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CO 108
Conservation Order Cover Page XHVZE This page' is required for administrative purposes in managing the scanning process. It marks the extent of scanning and identifies certain actions that have been taken. Please insure that it retains it's current location in this file. Conservation Order Category Identifier Organizing RESCAN [] Color items: [] Grayscale items: n Poor Quality Originals: [] Other: NOTES: DIGITAL DATA [] Diskettes, No. [] Other, No/Type OVERSIZED (Scannable with large plotter/scanner) [] Other items OVERSIZED (Not suitable for plotter/scanner, may work with 'log' s.~.q~F- [~"~Logs of various kinds [] Other BY: MARIA Scanning Preparation TOTAL PAGES ?~.~/-- Production Scanning Stage I PAGE COUNT FROM SCANNED DOCUMENT: /~'~ PAGE COUNT MATCHES NUMBER IN SCANNING pRE~ARA'IJlON: ~//' YES NO BY: Stage 2 IF NO IN STAGE 1, PAGE(S) DISCREPANCIES WERE FOUND: .... YES ~ NO (SCANNING IS COMPLETE AT THIS POINT UNLESS SPECIAL ATTENTION IS REQUIRED ON AN INDIVIDUAL PAGE BASIS DUE TO QUAU'r¥, GRAYSCALE OR COLOR IMAGES) General Notes or Comments about this Document: 5/21/03, ConservOrdCvrPg.wpd STATE OF ALASKA DEPARTMENT OF NATURAL RESOURCES DIVISION OF OIL AND GAS Alaska Oil and Gas Conservation Committee 3001 Porcupine Drive Anchorage, Alaska 9§504 Re: THE APPLICATION OF THE ATLANTIC ) RICHFIELD COMPANY for an order ) permitting a pressure maintenance ) project in the North Trading Bay ) Unit for the "~" NE and Hemlock ) NE Oil Pools ) Conservation ~rder No. 108 Trading Bay Field Pressure Maintenance' Project TradinR Bay "C" NE and Hemlock NE Oil Pools November 18, 1971 IT APPEARING THAT: 1. Atlantic Richfield Company, as Unit Operator for the North Trading Bay Unit participants, submitted a petition dated September 24, 1971, requesting the referenced project pursuant to Title 11, Alaska Administrative Code, Section 2226 (Alaska Oil and Gas Conservation Regulations). 2. The Alaska Oil and Gas Conservation Committee moved to hear testimony on rules for the referenced project. 3. Notice of the hearing was published in the Anchorage Daily News on October 13, 1971. 4. A public hearing was held in the City Council Chambers of the Z. J. Loussac Library, Anchorage, Alaska, on October 27, 1971. Testimony was presented in support of the petition. FINDINGS: 1. The producing intervals in the Tradins Bay "C" NE and Hemlock NE Oil Pools within the North Tradin~ Bay Unit do not appear to be faulted, and the reservoir beds are, for the most part, continuous throughout the Unit area. 2. The reservoirs of the Trading Bay "C" NE and Hemlock NE Oil Pools are highly undersaturated and have a limited amount of energy available to sustain the producing capacity. 3. Calculations indicate the aq~uifer is fairly small, but due to low permeability it will be of limited effectiveness as an energy source. 4. Engineering studies have shown that pressure maintenance is needed to maximize oil recovery, from these pools. 5. The proposed pressure maintenance project by water injection should substantially increase the recovery, of oil from the Trading Bay "G" NE and Hemlock NE Oil Pools. Conservation Order No. 108 Page 2 November 18, 1971 6. It appears that the correlative rights of all affected parties will be protected in this project. CONCLUSION: Reservoir performance data as shown at the hearin~ indicate the feasibility of a pressure maintenance project and that such a project should be approved. NOW, THEREFORE, IT IS ORDERED THAT: 1. The injection of water for the purpose of pressure maintenance, secondary recovery or of conducting inJectivity tests is hereby permitted in the Trading Bay "G" NE and Hemlock NE Oil Pools within the North Trading Bay Unit. A semiannual progress report detailing project operations and results shall be submitted to the Committee in January and July of each year. 2. The Committee may authorize the conversion or drilling of any well at any location, the termination or suspension of the program, or any operation reasonably designed to further the purposes of the program. Thomas R.. Marshall, ,.Ir., Executive Secretary Alaska Oil and Gas Conservation Committee Concurrence: Alaska Oil and Gas Conservation Committee O' 'K. Gilb-reth' jr., Mere~- Alaska Oil and Gas Conservation Committee ALASKA OIL AND GAS CONSERVATION COMNITTEE January 29, 1974 Re: Appllcatton of Atlantic Richfield Company, North Trading Bay Unit Operator, to redrll I and produce the S-I well as part of t.he pressure