAI RECE1VED OCT J 1 1995 Alaska Oil & Gas Cons. CcrnfT',:sslon Ar.chcmgo ARCO Alaska, Inc. is a Subsidiary of AtlanticRichfieldCompany ._-_.__...,.-._._-,~"..-.., - - ,-. - --'-' --..-.. .-.". ..._-_.....'---...-".._~.- -- " RRCO RLRSKR FRX NO.: 9072634894 01-21-98 01 :53P It is my understanding that Mssrs. Kotowski, Platt and Hartz support the settlement methodology outlined in the October 2, 1996 memo utilizing the Point McIntyre correction presented above. Please indicate your acceptance of our resolution strategy by signing and returning a copy of this memo. Once AA[ receives concurrence from the OOR, DNR and the AOGCC we will notify BPX and Exxon.. We will then proceed with finalizing the settlement of this issue. Sincerely, / " . ./ " .- - - .. I ;¿¿ Krís Fuhr Operations Support Supervisor GPMA Area, ARCa Alaska Ine J.E. Pilkinton DOR cc: J. Leone D. Coleman ~es M. Kotowski R. Provan D. Platt M.Hay M. Bandy AAI Exxon AOGCC BPX DNR BPX OOR AAI AAI ARea AI4Ska. Inç. is a Subsidiary of At'4l1ticRichfieldCompM)' --.._- K. Boyd DNR RECEIVED OCT 3 1 199G aska Oil & Gas Cons. Cornml5slon AI Anctmrage P.04 rRO " RRCO RLRSKR FRX NO.: 9072634894 01-21-98 01:53P P.05 It is my understanding that Mssrs. Kotowski~ Platt and Hartz support the ::;~ttlement methodology outlined in the October 2, 1996 memo utilizing the Point McIntyre correction presented above. Please indicate your acceptance of our resolution strategy by signing and returning a copy of this memo. Once AAI receives concurrence from the DOR, DNR and the Acx;CC we will notify BPX and Exxon. We will then proceed with finalizing the settlement of this issue. ~C?l:G /~ Kris Fuhr Operations Support Supervisor GþMA Area, ARCO Alaska Inc ~~~ AU.""" þt/j DOR S~~1FCr .,-ø ""t.t.. ¿JIÞÞr~'U H.$" N" ,$",..,r AI""'H'~ pi'" cc J. Leone D. Coleman J. ,Hartz R. W.Janes M. Kotowski R. Provan D. Platt M.Hay M. Bandy D.W. Johnston AOGCC K Boyd DNR AAI Exxon AOGCC SPX DNR BPX DOR AAI AAI ARCO ^Iaska. Inc. is a SlIb:;idiary of AtlantiçRiçhfilllclCol11p;U1)' 7"$íTÆ~æ @w ÆX(~~2~~ DEPARTMENT OF NATURAL RESOURCES DIVISION Of: OIL AND GAS December 6, 1996 Mr. Kris J. f'uhr, Supervisor GPMA Field Operations ARCa Alaska, Inc. P.O. Box 100360 Anchorage, AK 99510·0360 01-21-98 01152P P.02 TONY KNOWLES, GOVERNOR 3601 "e" STREET. SUItE /380 ANCHORAGE, ALASKA 99503-5948 PHONE.. (907) 269.8784 Ref: GPMA Watercut Correction, your letters dated Oct. 23. 1996 & Dee 2, 1996 Dear Mr. Fuhr: My staff and I have reviewed th~ volumes and the allocation of these volumes listed in your October 23, 1996 tetter and the financial settlement methodology to account for these volumes which was included in your December 2, 1996 Jetter. The Department of Natural Resources desires that the three co~owners agree to the revised volume amounts and allocations and agree to account for these revised volumes by aU using the same methodology. Therefore, we will accept the revised volume allocations and the methodology to account for these revised volumes after authorized representatives of ARCa Alaska, Ine, Exxon, Inc, and BP Exploration, Inc. have signed the statement below. Sincerely. ~ KeIUleth A. Boyd Director L TKFLlLS "'" FRO"' ~1t&1rŒ @ W F~"['Æ'~3~~ DEPARTMENT OF NATURAL RESOURCES DIVISION OF OIL AND GAS January 8, 1997 Mr. Kris J. Fuhr, Supervisor GPMA Field Operations ARCQ Alaska, Inc. P.O. Bob 100360 Anchol:'age, AK 99510-0360 Ref: GPMA Watercut Correction, our letter dated Occ. 6, 1996 Dear Mr Fuhr: 01-21-98 01:52P P.03 TONY KNOWLES, GOVl!!ffNOR )601 wC" S1'REET. SUITE J 380 ANCHORAGE, AlASKA 99503&5948 PHONE: (907) 269-8784 ~ ~ I ~ I I 1 Representatives of ARCO Ala.ska, Inc., Exxon, Inc., and BP Exploration, Inc., have approved the GPMA volumes and the allocation of these volumes that were listed in your October 23, 1996 Jetter and the financial settlement methodology to account for these volumes which was included in your December 2, 1996 letter. Therefore, the Department of Natural Resources accepts the revised GPMA volume allocations and the methodology to account for these revised volumes. Sincel:'ely, ~ Kenneth A. Boyd Director cc: Sent via Fa.x FAX Number J.Leone M.Hay M. Bandy D. Coleman C. Crawford R. W. Janes P. Mers J. Hartz J. Pilkinton M. Kotowski J. Stouffer AAI AAI AAI Exxon Exxon BPX BPX AOGCC DOR ONR DNR (907) 263·4894 (907) 265-1566 (907) 265-1306 (907) 564-3789 (713) 680-5299 (907) 564-4680 (907) 564-4094 (907) 276-7542 (907) 278-5026 (907) 562-3852 (907) 562-5269 LTKU.2LS .~ orn'éd ð,." rr~.....,~....]4"o,", 1"\.".,......, )o'¡ '1 c.-h I I I I I ! I I I ~ ¡;: ~i ~ ~\: f\ I ~ !G ~; &.1 M t] ~' ~ Inclusive DS-P1 WC Changes ATTACHMENT 3 GPMA WATER CUT CORRECTION DATA April 1993 - April 1995 Revision 10/96 DIFFERENTIAL CORRECTED ALLOCATED PRODUCTION DATA PT. MciNTYRE I NIAKUK I LISBURNE I NPB I WB I WEST NK MONTH OIL WATER Oil WATER Oil WATER Oil WATER Oil WATER Oil WATER 04/93 0 0 0 0 -491 -110 0 0 491 110 0 0 05/93 0 0 0 0 -1,165 -94 0 0 1,165 94 0 0 06/93 0 0 0 0 -359 -12 0 0 359 12 0 0 07/93 0 0 0 0 -1,189 -82 0 0 1,189 82 0 0 08193 0 0 0 0 -1,065 -61 0 0 1,065 61 0 0 09/93 0 0 0 0 -688 -36 0 0 688 36 0 0 10/93 8,644 -14,582 0 0 -7,967 14.439 -396 37 -281 106 0 0 11/93 10.454 -28,396 0 0 -8,987 28,021 -1,001 219 -466 156 0 0 12/93 4,952 -639 0 0 -5,084 469 117 91 16 79 0 0 01/94 6,700 -1,114 0 0 -5,700 200 -1,023 863 22 50 0 0 02/94 8,639 -1,576 0 0 -7,138 398 -1,577 1,120 76 58 0 0 03194 10,733 -1,650 0 0 -8,849 185 -1,998 1,384 114 81 0 0 04/94 10,575 -1,963 1,058 -37 -9,664 520 -2,085 1.416 117 64 0 0 05/94 11,619 -2,416 2,102 -41 -10,589 397 -3,232 2,013 100 46 0 0 06/94 13,040 -3,076 2,238 -291 -11,133 924 -4,208 2,371 63 72 0 0 07/94 12,206 -4,182 2,161 -163 -10,543 1,785 -3,904 2,489 80 71 0 0 08/94 12,756 -6,234 1,719 -74 -9,986 3,554 -4,569 2,712 80 42 0 0 09/94 8,930 -1,140 1,155 -449 -9,891 1.422 -203 116 8 51 0 0 1 0/94 10,765 -1,110 905 -1,097 -11,570 2,077 -108 63 8 68 0 0 11/94 14,334 -2,656 1,069 -1,806 -8,221 352 -7,181 4,111 0 0 0 0 12/94 18,354 -4,722 943 -1,177 -7,282 -612 -12,122 6.474 106 36 0 0 01/95 16,610 -3,898 1,967 -3,048 -5,835 100 -12,771 6,839 29 6 0 0 02/95 15,457 -4,347 2,159 -3,086 -6,074 177 -11,542 7,257 0 0 0 0 03195 19,683 -8,254 2,440 -1,450 -8,418 269 -13,704 9,435 0 0 0 0 04/95 19,064 -8,496 2,890 -1,697 -7,201 610 -14,822 9,590 0 0 69 -7 233,515 -100,451 22,805 -14,418 -165,086 54,892 -96,331 58,603 5,028 1,382 69 -7 ~ J¡ .it J., 1 t ~ ~ 1 1 t J- -/oot{1/ -1''lA'f ~ "2-3/770 2.333~ -/t.f'flf:. 1 ? -('''t:Þ/ ~t{~7f, St>'f1 1318 . -; \. ~ " -c "U Ø> ::T 0 X 0 III .. ::> - CD I .. ;::¡: ~ " ïl t\) 'í' x z 0 CD " -...J 0> -...J ...... " -c 0 " 0 Ø> ::T P 0 a x 0 3 CD .. ::> CD .. --j -....1) 'Vol ( - ~ \AI ~ Pi r ~ C?4--5 ¡r~d .þ ÆPr t£. 's t>2.-1-#1f:#*if _ 3s ðÞl.- J(JM. {'¥'J ç ¿'Cft~ $û..b~cfJ 7/1/97 Page 7 of 7 Inclusive DS-P1 WC Changes ATTACHMENT 4 GPMA WATER CUT CORRECTION DATA Monthly Correction Factors Point Mcintyre Niakuk Lisburne North Prudhoe Bay West Beach W. Niakuk Oil Water Oil Water Oil Water Oil Water Oil Water Oil Water MONTH 04/93 .9994 .9996 1.0075 1.0751 05/93 .9985 .9997 1.0095 1.0731 06193 .9982 .9998 1.0113 1.0670 07/93 .9984 .9996 1.0096 1.0659 08193 .9986 .9997 1. 0 106 1.0627 09/93 .9990 .9998 1.0101 1.0652 10/93 1.0061 .0 .9872 1. 1 049 .9964 1.1741 .9955 1.1741 11/93 1.0036 .1441 .9851 1.1498 .9939 1.2369 .9935 1.2369 12/93 1.0015 .9704 .9917 1.0022 1.0008 1.0782 1.0002 1.0782 01/94 1 .0022 .9648 .9911 1.0010 .9881 1.0720 1.0005 1.0720 02/94 1.0033 .9531 .9880 1.0020 .9789 1.0590 1.0014 1.0590 03194 1.0036 .9532 .9857 1.0007 .9642 1.0591 1.0017 1.0591 04/94 1.0041 .9503 1.0041 .9503 .9844 1.0019 .9582 1.0559 1.0021 1.0559 05194 1.0042 .9485 1.0042 .9485 .9831 1.0014 .9462 1.0539 1.0024 1.0539 06/94 1.0047 .9474 1.0047 .9474 .9808 1.0036 .9422 1.0527 1.0015 1.0527 07/94 1.0045 .9484 1.0045 .9484 .9797 1.0070 .9343 1.0538 1.0018 1.0538 08/94 1.0042 .9547 1 .0042 .9547 .9811 1.0196 .9324 1.0608 1.0022 1.0608 09/94 1.0026 .9497 1.0026 .9497 .9825 1.0069 .9368 1.0553 1.0002 1.0553 10/94 1.0028 .9515 1.0028 .9515 .9799 1.0084 .6310 1.0573 1.0002 1.0573 11/94 1.0041 .9463 1.0041 .9463 .9846 1.0017 .9280 1.0515 12/94 1.0044 .9457 1.0044 .9457 .9869 .9969 .9135 1.0508 1.0026 1.0508 01/95 1.0042 .9440 1.0042 .9440 .9892 1.0006 .9007 1.0489 1.0029 1.0489 02/95 1.0042 .9494 1.0042 .9494 .9876 1.0010 .8856 1.0549 03195 1.0049 .9498 1.0049 .9498 .9840 1.0010 .8706 1.0554 04/95 1.0048 .9498 1.0048 .9498 .9854 1.0029 .8219 1.0553 1.0048 .9498 ~ III en Š g QCI ~m ~IU g~, ~~ c- § I <:) ;;:0 n m --{ () CN rT1 <.D < <.D ï1 Page 8 of 8 a:. CJ Inclusive DS-P1 WC Changes ATTACHMENT 2 GPMA WATER CUT CORRECTION DATA April 1993 - April 1995 Revision 10/96 '! ~;7 /.$ c~ CORRECTED ALLOCATED PRODUCTION DATA TOTAL CORRECTED PT. MciNTYRE I NIAKUK I LISBURNE I NPB I WB I WEST NK ALLOCATED MONTH Oil WATER OIL WATER Oil WATER all WATER OIL WATER all WATER all WATER 04/93 0 0 0 0 848,826 273,097 0 0 66,109 1,577 0 0 914,935 274,674 05/93 0 0 0 0 797,845 286,759 0 0 123,112 1,381 0 0 920,957 288,140 06/93 0 0 0 0 195,280 61,833 0 0 32,233 196 0 0 227,513 62,029 07/93 0 0 0 0 763,368 230,321 0 0 125,026 1,332 0 0 888,394 231,653 08/93 0 0 0 0 748.002 221,314 0 0 101.467 1,029 0 0 849.469 222,343 09/93 0 0 0 0 671,506 207,114 0 0 68,787 584 0 0 740,293 207,698 10/93 1,419,578 0 0 0 615,071 152.065 108,107 248 62,909 717 0 0 2,205,665 153,030 11/93 2,918,775 4.780 0 0 593.447 215,037 163,048 1,143 71,667 813 0 0 3,746,937 221,773 12/93 3,204,706 20,918 0 0 611,091 213,006 147,280 1,261 72,983 1,085 0 0 4,036,059 236,270 01/94 3,078,874 30,529 0 0 633,919 206,140 84,711 12,849 43,070 748 0 0 3,840,575 250,267 02/94 2,653,496 32,053 0 0 586,023 203,121 73,116 20,097 52,718 1,047 0 0 3,365,353 256,318 03/94 3,006,569 33,619 0 0 611,034 259,880 53,867 24,790 68,665 1,457 0 0 3,740,135 319,746 04/94 2,607,400 37,546 260,789 715 609,721 273,344 47,807 26,745 54,629 1,214 0 0 3,580,345 339,564 05/94 2,745,920 44,521 496,683 753 616,833 279,887 56,899 39,355 42,755 900 0 0 3,959,090 365,417 06194 2.799,030 55,406 480,444 5,244 569.372 254,562 68,548 47,389 43,375 1,431 0 0 3,960,769 364,032 07/94 2.749,189 76,876 486,623 2,997 507,906 255,244 55.489 48,758 44,896 1,385 0 0 3,844,103 385,260 08/94 3,039,872 131.371 409,583 1,568 517,631 184,883 63,002 47,342 37,106 729 0 0 4,067,194 365,893 09/94 3,481,354 21,552 450,444 8,493 556,566 207,984 3,001 2,219 39,908 981 0 0 4,531,274 241,229 10/94 3,832,416 21.803 322,152 21,536 563,067 247,896 185 1,169 44,651 1,247 0 0 4,762,471 293,650 11/94 3,515,100 46,834 262,057 31,845 524,802 205,767 92,575 83,979 0 0 0 0 4,394,533 368,424 12/94 4,174,778 82,271 214,433 20,505 549,224 197,074 127,977 133,908 40,375 744 0 0 5,106,788 434,503 01/95 3.966,766 65,660 469,797 51,346 533,984 156,009 115,883 146,847 9,953 137 0 0 5,096,383 420,000 02/95 3,664,959 81,618 511,901 57,943 482,586 182.022 89,376 139,394 0 0 0 0 4,748,822 460,976 03/95 4,038,018 156,254 500,532 27,460 517,434 268,756 92,227 179,847 0 0 0 0 5,148,210 632,317 04/95 4,028,334 160,750 610,760 32,106 487,369 214,536 68.412 182,917 0 0 14,506 140 5,209,381 590.449 *" 60,925,134 1,104.361 5.476,197 262.509 14,711.910 5,457,651 1,511,508 1,140,260 1,246,393 20,735 l> 0 T I t2- - '3 ð..-/ -t ~ ~ ~- +1 -J d~~ ~~~ D~~?? d;:;J: Vr ~ I/'<D -*-~J f,.Ms ~ ~ ckJc ~ s-..~.:.... ",f 14 ....~ ~ Cètþ fl< +/- "-~ .-.P. :7hft-~- <fz.f?8 / dV 4j~ ./' . "V / r;) 14,506 Q 140 83,885,648 7,985,655 eo f! ,~-- \0 \'11 '" Page 6 of 7 t . The results of the Point McIntyre DS-Pl correction were then inserted into the field wide Ll and L5 correction spreadsheets. After discussions with all groups involved we felt it was appropriate to resolve both the Ll/L5 and Point McIntyre DS-Pl errors simultaneously. Once the Point McIntyre corrections were inserted new fie1dwide allocated production totals were calculated. Attachment 4 is the Corrected Allocated Production (inclusive of the Point McIntyre DS-Pl error correction). Attachment 5 is the new Differential Corrected Allocated Production which also includes the Point Mcintyre correction. Pending final approval the incremental volumes identified in Attachment 5 are the volumes used for Severance and Royalty corrections. These identified incremental volumes will also be used to correct the individual reservoir production volumes. ITEM 3) - Royalty and Severance Resolution - AAI proposes the Severance and Royalty obligations which resulted from the subject mis-allocations be handled by a schedular spreadsheet settlement. In the July 16, 1996 memo, we proposed to handle the Settlement through the nomination process only, with the caveat that we would insure that the State revenues stayed whole based on the price received at the time the volumes were moved; when compared to the price received during the time frame in question. This approach is no longer practical in that North Prudhoe Bay is not currently capable of producing the volume required to make up its debit. Therefor~º~_~PP~a.:1's.._t,bªtJh~_mº§t~)~:¡?_~_4_~~t:lt m~(1.!ls.._ tQ.§~J;tl~.ºyxJi!!(1!!s.i.ªLºþ.!!ga~ig!ls_i~!<:>.. pr~Pélre.~pr~élcisl1~et§.gºç\lIl1gnting thej!:!11?_ª.ct.of.the_re:::allQfª!iol},Þ-yJieIa oy Il1QD!Þ' From earlier discussions we feel that adding an additional 11 %êömpounded interest to the amounts owed is also a normal practice. I have sent electronic files to Mssrs Kotowski and Platt for their review based on the incremental oil volumes presented in Attachment 5. The files sent reflect an estimate of AAI's obligation only. We have had discussions with BPX and Exxon concerning the financial resolution of this issue. I believe we have a general consensus on the approach. It is AAI's intent to furnish each of the other owners with a template of our schedulars for their use. Assuming we receive concurrence from the State it would be our desire to issue a one time settlement payment before year end. It has been impressed on me the States desire that all of the owners use a consistent approach to resolve our Severance and Royalty issues with respect to the above settlement. AAI has passed this information on to our co-owners for their consideration. AAI will provide whatever assistance we can to minimize the admistrative burdens within BPX and Exxon to complete this settlement. With respect to the reservoir volumes it is our intent to modify one historical tape. A trial run through our accounting system has shown that we can create one fictitious well per reservoir. The fictitious wells will be used to move the field total correction volumes. Unfortunately our current accounting system is not flexible enough to allow us to correct the allocations on a per well basis within any reasonable time frame. We sincerely believe that any attempt to correct the error to this detail will require years to complete. After much discussion we felt it would be acceptable to live with this one time anomaly. This anomaly will be well documented hopefully avoiding any future confusion. To assist the AOGCC AAI will furnish monthly correct~<:>!l_fil_Ç.!º!~for oil andwélter for~ªshE<:>.<:>l. Mr. Hartz indicates tI1at newiIIuse this information tò mõêfify A:OGCC's database as appropriate. ARca Alaska, Inc. is a Subsidiary of AtlanticRichfieldCompany ï' . ARCO Alaska, Inc. Post Office Box 100360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 ..,~ ~". Kris J. Fuhr Supervisor GPMA Field Operations October 2, 1996 J. E. Pilkinton Director, Oil & Gas Audit Division Alaska Department of Revenue 550 West 7th Avenue, Suite 570 Anchorage, AK 99501 D. W. Johnston Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 K.Boyd Alaska Department of Natural Resources 3601 C Street, Suite 1380 Anchorage, AK 99510 Dear Sirs: As you know we are currently working to resolve a mis-allocation for the GPMA area which spanned from April 1993 to April 1995. This mis-allocation was the result of a watercut calculation error stemming from our Lisburne Drillsites L1 and L5. A memo was issued on July 16, 1996 discussing a proposed methodology to assess the volumetric error. In addition, a proposal was made with respect to a severance tax and royalty resolution. We also have the need to resolve an early time Point McIntyre DS-P1 watercut error. This issue had also been brought to the States attention in earlier State Allocation meetings. AAI met with Representatives of the OOR (Platt), the DNR (Kotowski) and the AOGCC (Hartz) on September 26, 1996 to progress the resolution of these errors. During our meeting our discussions were centered on 3 topics: 1) A rigorous review of the methodology used to assess the mis-allocated volume estimation resulting from the watercut error at DS's L1 and L5. 2) Discussion of the methodology to be used to correct an additional watercut error stemming from Point McIntyre DS-P1 from October 1993 through November 1993. ARca Alaska. Inc. is a Subsidiary of AtlanticRichfieldCompany Please review these attachments and the AAI provided Severance and Royalty schedulars. I will contact your groups within the next 2 weeks to determine if the above approach will be acceptable to the State. If you have any questions or concerns in the interim please contact me at-2'5b-6488. 'Z6~~ Sincerely, " ,< / ,;/'>/) 'L-,"-:' I ,,/..::..... - ;;;-----,L /- / . {-../\._ Kris Fuhr Operations Support Supervisor GPMA Area, ARCO Alaska Inc cc: A. N. Bo1ea J. Leone D. Coleman ,ttJrHartz ' R. W. Janes M. Kotowski R. Provan D. Platt M.Hay M. Bandy P. Bly BPX (w/o attachments) AAl Exxon AOGCC BPX DNR BPX OOR AAl AAl BPX RECEIVED OCT 0 '7 1996 Alaska on & Gas Cons. Commission Ancho!"Llg9 ARca Alaska. Inc. is a Subsidiary of AtlanticRichfieldCompany 1 3) Determine an acceptable method to resolve the resultant royalty and severance issues. In addition, the method would also require the correction of the individual reservoir oil production volumes. The resolution of these topics is discussed below. ITEM 1) - L1 and L5 Correction - Our step by step review began with the correction of each months theoretical oil and water production from L1 and L5. Once the method to assess the mathematical watercut correction was understood we progressed to the GPMA wide re-allocation. We progressed through a detailed review of the complete December 1994 re-allocation process to insure a general acceptance by all parties with respect to the methodology. As part of our review we also estimated the impact of the mis-allocation on NGL allocations and total gas dispositions. Packets were provided to Mssrs Kotowski, Hartz and Platt documenting each phase of the analysis. Attachments 1 and 2 document the results of the L1 and L5 proposed corrections. Attachment 1 presents our recommended Corrected Allocated Production Data throughout the time period in question by producing reservoir. Attachment 2 presents the Differential Production Data from the original allocated production when compared to the proposed corrected allocated production. The Differential Production Data will be used to assess the Royalty and Severance issues. It is my understanding that all groups have accepted this volumetric correction methodology. ITEM 2 - Point McIntyre DS-P1 Correction - This issue surrounds the watercut calculation during the first 2 months of Point McIntyre production. AAI discovered through rigorous field testing that the Phase Dynamics watercut meter was indicating an approximately 1.5% - 2.5% watercut when in fact there was essentially no water production. AAI's Field Engineering personnel worked closely with the Phase Dynamics engineering people to correct this error. The error was corrected by the installation of an oil adjustment factor (to correct for the compositional differences in the crude used for initial calibration versus Pt Mac crude) and hardware modifications to the meters themselves to make them more sensitive. Due to the nature of this error a definitive factor to correct the error cannot be developed. This error was not a strictly mathematical error which could be reversed as in the L1 and L5 case. The estimation of the oil volume which needs to be allocated to Point McIntyre during this time period is somewhat subjective. The approach used was to assume a 0.0% watercut on October 14, 1993. The watercut was then linearly increased until the end of November. The daily Point McIntyre watercuts beginning in December appear to be correct. The methodology used to estimate the Point McIntyre DS-P1 mis-allocated volumes was identical with the L1 and L5 drillsite corrections once the linearly increasing watercuts were inserted. Attachment 3 is the Point McIntyre DS-P1 drillsite re- allocation based on the manually input watercuts. The results of this analysis demonstrated an un-allocated error of 13,241 bb1s of oil in October and 26,495 bbls of oil in November. Following our fie1dwide allocation methodology results in 4804 bbls of oil in October and 5901 bb1s of oil in November being incrementally re-allocated to Point McIntyre. ARca Alaska. Inc. is a Subsidiary of AtlanticRichfieldCompany ATTACHMENT 2 GPMA WATER CUT CORRECTION DATA 8/96 REVISION w/o PI Mc DS-P1 corrEtion DIFFERENTIAL CORRECTED ALLOCATED PRODUCTION DATA PT. MciNTYRE I NIAKUK I LISBURNE I NPB I WB I WEST NK MONTH OIL WATER OIL WATER OIL WATER OIL WATER OIL WATER OIL WATER 04/93 0 0 0 0 -491 -110 0 0 491 110 0 0 05193 0 0 0 0 -1,165 ·94 0 0 1,165 94 0 0 06193 0 0 0 0 -359 -12 0 0 359 12 0 0 07/93 0 0 0 0 -1,189 -82 0 0 1,189 82 0 0 08/93 0 0 0 0 -1,065 -61 0 0 1,065 61 0 0 09/93 0 0 0 0 -688 ·36 0 0 688 36 0 0 10/93 3,798 -582 0 0 -4,175 528 270 14 107 41 0 0 11/93 4,546 -920 0 0 -4,753 793 162 74 45 53 0 0 12/93 4,952 -639 0 0 -5,084 469 117 91 16 79 0 0 01/94 6,700 -1,114 0 0 -5,700 200 -1,023 863 22 50 0 0 02/94 8,639 -1,576 0 0 -7,138 398 -1,577 1,120 76 58 0 0 03194 10,733 -1,650 0 0 -8,849 185 -1,998 1,384 114 81 0 0 04/94 10,575 -1,963 1,058 -37 -9,664 520 -2,085 1,416 117 64 0 0 05194 11,619 -2,416 2,102 -41 -10,589 397 -3,232 2,013 100 46 0 0 06194 13,040 -3,076 2,238 -291 -11,133 924 -4,208 2,371 63 72 0 0 07/94 12,206 -4,182 2,161 -163 -10,543 1,785 -3,904 2,489 80 71 0 0 08194 12,756 -6,234 1,719 -74 -9,986 3,554 -4,569 2,712 80 42 0 0 09/94 8,930 -1,140 1,155 -449 -9,891 1,422 -203 116 8 51 0 0 10/94 10,765 -1,110 905 -1,097 -11,570 2,077 -108 63 8 68 0 0 11/94 14,334 -2,656 1,069 -1,806 -8,221 352 -7,181 4,111 0 0 0 0 12/94 18,354 -4,722 943 -1,177 -7,282 -612 -12,122 6,474 106 36 0 0 01/95 16,610 -3,898 1,967 -3,048 -5,835 100 -12,771 6,839 29 6 0 0 02/95 15,457 -4,347 2,159 -3,086 -6,074 177 -11,542 7,257 0 0 0 0 03195 19,683 -8,254 2,440 -1 ,450 -8,418 269 -13,704 9,435 0 0 0 0 04/95 19,064 -8,496 2,890 -1,697 -7,201 610 -14,822 9,590 0 0 69 -7 222,761 -58,977 22,805 -14,418 -157,060 13,753 -94,501 58,435 5,927 1,213 69 -7 }:>; ¡;) m X" ~~ ';:;; ....; ::p t;"' g ~ õ' :::! 0 ?C c> in .......{ n 0 rT1 -J - .