maintenance projec~ approved by Conservation Order No. 108. Mr. B. T. Louderm!lk D.rt I I lng SupervI sot South Al as.ka Dlstricf Atlantic Richfield Company Box 360 Anchorage., Al aska 99510 Dear Mr. Lou. der~i lk: On January 28,. t 974 the re ferenced app I t cat ton was race i ved wh'i.ch stated that the proposed well would provide a better structural location and result in addltl.onal ultimate recovery from tine "G''~ NE and Hemlock NE oil pools i:n the North Trading Bay Unit. The proposed S-I redrill wltl encounter producing intervals at tess tha~ 1000 feet from correlative Intervals In the TS-I wet l and the T$-9 injector. The Oil and Gas conservation Committee hereby autho.rized the drilltng and .completion .of the referenced well pursuant to Rule 2 of Conservation Order No. 108. Very truly yours, /:, ,,,, ,,:,,,,. ,y, ,/ ,, ,!:?,?~" .' Thomas R, ~4arsha't l, J r. Execut t ye Secretary THIRTEENTH SEMI-ANNUAL PROGRESS REPORT PROJECT OPERATIONS AND RESULTS PRESSURE b~INTENANCE PROJECT TRADING BAY FIELD "G" AND HEMLOCK NORTHEAST OIL POOLS DATA TO JANUARY I, 1978 CONSERVATION ORDER NO. 108 Prepared by A. O. Sko0g 13th SEMI-ANNUAL REPORT Introduction This thirteenth semi-annual progress report of water injection pressure maintenance project operations and results for the Trading Bay "G" and Hemlock NE oil pools of the North Trading Bay Unit is submitted to the State of Alaska Oil and Gas Conservation Committee, in compliance with Conservation Order No. 108, Rule No. 1. The period covered by this report is from July l, 1977 to January 1, 1978. Project Operations There are nine producing wells and four injection wells completed in the "G" and Hemlock intervals at NTBU..Three producing wells and four injection wells were standing shut-in as of this report date. The injection system was down as a result of a turbine failure. The attached P-12 forms are hereby submitted to the State of Alaska, Division of Oil and Gas, showing static pressure data collected during the report period from injection wells S-4 and S-5. The attached Exhibit I, a structure map on the top of the Hemlock interval, shows the location of all wells in the North Trading Bay Unit area. 'ReSults On January 1, 1978, cummulative water injection was 23,274,977 barrels, cummulative l, production was 20,087,360 ST barrels, and cummulative water production was ~ 093,!07 barrels During the report period water injection (5,256 RB/D) exceeded reservoir withdrawals (4,'619 RB/D) by 637 RB/D. The average reservoir pressure is believed to have continued to increase during the report Period from about 3950 psi (9800' SS) to about 4000 psi (9800' SS), or about 2220 psi above the bubble point pressure of the crude'oil. Estimates of average reservoir pressure at North Trading Bay Unit are complicated by the layered nature of the reservoir and.the unknown amount of injection water dissipating into the aquifer. The attached Exhibit II (a summary table of the pressure maintenance project), Exhibit III (a plot of well static pressures versus cumulative oil production), Exhibit IV (a summary of historical production and injection data), and Exhibit V (a production rate and reservoir pressure plot) summarize pertinent North Trading Bay Unit production, injection, and pressure' data. SUPERIOR T~XA¢O ~ m ~~l mm TEXA~ iADL-17597' I ' I I I I I I I I ! I I I 1 -- I TS-5-t~- / + .. I / ;/ TEXACO m / El 24 KB ~_~ ~o~,o~ m TVD 9104 m I UN/ON Az~RATH6W ADL-I8731 SUPER/OB 7~XA~ t~L-3543t I S-4 TO 10770 _TVD ]0:552 / ' TD 1054~ / I TVDtO'26 TS-9 TvD · , /TD 11060 iVD 10168 9727 TS I ~,D lTD ~0529 TV£ TVDIO 7l ,x.C954.2' ;: / TD i l65.~ RD 9606 Io25o - // S-P TYDiO094 // fO 0972 / T ',,'b .x' ,',V. -9565 ~ E~ 5?KB~ ARCo E~ ilSKB A. RCo I I I I t I I I ! I I i ! UN/ON t~4RATHON ADL- 17596 ! o ~o / o ,,4' TDl,353 O~ C~ / ~:/ Oh (~)~' /i m TVD 10128 I / I' I //// I v ,"I ~ I ,, ,,'~/ ~ ~/ I I11 /// / . ~ /,, ~/~ I ~ ~ / / /~ ~ I I 0~ m ~ ~D.~o~ / / // ~ ~-~-~'~ ! I I I TV~N~)'r~4 ~ . ,/ I/ TD ~2~5 / / m / .,,"'./~'~., / // I ~ ,; /~,o,,,,/ /I I / //" ,. I TVD 10066 /' / I Y U~IT T. ION. R. 13W. T. 9 N. R 13 W. ) u/v/o/v U/V/OIV MARATHON MARATHON I ADL - 17596 2 ADL-17596 Ioo,, lo,,0k~,.l~',l AtlanticRichfieldCompany O- J !°~"1""" [ [ [ Alaska District LEGEND 7-21-BR . . .. . .............. NORTH TRADING BAY UN IT ~ "'"" ............ TRADING BAY FIELD, NORTHEAST OIL F:N:X)L ~ P~uggld and Ab~ld~rmd ,w J0H Sh~ o ........ " Cook Inlet, Alaska ~*' '~ STRUCTURE MAP --- -~-' ^.~.~o.