~. < 1.1;) t.O r-n c::n c:;J g ~ ., .... ATTACHMENT 1 GPMA WATER CUT CORRECTION DATA 8/96 REVISION wlo Pt Mc DS·P1 correction CORRECTED ALLOCATED PRODUCTION DATA TOTAL CORRECTED PT. MciNTYRE I NIAKUK I LISBURNE I NPB I WB I WEST NK ALLOCATED MONTH OIL WATER OIL WATER OIL WATER OIL WATER OIL WATER OIL WATER OIL WATER 04/93 0 0 0 0 848,826 273,097 0 0 66,109 1,577 0 0 914,935 274,674 05193 0 0 0 0 797,845 286,759 0 0 123,112 1,381 0 0 920,957 288,140 06193 0 0 0 0 195,280 61,833 0 0 32,233 196 0 0 227,513 62,029 07/93 0 0 0 0 763,368 230,321 0 0 125,026 1,332 0 0 888,394 231,653 08193 0 0 0 0 748,002 221,314 0 0 101,467 1,029 0 0 849,469 222,343 09/93 0 0 0 0 671,506 207,114 0 0 68,787 584 0 0 740,293 207,698 10/93 1,414,732 14,000 0 0 618,863 138,154 108,773 225 63,297 652 0 0 2,205,665 153,030 11/93 2,912,867 32,256 0 0 597,681 187,809 164,211 998 72,178 710 0 0 3,746,937 221,773 12/93 3,204,706 20,918 0 0 611,091 213,006 147,280 1,261 72,983 1,085 0 0 4,036,059 236,270 01/94 3,078,874 30,529 0 0 633,919 206,140 84,711 12,849 43,070 748 0 0 3,840,575 250,267 02/94 2,653,496 32,053 0 0 586,023 203,121 73,116 20,og7 52,718 1,047 0 0 3,365,353 256,318 03194 3,006,569 33,619 0 0 611,034 259,880 53,867 24,790 68,665 1,457 0 0 3,740,135 319,746 04/94 2,607,400 37,546 260,789 715 609,721 273,344 47,807 26,745 54,629 1,214 0 0 3,580,345 339,564 05194 2,745,920 44,521 496,683 753 616,833 279,887 56,899 39,355 42,755 900 0 0 3,959,090 365,417 06194 2,799,030 55,406 480,444 5,244 569,372 254,562 68,548 47,389 43,375 1,431 0 0 3,960,769 364,032 07/94 2,749,189 76,876 486,623 2,997 507,906 255,244 55,489 48,758 44,896 1,385 0 0 3,844,103 385,260 08194 3,039,872 131,371 409,583 1,568 517,631 184,883 63,002 47,342 37,106 729 0 0 4,067,194 365,893 09/94 3,481,354 21,552 450,444 8,493 556,566 207,984 3,001 2,219 39,908 981 0 0 4,531,274 241,229 10/94 3,832,416 21,803 322,152 21,536 563,067 247,896 185 1,169 44,651 1,247 0 0 4,762,471 293,650 11/94 3,515,100 46,834 262,057 31,845 524,802 205,767 92,575 83,979 0 0 0 0 4,394,533 368,424 12/94 4,174,778 82,271 214,433 20,505 549,224 197,074 127,977 133,908 40,375 744 0 0 5,106,788 434,503 01/95 3,966,766 65,660 469,797 51,346 533,984 156,009 115,883 146,847 9,953 137 0 0 5,096,383 420,000 02/95 3,664,959 81,618 511,901 57,943 482,586 182,022 89,376 139,394 0 0 0 0 4,748,822 460,976 03195 4,038,018 156,254 500,532 27,460 517,434 268,756 92,227 179,847 0 0 0 0 5,148,210 632,317 04/95 4,028,334 160,750 610,760 32,106 487,369 214,536 68,412 182,917 0 0 14,506 140 5,209,381 590,449 60,914,380 1,145,835 5,476,197 262,509 14,719,936 5,416,512 1,513,338 1,140,092 1,247,292 20,566 14,506 140 83,885,648 7,985,655 Inclusive DS-P1 WC Changes ATTACHMENT 4 GPMA WATER CUT CORRECTION DATA 9/96 REVISION CORRECTED AllOCATED PRODUCTION DATA TOTAL CORRECTED PT. MciNTYRE I NIAKUK I LISBURNE I NPB I WB I WEST NK AllOCATED MONTH Oil WATER Oil WATER Oil WATER Oil WATER Oil WATER Oil WATER Oil WATER 04/93 0 0 0 0 848,826 273,097 0 0 66,109 1,577 0 0 914,935 274,674 05/93 0 0 0 0 797,845 286.759 0 0 123,112 1,381 0 0 920,957 288,140 06/93 0 0 0 0 195,280 61,833 0 0 32,233 196 0 0 227,513 62,029 07/93 0 0 0 0 763,368 230,321 0 0 125,026 1,332 0 0 888,394 231,653 08/93 0 0 0 0 748,002 221,314 0 0 101,467 1,029 0 0 849,469 222,343 09/93 0 0 0 0 671,506 207,114 0 0 68,787 584 0 0 740,293 207,698 10/93 1,419,536 136 0 0 615,104 151,930 108,113 248 62,912 717 0 0 2,205,665 153,030 11/93 2,918,768 4.818 0 0 593,452 215,000 163.050 1,143 71,667 813 0 0 3,746,937 221,773 12/93 3,204,706 20,918 0 0 611,091 213,006 147,280 1.261 72,983 1.085 0 0 4,036,059 236,270 01/94 3,078,874 30.529 0 0 633,919 206,140 84,711 12.849 43,070 748 0 0 3,840,575 250,267 02/94 2.653,496 32,053 0 0 586,023 203,121 73,116 20.097 52,718 1,047 0 0 3,365,353 256,318 03/94 3,006,569 33,619 0 0 611,034 259,880 53,867 24,790 68,665 1,457 0 0 3,740,135 319,746 04/94 2,607,400 37,546 260,789 715 609,721 273,344 47,807 26,745 54,629 1,214 0 0 3,580,345 339,564 05/94 2,745,920 44,521 496,683 753 616,833 279,887 56,899 39,355 42,755 900 0 0 3,959,090 365,417 06/94 2,799,030 55,406 480,444 5,244 569,372 254,562 68,548 47,389 43,375 1,431 0 0 3,960,769 364,032 07/94 2,749,189 76,876 486,623 2,997 507,906 255,244 55,489 48,758 44,896 1,385 0 0 3,844,103 385,260 08/94 3,039,872 131,371 409,583 1,568 517,631 184,883 63,002 47,342 37,106 729 0 0 4,067,194 365,893 09/94 3,481,354 21,552 450,444 8,493 556,566 207.984 3,001 2,219 39,908 981 0 0 4,531,274 241,229 10/94 3,832,416 21,803 322,152 21,536 563,067 247,896 185 1,169 44,651 1,247 0 0 4,762,471 293,650 11/94 3,515,100 46,834 262,057 31,845 524,802 205,767 92,575 83,979 0 0 0 0 4,394,533 368,424 12/94 4,174,778 82,271 214,433 20,505 549,224 197,074 127,977 133,908 40,375 744 0 0 5,106,788 434,503 01/95 3,966,766 65,660 469.797 51,346 533,984 156,009 115,883 146,847 9,953 137 0 0 5,096,383 420,000 02/95 3.664,959 81,618 511,901 57,943 482,586 182,022 89.376 139,394 0 0 0 0 4,748,822 460,976 03/95 4,038,018 156.254 500,532 27,460 517,434 268.756 92,227 179,847 0 0 0 0 5,148,210 632,317 04/95 4,028,334 160,750 610,760 32,106 487,369 214,536 68,412 182,917 0 0 14,506 140 5,209,381 590,449 60,925,085 1,104,533 5,476,197 262,509 14,711,948 5,457,480 1,511,516 1,140,259 1,246,397 20,734 14,506 140 83,885,648 7,985,655 Page 6 of 7 PM DS-P1 10/14 to 11/30/93 Water Cut Correction Data 10/14/93 to 11/30193 s.. 1.010 aw. 1.0tO AU...OCAl1ON FACTORS CURRENT A1J OCA11ON DATA A A ATA SEP AA SEPARAlOA RATES OOAAECTED '" ES DELTA DELTA "",,, ........ ~ WA=o TOTVOl I .., 01 VOl I WTA VOl TOT VOl .., SEPOIl I ~wm TOr SEP cæPWC I GgEpð!L C8EPwm I CSEP AlX) '''TOIl = =wc T T ~ wm PM IJSP1 10/14/93 0.7668 1.3129 22.189 132 22,321 0.006 28,937 101 29,038 0.0035 31,541 102 31,643 0.00321 0.00000 31,643 0 31,643 29,030 0 0.000 29,030 .3 -101 PMDS-P1 10/15/93 1.0754 1.2376 71,147 33. 71,485 0.005 66,159 273 68,432 0.0041 72,113 276 72,389 0.00381 0.00014 72,379 10 72,389 66,402 10 0,000 66,412 244 ·263 PMDS-P1 10/16/93 1.0317 1.0676 71,909 356 72,265 0.005 89,700 333 70,033 0.0046 75,972 337 76,309 0.00441 0.00027 76,289 21 76,309 69,990 20 0,000 70,010 2.0 -313 PMDS-P' 10/17/93 1.0591 1.0060 79,956 .25 80,381 0.005 75,494 .22 75,917 0.0058 82,289 '27 82.715 0.00516 0.00040 82,682 33 82,715 75,855 33 0.000 75,888 361 ·390 PM IJSP1 10/18193 1.0314 0.9558 77,880 ..2 78,362 0.008 75,509 50. 76,013 0.0066 82,305 50. 82,814 0.00615 0.00053 82,770 .. 82,814 75,936 43 0.001 75,979 .27 -461 PMDS-P1 10/19/93 1.0231 0.9513 88,711 6.. 89,395 0.008 86,708 71. 87,427 0.0082 94,512 726 95,238 0.00763 0.00066 95,175 63 95,238 87,317 62 0.001 87,379 60. -657 PMDS-P1 10/20/93 1.0199 0.9061 81,244 6.0 81,934 0.008 79,659 762 80,420 0.0095 86,828 76. 87,597 0.00878 0.00079 87,528 6. 87,597 80,30t 6. 0.001 80,369 6'2 -693 PMDS-P1 10/21/93 1.0109 0.8719 70,043 725 70,768 0.010 69,288 .32 70,119 0.0119 75,524 ..0 76,363 0.01100 0.00092 76,293 70 76,363 69,914 70 0.001 70,063 706 -762 PMDS-P1 10/22193 1.0012 0.8971 67.473 7.0 68,233 0.011 67,392 847 68,239 0.0124 73,457 .56 74,313 0.01151 0.00105 74,235 76 74,313 68,106 77 0.001 68,183 713 -770 PMDS-P1 10/23/93 1.0578 0.8673 77,549 ..2 78,391 0.011 73,312 ." 74,282 0.0131 79,910 .61 80,890 0.01212 0.001t8 80,795 .5 80,890 74,124 ., 0.001 74,218 .,2 -876 PMDS-P1 10/24/93 1.0491 0.9192 87,672 1,082 88,754 0.012 83,569 1,177 84,746 0.0139 91,090 1,189 92,279 0.01288 0.00131 92,158 121 92,279 84,549 120 0.001 84,668 .60 -1,057 PMDS-P1 10/25/93 1.0248 0.6445 87,199 601 88,000 0.009 85,089 1,243 86,332 0.0144 92,747 1,255 94,002 0.01335 0.00144 93,867 135 94,002 86,116 13. 0.002 86,250 1,027 -1,109 PMDS-P1 10/26/93 0.9955 0.4171 86,867 5.. 87,415 0.006 87,260 1,314 88,574 0.0148 95,113 1,327 96,440 0.01376 0.00157 96,289 151 96,440 88,338 150 0.002 88,488 1,078 -1,164 PMDS-P1 10/27/93 0.9951 1.0884 86,827 1,441 88,268 0.016 87,255 1,324 88,579 0.0149 95,107 1,337 96,445 0.01386 0.00170 96,281 16. 96,445 88,331 162 0.002 88,493 1,076 -1,162 PMDS-P1 10/28/93 0.9931 0.9568 85,851 1,269 87,120 0.015 86,447 1,326 87,774 0.0151 94,228 1,340 95,567 0.01402 0.00183 95,392 '" 95,567 87,51& 173 0.002 87,689 1,069 -1,153 PUDS-P1 10/29/93 0.9169 0,9972 76,176 1,222 77,398 0.016 83,080 1,225 84,305 0.0145 90,557 1,23,8 91,795 0.01348 0.00196 91,615 160 91,795 84,050 17. 0.002 84,229 .70 -1,047 OIL WATER! I PMDS-P1 10/30/93 1.0145 1.0175 93,484 1,387 94,871 0.015 92,148 1,363 93,511 0.0146 100,441 1,377 101,818 0.01352 0.00209 101,605 213 101,818 93,216 211 0.002 93,426 1,068 -1,152 ""M.P1 10/31/D~ 10<7> 1.nn84 DR 7"7 1 ~98 inn 155 0 14 0',1 4"3 t 38"" 04 809 .0146 1011'131 1400 103231 0.01356 0.002 2 10300" 22. 1n',l "31 94 497 227 0.002 947':>4 1074 -1 159 13241 -14 ?89 PMDS-P1 1111/93 0.9978 0.8672 95,612 1,292 98,904 0.013 95,823 1,490 97,313 0.0153 104,447 1,505 105,952 0.01420 0.00200 105,740 212 105,952 97,009 210 0.002 97,219 1,188 -1,280 PMDS-P1 1112/93 1.0092 0.8408 100,....2 1,337 101,779 0.013 99,526 1,590 101,117 0.0157 108,"84 1,606 110,090 0.01459 0.00200 109,870 220 110,090 100,798 218 0.002 101,018 1,271 -1,372 PMDS-P1 11/3193 0.9818 0.9331 103,723 1,6"9 105,372 0.016 105,667 1,767 107,435 0.0184 115,177 1,785 116,962 0.01526 0.00200 116,728 234 116,982 107,090 232 0,002 107,322 1,423 -1,536 PMDS-P1 11/4/93 1.003.. 0.8988 106,"29 1,6"7 108,076 0.015 106,068 1,833 107,901 0.0170 115,615 1,851 117,"66 0.01576 0.00200 117,231 235 117 ,486 107,551 233 0.002 107,784 1,483 -1,600 PMDS-P1 11/5/93 1.0417 0.8"14 106,3"5 1,52" 107,869 0.014 102,088 1,811 103,899 0.0174 111,276 1,829 113,105 0.01817 0.00200 112,879 226 113,105 103,559 224 0.002 10~,783 1,471 -1,587 PMDS-P1 11/6/93 1.0076 0.62"0 100,290 1,139 101,429 0.011 99,53" 1,825 101,359 0.0180 106,"92 1,84" 110,335 0.01871 0.00200 "0,1'" 221 110,335 101,022 218 0.002 101,241 1,489 -1,607 PMDS-P1 11/7/93 1.0218 1.1528 97,565 2,068 99,631 0.021 95,"83 1,792 97,276 0.0184 104,077 1,810 105,887 0.01710 0.00200 105,676 212 105,887 96,950 210 0.002 97,160 1,467 -1,583 PM DS-P1 11/8/93 1.0151 0.8685 94,732 1,534 96,266 0.016 93,323 1,786 95,089 0.0186 101,722 1,78" 103,506 0.01724 0.00200 103,299 207 103,506 94,770 205 0.002 94,974 1,447 -1,561 PMDS-P1 1119/93 1.0193 0.9259 95,333 1,652 98,985 0.017 93,528 1,784 95,312 0.0187 101,945 1,802 103,747 0.01737 0.00200 103,540 207 103,747 94,991 20' 0.002 95,196 1,463 -1,579 PMDS-P1 11/10/93 1.0251 0.9288 96,360 1,625 91,985 0.017 94,001 1,753 95,75" 0.0183 102,461 1,771 104,232 0.01699 0.00200 104,023 206 104,232 95,"34 206 0.002 95,640 1,433 -1,547 PMDS-P1 11/11/93 1.0053 0.8822 9",838 1,530 9S,368 0.016 9",338 1,73' 96,072 0.0181 102,828 1,752 104,580 0.01675 0.00200 104,311 20. 104,580 95,753 207 0,002 95,960 1,415 -1,527 PMDS-P1 11/12/93 1.00"0 0.9511 94,551 1,6"3 9S,194 0.017 94,174 1,727 95,902 0.0180 102,650 1,745 104,395 0.01671 0.00200 104,186 20. 104,395 95,583 207 0.002 95,790 1,409 -1,521 PMDS-P' 11/13/93 0.9960 1.0151 90,177 1,671 91,848 0.018 90,539 1,6"6 92,185 0.0179 98,688 1,663 100,350 0.01657 0.00200 100,150 201 100,350 91,880 ". 0.002 92,079 1,341 -1,447 PMDS-P1 11/14/93 1.0057 1.0258 93,370 1,669 95,039 0.018 92,841 1,627 94,468 0.0172 101,196 1,643 102,840 0.01598 0.00200 102.634 206 102,840 94,160 20' 0.002 94.363 1,319 -1,423 PMDS-P1 11/15/93 0.9927 0.95"2 96,519 1,638 98,157 0.017 97,229 1,717 98,945 0.0173 105,979 1.734 107,713 0.01610 0.00200 107,498 215 107,713 18,622 213 0.002 98,835 1,393 -1,503 PMDS-P1 11/16/93 0.9626 1.0071 76,875 1,330 78,205 0.017 79,862 1,321 81,182 0.0163 87,049 1,334 88,383 0.01509 0.00200 88,206 177 68,383 80,923 17' 0.002 81,098 1,062 -1.146 PMDS-P' 11/17/93 0.9937 0.9798 80,529 1,197 81.726 0.015 81,040 1,222 82,261 0.0149 88,333 1,234 89,567 0.01378 0.00200 89,388 17. 89,567 82,001 177 0.002 82,185 .66 -1,044 PM IJSP1 11/18/93 1.0131 0.9723 97,565 1,057 98,622 0.01t 96,303 1,087 97,391 0.0112 104,971 1,098 106,069 0.01035 0.00200 105,857 212 106,069 97,116 210 0.002 97,326 .13 -877 PMDS-P1 11/19/93 1.0058 1.02"7 99,053 1,071 100,124 0.011 98,482 1,045 99,527 0.0105 107,345 1,056 108,401 0.00974 0.00200 108,184 217 108,401 n,251 215 0,002 99,466 770 -831 PMDS-P1 11/20/93 0.99"3 1.0331 96,589 .17 97,506 0.009 97,143 ... 98,030 0.0091 105,886 ..6 106,782 0.00840 0.00200 106,568 214 108,782 97,769 211 0.002 97,981 627 -676 PMDS-P1 11/21/93 0.9926 1.038" 96,986 761 97,727 0.008 97,689 733 98,"22 0.0074 106,481 7.0 107,221 0.00690 0.00200 107,007 214 107,221 98,171 212 0.002 98.384 4.2 -521 PMDS-P1 11/22/93 0.9961 1.0896 98,243 6" 98,896 0.007 98,628 5.. 99,227 0.0060 107,504 60S 108,109 0.00560 0.00200 107,893 216 108,109 18,985 214 0.002 99,199 357 -385 PMDS-P1 1 t/23/93 1.0120 1.2187 100,037 563 100,600 0.006 98,851 .62 99,313 0.0047 107,747 .67 108,214 0.00"31 0,00200 107,998 216 108,214 99,080 214 0.002 99,295 230 -246 PMDS-P1 11/24193 1.00"9 1.1518 99,069 3.. 99,467 0.004 98,586 346 98,931 0.0035 107,459 34. 107,808 0.00324 0.00200 107,592 216 107,e08 98,708 213 0.002 98,922 122 -132 PM DS-P1 11/25/93 1.0156 1.1338 100,252 310 100,562 0.003 98,712 273 98,988 0.0028 101,596 276 107,872 0.00256 0.00200 107,651 216 107,872 98,768 214 0.002 98,981 55 -60 PMDS-P1 11/26/93 1,0172 1.19"8 99,743 25. 100,001 0.003 98,056 21. 98,272 0.0022 106,682 216 107,100 0.00204 0.00204 106,882 21. 107,100 98,056 216 0.002 98,272 0 0 PMDS-P1 11/27193 1.0083 1.2374 100,726 2.5 100,971 0.002 99,897 ,.. 100,095 0.0020 108,888 200 109,086 0.00183 0.00183 108,888 200 109,088 99,897 ... 0.002 100,095 0 0 PM !JS.P1 11128/93 0.9981 1.2577 98,265 265 98,530 0.003 98,'52 211 98,663 0.0021 107,313 213 107,526 0.00198 0.00198 107,313 213 107,526 98,452 211 0.002 98,663 0 0 Oil WATEA~ I PM !JS.P1 11/29/93 0.99'" 1.3"'3 99,317 276 99,593 0.003 99,906 206 100,112 0.0021 108,898 20. 109,106 0.00190 0.00190 108,898 20. 109,108 99,906 206 0.002 100,112 0 0 ...M.P1 '1/30/9'4 1.0"04 1.~58" .. .n. '5· 99 nA5 o. ,n' .. 6' 206 94.271 o 0022 102.531 206 102.739 0.00203 0.00203 102531 20. 102739 94065 206 O.OO~ 94271 0 0 26.495 -285Q3 ",319,255 47,758 4,367,013 4,280,260 50,999 ",331,260 4,716,993 4,716,993 4,319,995 8,117 4,328,112 39,735 -42,882 Oil WATER ""L ---- 1/ 'THEORETICAL DIFFERENCES 39,735 -42,882 FLUID GAIN DUE ~ (J,UT) (SIB) (STS) EQUAL AS NO VOLUME 10 SHRINKAGE DlFF (STB) I THE NET 01. LOSS AND WATER GAIN ARE NOT EQUAL DUETO THE DIFFERENCE BETWEEN OIL AND WATER I CHANGE WASSEEN IN THE _. SEPARATOR Attachment 3 PM DS-P1 Correction Inclusive DS-P1 WC Changes ATTACHMENT 5 GPMA WATER CUT CORRECTION DATA 9/96 REVISION DIFFERENTIAL CORRECTED AllOCATED PRODUCTION DATA PT. MciNTYRE I NIAKUK I LISBURNE I NPB I WB I WEST NK MONTH Oil WATER Oil WATER Oil WATER Oil WATER Oil WATER Oil WATER 04/93 0 0 0 0 -491 -110 0 0 491 110 0 0 05/93 0 0 0 0 -1,165 -94 0 0 1,165 94 0 0 06193 0 0 0 0 -359 -12 0 0 359 12 0 0 07/93 0 0 0 0 -1,189 -82 0 0 1,189 82 0 0 08/93 0 0 0 0 -1,065 -61 0 0 1,065 61 0 0 09/93 0 0 0 0 -688 -36 0 0 688 36 0 0 10/93 8,602 -14,446 0 0 -7,934 14,304 -390 37 -278 106 0 0 11/93 10,447 -28,358 0 0 -8,982 27,984 -999 219 -466 156 0 0 12/93 4,952 -639 0 0 -5,084 469 117 91 16 79 0 0 01/94 6,700 -1,114 0 0 -5,700 200 -1,023 863 22 50 0 0 02/94 8,639 -1,576 0 0 -7,138 398 -1,577 1,120 76 58 0 0 03/94 10,733 -1,650 0 0 -8,849 185 -1,998 1,384 114 81 0 0 04/94 10,575 -1,963 1,058 -37 -9,664 520 -2,085 1,416 117 64 0 0 05/94 11,619 -2,416 2,102 -41 -10,589 397 -3,232 2,013 100 46 0 0 06194 13,040 -3,076 2,238 -291 -11,133 924 -4,208 2,371 63 72 0 0 07/94 12,206 -4,182 2,161 -163 -10,543 1,785 -3,904 2,489 80 71 0 0 08/94 12,756 -6,234 1,719 -74 -9,986 3,554 -4,569 2,712 80 42 0 0 09/94 8,930 -1,140 1,155 -449 -9,891 1 ,422 -203 116 8 51 0 0 10/94 10,765 -1,110 905 -1,097 -11,570 2,077 -108 63 8 68 0 0 11/94 14,334 -2,656 1,069 -1,806 -8,221 352 -7,181 4,111 0 0 0 0 12/94 18,354 -4,722 943 -1,177 -7,282 -612 -12,122 6,474 106 36 0 0 01/95 16,610 -3,898 1,967 -3,048 -5,835 100 -12,771 6,839 29 6 0 0 02/95 15,457 -4,347 2,159 -3,086 -6,074 177 -11,542 7,257 0 0 0 0 03/95 19,683 -8,254 2,440 -1 ,450 -8,418 269 -13,704 9,435 0 0 0 0 04/95 19,064 -8,496 2,890 -1,697 -7,201 610 -14,822 9,590 0 0 69 -7 233,466 -100,279 22,805 -14,418 -165,048 54,721 -96,323 58,602 5,032 1,381 69 -7 Page 7 of 7 cr!"2s'!7b ." GPMA WATER CUT REVISION METHODOLOGY The correction of the watercut error was completed in two phases. The first phase required correcting the individual oil and water production volumes for all wells flowing through DS-L 1 and DS-L5 test separators, including West Beach and North Prudhoe Bay. This correction was completed on monthly production volumes only for the time period from April 1993 to April 1995 using the following methodology. An example calculation based on data from North Prudhoe Bay #3 during December 1994 has been included for reference. Also attached as Appendix #1 are the remaining wells for which this correction was made. All calculations are identical per well. See from State reports taken factors Download current monthly allocation Attachment #1, Part 1. 1) OIL ALLOCATION FACTOR = 1.0067 WATER ALLOCATION FACTOR = 1.0292 Download current allocated individual oil and water volumes for all wells produced through the L 1 and L5 test separators from the GPMA database. See Attachment #1, Part 2. WTR = WATER, TOT = TOTAL, WC WATERCUT 2) ALLOCATED OIL VOL = 140,099 STB ALLOCATED WTR VOL = 127,434 STB ALLOCATED TOT VOL = OIL VOL + WTR VOL = 267,533 STB ALLOCATED WC = WTR VOL/OIL VOL + WTR VOL = 0.476 #1 See Attachment theoretical production data Convert allocated data to Part 3. 3) THEORETICAL OIL VOL = ALLOCATED OIL VOL + OIL ALLOCATION FACTOR = 140,099 + 1. 0067 = 139, 1~7 STB THEORETICAL WTR VOL = ALLOCATED WTR VOL + WTR ALLOCATION FACTOR = 127,434 + 1.0292 = 123,818 STB THEORETICAL TOT VOL = THEO. OIL VOL + THEO. WTR VOL = 262,985 STB THEORETICAL WC = THEO. WTR VOL + (THEO OIL VOL + THEO WTR VOL) = 0.471 4) Multiply theoretical data by average Bo and Bw to calculate oil and water rates at sel:larator conditions. Calculate separator watercut. This watercut was originally measured by the meter and incorrectly adjusted (percent to decimal error) and reported. See Attachment #1, Part 4. (SEP = SEPARATOR BBLS BBLS 115 BBLS THEORETICAL OIL VOL X Bo = 139,167 X 1.117 = 155,449 SEP WTR THEORETICAL WTR VOL X Bw = 123,818 X 1.023 = 126,666 TOT SEP FLUID = SEP OIL + SEP WTR = 282, SEP WC = SEP WTR + (SEP OIL + SEP WTR) = 126,666 + (155,449 + 126,666) = 0.449 SEP OIL Utilize correction factor to re-calculate the water cut. This correction factor is based on the original percent to decimal conversion of 0.009 used versus the required value of 0.01. Thus, multiplying by 0.01 and then dividing this resLJlt by 0.009 corrects this error. Use this correëfêë:l watefcùt to re-calculatEfoil and'water voTü"ñîësarsëparator conditions. See Attachment #1, Part 5. C SEP = CORRECTED SEPARATOR) ...·"'_"'...,~""''"._,___.~'w,.,.~....\..''~~..~..__ C SEP WC SEP 009 009 + 0 X (0.01 + 0 449 X (0.01 499 WC = 0 = 0 5) .. C. SEP OIL = TOT SEP FLUID X (1 - C. SEP WC) = 282,115 X (1 - 0.499) = 141,375 BBLS C. SEP WTR = TOT SEP FLUID X C. SEP WC = 282,115 X 0.499 = 140,740 BBLS C. SEP FLUID = C. SEP OIL + C. SEP WTR = 282,115 BBLS 6) Use average Bo and Bw to re-calculate corrected theoretical oil and water volumes at standard conditions for all wells. See Attachment #1, Part 6. (C-ST = CORRECTED STOCK TANK THEORETICAL) C-ST OIL = C. SEP OIL + Bo = 141,375 + 1.117 = 126,567 STB C-ST WTR = C. SEP WTR + Bw = 140,740 + 1.023 = 137,576 STB C-ST WC = C-ST WTR + (C-ST OIL + C-ST WTR) = 137,576 + (126,567 + 137,576) = 0.521 C-ST TOT = C-ST OIL + C-ST WTR = 264,143 STB 7) Calculate delta from original theoretical data and corrected theoretical data for oil and water by well by month. See Attachment #1, Part 7. DELTA OIL = C-ST OIL - THEO. OIL VOL = 126,567 - 139,167 = -12,600 STB DELTA WTR = C-ST WTR - THEO. WTR VOL = 137,576 - 123,818 = 13,758 STB 8) Summarize delta theoretical oil and water volumes by well and total at the field level per month during time period for Lisburne, North Prudhoe Bay and West Beach. See Attachment #2. The second phase quired correcting the total delta theoretical oil and water volume ase one to corrected allocated volumes on a field basis. This correction was completed on monthly field production volumes for the time period from April 1993 to April 1995 using the following methodology. An example calculation based on monthly field data from December 1994 has been included for reference. 1) Download historical allocated production data for each field from the GPMA database along with historical monthly allocation factors from State reports. Total allocated production for all fields. See Attachment #3, Part 1. OIL ALLOCATION FACTOR = 1.0067 WATER ALLOCATION FACTOR = 1.0292 TOTAL ALLOCATED VOLUMES FROM ALL FIVE FIELDS IS SUM OF CURRENT ALLOCATED PRODUCTION DATA BY FIELD BY MONTH. (ALL. = ALLOCATED, CURRo = CURRENT) TOTAL ALL. OIL = l CURRo ALL. OIL VOL BY FIELD = 5,106,788 STB TOTAL ALL. WATER = l CURRo ALL. WATER VOL BY FIELD = 434,503 STB 2) Use historical allocation factors and allocated production data from Part 1 to calculate theoretical oil and water volumes for each field by month for time period. See Attachment #3, Part 2. Example is for Lisburne volumes. THEO. OIL VOL = ALLOCATED OIL VOL + OIL ALLOCATION FACTOR = 556,506 + 1.0067 = 552,802 STB THEO. WTR VOL = ALLOCATED WTR VOL + WTR ALLOCATION FACTOR = 197,686 + 1.0292 = 192,077 STB 3) Import total delta theoretical oil and water volumes on a by month by field basis from individual well delta volumes calculated during phase one (section 7 & 8) of this analysis for Lisburne, West Beach and North Prudhoe Bay. See Attachment #3, Part 3. Example is for Lisburne volumes. THEa. LOSS OIL = L DELTA THEa. OIL BY WELL = -9,632 STB THEa. LOSS WATER = L DELTA THEa. WATER BY WELL = 10,395 STB 4) Correct theoretical field oil and water volumes at Lisburne, West Beach and North Prudhoe Bay utilizing the total theoretical loss data from previous step and summarize data from all fields. See Attachment #5, Part 4. Note: No correction was required or made to Point Mcintyre and Niakuk theoretical values. These values are the same on Attachment #5 Part 2 and 4. Example is for Lisburne volumes. CORRECTED THEa. OIL = THEa. OIL VOL + THEa. LOSS OIL = 552,802 + (-9,632) = 543,170 STB CORRECTED THEa. WATER = THEa. WATER VOL + THEa. LOSS WATER = 192,077 + 10,395 = 202,472 STB 5) Total corrected theoretical oil and water volumes for all fields. See Attachment #3, Part 5. (CaRR. = CORRECTED) SUMMARY VOLUMES FROM ALL FIVE FIELDS TOTAL CaRR. THEO. OIL = L CaRR. THEa. OIL VOL = 5,050,498 STB TOTAL CaRR. THEa. WATER = L CaRR. THEa. WATER VOL = 446,404 STB 6) Calculate new monthly allocation factors using total corrected theoretical volumes and actual metered crude and water volumes. See Attachment #3, Part 5. (AF=ALLOCATION FACTOR) CaRR. OIL AF = TOTAL ALLOCATED OIL + TOTAL CaRR. THEa. OIL = 5,106,788 + 5,050,498 = 1. 