~_. TOP HEM'LOCK PRODUCING INTERVAL . EXHIBIT T INTERPRETED BYe' GEOLOGICAL SUB COMMITTEE (TO ACCOMPANY 13T__H. SEMIANNUAL PROGRESS REPORT) c.l.= IOO' $coll' I"=1000' PRESSURE MAINTENANCE PROJECT Di~m~,,i~.: U~T M~MS~.S 0~,. Co~: ~-~69 ....... File 'No, lO-D- ,5 L EXHIBIT II (To Accompany Thirteenth Semi-Annual Progress Report) PRESSURE MAINTENANCE PROJECT "G" AND HEMLOCK NORTHEAST OIL POOLS NORTH TRADING BAY UNIT SUMMARY TABLE Dates Date of first oil production Date of first water injection (start of project) September, 1968 February 9,, 1972 Production and Injection Rates Average oil producing. Fate--second half of 1977, STBD Average water producing rate--second half of 1977, BD Average water injection rate--second half of 1977, BD Average oil producing rate-.Dec., 1977, STBD Average oil producing rate--Dec., 1977, RBD @ 4000 psig Average water producing rate--Dec., 1977, BD Average water injection rate--Dec., 1977, BD Number'of'Wells'Completed in "G" and Hemlock Producing, january l, 1978 Injecting, January l, 1978 Shut-In, January l, 1978 ' 2,333 1,884 5,256 2,135 2,502 2,096 1,100 Cmi~Ulative Production and Injection Cumulative oil produced since first production,, STB Cumulative oil produced since project started, STB Cumulative oil produced since project started, RB @ 4000 psig Cumulative free gas produced since first production RB Cumulative water produced since first production, B Cumulative water produced since project started,'B Cumulative water injected since project started, B 20,087,360 10,094,151 11,830,344 0 13,093,107 11,134,256 23,274,977 PresSUre'at'9800' Subsea Estimated initial average reservoir pressure, psig Estimated current aver'age reservoir pressure, pSig Bubble point pressure,' Psig 4,470 4,OOO 1,78O 0 : 0 W W I0001 EXHIBIT TIT NORTH TRADING BAY UNIT AREA WEEL STATIC PRESSURES / versus CUMULATIVE OIL PRODUCTION ( TO ACCOMPANY I.Sth SEMIANNUAL PROGRESS REPORT) PRESSURE MAINTENANCE PROJECT "G" AND HEMLOCK NORTHEAST L POOLS I 2 3 4 5 6 7 8 9 I0 II 12 IS 14 15 16 17 18 19 20 CUMULATIVE OIL PRODUCTION - MILLION 'STOCK TANK BARRELS 21 Z2 23 24 25 EXHIBIT 1%' (To Accompany Thirteenth Semi-Annual Progress Report) PRKSSL'RE MAINTENAN[ E PllO.$EC~r TRADING BAY FIELD--"G" AND IlEMLDCK NORI'IIEAST OIL I~OI~S--NORTH TRADING BAY UNIT ARF~ ItlSTORICAL PRODUCTION AND INJECTION DATA Oil Production Water Producl ion Gas-Oil Water Inject ion RateI Monthly Cumul. at ivez Ratel Monthly Cumulat ive2 Ratio Rate1 Monthly Cumulat irez Year Month BOPD STB STB BWPD BW BW SCF/STB BWPD BW BW Non-unitized operations September, 1968 toJuly 1 Sept. 95 2,857 Oct. 532 16,500 Nov. 1,715 51,462 Dec. 3,673 113,867 Jan. 3,R26 118,620 Feb. 7,706 215,757 Mar. 10,432 323,395 Apr. 12,891 386,719 May 13,435 416,488 Juno 12,401 372,034 July 10,536 326,615 Aug. 13,081 405,499 Sept. 13,388 401,627 Oct. 13,938 432,076 Nov. 15,301 459,032 Dec. 14,580 451,985 Jan. 13,690 424,396 Feb. 12,479 349,410 Mar. 9,901 306,919 Apr. 9,245 277,357 May 9,185 284,7't0 June 8106 243,173 July 8,222 254,870 Aug. 7,134 221,163 Sept. 6,607 198,204 Oct. 7,141 221,384 Nov. 8,151 244,519 Dec. .7,707 238,905 Jan. 7,026 217,795 Feb. 6,692 187,370 Mar. 6,457 200,165 Apr. 6,527 195,810 May 6,252 193,827 Juno 5,159 154,758 , 1971 2,857 0 0 19,357 15 480 70,819 76 2,280 184,686 86 2,657 303,306 87 2,709 519,063 120 3,367 842,~58 332 10,303 1,229,177 443 13,291 1,645,665 738 22,565 2,017,699 2,057 61,723 2,344,314 1,505 46~650 2,749,813 608 1~,841 3,151,440 606 18,182 3,583,516 505 15,646 4,042,548 677 20,309 4,494,533 720 22,328 4,918,929 887 27,489 5,268,339 1,502 42,056 5,575,258 2,106 65,290 5,852,6].5 1,729 51,861 6,137,355 1,998 61,932 6,380,528 2,004 60,119 6,635,398 1,513 46,908 6,856,561 937 29,060 7,054,765 1,372 41,169 7,276,149 1,164 36,095 7,520,668 1,434 43,027 7,759,573 1,560 7,977,368 1,~69 8,164,738 1,514 8,364,903 1,756 8,560,713 2~012 8,754,540 1,787 8,909,298 1,811 1968 1969 1970 0 480 2,760 5,417 8 126 11 493 21 796 35 087 57 952 119 675 166 325 185.166 203 348 218 994 239 303 261 631 289 120 331 176 396 466 448 327 510 259 570 378 617 286 646 346 687 515 723 610 766.637 48,359 814 996 1971 Page 1 of 3 · Est tmated Reservoir Number of Wells Completed Pressu re3--PSIG Producing Injecting Shut-D 252 - - - 241 - - - 245 - - 248 - - - 282 - - - 3 - 325 - - - 3 - 288 - - - 3,870 4 - 341 - - - 5 - 268 - - - 5 - 270 - - - 3,320 '..7 - 274 - - - 7 - 263 - - - 7 - 261 - - - 2,980 8 - 256 - - - 10 - 251 - - - 10 - 254 - - ~ 2,750 9 - 248 - - - 9 259 - - - 9 256 - - - 2,620 9 235 - - - 9 243 - - - ~8 235 - - - 