0111 CaRR. WATER AF = TOTAL ALLOCATED WATER + TOTAL CaRR. THEa. WATER = 434,503 + 446,404 = 0.9733 7) Use corrected monthly allocation factors and corrected theoretical volumes to re-allocate production volumes to each field during the time period in question. See Attachment #3, Part 6. Example is for Lisburne volumes'. Ensure original (Attachment #3, Part 1) and corrected allocated production totals remain equal. CaRR. ALLOCATED OIL = CaRR. OIL AF X CORRECTED THEa. OIL = 1.0111 X 543,170 = 549,224 STB CaRR. ALLOCATED WATER = CORR. WATER AF X CORRECTED THEa. WATER . = 0.9733 X 202,472 = 197,074 STB 8) Calculate differential corrected allocated volume impacts by field by month. See Attachment #3, Part 7. DIFF. CaRR. ALL. OIL = CaRR. ALL. OIL - CURRo ALLOCATED OIL = 549,224 - 556,506 = -7,282 STB DIFF. CaRR. ALL. WATER = CaRR. ALL. WATER - CURRo ALLOCATED WATER = 197,074 - 197,686 STB -612 North Pr'Udhoe Bay Water Cut CorrectIon Date _ ~;: 11:"~~"\ Sì'B1 P-IS ... 1.023 NP-03 NP-03 NP-03 NP-03 NP-03 NP-03 NP-03 NP-03 NP-03 NP-03 NP-03 NP-03 NP-03 NP-03 NP-03 NP-03 NP-03 NP-03 NP-03 NP-03 NP-G3 NP-03 NP-03 NP-03 AU.OCA11ON FACroRS 04103 05/83 08/03 07/83 08/03 09/03 10/83 11/93 12/03 01/94 02/14 03/04 04/04 05/94 oe/04 07104 08/8-4 09184 10/04 111114 12114 01195 02/115 03/85 , 1.0203 0.9836 1.0358 1.0052 1.0387 0.0186 1.0251 0.9937 1.0350 0.9935 1.0246 1.0641 1.0152 1.0116 1.0082 1.0089 1.0140 1.0873 1.0179 1.0286 1.0086 1.0733 1.0020 1.0894 0.9918 1.1283 0.9078 1.0915 1.0000 1.0118 I PART 1 I " 1,0036 1.0987 1.0104 1.0081 1.0125 o o o o o o 211 .2' 1,170 11,888 18,977 23,408 26.3211 37,342 46,018 5 1.0790 1.0292 1.0859 1.1384 1.2405 .17 1,1 10,868 127,434 140,008 132,137 170,412 1 1,081,657 , .. 179,824 287,533 288,862 233,055 278,343 o o o o o o 108,714 184,873 148,333 87,720 83,870 79,271 75,221 97,-473 117,774 o o o o o o 0.002 0.006 0,008 0.123 0.203 0.285 0.337 0.383 0.382 0.438 o o o o o o 106,878 183,038 145,137 84,225 74,063 56,753 50,002 60,278 72.758 68,822 o o o o o o 20. .,S 1,076 11,664 17,681 21,0486 22.....9 304,212 44,0488 OIL WA1'ER THEORETICAL DIFFERENCES -11,811 101.111 (STS) (ST8) THE NETOtLLOSSAND WATER OAINARE P«)T EOlIAl DUE TO Tt£ DIFFERENCE 8£TWEENOfLAtÐ WA'ŒR 9ftN<AŒ. 1.607,839 2,689,498 0.388 0.791 0.445 0.475 0.621 0.667 0.617 3,184 282 1. EJiÐ 74,020 139,167 123,916 4 0 128.833 100,008 116,073 104,623 137,374 . 1,594,718 973,0.47 I PART31 , 51 173,0428 252,985 266.262 216,080 2041,897 1 2,567,766 o o o o o o 107,087 163,954 148,213 95,879 91,734 17,239 72.451 84,487 117,245 o o o o o o 0.002 0.006 0.007 0.122 0.193 0.278 0.310 0.362 0.379 0.407 0.392 0.785 0.427 0.471- 0.503 0.537 0.568 3.556 32S 111,039 155,449 142,227 111,709 116,864 . ATTACHMENT'1 119,383 182,114 162.118 94,079 82,717 62,276 55,852 67,328 81,268 65,705 " 75,723 126,1168 131,898 118,742 140,533 5 213 .37 1,101 11,922 18,088 21,979 22,g85 34,9tiltil 45,512 119,587 183,051 163,219 106,001 100,805 84,256 78,817 102,328 126,780 S 186,782 292,115 274,125 230,451 257,397 2,776,728 WTR we 0.002 0.002 119,360 231 119,597 10'.157 .3. 0.002 107,089 0.005 0.006 182,010 1,041 183,051 162.1.5 1.011 0.006 163,963 0.007 0.007 161,996 1,223 163,21ti1 146,02. 1.111 0.008 146,223 0.112 0.125 92,754 13,247 106,001 .3.031 12.141 0.135 tilS.til68 0.17ti1 0.1ti1g 80,707 20,Otil8 100,805 72.253 11.... 0.214 91,899 0.261 0.290 59,834 24,422 84,256 53.&67 23,'72 0.308 17 ,439 0.291 0.324 53,301 26,617 18,817 47,718 24,143 0.343 72,681 0.342 0.380 63,439 38,887 102,326 5'.714 '..013 0.401 94,807 0.369 0.399 76,212 50,569 126,780 1'.221 .1.432 0.420 117,661 0.386 0.429 107,026 54,712 ~ ..,5.. 0.3g2 0.435 I PART51 122 939 12 115 I PART 6 I _ 114 463 0.371 0.413 5,658 2.175 5,257 0.769 0.855 1 1,416 18' 1, . 65 1,367 0.405 0.451 102,625 84,137 186,762 .2.245 0.472 174,121 0.449- 0.499 141,375 140,740 292,115 125,567 137,575 0.521 254,143 0.481 0.535' 127',572 146,553 274;t25 143.251 0.556 257,468 0.515 0.573 98,515 131,938 230,451 '.,11' 128,170 0.594 217,166 0.546 0.607 101,249 156,148 257,397 '0.6"" 162,637 0.627 243,281 0 0 7 1S 17 8 7743 53 7 23 7S 2,776,728 1,495,701 1,081,163 2,576,B64 ~ ~ FlUOGAlNOUE TO 9ANKAGE DlFF. TIESE VAlUES MUST BE EQUAl AS NO VOlUME CHANGE WAS seEN IN Tt£ ""'_TOR DELTA DELTA o 0 o 0 o 0 o 0 o 0 o 0 -21 23 -93 102 -109 120 -1,186 1,295 -1,799 1,965 -2,186 2,387 -2,284 2,494 -3,481 3,801 -4,527 4,943 I PART7 I -7,532 -12,800 ·13,120 -11,812 -13,979 ·1 069 -99,018 8 8,224 ·13,758 14,326 12,897 15,284 1 453 108,116 +1,01. (STB) ...f) - ~ 1t ATTACHMENT 3 GPMA WATER CUT CORRECTION DATA 8/96 REVISION THEORETICAL PRODUCTION DATA PT. MciNTYRE NIAKUK LISBURNE NPB WB WEST NK MONTH OIL WATER OIL WATER OIL WATER OIL WATER OIL WATER OIL WATER 04193 0 0 0 0 832,419 283,527 0 0 64,312 1,522 0 0 05/93 0 0 0 0 771,394 285,369 0 0 117,732 1,280 0 0 06193 0 0 0 0 188,350 67,325 0 0 30,686 200 0 0 07/93 0 0 0 0 745,821 231,871 0 0 120,802 1,258 0 0 08/93 0 0 0 0 723,723 222,817 0 0 97,005 974 0 0 09/93 0 0 0 0 656,055 194,672 0 0 66,464 515 0 0 10/93 1,389,809 14,416 0 0 613,710 136,061 106,878 209 62,244 604 0 0 11/93 2,890,401 32,883 0 0 598,722 185,366 163,038 916 71,689 651 0 0 12/93 3,155,709 19,826 0 0 607,693 195,467 145,137 1,076 71,963 925 0 0 01/94 3,018,091 30,767 0 0 628,359 200,241 84,225 11,654 42,290 679 0 0 02/94 2,622,184 31,333 0 0 53 17,681 52,191 921 0 0 03194 2,989,847 32,375 0 0 [- 21,485 68,414 1,263 0 0 04/94 2,602,551 35,016 260,304 22,449 54,632 1,019 0 0 05/94 2,740,879 43,002 495,771 PART 2 ,212 42,758 782 0 0 06194 2,785,990 57,794 478,206 5, 44,489 43,312 1,343 0 0 07/94 2,710,689 70,762 479,808 2,75 40,392 44,385 1,147 0 0 08/94 2,999,520 145,122 404,146 1,732 5 ,955 47,068 36,688 725 0 0 09/94 3,450,685 22,162 446,476 8,733 562,911 201,740 3,184 2,054 39,650 908 0 0 10/94 3,812,121 22,064 320,446 21,794 573,204 236,706 292 1,065 44,532 1,135 0 0 11/94 3,488,556 45,867 260,078 31,187 531,164 190,375 99,408 74,020 0 0 0 0 12/94 4,128,761 84,525 212,069 21,067 552,802 192,077 139,167 123,818 40,001 688 0 0 01/95 3,909,497 64,056 463,015 50,091 534,263 143,576 127,330 128,933 9,822 121 0 0 02/95 3,616,591 75,514 505,145 53,609 484,253 159,737 100,008 116,073 0 0 0 0 03195 3,968,726 132,614 491,943 23,305 519,360 216,435 104,623 137,374 0 0 0 0 04/95 3,988,926 144,593 604,786 28,879 492,060 182,765 82,812 148,079 0 0 14,364 126 60,269,534 1,104,692 5,422,191 250,020 14,689,446 5,114,411 1,594,719 973,047 1,221,573 18,662 14,364 126 Page 2 of 7 ATTACHMENT 3 GPMA WATER CUT CORRECTION DATA 8/96 REVISION THEORETICAL LOSS DATA LISBURNE LOSS NPB LOSS WB LOSS MONTH OIL WATER OIL WATER OIL WATER 04193 -8,678 9,366 0 0 -157 169 05193 -9,267 10,001 0 0 -132 142 06/93 -2,566 2,769 0 0 -21 22 07/93 -9,033 9,748 0 0 -130 140 08/93 -9,352 10,093 0 0 -101 108 09/93 -7,743 8,356 0 0 -53 57 10/93 -5,749 6,205 -21 23 -62 67 11/93 -5,651 6,098 -93 102 -67 72 12/93 -5,946 6,416 -109 120 -96 103 01/94 -6,955 7,506 -1,186 1,295 -70 75 02/94 -8,968 9, -95 102 03194 -11,008 140 04/94 -12,1 113 05194 -13,2 PART 3 87 06/94 -13,78 149 07/94 -12,675 127 08/94 -12,047 13, -75 81 09/94 -11,248 12,139 -209 228 -94 101 10/94 -13,118 14,157 -108 118 -117 126 11/94 -10,325 11,143 -7,532 8,224 0 0 12/94 -9,632 10,395 -12,600 13,758 -71 76 01/95 -7,9f57 8,620 -13,120 14,326 -12 13 02/95 -8,036 8,672 -11,812 12,897 0 0 03195 -10,805 11,661 -13,979 15,264 0 0 04/95 -9,460 10,209 -15,069 16,453 0 0 -235.428 2~,076 -99,018 108,116 -1,927 2,074 Page 3 of 7 ATTACHMENT 3 GPMA WATER CUT CORRECTION DATA 8/96 REVISION MONTH 04/93 05193 06193 07/93 08/93 09/93 10/93 11/93 12/93 01/94 02/94 03194 04/94 05194 06194 07/94 08/94 09/94 10/94 11/94 12/94 01/95 02/95 03195 04195 TOTAL CORRECTED THEORETICAL OIL WATER 887,896 294.585 879,727 296,793 216,450 70.317 857,460 243,017 811,276 233,993 714,723 203,600 2,166,808 157,585 3,718.038 226.089 3,974,352 223,933 3,764,754 252,218 3,325,6 3 3, 4,013,20 4,491,355 4,737.251 4.361,348 5,050,498 5,022.806 4,686,150 5,059,868 5,158,420 82,875,455 248,066 297,166 360,817 446,404 409,735 426,502 536,652 531,104 7.825,223 Page 5 of 7 CORRECTED ALLOCATION FACTORS OIL WATER 1.0305 0.9324 1.0469 0.9708 1.0511 . 0.8821 1.0361 0.9532 1.0471 0.9502 1.0358 1.0201 1.0179 0.9711 1.0078 0.9809 1.0155 1.0551 1.0201 0.9923 1.0230 PART 5 1.0089 1.0053 1.0076 1.0111 1.0146 1.0134 1.0175 1.0099 64 0.9052 0.9724 0.9882 1.0211 0.9733 1.0251 1.0808 1.1783 1.1117 ATTACHMENT 2 GPMA WATER CUT CORRECTION DATA DELTA VOLUMES LISBURNE NORTH PRUDHOE BAY WEST BEACH DELTA DELTA DELTA DELTA DELTA DELTA DATE OIL WTR OIL WTR OIL WTR 04/93 -8,678 9,366 0 0 -157 169 05/93 -9,267 10,001 0 0 -132 142 06/93 -2,566 2,769 0 0 -21 22 07/93 -9,033 9,748 0 0 -130 140 08/93 -9,352 10,093 0 0 -101 108 09/93 -7,743 8,356 0 0 -53 57 10/93 -5,749 6,205 -21 23 -62 67 11/93 -5,651 6,098 -93 102 -67 72 12/93 -5,946 6,416 -109 120 -96 103 01/94 -6,955 7,506 -1 ,186 1,295 -70 75 02/94 -8,968 9,679 -1 ,799 1,965 -95 102 03/94 -11,008 11 ,880 -2,186 2,387 -130 140 04/94 -12,163 13,127 -2,284 2,494 -105 113 05/94 -13,231 14,279 -3,481 3,801 -81 87 06/94 -13,786 14,878 -4,527 4,943 -139 149 07/94 -12,675 13,679 -4,110 4,488 -118 127 08/94 -12,047 13,001 -4,790 5,230 -75 81 09/94 -11,248 12,139 -209 228 -94 101 10/94 -13,118 14,157 -108 118 -117 126 11/94 -10,325 11,143 -7,532 8,224 0 0 12/94 -9,632 10,395 -12,600 13,758 -71 76 01/95 -7,987 8,620 -13,120 14,326 -12 13 02/95 -8,036 8,672 -11,812 12,897 0 0 03/95 -10,805 11,661 -13,979 15,264 0 0 04/95 -9,460 10,209 -15,069 16,453 0 0 TOTALS -235,428 254,076 -99,018 108,116 -1,927 2,074 1~~~}1~ J) ~~ ~\ 9-\~¥ ~ ~ ~\ GIG P (j"f BP EXPLORATION July 24, 1997 Alaska Oil & Gas Conservation Commission A TIN: Steve McMain 3001 Porcupine Drive Anchorage, Alaska 99501 BP Exploration (Alaska) Inc. 900 East Benson Boulevard P.O. Box 196612 Anchorage, Alaska 99519-6612 (907) 561·5111 Enclosed is the REVISED Monthly Production Report (Form 10-405), and the Injection Report (Form 10-406) covering Niakuk Unit Production for January 1995. This revision reflects the reallocation of volumes between fields due to the errors resulting from a watercut calculation and measurement error. Please address any questions to Bob Wilks at 907/564-5670. Sincerely yours, e1o~~,!f Manager, Volume, Royalty and Severance Tax Department Enclosures RE€E\'VED JUL 2. 8 1991 r'omro.\$'S\ AlIsKi ~ &ßas Cons. JoL·- ·,,·."4 rM-cn.omgG JOB: RTZ14NIH PROG: LRTB1700-01 ARCO ALASKA INC. PAGE: 1 AS OF: 01/31/1995 RUN TIME: 09:35 FORM 10-405 RUN DATE: 07/02/1997 ALASKA OIL AND GAS CONSERVATION COMMISSION FIELD - NIAKUK PARTICIPATING AREA 640 MONTHLY PRODUCTION REPORT OPERATOR - BP EXPLORATION, INC. NIAKUK PARTICIPATING AREA PRODUCTION MONTÀ - JANUARY-1995 AVG DAILY DAILY DAILY TOTAL TOTAL TOTAL WELL API FIELD DAYS GAS/OIL TUB1NG AVERAGE AVERAGE AVERAGE OIL WATER GAS NUMBER NUMBER CLASS CODE MTH PROD RATIO PRESSURE OIL WATER GAS (BBL) (BBL) (MCF) 13-07 029-22410-00 0 640148 2 1 0470 2270 994 1 467 994 1 "- 467 13-08 029-22491-00 0 640148 2 28 0612 735 2198 1308 1345 61548 36629 37669 13-09 029-22518-00 0 640148 2 0 0000 0 0 0 0 0 0 0 13-10 029-22425-00 0 640148 8 0 0000 0 0 0 0 0 0 0 13-12 029-22414-01 0 640148 2 31 0569 759 2707 18 1541 83926 552 '" 47763 13-18 029-22421-00 0 640148 8 0 0000 0 0 0 0 0 0 0 13-19 029-22807-00 0 640148 8 0 0000 0 0 0 0 0 0 0 13-20 029-22429-00 0 640148 2 29 0922 736 3603 26 3323 104500 746 "-- 96371 13-21 029-22487-00 0 640148 2 30 1267 732 2109 14 2671 63259 419 80122 13-22 029-22402-00 0 640148 2 22 0739 1119 4245 703 3137 93400 15458 - 69017 13-23 029-22455-00 0 640148 2 15 0619 1022 3979 39 2461 59684 590 36917 13-35 029-20013-35 0 640148 1 31 0001 0 753 465- 1 23333 14416- 30 13-42 029-22499-00 0 640148 8 0 0000 0 0 0 0 0 0 0 FACILITY TOTAL 187 490644 39979 368356 VOLUME TOTAL 187 490644- 39979 368356 - ** END OF REPORT ** /' .' ;0.---"-. ARca Alaska, Inc. Post Office Box 100360 Anchorage, Alaska 99510-0360 Telephone 907 276-1215 ~~ ~~ July 3, 1997 TO: Recipients of the Production Report (Form 10-406) Lisburne Participating Area Monthly (Form 10-405) and Injection Report Enclosed are the REVISED Production and Injection Reports for production month January 1995. This revision reflects the reallocation of vol urnes between fields due to the errors resulting from a watercut calculation and measurement error. Please address any questions to Kim Kerns 907/265-1588. E. R. He drickson, Supervisor Production & Revenue Accounting Enclosure ERH/kak/mac kak/OO lIlisb/R2 ,,(,1 1.ç¿';5 ';c.:, ,,~ "" . . . 9'../(qnJ. . .""'~, PRODUCTION/INJECTION REPORT LISBURNE PARTICIPATING AREA ALASKA OIL & GAS CONSER. COMM. Attn: Mr. Steve McMains 3001 Porcupine Drive Anchorage, Alaska 99501-3192 ALASKA OIL & GAS CONSER. COMM. Attn: Mr. D. W. Johnston 3001 Porcupine Drive Anchorage, Alaska 99501-3192 BP EXPLORATION, INC. Attn: Ms. Pat Mers P. O. Box 196612 Anchorage, Alaska 99519-6612 K. A. Kerns - ATO 740 M. Dolphin - ATO 706 C. P. Smithhisler - ATO 704 D. Vanderbilt - A TO 430 JOB: RTZ14LP# PROG: LRTB1701-05 AS OF: 01/31/1995 ARCO ALASKA INC. PAGE: 1 RUN TIME: 09:08 RUN DATE: 07/02/1997 FIELD - LISBURNE PARTICIPATING AREA 640 OPERATOR - ARCO ALASKA, INC. PRODUCTION MONTH - JA~UARY-1995 ALASKA OIL AND GAS CONSERVATION COMMISSION MONTHLY PRODUCTION AND INJECTION REPORT LISBURNE PARTICIPATING AREA RECONCILIATION TOTAL PIPELINE DELIVERIES FOR ALYESKA FROM LPC LESS DELIVERIES FROM FIELDS OTHER THAN LPA TOTAL PIPELINE DELIVERIES FROM LPA LESS LOAD OIL LESS OTHER OIL NET PIPELINE DELIVERY PLUS LEASE USE CRUDE PLUS INJECTED SLP LESS NGLS TO PIPELINE TOTAL NET ALLOCATED PRODUCTION FORM 10-405 I HEREBY CERTIF 5,244,863.00-: 4,787,296.00 457,567.00 - ( 0.00 ) ( 490.00) 457,077 .00 . 0.00 0.00 82,355.00 ) 374,722.00 - AND CORRECT TO THE BEST OF MY KNOWLEDGE. ~¡{;?- ( SUPERVISOR PRODUCTION & REVENUE ACCOUNTING DATE: ** END OF REPORT ** JOB: RTZ14LPH PROG: LRTB 1700-0 1 ARCO ALASKA INC. PAGE: 1 AS OF: 01/31/1995 RUN TIME: 09:07 FORM 10-405 RUN DATE: 07/02/1997 ALASKA OIL AND GAS CONSERVATION COMMISSION FIELD - LISBURNE PARTICIPATING AREA 640 MONTHL Y PRODUCTION REPORT OPERATOR - ARGO ALASKA, INC. LISBURNE PARTICIPATING AREA PRODUCTION MONTH - JANUARY-1995 AVG DAILY DAILY DAILY TOTAL TOTAL TOTAL WELL API FIELD DAYS GAS/OIL TUBING AVERAGE AVERAGE AVERAGE OIL WATER GAS NUMBER NUMBER CLASS CODE MTH PROD RATIO PRESSURE OIL WATER GAS (BBL) (BBL) (MCF) LGI04 t!I~9-21783-00 0 640144 1 31 27274 596 289 22 7871 ...,/ 8946 692 243997 LGI08 029-21562-00 0 640144 8 0 0000 0 0 0 0 0 0 0 LGI12 029-21560-00 0 640144 8 0 0000 0 0 0 0 0 0 0 01-01 029-21317-00 0 640144 2 16 3491 659 566 994 1976 v'9054 15903 31611 01-02 029-21403-00 0 640144 1 31 12953 611 324 7 4197 v1 0044 213 130096 01-09 029-21265-00 0 640144 2 21 8079 737 1943 2234 15695 v40795 46904 329603 01-10 029-21340-00 0 640144 8 0 0000 0 0 0 0 0 0 0 01-14 029-21381-00 0 640144 8 0 0000 0 0 0 0 0 0 0 01-15 029-21995-00 0 640144 2 11 13274 593 226 1 3004 ",2489 14 33039 01-21 029-20304-00 0 640144 1 31 24420 663 815 5 19895 ,/25255 167 616730 01-27 029-21989-00 0 640144 8 0 0000 0 0 0 0 0 0 0 01-28 029-21792-00 0 640144 8 0 0000 0 0 0 0 0 0 0 01-30 029-22010-00 0 640144 8 0 0000 0 0 0 0 0 0 0 OJ-3~ 029-20001-35 0 640144 1 31 0000 0 5310- 1770 1 164601- 54878 30 02-0 029-214Ó~-OO 0 640144 8 0 0000 0 0 0 0 0 0 0 02-06 029-20930-00 0 640144 2 31 6418 509 402 78 2580 Vl2460 . 2425 79965 02-08 029-21761-00 0 640144 8 0 0000 0 0 0 0 0 0 0 02-10 029-21746-00 0 640144 8 0 0000 0 0 0 0 0 0 0 02-13 029-21440-00 0 640144 8 0 0000 0 0 0 0 0 0 0 02-14 029-21758-00 0 640144 8 0 0000 0 0 0 0 0 0 0 02-16 029-21754-00 0 640144 8 0 0000 0 0 0 0 0 0 0 02-18 029-21766-00 0 640144 8 0 0000 0 0 0 0 0 0 0 02-20 029-21376-00 0 640144 8 0 0000 0 0 0 0 0 0 0 02-21 029-21485-00 0 640144 2 3 3006 539 225 10 676 .A575 30 2029 02-24 029-21346-00 0 640144 8 0 0000 0 0 0 0 0 0 0 02-25 029-21525-00 0 640144 8 0 0000 0 0 0 0 0 0 0 02-26 029-21359-00 0 640144 8 0 0000 0 0 0 0 0 0 O. 02-28 029-21298-00 0 640144 8 0 0000 0 0 0 0 0 0 0 02-29 029-21505-00 0 640144 8 0 0000 0 0 0 0 0 0 0 02-30 029-21272-00 0 640144 8 0 0000 0 0 0 0 0 0 0 02-32 029-21778-00 0 640144 1 27 27481 667 444 86 12207 11994 2319 329602 02-33 029-21534-00 0 640144 8 0 0000 0 0 0 0 0 0 0 03-02 029-21644-00 0 640144 1 31 16937 507 701 44 11878 21741 1358 368224 03-05 029-21421-00 0 640144 1 20 31770 540 301 473 9556 6016 9469 191128 03-08 029-21019-00 0 640144 8 0 0000 0 0 0 0 0 0 0 03-11 029-21452-00 0 640144 8 0 0000 0 0 0 0 0 0 0 03-12 029-21651-00 0 640144 8 0 0000 0 0 0 0 0 0 0 03-15 029-21476-00 0 640144 8 0 0000 0 0 0 0 0 0 0 03-18 029-21657-00 0 640144 2 16 29969 531 292 371 8758 4676 5943 140134 03-19 029-21494-00 0 640144 8 0 0000 0 0 0 0 0 0 0 03-22 029-21663-00 0 640144 1 17 8454 499 635 398 5366 10791 6769 91228 03-23 029-21513-00 0 640144 8 0 0000 0 0 0 0 0 0 0 03-24 029-21670-00 0 640144 2 16 11614 506 15 890 175 241 14236 2799 03-30 029-21673-00 0 640144 2 15 3006 506 236 759 711 3547 11390 10661 JOB: RTZ14LPH PROG: LRTB 1700-01 ARCO ALASKA INC. PAGE: 2 AS OF: 01/31/1995 RUN TIME: 09:07 FORM 10-405 RUN DATE: 07/02/1997 ALASKA OIL AND GAS CONSERVATION COMMISSION FIELD - LISBURNE PARTICIPATING AREA 640 MONTHLY PRODUCTION REPORT OPERATOR - ARCO ALASKA, INC. LISBURNE PARTICIPATING AREA PRODUCTION MONTH - JANUARY-1995 AVG DAILY DAILY DAILY TOTAL TOTAL TOTAL WELL API FIELD DAYS GAS/OIL TUBING AVERAGE AVERAGE AVERAGE OIL WATER GAS NUMBER NUMBER CLASS CODE MTH PROD RATIO PRESSURE OIL WATER GAS (BBL) (BBL) (MCF) 03-31 029-21544-00 0 640144 2 21 6328 498 187 333 1180 3917 6990 24787 04-03 029-21831-00 0 640144 2 1 8775 657 160 65 1404 160 65 1404 04-10 029-21983-00 0 640144 2 31 9363 497 882 15 8259 27344 479 256034 04-11 029-21846-00 0 640144 8 0 0000 0 0 0 0 0 0 0 04-12 029-22216-00 0 640144 2 16 8886 607 504 21 4477 8060 328 71624 04-14 029-21973-00 0 640144 2 17 4290 494 211 134 905 3585 2274 15378 04-15 029-20952-00 0 640144 2 31 2667 493 . 256 52 684 7950 1620 21205 04-18 029-21845-00 0 640144 8 0 0000 0 0 0 0 0 0 0 04-30 029-21860-00 0 640144 8 0 0000 0 0 0 0 0 0 0 04-31 029-21966-00 0 640144 2 19 2172 498 166 310 361 3159 5897 6861 04-32 029-22205-00 0 640144 8 0 0000 0 0 0 0 0 0 0 04-36 029-22189-00 0 640144 8 0 0000 0 0 0 0 0 0 0 05-01 029-21908-00 0 640144 8 0 0000 0 0 0 0 0 0 0 05-04 029-21679-00 0 640144 1 16 14634 598 412 371 6026 6588 5932 96411 05-05 029-21742-00 0 640144 1 31 13862 632 784 135 10868 24304 4180 336893 05-08 029-21711-00 0 640144 1 16 16991 592 307 143 5211 4907 2292 83374 05-09 029-22086-00 0 640144 1 31 20562 679 447 66 9185 13848 2043 284747 05-12 029-21694-00 0 640144 8 0 0000 0 0 0 0 0 0 0 05-13 029-21059-00 0 640144 1 12 29889 662 405 42 12103 4859 500 145233 05-15 029-21868-00 0 640144 1 23 31686 876 448 6 14208 10313 144 326774 05-16 029-21700-00 0 640144 1 31 23565 616 418 5 9842 12948 168 305116 05-17 029-21889-00 0 640144 2 31 11132 606 944 88 10507 29258 2738 325713 05-18 029-22060-00 0 640144 1 31 18695 609 421 6 7876 13060 182 244162 05-21 029-217 32-00 0 640144 1 9 20440 633 387 14 7920 3487 124 71276 05-23 029-22039-00 0 640144 1 30 13792 641 1186 38 16360 35587 1142 490814 05-24 029-21327-00 0 640144 1 31 28219 681 646 0 18228 20024 0 565058 05-25 029-21886-00 0 640144 1 31 29075 877 559 0 16256 17332 0 503928 05-26 029-22079-00 0 640144 8 0 0000 0 0 0 0 0 0 0 05-28 029-21717-00 0 640144 _ 2 31 12623 600 347 4 4385 .10769 135 135940 05-31 029-22091-00 0 640144 2 16 30028 687 514 41 15425 8219 650 246802 05-32 029-21861-00 0 640144 1 31 22965 608 594 2 13647 18422 50 423060 05-33 029-21943-00 0 640144 1 15 32164 815 568 3 18265 8518 51 273974 05-36 029-21933-00 0 640144 2 31 13069 615 739 1 9656 22904 22 299328 06-26 029-22440-00 0 640144 2 31 2995 756 1648 2 4935 51077 77 152976 FACILITY TOTAL 962 374722 210793 8309748 VOLUME TOTAL 962 374722 210793 8309748- ** END OF REPORT ** JOB: RTZ14LPU PROG: LRTB1701-06 AS OF: 01/31/1995 ARCO ALASKA INC. ALASKA OIL AND GAS CONSERVATION COMMISSION MONTHLY PRODUCTION REPORT LISBURNE PARTICIPATING AREA LPA NGLS PAGE: 1 RUN TIME: 09:08 RUN DATE: 07/02/1997 FIELD - LISBURNE PARTICIPATING AREA 640 OPERATOR - ARCO ALASKA, INC. PRODUCTION MONTH - JANUARY-1995 LEASE DAILY DAILY DAILY TOTAL TOTAL TOTAL OR UNIT WELL API FIELD AVERAGE AVERAGE AVERAGE DAYS NGLS WATER GAS NUMBER NUMBER NUMBER TYPE CODE MTH NGLS WATER GAS PROD (BBL) (BBL) (MCF) 11650 50-029-00000-09 P 640144 7 2657 0 0 31 82355 0 0 F AC I LI TY TOTAL 31 82355· 0 0 ** END OF REPORT ** JOB: RTZ14LPH PROG: LRTB1700-03 AS OF: 01/31/1995 FORM 10-406 ARCO ALASKA INC. ALASKA OIL AND GAS CONSERVATION COMMISSION MONTHLY INJECTION REPORT LISBURNE PARTICIPATING AREA PAGE: 1 RUN TIME: 09:07 RUN DATE: 07/02/1997 FIELD - LISBURNE PARTICIPATING AREA 640 OPERATOR - ARCO ALASKA, INC. PRODUCTION MONTH - JANUARY-1995 MAX AVG MAX AVG DAILY DAILY TOTAL TOTAL WELL API FIELD DAYS TUBING TUBING CASING CASING AVERAGE AVERAGE LIQUID GAS NUMBER NUMBER CLASS CODE INJ PRESSURE PRESSURE PRESSURE PRESSURE LIQUID GAS (BBL) (MCF) LGI02 029-21634-00 G 640144 31 4200 4045 520 440 0 98031 0 3038954 LGI06 029-21572-00 G 640144 31 4200 4050 100 68 0 46024 0 1426751 LGll0 029-21573-00 G 640144 31 4200 4030 290 175 0 106076 0 3288350 05-29 029-21724-00 G 640144 31 3540 3525 220 85 0 72535 0 2248590 FACILITY TOTAL 124 0 10002645 VOLUME TOTAL 124 0 10002645 ** END OF REPORT ** JOB: RTZ14LPH PROG: LRTB1700-04 AS OF: 01/31/1995 fORM 10-406 WELL NUMBER PWDDW API FIELD NUMBER CLASS CODE 029-21554-00 D 640034 VOLUME TOTAL ~ ~~~ ~.q:,. ~ ,,:~, ,,'C' "i) ,..¢j"'r,~ !{~) Q,~~:j:;:f)0 . t'" "t:~ I.~;· l~~' ~' PAGE: 1 RUN TIME: 09:07 RUN DATE: 07/02/1997 FIELD - LISBURNE PARTICIPATING AREA 640 OPERATOR - ARCO ALASKA, INC. PRODUCTION MONTH - JANUARY-1995 ARCO ALASKA INC. ALASKA OIL AND GAS CONSERVATION COMMISSION MONTHLY INJECTION REPORT LISBURNE PARTICIPATING AREA PRODUCED WATER DISPOSAL WELLS MAX AVG MAX AVG DAILY DAILY DAYS TUBING TUBING CASING CASING AVERAGE AVERAGE INJ PRESSURE PRESSURE PRESSURE PRESSURE LIQUID GAS 31 1487 1309 0 0 13253 0 31 ** END OF REPORT ** TOTAL LIQUID (BBL) 410828 410828 TOTAL GAS (MCF) o o ¿J ->') . ARCO Alaska, Inc. Post Office Box 100360 Anchorage, Alaska 99510-0360 Telephone 907 276-1215 ~~ ~~ July 3, 1997 TO: Recipients of the Production Report (Form 10-406) Lisburne Participating Area Monthly (Form 10-405) and Injection Report Enclosed are the REVISED Production and Injection Reports for production month January 1995. This revision reflects the reallocation of volumes between fields due to the errors resulting from a watercut calculation and measurement error. Please address any questions to Kim Kerns 907/265-1588. ERH/kak/mac kak/OO l/lisb/R2 ($J \'y ~"\ ('LV" '\ > ~fi ~'~v .'. ,O;:;,~ #" ~ '. f" '\ C·>:;": "ê1 v \). ,~~. ,\. " (" s::.' .../Q <'\.J " ~ 'Y ';}:-& ..) ,,<>'0' ~~~ .... "b- .~<v f'\.'~ . 'o{J' >9'J.,~ ~'ò.~' E. R. He drickson, Supervisor Production & Revenue Accounting Enclosure A PRODUCTION/INJECTION REPORT LISBURNE PARTICIPATING AREA ALASKA OIL & GAS CONSER. COMM. Attn: Mr. Steve McMains 3001 Porcupine Drive Anchorage, Alaska 99501-3192 ALASKA OIL & GAS CONSER. COMM. Attn: Mr. D. W. Johnston 3001 Porcupine Drive Anchorage, Alaska 99501-3192 BP EXPLORATION, INC. Attn: Ms. Pat Mers P. O. Box 196612 Anchorage, Alaska 99519-6612 K. A. Kerns - ATO 740 M. Dolphin - A TO 706 C. p, Smithhisler - A TO 704 D. Vanderbilt - ATO 430 """'..