2,550 7 210 - - - 8 181 - - - 8 191 - - - 2,490 7 173 - - - 8 178 - - - 9 192 - - - 2,,130 10 4,470 1 - - 1 - - I - - 4,320 2 - - 39,350 854,346 191 - - - 8 - 42,391 896.737 200 - - - 9 - 54,444 951,181 203 - - - 2,380 9 - 60,350 1,011,531 179 - - - 9 - 55,401 1,066,932 192 - - 9 - 54,325 1,121,257 183 - - 2,350 9 - Unitized effective July 1, 1971--North Trading Bay Unit July 4,921 152,561 9,061,859 4,832 149,781 Aug. 4,387 136,009 9,197,868 4,163 129,058 Sept. 4,876 146,291 9,344,159 3,213 96,404 Oct. 4,997 154,901 9,499,060 3,701 114,725 Nov. 5,041 151,223 9,650,283 3,364 100,931 Dec. 4,469 138,538 9,788,821 3,480 107,870 1 271,038 1 400,096 1 496,500 1 611,225 1 712,156 1 820,026 Jan. 5,129 158,987 9,947,808 3,451 106,980 1,927,006 Feb. 5,252 152,304 10,100,112 3,684 106,832 2,033,838 Mar. 6,218 192,750 10,292,862 3,338 103,465 2,137,303 Apr. 8,367 251,011 10,543,873 3,596 107,890 2,245,193 May 9,014 279,4.tl 10,823,314 3,659 113,429 2,358,622 June 8,428 252,838 11,076,152 4,243 127,294 2,-185,916 Pressure-Cumulative Oil Production plot. 223 - - - 9 243 - - 9 259 - - - 2,320 8 240 - - - 9 228 - - - 8 225 - - 2,300 8 1 0 0 0 1 1 1 1 1 2 3 2 2 3 2 1 0 1 1 1 1 1972 1 Monthly volume divided by number o~ days in month. '2 Cttmulative volume at end of month. 3 At 9,800 feet subsea from 226 - - - 11 - 223 5,574 161,647 161}647 8 2 259 7,644 236,953 398,600 2,300 9 2 243 10,830 324,912 723,512 8 3 1 264 9,178 284,516 1,008,028 8 3 1 265 9,159 274,769 1,282,797 21700 8 3 1 1 1 2 1 2 2 . I , Year Month Oil Production Rate1 Monthly STB BOPD EXHIBIT iV (To ACcompany Thirteenth Semi-Annual Progress Report) -7 PRESSURE ~INTENANCE PROJECT · . . . TRADING BAY FIELD--"G" AND KE~LOCK NORTHEAST OIL POOLS--NORTH TRADING BAY D~IT AREA HISTORICAL PRODUCTION AND INJECTION DATA -r Water Production Gas-Oil Water Injection Estimated Cumulative2 Rate! Monthly Cumulative2 Ratio Rate~ Monthly Cumulative2 ..Reservoir STB BWPD BW BW SCF/STB BWPD BW ~ PressureB---PSIG 1972 973 1974 1975 July Aug. Sept. Oct. Nov. Dec. Jan. Feb. Ma r. Apr. May June July Aug. Sept. Oct. Nov. Dec. Jgn. Feb. Mar. Apr. May June July Aug. Sept. Oct. Nov. Dec. Jan. Feb. Mar. Apr. May June 7,674 7,646 7,073 6,529 6,078 6,236 6,463 6,015 5,417 5,396 5,166 4,532 5,890 5,640 5,650 5,484 5,402 5,438 237,887 237,026 212,203 202,397 182,350 193,325 200,360 168,409 167,917 161 888 160 156 135964 182 580 174849 169 512 170 004 162 070 168 592 11,314,039 4,177 129,499 2,615,415 253 11,551,065 4,663 144,549 2,759,964 252 11,763,268 4,748 142,447 2,902,411 245 11,965,665 4,698 145,638 3,048,049 243 12,148,015 4,806 144,187 3,192,236 229 12,341,340 6,797 210,717 3,402,953 263 12,541,700 7,179 222,556 12,710,109 6,592 184,583 12,878,026 6,471 200,627 13,039,914 5,691 170,741 13,200,070 6,334 196,351 13,336,034 6,571 197,122 13,518,614 7,879 244,234 13,693,463 6,589 204,265 13,862,975 7,053 211,589 14,032,979 7,024 217,745 14,195,049 7,200 215,992 14,363,641 7,236 224,303 5,481 169,900 14,533,541 7,276 225,548 5,342 149,574 14,683,115 6,704 187,708 5,212 161,570 14,844,685 7,172 222,326 ~,963 148,895 14,993,580 6,554 196,622 4,936 153,005 15,146,585 7,036 218,129 6,083 182,482 15,329,067 7,067 212,057 6,281 194,713 '15,523,780 8,533 .... 264,510 7,396 229,285 15,753,065 8,810 273,119 6,498 194,934 15,947,999 8,632 258,967 6,236 193,325 16,141,324 8,901 275,926 6,035 181,053 16,322,377 7,978 239,328 5,445 168,794 16,491,171 6,608 204,863 5,473 5,110 4,618 4,530 4,440 3,999 * Well S-5 3,625,509 297 3,810,092 284 4,010,719 290 4,181,460 287 4,377,811 276 4,574,933 294 4,819,167 307 5,023,432 311 5,235,021 297 5,452,766 287 5,668,758 283 5,893,061 274 Page 2 of 3 Number of Wells Comple%ed 6,118,609 275 '6,306,317 276 6,528,643 298 6,725,265 282 6,943,394 281 7,155,451 266 7,419,961 273 7,693,080 268 .7,952,047 281 8,227,973 286 8,467,301 296 8,672,164 321 169,672 16,660,843 6,161 191,015 8,86~,179 309 143,070 16~p03!913 5,721 160,193 9,023,372 317 143,164 16,947,077 6,354 '196,991 9,220,363 298 135,894 17,082,971 5,913 177,396 9,397,759 305 137,642 17,220,613 6,240 193,458 9,591,217 315 119,961 17,340,574 7,244 217,332 9,808,549 315 Producl-ng Injecting Shut-in 7,869 243,924 1,526,721 8 3 ' 1 7,726 239,516 1,766,237 ~ 8 3 1 8,212 246,360 2,012,597 2950 8 3 1 9,102 282,163 2,294,760 ;~ 9 3 0 11,592 347,749 2,642,509 8 3 1 11,813 366,206 3,008,715 :' 3050 8 S 1 11,107 344,315 3,353,030 8 3 1 5,845 163,651 3,516,681 8 3 1 8,700 269,709 3,786,390 3080 ~ 8 3 1 12,736 382,069 4,168,459 8 3 1 6,825 211,587 4,380,046 8 3 1 2,956 88,675 4,468,721 3100 8 3 1 8,564 265,494 4,734,215 8 3 0 5,562 172,418 4,906,633 8 3 0 8,354 250,615 5,157,248 3100 8 3 0 10,552 327,116 5,484,364 8 3 0 9,627 288,816 5,773,180 8 3 0 9,912 307,'266 6,080,446 3100 8 3 0 1 2 9,661 299,481. 