\'~ 1 'R(!'V~ " \J ,~\c::,'~)' \00/.\\\ _ t"~~. A'á$\{~ v' JOB: RTZ14LP# PROG: LRTB1701-05 AS OF: 01/31/1995 ARCO ALASKA INC. ALASKA OIL AND GAS CONSERVATION COMMISSION MONTHLY PRODUCTION AND INJECTION REPORT LISBURNE PARTICIPATING AREA RECONCILIATION TOTAL PIPELINE DELIVERIES FOR ALYESKA FROM LPC LESS DELIVERIES FROM FIELDS OTHER THAN LPA TOTAL PIPELINE DELIVERIES FROM LPA LESS LOAD OIL LESS OTHER OIL NET PIPELINE DELIVERY PLUS LEASE USE CRUDE PLUS INJECTED SLP LESS NGLS TO PIPELINE TOTAL NET ALLOCATED PRODUCTION FORM 10-405 I HEREBY CERTIF 5,244,863.00-: 4,787,296.00 457,567.00 - ( 0.00 ) ( 490.00) 457,077 .00 . 0.00 0.00 82,355.00 374,722.00 . PAGE: 1 RUN TIME: 09:08 RUN DATE: 07/02/1997 FIELD - LISBURNE PARTICIPATING AREA 640 OPERATOR - ARCO ALASKA, INC. PRODUCTION MONTH - JA~UARY-1995 9-h¡1?- ( AND CORRECT TO THE BEST OF MY KNOWLEDGE. SUPERVISOR PRODUCTION & REVENUE ACCOUNTING DATE: ** END OF REPORT ** JOB: RTZ14LPH PROG: LRTB1700-01 ARCO ALASKA INC. PAGE: 1 AS OF: 01/31/1995 RUN TIME: 09:07 FORM 10-405 RUN DATE: 07/02/1997 ALASKA OIL A~D GAS CONSERVATION COMMISSION FIELD - LISBURNE PARTICIPATING AREA 640 MONTHLY PRODUCTION REPORT OPERATOR - ARCO ALASKA, INC. LISBURNE PARTICIPATING AREA PRODUCTION MONTH - JANUARY-1995 AVG DAILY DAILY DAILY TOTAL TOTAL TOTAL WELL API FIELD DAYS GAS/OIL TUBING AVERAGE AVERAGE AVERAGE OIL WATER GAS NUMBER NUMBER CLASS CODE MTH PROD RA TI 0 PRESSURE OIL WATER GAS (BBl) (BBL) (MCF) LGI04 029-21783-00 0 640144 1 31 27274 596 289 22 7871 8946 692 243997 LGI08 029-21562-00 0 640144 8 0 0000 0 0 0 0 0 0 0 LGI12 029-21560-00 0 640144 8 0 0000 0 0 0 0 0 0 0 01-01 029-21317-00 0 640144 2 16 3491 659 566 994 1976 9054 15903 31611 01-02 029-21403-00 0 640144 1 31 12953 611 324 7 4197 10044 213 130096 01-09 029-21265-00 0 640144 2 21 8079 737 1943 2234 15695 40795 46904 329603 01-10 029-21340-00 0 640144 8 0 0000 0 0 0 0 0 0 0 01-14 029-21381-00 0 640144 8 0 0000 0 0 0 0 0 0 0 01-15 029-21995-00 0 640144 2 11 13274 593 226 1 3004 2489 14 33039 01-21 029-20304-00 0 640144 1 31 24420 663 815 5 19895 25255 167 616730 01-27 029-21989-00 0 640144 8 0 0000 0 0 0 0 0 0 0 01-28 029-21792-00 0 640144 8 0 0000 0 0 0 0 0 0 0 01-30 029-22010-00 0 640144 8 0 0000 0 0 0 0 0 o· 0 01-35 029-20001-35 0 640144 1 31 0000 0 5310- 1770 1 164601- 54878 30 02-03 029-21465-00 0 640144 8 0 0000 0 0 0 0 0 0 0 02-06 029-20930-00 0 640144 2 31 6418 509 402 78 2580 12460 . 2425 79965 02-08 029-21761-00 0 640144 8 0 0000 0 0 0 0 0 0 0 02-10 029-21746-00 0 640144 8 0 0000 0 0 0 0 0 0 0 02-13 029-21440-00 0 640144 8 0 0000 0 0 0 0 0 0 0 02-14 029-21758-00 0 640144 8 0 0000 0 0 0 0 0 0 0 02-16 029-21754-00 0 640144 8 0 0000 0 0 0 0 0 0 0 02-18 029-21766-00 0 640144 8 0 0000 0 0 0 0 0 0 0 02-20 029-21376-00 0 640144 8 0 0000 0 0 0 0 0 0 0 02-21 029-21485-00 0 640144 2 3 3006 539 225 10 676 675 30 2029 02-24 029-21346-00 0 640144 8 0 0000 0 0 0 0 0 0 0 02-25 029-21525-00 0 640144 8 0 0000 0 0 0 0 0 0 0 02-26 029-21359-00 0 640144 8 0 0000 0 0 0 0 0 0 0, 02-28 029-21298-00 0 640144 8 0 0000 0 0 0 0 0 0 0 02-29 029-21505-00 0 640144 8 0 0000 0 0 0 0 0 0 0 02-30 029-21272-00 0 640144 8 0 0000 0 0 0 0 0 0 0 02-32 029-21778-00 0 640144 1 27 27481 667 444 86 12207 11994 2319 329602 02-33 029-21534-00 0 640144 8 0 0000 0 0 0 0 0 0 0 03-02 029-21644-00 0 640144 1 31 16937 507 701 44 11878 21741 1358 368224 03-05 029-21421-00 0 640144 1 20 31770 540 301 473 9556 6016 9469 191128 03-08 029-21019-00 0 640144 8 0 0000 0 0 0 0 0 0 0 03-11 '029-21452-00 0 640144 8 0 0000 0 0 0 0 0 0 0 03-12 029-21651-00 0 640144 8 0 0000 0 0 0 0 0 0 0 03-15 029-21476-00 0 640144 8 0 0000 0 0 0 0 0 0 0 03-18 029-21657-00 0 640144 2 16 29969 531 292 371 8758 4676 5943 140134 03-19 029-21494-00 0 640144 8 0 0000 0 0 0 0 0 0 0 03-22 029-21663-00 0 640144 1 17 8454 499 635 398 5366 10791 6769 91228 03-23 029-21513-00 0 640144 8 0 0000 0 0 0 0 0 0 0 03-24 029-21670-00 0 640144 2 16 11614 506 15 890 175 241 14236 2799 03-30 029-21673-00 0 640144 2 15 3006 506 236 759 711 3547 11390 10661 JOB: RTZ14LPH PROG: LRTB1700-01 ARCO ALASKA INC. PAGE: 2 AS OF: 01/31/1995 RUN TIME: 09:07 FORM 10-405 RUN DATE: 07/02/1997 ALASKA OIL AND GAS CONSERVATION COMMISSION FIELD - LISBURNE PARTICIPATING AREA 640 MONTHLY PRODUCTION REPORT OPERATOR - ARCO ALASKA, INC. LISBURNE PARTICIPATING AREA PRODUCTION MONTH - JANUARY-1995 AVG DAILY DAILY DAILY TOTAL TOTAL TOTAL WELL API FIELD DAYS GAS/OIL TUBING AVERAGE AVERAGE AVERAGE OIL WATER GAS NUMBER NUMBER CLASS CODE MTH PROD RATIO PRESSURE Oil WATER GAS (BBL) (BBL) (MCF) 03-31 029-21544-00 0 640144 2 21 6328 498 187 333 1180 3917 6990 24787 04-03 029-21831-00 0 640144 2 1 8775 657 160 65 1404 160 65 1404 04-10 029-21983-00 0 640144 2 31 9363 497 882 15 8259 27344 479 256034 04-11 029-21846-00 0 640144 8 0 0000 0 0 0 0 0 0 0 04-12 029-22216-00 0 640144 2 16 8886 607 504 21 4477 8060 328 71624 04-14 029-21973-00 0 640144 2 17 4290 494 211 134 905 3585 2274 15378 04-15 029-20952-00 0 640144 2 31 2667 493 256 52 684 7950 1620 21205 04-18 029-21845-00 0 640144 8 0 0000 0 0 0 0 0 0 0 04-30 029-21860-00 0 640144 8 0 0000 0 0 0 0 0 0 0 04-31 029-21966-00 0 640144 2 19 2172 498 166 310 361 3159 5897 6861 04-32 029-22205-00 0 640144 8 0 0000 0 0 0 0 0 0 0 04-36 029-22189-00 0 640144 8 0 0000 0 0 0 0 0 0 0 05-01 029-21908-00 0 640144 8 0 0000 0 0 0 0 0 0 0 05-04 029-21679-00 0 640144 1 16 14634 598 412 371 6026 6588 5932 96411 05-05 029-21742-00 0 640144 1 31 13862 632 784 135 10868 24304 4180 336893 05-08 029-21711-00 0 640144 1 16 16991 592 307 143 5211 4907 2292 83374 05-09 029-22086-00 0 640144 1 31 20562 679 447 66 9185 13848 2043 284747 05-12 029-21694-00 0 640144 8 0 0000 0 0 0 0 0 0 0 05-13 029-21059-00 0 640144 1 12 29889 662 405 42 12103 4859 500 145233 05-15 029-21868-00 0 640144 1 23 31686 876 448 6 14208 10313 144 326774 05-16 029-21700-00 0 640144 1 31 23565 616 418 5 9842 12948 168 305116 05-17 029-21889-00 0 640144 2 31 11132 606 944 88 10507 29258 2738 325713 05-18 029-22060-00 0 640144 1 31 18695 609 421 6 7876 13060 182 244162 05-21 029-21732-00 0 640144 1 9 20440 633 387 14 7920 3487 124 71276 05-23 029-22039-00 0 640144 1 30 13792 641 1186 38 16360 35587 1142 490814 05-24 029-21327-00 0 640144 1 31 28219 681 646 0 18228 20024 0 565058 05-25 029-21886-00 0 640144 1 31 29075 877 559 0 16256 17332 0 503928 05-26 029-22079-00 0 640144 8 0 0000 0 0 0 0 0 0 0 05-28 029-21717-00 0 640144 _ 2 31 12623 600 347 4 4385 10769 135 135940 05-31 029-22091-00 0 640144 2 16 30028 687 514 41 15425 8219 650 246802 05-32 029-21861-00 0 640144 1 31 22965 608 594 2 13647 18422 50 423060 05-33 029-21943-00 0 640144 1 15 32164 815 568 3 18265 8518 51 273974 05-36 029-21933-00 0 640144 2 31 13069 615 739 1 9656 22904 22 299328 06-26 029-22440-00 0 640144 2 31 2995 756 1648 2 4935 51077 77 152976 FACiliTY TOTAL 962 374722 210793 8309748 VOLUME TOTAL 962 374722· 210793 8309748- ** END OF REPORT** JOB: RTZ14LPH PROG: LRTB1701-06 AS OF: 01/31/1995 ARCO ALASKA INC. ALASKA OIL AND GAS CONSERVATION COMMISSION MONTHLY PRODUCTION REPORT LISBURNE PARTICIPATING AREA LPA NGLS PAGE: 1 RUN TIME: 09:08 RUN DATE: 07/02/1997 FIELD - LISBURNE PARTICIPATING AREA 640 OPERATOR - ARCO ALASKA, INC. PRODUCTION MONTH - JANUARY-1995 LEASE DAILY DAILY DAILY TOTAL TOTAL TOTAL OR UNIT ~LL API FIELD AVERAGE AVERAGE AVERAGE DAYS NGLS WATER ()~5 NUMBER NUMBER NUMBER TYPE CODE MTH NGLS WATER GAS PROD (BBL) (BBL) (MCF) 11650 50-029-00000-09 P 640144 7 2657 0 0 31 82355 0 0 F AC I L ITY TOTAL 31 82355· 0 0 ** END OF REPORT ** JOB: RTZ14LP# PROG: LRTB1700-03 AS OF: 01/31/1995 FORM 10-406 ARCO ALASKA INC. PAGE: 1 RUN TIME: 09:07 RUN DATE: 07/02/1997 FIELD - LISBURNE PARTICIPATING AREA 640 OPERATOR - ARCO ALASKA, INC. PRODUCTION MONTH - JANUARY-1995 ALASKA OIL AND GAS CONSERVATION COMMISSION MONTHLY INJECTION REPORT LISBURNE PARTICIPATING AREA MAX AVG MAX AVG DAILY DAILY TOTAL TOTAL WELL API FIELD DAYS TUBING TUBING CASING CASING AVERAGE AVERAGE LIQUID GAS NUMBER NUMBER CLASS CODE INJ PRESSURE PRESSURE PRESSURE PRESSURE LIQUID GAS (BBL) (MCF) LGI02 029-21634-00 G 640144 31 4200 4045 520 440 0 98031 ' 0 3038954 LGI06 029-21572-00 G 640144 31 4200 4050 100 68 0 46024 0 1426751 LGI10 029-21573-00 G 640144 31 4200 4030 290 175 0 106076 0 3288350 05-29 029-21724-00 G 640144 31 3540 3525 220 85 0 72535 0 2248590 F AC I L ITY TOTAL 124 0 10002645 VOLUME TOTAL 124 0 10002645 ** END OF REPORT ** JOB: RTZ14LP# PROG: LRTB1700-04 AS OF: 01/31/1995 FORM 10-406 ARCO ALASKA INC. ALASKA OIL AND GAS CONSERVATION COMMISSION MONTHLY INJECTION REPORT LISBURNE PARTICIPATING AREA PRODUCED WATER DISPOSAL WELLS PAGE: 1 RUN TIME: 09:07 RUN DATE: 07/02/1997 FIELD - LISBURNE PARTICIPATING AREA 640 OPERATOR - ARCO ALASKA, INC. PRODUCTION MONTH - JANUARY-1995 MAX AVG MAX AVG DAILY DAILY TOTAL TOTAL WELL API FIELD DAYS TUBING TUBING CASING CASING AVERAGE AVERAGE LIQUID GAS NUMBER NUMBER CLASS CODE INJ PRESSURE PRESSURE PRESSURE PRESSURE LI QU I D GAS (BBL) (MCF) PWDDW 029-21554-00 D 640034 31 1487 1309 0 0 13253 0 410828 0 VOLUME TOTAL 31 410828 0 ** END OF REPORT ** ARca Alaska, Inc. Post Office Box 100360 Anchorage, Alaska 99510-0360 Telephone 907 276-1215 ~~ ~~ July 3, 1997 TO: Recipients of the Production Report (Form 10-406) Point (Form McIntyre 10-405) Participating and Injection Area Monthly Report Enclosed are the REVISED Production and Injection Reports for production month January 1995. This revision reflects the reallocation of volumes between fields due to the errors resulting from a watercut calculation and measurement error. Please address any questions to Kim Kerns 907/265-1588. SinCe~el~j :ç14i~or Production & Revenue Accounting ERH/kak/mac kak/OO I/ptm/R2 þ <,,) /,\.', 'X;·· ,,'\ '. :<;'''' '\ . '. "1, (),' '(8 , ~\' ~'- ~¡f? .~<{;) '1,1),' q;¡..... <§:' &f/:? ~{? Enclosure PRODUCTION /INJECTION REPORf POINT MCINTIRE PARTICIPATING AREA BP EXPLORATION, INC. Attn: Ms. Pat Mers P.O, Box 196612 Anchorage. Alaska 99519-6612 ALASKA OIL & GAS CONSER. COMM, Attn: Mr. Steve McMains 3001 Porcupine Drive Anchorage, Alaska 99501-3192 ALASKA OIL & GAS CONSER. COMM. Attn: Mr. D. W. Johnston 3001 Porcupine Drive Anchorage, Alaska 99501-3192 K. A. Kerns - ATO 740 M. Dolphin - ATO 706 C. P. Smithhisler - ATO 704 D. Vanderbilt - ATO 430· JOB: RTZ14PT# PROG: LRTB1701~05 AS OF: 01/31/1995 ARCO ALASKA INC. ALASKA OIL AND GAS CONSERVATION COMMISSION MONTHLY PRODUCTION AND INJECTION REPORT POINT MCINTYRE PA RECONCILIATION TOTAL P'PEL'HE DEL'VER'ES fOR ALYESKA fROM LPC LESS DELIVERIES FROM FIELDS OTHER THAN PTMAC TOTAL PIPELINE DELIVERIES FROM PTMAC LESS LOAD OIL LESS OTHER OIL NET PIPELINE DELIVERY PLUS LEASE USE CRUDE PLUS INJECTED SLP LESS NGLS TO PIPELINE TOTAL NET ALLOCATED PRODUCTION /(J .~ -A .. A, ._µY~ '\ ,t' ~ , \~ 5,244,863.00_ 1,005,959.00 4,238,904.00 _ ( 0.00 , ( 0.00 , 4,238,904.00 0.00 0.00 55, 181 ,00 4,183,723.00 ~~ ~~ '. ,,¿;- <t. ()~'t". ,(9,"~ ~~. ".y'J, :?/>.M "0;,., I' "'1& <IS' i?~ <'. c.' ß"q 00>Q] . v.s:.~;. FORM 10-405 I HEREBY CERT, Y TH T THE fOREGD'HG STATEMENTS ARE TRUE AND GDRREGT TO THE BEST Of MY KNOWLEDGE, SUPERVISOR PRODUCTION & REVENUE ACCOUNTING ** END OF REPORT ** PAGE: 1 RUN TIME: 09: 17 RUN DATE; 07/02/1997 FIELD - POINT MCINTYRE PA 666 OPERATOR - ARCO ALASKA, INC. PRODUCTION MONT'H ~ JANUARY-1995 DATE, ~þ JOB: RTZ14PTH PROG: LRTB 1700-0 1 ARCO ALASKA INC. PAGE: 1 AS OF: 01/31/1995 RUN TIME: 09:16 FORM 10-405 RUN DATE: 07/02/1997 ALASKA OIL AND GAS CONSERVATION COMMISSION FIELD - POINT MCINTYRE PA 666 MONTHLY PRODUCTION REPORT OPERATOR - ARCO ALASKA, INC. POINT MCINTYRE PA PRODUCTION MONTH - JANUARY-1995 AVG DAILY DAILY DAILY TOTAL TOTAL TOTAL WELL API FIELD DAYS GAS/OIL TUBING AVERAGE AVERAGE AVERAGE OIL WATER GAS NUMBER NUMBER CLASS CODE MTH PROD RATIO PRESSURE OIL WATER GAS (BBL) (BBL) (MCF) 11-02 Qa9-21779",00 0 ~66100 2 31 3133 2236 1373 1 4302 v-42573 25 133371 11-03 029-21912-00 0 666100 2 29 0739 963 5647 65 4175 ..-163762 1885 121063 11-04 029-22366-00 0 666100 2 31 3160 2031 5393 209 17043 tA67175 6466 528339 11-05 029-22378-00 0 666100 2 31 1003 1546 5037 9 5052 ..156158 267 156625 11-07 029-21996-00 0 666100 2 31 2645 644 655 1 1733 ~20313 19 53734 11-08 029-22384-00 0 666100 2 31 0843 1625 1726 0 1455 v53511 4 45091 11-11 029-22284-00 0 666100 2 29 0681 679 6310 173 4298 v182978 5019 124633 11-12 029-22134-00 0 666100 2 26 0668 695 5554 468 3707 v144391 12163 96390 11-13 029-22372-00 0 666100 2 31 0733 1536 2383 1 1748 v73881 22 54176 11-17 029-22358-00 0 666100 2 31 4467 2504 2932 0 13100 v 90899 0 406086 11-20 029-22288-00 0 666100 2 29 1380 1611 1996 1 2753 {/ 57875 42 79843 11-35 029-20011-35 0 666100 1 31 0000 0 7476 3242- 1 231770 100491- 30 12-06 029-22388-00 0 666100 2 29 0574 649 1028 3 590 ....29822 96 17115 12-07 029-22469-00 0 666100 2 28 0764 702 11951 39 9128 ,",,'334623 1104 255592 12-12 029-22395-00 0 666100 2 31 0672 664 7478 35 5028 v231829 1082 155881 12-18 029-22471-00 0 666100 2 29 0724 728 7896 29 5720 V'228973 844 165881 12-21 029-22467-00 0 666100 2 31 0792 700 8600 34 6811 v266594 1058 211131 12-30 029-22289-00 0 666100 2 31 0824 681 8479 42 6986 .1262849 1305 216568 12-31 029-22456-00 0 666100 2 31 0743 674 8873 623 6591 ..-'275060 19300 204319 12-48 029-22309-00 0 666100 2 18 0870 782 3073 835 2674 v 55312 15030 48129 12-49 029-22252-00 0 666100 2 28 0679 939 6472 29 4395 v181223 805 123046 12-51 029-22262-00 0 666100 2 10 0471 650 835 19 393 v 8348 194 3934 12-54 029-22470-00 0 666100 2 31 0855 664 9289 16 7940 0/287957 492 246138 12-57 029-22183-00 0 666100 2 27 1082 1647 4823 6 5220 030233 172 140935 12-58 029-22000-00 0 666100 2 31 0659 670 8575 45 5648 ,,"265828 1390 175081 12-60 029-22192-00 0 666100 2 28 0696 687 8564 28 5963 .-"239786 793 166975 F AC I LI TY TOTAL 744 4183723 30914- 3930106 VOLUME TOTAL 744 4183723 30914- 3930106/ ** END OF REPORT ** JOB: RTZ14PTH PROG: LRTB1701-06 AS OF: 01/31/1995 ARCO ALASKA INC. PAGE: 1 RUN TI ME: 09: 17 RUN DATE: 07/02/1997 FIELD - POINT MCINTYRE PA 666 OPERATOR - ARCO ALASKA, INC. PRODUCTION MONTH - JANUARY-1995 ALASKA OIL AND GAS CONSERVATION COMMISSION MONTHLY PRODUCTION REPORT POINT MCINTYRE PA PTMAC NGLS LEASE DAILY DAilY DAILY TOTAL TOTAL TOTAL ø" UNIT \fELL API FIELD AVERAGE AVERAGE AVERAGE DAYS NGLS WATER GAS NUMBER NUMBER NUMBER TYPE CODE MTH NGlS WATER GAS PROD (BBL) (BBL) (MCF) 11650 50-029-00000-11 P 666100 7 1780 0 0 31 55181 0 0 FACILITY TOTAL 31 55181 . 0 0 ** END OF REPORT ** JOB: RTZ14PTH PROG: LRTB 1700-03 ARCO ALASKA INC. PAGE: 1 AS OF: 01/31/1995 RUN TIME: 09:16 FORM 10-406 RUN DATE: 07/02/1997 ALASKA OIL AND GAS CONSERVATION COMMISSION FIELD - POINT MCINTYRE PA 666 MONTHLY INJECTION REPORT OPERATOR - ARCO ALASKA, INC. POINT MCINTYRE PA PRODUCTION MONTH - JANUARY-1995 MAX AVG MAX AVG DAILY DAILY TOTAL TOTAL WELL API FIELD DAYS TUBING TUBING CASING CASING AVERAGE AVERAGE LIQUID GAS NUMBER NUMBER CLASS CODE INJ PRESSURE PRESSURE PRESSURE PRESSURE LIQUID GAS (BBL) (MCF) 08-01 029-22298-00 G 666100 31 3980 3540 500 487 0 60024 0 1860742 11-01 029-22018-00 W 666100 31 0 0 1800 1765 2093 0 64876 0 11-14 029-22338-00 W 666100 31 0 0 20 13 26408 0 818654 0 11-16 029-22349-00 W 666100 31 0 0 520 398 15847 0 491242 0 11-21 029-22363-00 W 666100 31 0 0 100 48 15926 0 493717 0 11-25 029-21937-00 W 666100 31 0 0 80 70 14454 0 448074 0 12-15 029-22409-00 W 666100 31 0 0 80 50 17466 0 541437 0 12-16 029-22397-00 W 666100 31 0 0 20 18 26705 0 827849 0 12-23 029-22453-00 W 666100 31 0 0 30 18 21635 0 670674 0 12-29 029-22407-00 W 666100 31 0 0 1850 1823 28169 0 873239 0 12-42 029-22405-00 W 666100 31 0 0 20 18 21837 0 676936 0 12-46 029-22401-00 W 666100 31 0 0 20 18 21837 0 676933 0 FACILITY TOTAL 372 6583631 1860742 VOLUME TOTAL 372 6583631 . 1860742- ** END OF REPORT ** JOB: RTZ14PTH PROG: LRTB1700-02 AS OF: 01/31/1995 FORM 10-405 ARCO ALASKA INC. WELL NUMBER API NUMBER ALASKA OIL AND GAS CONSERVATION COMMISSION MONTHLY PRODUCTION REPORT POINT MCINTYRE PA ENHANCED OIL RECOVERY INJECTION PROJECT ALLOCATED PRODUCTION FIELD DAYS CLASS CODE MTH PROD GAS/OIL RATIO AVG TUBING PRESSURE DAILY AVERAGE OIL **** NO DATA FOR REPORT **** ** END OF REPORT ** DAILY AVERAGE WATER DAILY AVERAGE GAS PAGE: 1 RUN TIME: 09: 16 RUN DATE: 07/02/1997 FIELD - POINT MCINTYRE PA 666 OPERATOR - ARCO ALASKA, INC. PRODUCTION MONTH - JANUARY-1995 TOTAL OIL (BBL) TOTAL WATER (BBL) TOTAL GAS (MCF) ARca Alaska, Inc. Post Office Box 100360 Anchorage, Alaska 99510-0360 Telephone 907 276-1215 ~~ ~~ July 3, 1997 TO: Recipients of the Production Report (Form 10-406) West (Form Beach Participating Area 10-405) and Injection Monthly Report Enclosed are the REVISED Production and Injection Reports for production month January 1995. This revision reflects the reallocation of volumes between fields due to the errors resulting from a watercut calculation and measurement error. Please address any questions to Kim Kerns 907/265-1588. Sincerely rd~perVisor Production & Revenue Accounting Enclosure ERH/kak/mac kak/OO lIwb/R2 R't~':(;" ." .:-,l~~ ::., ",-, f¡ , \ d ·CC..\\.î' c,ü'{ÎI \\\ \;:> ~ _ ,,:\\ Ñ, "I/~ \J.' ... A.lasl"~ PRODUCTION /INJECTION REPORT WEST BEACH PARTICIPATING AREA AIASKA OIL & GAS CONSER. COMM. Attn: Mr. Steve McMains 3001 Porcupine Drive Anchorage. Alaska 9950J-3192 AIASKA OIL & GAS CONSER. COMM. Attn: Mr. D. W. Johnston 3001 Porcupine Drive Anchorage. Alaska 995f) 1-3192 K. A Kerns - ATO 740 M. Dolphin - ATO 706 C. P.Smithhisler - AT0704 D. Vanderbilt - ATO 43() kak/OO 1 b/wb JOB: RTZ14WBH PROG: lRTB1701-05 AS OF: 01/31/1995 ARCO ALASKA INC. PAGE: 1 RUN TIME: 09:24 RUN DATE: 07/02/1997 FIELD - WEST BEACH PARTICIPATING AR 640 OPERATOR - ARCO ALASKA, INC. PRODUCTION MONTH - JANUARY-1995 ALASKA Oil AND GAS CONSERVATION COMMISSION MONTHLY PRODUCTION AND INJECTION REPORT WEST BEACH PARTICIPATING AREA RECONCiliATION TOTAL PIPELINE DELIVERIES FOR AlYESKA FROM lPC lESS DELIVERIES FROM FIELDS OTHER THAN WBEACH TOTAL PIPELINE DELIVERIES FROM WBEACH lESS lOAD Oil lESS OTHER Oil NET PIPELINE DELIVERY PLUS lEASE USE CRUDE PLUS INJECTED SlP lESS NGlS TO PIPELINE 5,244,863.00- 5,229,612.00 15,251.00- 0.00 ) 0.00 ) 15,251.00 . 0.00 0.00 287.00 .) TOTAL NET AllOCATED PRODUCTION 14,964.00 - FORM 10-405 I HEREBY CERTIF ARE TRUE AND CORRECT TO THE BEST OF MY KNOWLEDGE. SUPERVISOR PRODUCTION & REVENUE ACCOUNTING DATE' +h ~7 / ** END OF REPORT ** JOB: RTZ14WB# PROG: LRTB1700-01 AS OF: 01/31/1995 FORM 10-405 ARCO ALASKA INC. PAGE: 1 RUN TIME: 09:24 RUN DATE: 07/02/1997 FIELD - WEST BEACH PARTICIPATING AR 640 OPERATOR - ARCO ALASKA, INC. PRODUCTION MONTH - JANUARY-1995 ALASKA OIL AND GAS CONSERVATION COMMISSION MONTHLY PRODUCTION REPORT WEST BEACH PARTICIPATING AREA AVG DAILY DAILY DAILY TOTAL TOTAL TOTAL WELL API FIELD DAYS GAS/OIL TUBING AVERAGE AVERAGE AVERAGE OIL WATER GAS NUMBER NUMBER CLASS CODE MTH PROD RATIO PRESSURE OIL WATER GAS (BBL) (BBL) (MCF) 10-04 029-22117-00 0 640186 4 2439 642 2481 33 6053 9925 131 24212 10-35 029-20010-35 0 640186 31 0006 0 163 45 1 5039 1398 30 FACILITY TOTAL 35 14964 1529 24242 VOLUME TOTAL 35 14964, 1529 24242 - ** END OF REPORT ** JOB: RTZ14WBU PROG: LRTB1701-06 AS OF: 01/31/1995 ARCO ALASKA INC. PAGE: 1 RUN TIME: 09:24 RUN DATE: 07/02/1997 FIELD - WEST BEACH PARTICIPATING AR 640 OPERATOR - ARCO ALASKA, INC. PRODUCTION MONTH - JANUARY-1995 ALASKA OIL AND GAS CONSERVATION COMMISSION MONTHLY PRODUCTION REPORT WEST BEACH PARTICIPATING AREA WBEACH NGLS I..USE DAILY DAILY DAILY TOTAL TOTAL TOT4L OR UNIT WELL API FIELD AVERAGE AVERAGE AVERAGE DAYS NGLS WATER GAS NUMBER NUMBER NUMBER TYPE CODE MTH NGLS WATER GAS PROD (BBL) (BBL) (MCF) 1 1650 50-029-00000-10 P 640186 7 9 0 0 31 287 0 0 FACILITY TOTAL 31 287- 0 0 ** END OF REPORT ** J, ARca Alaska, Inc. Post Office Box 100360 Anchorage. Alaska 99510-0360 Telephone 907 276-1215 ~~ ~~ July 3, 1997 TO: Recipients Production 10-406) of the North Prudhoe Bay Area Monthly Report (Form 10-405) and Injection Report (Form Enclosed are the REVISED Production and Injection Reports for production month January 1995. This revision reflects the reallocation of volumes between fields due to the errors resulting from a watercut calculation and measurement error. Please address any questions to Kim Kerns 907/265-1588. Sinc"')i ~. H~erVisor Production & Revenue Accounting Enclosure ERH/kak/mac kak/OO 1/npb/R2 Þ' n~. ·""''¡~···'"'''''··D. t· ,~ ;~'; ~""Jt '& ~ ,§' <f . ~-4!; h .c'l ,,,¡ o 1997 & , PRODUCTION /INJECTION REPORT NORTH PRUDHOE BAY PARTICIPATING AREA AlASKA OIL & GAS CONSER. COMM. Attn: Mr. Steve McMains 3001 Porcupine Drive Anchorage. Alaska 99501-3192 AlASKA OIL & GAS CONSER. COMM. Attn: Mr. D. W. Johnston 3001 Porcupine Drive Anchorage, Alaska 99501-3192 K. A Kerns - ATO 740 M. Dolphin - ATO 706 C. P. Smithhisler - ATO 704 D. Vanderbilt - ATO 430 kak/001 b/npb JOB: RTZ14NPH PROG: LRTB1701-05 AS OF: 01/31/1995 ARCO ALASKA INC. ALASKA OIL AND GAS CONSERVATION COMMISSION MONTHLY PRODUCTION AND INJECTION REPORT NORTH PRUDHOE BAY PA RECONCILIATION TOTAL PIPELINE DELIVERIES FOR ALYESKA FROM LPC LESS DELIVERIES FROM FIELDS OTHER THAN NPBU TOTAL PIPELINE DELIVERIES FROM NPBU LESS LOAD OIL LESS OTHER OIL NET PIPELINE DELIVERY PLUS LEASE USE CRUDE PLUS INJECTED SLP LESS NGLS TO PIPELINE 5,244,863.00"- 5,207,532.00 37,331 . 00 ~ 0.00 ) 0.00 ) 37 , 331 .00 0.00 0.00 5 , 003 . 00 ~ ) TOTAL NET ALLOCATED PRODUCTION 32,328.00- '" FORM 10-405 I HEREBY CERTIE E FOREGOING STATEMENTS ARE TRUE AND CORRECT TO THE BEST OF MY KNOWLEDGE. PAGE: 1 RUN TIME: 09:31 RUN DATE: 07/02/1997 FIELD - NORTH PRUDHOE BAY PA 640 OPERATOR - ARGO ALASKA, INC. PRODUCTION MONTH - JANUARY-1995 SUPERVISOR PRODUCTION & REVENUE ACCOUNTING DATE: ~h/'/ì- , r ** END OF REPORT ** JOB: RTZ14NPH PROG: LRTB1700-01 AS OF: 01/31/1995 FORM 10-405 ARCO ALASKA INC. PAGE: 1 RUN TIME: 09:31 RUN DATE: 07/02/1997 FIELD - NORTH PRUDHOE BAY PA 640 OPERATOR - ARCO ALASKA, INC. PRODUCTION MONTH - JANUARY-1995 ALASKA OIL AND GAS CONSERVATION COMMISSION MONTHLY PRODUCTION REPORT NORTH PRUDHOE BAY PA AVG DAILY DAILY DAILY TOTAL TOTAL TOTAL WELL API FIELD DAYS GAS/OIL TUBING AVERAGE AVERAGE AVERAGE OIL WATER GAS NUMBER NUMBER CLASS CODE MTH PROD RATIO PRESSURE OIL WATER GAS (BBL) (BBL) (MCF) 09-03 029-22322-00 0 640152 31 2763 645 4146 4517 11457 128532 140013 355168 09-35 029-20009-35 0 640152 31 0000 0 3103- 1890 1 96204- 58600 30 FACILITY TOTAL 62 32328 198613 355198 VOLUME TOTAL 62 32328~ 1986 13 355198~ ** END OF REPORT ** JOB: RTZ14NP# PROG: LRTB1701-06 AS OF: 01/31/1995 ARCO ALASKA INC. PAGE: 1 RUN TIME: 09:31 RUN DATE: 07/02/1997 FIELD - NORTH PRUDHOE BAY PA 640 OPERATOR - ARCO ALASKA, INC. PRODUCTION MONTH - JANUARY-1995 ALASKA OIL AND GAS CONSERVATION COMMISSION MONTHLY PRODUCTION REPORT NORTH PRUDHOE BAY PA NPBU NGLS LEASE DAILY DAILY DAILY TOTAL TOT AL . TOTAL OR UNIT WELL API FIELD AVERAGE AVERAGE AVERAGE DAYS NGLS WATER çtS NUMBER NUMBER NUMBER TYPE. CODE MTH NGLS WATER GAS PROD (BBL) (BBL) (MCF) 11650 50-029-00000-12 P 640152 7 161 0 0 31 5003 0 0 FACILITY TOTAL 31 5003~ 0 0 ** END OF REPORT **