6,379,927 8 ,' 3 9,428 263,985 6,643,912 8 3 9,259 287,036 6,930,948 3080 8 3 9,035 234,912 7,165,860 - 8 3 9,117 282,641 7,448,5Ol 7 3 9,019 270,573 7,719,074 '3050 8 3 8,933 276,917 7~995~99I 8,983 278,466 8,274,457 9 3 9,264 277,924 8,552,381 3000 9 3 8,619 267,177 8,819,558 9 3 5,655 169,656 8,989,214 10~' 3 7,278 225,615 9,214,829 .[. 2950 10'.' 4* . 16,180 501,587 9,716,416 9 4 16,829 471,212 10,187,628 9 4 17.452 226,876 10,414,504 3100 9 4 17,068 512,039 10,926,543 9 4 18,989 588,656 11,515,199 9 4 20,310 609,311 12,124,510 3350 9 4 was completed as both a producer and an injector during December, 1974. . · Monthly volume divided by number of days in month. Cumulative volume at end of month. At 9,800 feet subsea from Pressure-Cumulative Oil Production plot. · 0 0 0 0 1 0 o o o 0 '-' o 0 0 0 0 0 0 EXHIBIT IV (To accompany Thirteenth Semi-Annual Progress Report) PRESSURE MAINTENANCE PROJECT TRADING BAY FIELD--"G" AND HEMLOCK NORTHEAST OIL POOLS--NORTH TRADING BAY UNIT AREA Page 3 of 3 "HISTORICAL PRODUCTION AND INJECTION DATA Year 1975 1976 1977 Oil Production Ratel Monthly Cumulative2 Month BOPD STB STB July 3,717 115,240 17,455,814 Aug. 3,625 112,365 17,568,179 Sept. 3,783 113,482 17,681,661 Oct. 3,713 115,117 17,796,778 Nov. 3,697 110,908 17,907,686 Dec. 3,655 113,304 18,020,990 Water Production Gas~Oil Water Injection Estimated Ratel Monthly Cumulative2 Ratio Rate! Monthly Cumulative2 Reservoir BWPD BW BW SCF/STB BWPD BW BW Pressure3--PSIG 7,942 246,213 10,054,762 8,259 256,023 10,310,785 7,353 220,582 10,531,367 6,450 199,958 10,731,325 6,544 196,317 10,927,642 6,344 196,660 11,124,302 Jan. 3,883 120,371 18,141,361 7,160 Feb. 3,889 112,787 18,254,148 6,484 Mar. 3,683 114,176 18,368,324 5,262 Apr. 2,947 88,405 18,456,729 2,710 May 2,501 77,540 18,534,269 1,686 June 2,537 76,100 18,610,369 1,822 July 2,684 83,215 18,693,584 2,124 Aug. 2,775 86,032 18,779,616. 2,261 Sep. 2,482 74,472 18,854,088 1,973 Oct. 2,909 90,165 18,944,253 1,844 Nov. 2,761 82,834 19,027,087 1,826 Dec. 2,894 89,712 19,116,799 1,857 Jan. 3,153 97,749 19,214,548 3,083 ~eb. 3,235 90,593 19,305,141 3,174 ~r. 3,100 96,086 19,401,227 3,078 Apr. 2,967 89,013 19,490,240 2,955 May 2,806 86,999 19,577,239 2,187 June 2,695 80,836 19,658,075 1~994 July 2,474 76,687 19,734,762 1,719 Aug. 2,567 79,592 19,814,354 1,930 Sept. 2,332 69,955 19,884,309 2,082 Oct. 2,217 68,722 19,953,031 1,616 Nov. 2,272 68,147 20,021,178 1,868 Dec. 2,135 66,182 20,087,360 2,096 221,966 11,346,268 188,025 11,534,293 163,120 11,697,413 81,289 11,778,702 52,258 11,830,960 54,648 11,885,608 65,835 11,951,443 70,103 12,021,546 59,196 12,080,742 57,153 12,137,895 54,785 12,192,680 57,562 12,250,242 95,575 12,345,817 88,883 12,434,700 95,416 !2,530,116 88,653 12,618,769 67,803 12,686,572 59,828 !2,746,400 53,274 12,799,674 59,839 12,859,513 62,452 12,921,965 50,104 12,972,069 56,052 13,028,121 64,986 13,093,107 336 18,132 562,084 12,686,594 333 18,296 567,168 13,253,762 294 18,496 554,893 13,808,655 ~ 3475 306 18,049 559,506 14,368,161 311 15,797 473,904 14,842,065 318 13,626 422,419 15,264,484 3550 307 17,985 557,546 15,822,030 310 17,680 512,718 16,334,748 316 18,145 562,484 16,897,232 3650 289 11,268 338,048 17,235,280 276 13,839 429,005 17,664,285 267 13,925 417,749 18,082,034 3750 257 17,985 425,038 18,507,072 301 17,680 416,836 18,923,908 313 18,145 390,844 19,314,752 3800 271 11,268 313,392 19,628,144 285 13,839 345,238 19,639,652 271 13,925 408,154 20,047,806 3850 269 13,251 264 12,377 272 17,3!1 275 14,973 276 8,740 264 8~!98 303 4,846 261 2,503 302 3,252 290 276 284 410,784 20,458,590 346,561 20,805,!51 536,633 2!,341,784 3900 449,178 21,790,962 270,930 22,061,892 245,945 22,307,837 3950 150,233 22,458,070 77,597 22,535,667 97,570 22,633,237 3975 22,938,635 23,240,867 23,274,977 4000 9,852. 305,398 10,074 302,232 1,100 ' 34,110 l'Monthly volume divided by number of days in month. 2 Cumulative volume at end of month. 3 At 9,800 feet subsea from Pressure-Cumulative Oil Production plot. Number of Wells Completed Producin9 Injectin9 Shut-in 9 4 0 9 4 0 9 4 0 9 4 0 9 4 0 9 4 0 6 6 6 6 6 6 6 6 6 6 6 _ 6 4 0 4 1 4 1 4 2 4 3 4 3 6 4 3 7 4 2 8 4 1 6 2 § 6 4 3 6 4 3 4 3 4 3 4 3 4 3 4 3 3 4 2 5 2 5 2 5 2 5 2 5~ 2 5 r'~ Z <~ 03 0 Z 22 2O 18 17 16 12 II I0 9 EXHIBIT ~ NORTH TRADING BAY UNIT PRODUCTION AND PRESSURE HISTORY TO ACCOMPANY 3 _~J~ SEMIANNUAL PROGRESS REPORT) PRESSURE MAINTENANCE PROJECT "G" AND HEMLOCK NORTHEAST OIL POOLS -' [, · -1-' RAGE SSURE ~ . PRODUCT I -IF LJ !--r _ . . ..... '1 .., . . ... ........... [~ 19_ZO .... 19_._~ L ..... 19 72 .... 19 _7_~L .... 19__Z..~_ 19_ Z5_ 19.76_ 19_7_7__ 50O0 4000 3000 2OO0 10OO · Form P--12 .. or O~L AND CAS CONSF~RVAT~ON COMMitteE m S Rvom r EsSo E *See Instructions on I-leverse omc · Operator A~LANT4C RICHFIELD Box 360 Anchorage AK 99510 I Date ]01-24-78 Field NORTH TRADING BAY UNIT Producing Formation ] Oil Gradient "G" & HEMLOCK I - Lease ADL 18776 * PRESSURE FALLOFF ]TEST Designate type of report by "X". ~Nater Gradient 0.433 -I' S-5 WI l- County i Kena] Peninsula Brorough Initial Co~npletion* I Special* ! GenerM Survey* Date ' Tested 9-5-77 i 240 ~Hrs I Shut-In I Tubing 1 Test .Pressure Depth I5034' MD 4438' SS Bomb Test Data Temp. 'l Observed Pressure' 1988 Prod. Test (Bbls. per Day) Oil V, rater ., Datum Plane 9800' SS Sonic Instrument Test Data I Ga.u Gravity I - 104°F Liquid ~,Vt. of Liquid Liquid Level Gradient l Col,umn I ~Vt. of Casing Gas Column ]Pressure Pressure Datum - 4310 CERTIFICATE: I, the undersigned, state that I am the .lr.'..!.j.l.:...Y~.~.-.F.... of the .~.~{~.,.~.,.".x_D ......................... (company), and that I am authorized by said company, tO make this report; and that this report was prepared under my supervision and direction and that the facts stated therein are true, c0m-ect and completeto the best of my knowledge. ~. ~(~J~.'~----?-f ,~/ .... LZ. ..... ~/.2.~ ..... 5 ........ ~. ................................................................................ MINER PUBLISHING CO, Form 1>--12 oF COnSERVaTiON P~EsERVoIR PRESSURE REPORT ~See Instructions on Reverse Side ., Operator ' 9951 0 ATLANTIC RICHFIELD COMPANY . Address P. 0. 13o× 360,. Anchocage, AK Date Field NORTH TRADING BAY UNIT ~Producing Formation "G" a HEMLOCK ADL 35431 Oil Gradient Lease * PRESSURE FALLOFF TEST' ~'ater Gradient 0.433 Date Tes[ed 9-5-77 I 1243 Hfs Designate type of report by "X". County Kenai peninsula B0mu9h Initial Completion* [: Special* Test Dep th 5034' MD General Survey* x 2094 Bomb Test Data 131I-t. Observed [ Prod. Test . Temp. Pressur~e I (Bbls. per~ Dayj .:. Oil '1 ]Vater 99°F - I - Sonic Instrument Te~'t Data Liquid Level [01-24-78 Datum Plane I Gas Gravity 9800' SS ' I - ~Vt. of Gas Column Shut-In TUbing 'Pressure 4915' SS , I ~,Vt. of Liquid Liquid Gradient ! Column I 1>ressure Casing Pressure at Datum 4209 CERTIFICATE: I, the undersigned, state that I am the .~..k.~.~ ...... ~i~5.>..~*'of the .~.?.~ ..... -~..:>. .......................... (company), and that I am authorized by said company, to make this ~eport; and that this report was prepared under my supervision and direction and that the facts stated therein are true, correct and complete to the best of my knowledga ..~;--;.j~.j-~-~..,-..-~.~--~...~c- .............................................................. MINER PUBLISHING CO, ELEVENTH SEMI-ANNUAL PROGRESS REPORT PROJECT OPERATIONS AND RESULTS PRESSURE MAINTENANCE PROJECT TRADING BAY FIELD "G" AND HEMLOCK NORTHEAST OIL POOLS DATA TO. JANUARY 1, 1977 CONSERVATION ORDER NO. 108 Prepared 'bY A. O. Skoog D OivI~ioi~ o~ ~il atld GaS t¢en~f'Vatlon llth SEMI-ANNUAL REPORT Introduction This eleventh semi-annual progress report of water injection pressure maintenance project operations and results for the Trading Bay "G" and Hemlock NE oil pools of North Trading Bay Unit is submitted to the State of Alaska Oil and Gas Conservation Committee, in compliance with Conservation Order No. 108, Rule No. 1. The period covered by this report is from July 1, 1976 to January 1., 1977. Project Operations There are nine producing wells and four injection wells completed in the "G" and Hemlock intervals at NTBU. Three of the producing wells were standing shut-in as of this report date. Reda pump well S-7 RD (failed 4/76 because of excessive Sand production) remained shut-in during this report period.. Reda pump well TS-3 also remained shut-in because of a failed downhole pump. One routine workover to replace electric submersible pumping equipment was conducted on well TS-1 and is summarized on the attached 10-403 form. The Reda pump in this well'has failed again after a 20-day run. Further attempts to return these wells to production are not currently economic. Two other routine workovers were conducted with wireline tools and are summarized on attached 10-403 forms. The attached Exhibit I, a structure map on the top of the Hemlock interval, shows the location of all wells in the North Trading Bay Unit area. Results On January 1, 1977, cumulative water injection was 20,047,806 barrels, cumulative oil production was 19,116,799 ST barrels, and cumulative water production was 12,250,242 barrels. During the report period, water injection (12,497 RB/D) exceeded reservoir withdrawals (5213 RB/D) by 7284 RB/D. The average reservoir pressure is believed to have continued to increase during the report period from about 3750 psi (9800' SS) to about 3850 psi (9800' SS), or about 2070 psi above the bubble point pressure of the'crude oil. Estimates of average reservoir pressure at North Trading Bay Unit are complicated by the layered nature of the reservoir and the unknown amount of injection water dis- sipating into the aquifer. The attached Exhibit II (a summary table of the pressure maintenance project), Exhibit. III (a plot of well static pressures versus cumulative oil production), Exhibit IV (a summary table of historical production and injection data), and Exhibit V (a production rate and reservoir pressure .plot) summarize pertinent North Trading ~Bay Unit production, injection, and pressure data. S UPEt~IOt~ TEXACO PS-5-~- I + 22 SUPERIOB TEX4 C O · // ,k 23 SUPER I O t~ TEXACO ~DL-3543~ I 5'-4 TO 10770 .~¥D ~0352 1 -~?~ TS 9 9~2~T5_I ] ~ TD 11655 ~ ~D I~' EJ qSKB / / / / f- SUPERIOR TEXACO iADL-17597' I I I I I I I I I 27 I I I I I I 1 I I -- TVD 0 !3 ADL.- ~ 87"76 J I I I I I I I ., TS - 7~ . ~ /, ,~, I I I I' I I I I ,, // TEXACO i~I~T~ SI-~ /Et 2'4 KB TS--2~TO 9~04 TV{:) 910'~ _ / / , / / I T. ION. R. 13W UN/ON T. 9 N. R 13 W. t,,IA t~A TH OAI ADL-18751 I I I I I I EXHIBIT Z (TO ACCOMPANY I~ TH....~' SEMIANNUAL PROGRESS REPORT) PRE~SURE MAi~-TENANCE. PROJECT JAN. I] 1977 ADL- t 7596 UN/ON ~,4RA/7-/ON ADL- 17596 I BAY UNIT IVOHTH TH~4 D IIVG U/V/ON U/V/O~/ MARATHON tlfAt~A THO~t ADL 17596 2 - ADL- 17596 [ [ ~tlant,¢R,¢hheldCompan-~ LEGEND 72l E~ Alaska District ................ I I t /' t*~~ ~a¥ n[c~, ~.~s, o~[ ~!u~e.1 ~n~ Ab~no~ed w/OH ........It t I'/~kInlet, Alosko ..,,o.o ' l t 'l t I TOP HE~LOCK PRODUCING INTERV~! I I I I 1~"'~°' '°-*-' I EXHIBIT II (To Accompany Eleventh Semi-Annual Progress Report) PRESSURE MAINTENANCE PROJECT "G" AND HEMLOCK NORTHEAST OIL POOLS NORTH TRADING BAY UNIT SUMMARY TABLE Dates Date of first oil production Date of first water injection (start of project) September, 1968 February 9, 1972 Production and Injection Rates Average oil producing rate--second half of 1976, STBD Average water producing rate--second half of 1976, BD Average water injection rate--second half of 1976, BD Average oil' producing rate--Dec., 1976, STBD Average oil producing rate--Dec., 1976, RBD @ 3850 psig Average water producing rate--Dec., 1976, BD Average water injection rate--Dec., 1976, BD 2,752 1,982 12,497 2,894 3,398 1,857 13,166 Number of Wells Completed in "G" and Hemlock Producing, January l, 1977 Injecting, January l, 1977 Shut- In, January 1, 1977 Cumulative Production and Injection Cumulative oil produced since first production, STB Cumulative oil produced since project started, STB Cumulative oil produced since project started, RB @ 3850 psig Cumulative free gas produced since first production, RB Cumulative water produced since first production, B Cumulative water produced since project started, B Cumulative water injected since project started, B 19,116,799 9,123,590 10,711,094 0 12,250,242 10,291,391 '20,047,806 Pressure at 9800' Subsea Estimated initial average reservoir pressure, psig Estimated current average reservoir pressure, psig Bubble point pressure, psig 4,470 3,850 1,780 ~_[~-'!l: '~ ':-!-' ~:--~ .... ~ : !' ~'-'i ''! '-~ ' i '~' '~ : .-~.. ~. -j_ ,_. ~ ! EXHIBIT TIT --- --- ' -'- , .............. -, -, ~ ..... , - ' NORTH TRADING BAY UNIT AREA ]~-~--4---~-- ;.-~-~~-~-~--~-.---!--'---~---~-p~-:--~ ..... ~--~--~-'~%-'~ '---'~ ~'-- WELL STATIC PRESSURES ~ .... ~-' ~ .... , '~ ' l .... ~' ~ -- -- ' ~ ". . : ' versus ~:-~ ~ ?~'~-~-~ 1' : -: ' -7- -~ -d_ · ~.-. . ~. ~ ~ ! · CUMULATIVE OIL PRODUCTION ----:-- ..... ~ --- ~ ..... i ....... '. -- ~- I (~ ACCOMPANY t~ SEMIANNUAL PROGRESS REPORT) - .., ~_ I ........... : .... I ' ~ESSURE .... ~ ~ .: ': .... = - ' ..... ~ --t _ _ hF: '---I-:- ' ~ - ' J¢.-~ ~ - , . , '.- ·' i · . .. - - ~ X'" · ~ ; " t I ....... ; .... ' :: ~' I ~ ' ~ ~ ~ . ' ~ ~ '..- ' , ' '''. : .... ~1%''¢ i ' ~ ' ' ' ' ' ' ' ~ ' ': ' ~ ' ' ' ' ' ~ ' ; ' .... -- ~ ..... ~ - ' · · , · . ' ' ' ~ .... ' . ~ {. .t I:' 'f- ~1: ;. '. :t~ , t-:--i 0 0 --'~ ' ~~ . ~ . .i'~ -- '~ ~ ' r:--t-*- 'h - ' '-' , ~ '-t - " ~--]' . t---~-~'~ -~-~-~'%~'~. '"'~":' 7'-~ ..... % .... :7:;~ ....... ~-:--- ,--~;~.:. ~ . ~ -~ ~ - . ...... ' '~'-' · - l' ' ' ' ' .... ' .... ' .... ' .... '' - ' ' ' .... ~ I-;-L~' ~ ' -~" ': '1' ': ' ! ' ~ ' ~~: - ' ' ' ~ - ' . / : ' . . , ' · · ' . '- :.. :" -:::!- -'" ' ' i ' : ~ ' ~ l',t-: ~-. :/- '~' -f .... . I ' ~ ' .i ~ '- t ....... " ~ ........ , ..... ~ I'~%~~. /-: :. ':i.;-: t. : : - i ............. ' ' ' ' . . . ~ ..... ~ ....... - .....4 ...... ~ . : , ~ -:~-~ - - ' '- . ~ ' ' '; -' ': --~ f t- ' : .... t ~ - ~- -- i -- ' i . -t ~ ..... '1 ~ ~ - ~ i ' ' , ~ ' '__ .;Z;';;;.. ~ . ~ [.: ~ :;i ' : "~ "7 .' ~ . ~ !. : ~ .... ' ' ~ - : -- (-- ;.- i ;-; '- i- ;" i ~--; ~' ' ~ : ' ~ ' ' .... - .~, : · .1 ...... ~ - -I- --'-: , -i i ;.-i .- , ~ :-' :l :,, 1 t - , : ' ! ; , ~ ~ ': ~--h~'~ .... -- l- .,. ~ CUMULATIVE OIL RRODUCTION -- MILLION ST~K TANK BARRELS , (To Accompany Te~th Semi-Annual Progress Rep. orr) P~ESSb~E MA INTENANCE PROJECT TRADING BAY FIELD--"G" AND HEMLOCK NORTHEAST OIL POOLS--A~)RTH T~DING BAY UNIT AREA HISTORICAL PRODUCTION AS~O INJECTION DATA -Oil Production Water Production Gas-Oil Rate1 Monthly Cumulativez Rate1 Monthly Cumulativ~2 Ratio Year Month BOPD STB STB ~?PD BW ~ ,,. Non-unitized operations September, 1968 to July I, 1971 1968 Sept. 95 2,857 2,857 0 Oct. 532 16,500 19,357 15 Nov. 1,715 51,462 70,819 76 Dee. 3,673 113,867 ' 184,686 86 1969 Jan. 3,826 118,620 303,306 87 Feb. 7,706 215,757 519,063 120 Mar. 10,432 323,395 842,458 332 : Apr. 12,891 386,719 1,229,177 443 May 13,435 416,488 1,645,665 738 June 12,401 372,034 2,017,699 2,057 July 10,536 326,615 2,344,314 1,505 Aug. 13,081 405,499 2,749,813 608 Sept. 13,388 401,627 3,151,440 606 Oct. 13,938 432,076 3,583,516 505 Nov. 15,301 459,032 4,042,548 677 Dec. 14,580 451,985 4,494,533 720 1970 Jan. 13,690 424,396 4,918,929 887 ' Feb. 12,479 349,410 5,268,339 1,502 Ymr. 9,901 306,919 5,575,258 2,106 Apr. 9,245 277,357 5,852,615 1,729 May 9,185 284,740 6,137,355 1,998 Juno 8,106 2,13,173 6,380,528 2,004 July 8,222 254,870 6,635,398 1,513 Aug. 7,13,t 221,103 6.8.56,5G1 937 Sept. 6,607 198,204 7,054,765 1,372 Oct. 7,141 221,384 7,276,149 1,164 Nov. 8,151 244,519 7,520,668 1,434 : Dec. 7,707 23B,905 7,759,573 1,500 '1971 Jan. 7,026 217,795 7,977,368 1,269 Feb. 6,692 187,370 8,164,738 1,514 Mar. 6,457 200,165 8,364,903 1,756 Apr. 6,52? 195,810 8,560~713 2,012 May 6,2fi2 193,827 8,754,540 1,787 June 5,159 154,758 8,909,298 1,811 0 480 2,280 2,657 2 709 3 367 10 303 13 291 22 865 61 723 46 650 · 18 841 15 646 20.309 22,328 27,489 42,056 65,290 51,861 61,932 60,119 46,908 29,060 41,169 36,095 43,027 48,359 29,350 42,391 54,444 60,350 55,401 54,325 0 480 2,760 5,417 8 126 11 493 21 796 35 087 57 952 119 675 166 325 I85 166 203 348 218 994 239 303 261 631 289,120 331176 396 466 448327 510 259 570,378 617 286 646 346 '687 515 723610 766637 814 996 Water Injection Ratez Monthly Cumulativ~2 SCF/STB ~?PD ~V ~V · 252 241 245 248 282 325 288 341 268 270 274 263 261 256 251 254 248 259 256 235 243 235 210 181 191 173 178 192 -' 854,346 ..... 16i --~ 896,737 200 951,181 203 1,011,531 179 1,O66,932 192 1,12! 257 183 L~itized effective July 1, 1971--North Trading Bay Unit _ July 4,921 152,561 9,061,859 4,832 149,781 1,27{,038 223 Aug. 4,387 136,009 9,197,868 4,163 129,058 1,400,096 243 Sept. 4,876 146,291 9,344,159 3,213 96,404 1,496,500 259 Oct. 4,997 15,1,901 9,499,060 3,701 114,725 1,611,225 240 Nov. 5,041 151,223 9,650,283 3,364 100,931 1,712,156 228 Dec. 4,469 138,538 9,788,821 3,480 107,870 1,820,026 225 1972 Jan. 5,129 158,987 9,947,808 3,451 106,980 1,927,006 226 Feb. 5,252 152,304 10,100,112 3,684 106,832 2,033,838 223 Mar. 6,218 192,750 10,292,862 3,338 103,465 2,137,303 259 Apr. 8,367 251,011 10,543,873 3,596 107,890 2,245,193 243 ~iay 9,014 279,441 10,823,314 3,659 113,429 .2,358,622 264 June ~8,428 252,838 11,076,152 4,243. 127,294 2,485,916 265 1 Monthly volume divided by nmmber et days in month. 2 Cumulative volume at end of month. 3 At 9,800 feet ~ubsea frOm · ... 5,574 161,647 7,644 236,953 10,830 324,912 9,178 284,516. 9,159 274,769 Estimated Reservoir Number of WeIls Completed Pressure3-~PSIG Producing Injecting Shut-I~ Pressure-Cumulative Oil Production plot. 4,470 4,320 3,870 3,320 2,980 2,750 2,620 2,550 2,490 2,430 2,380 2,350 7 - '1' 8 - 0 10 - 0 10 . - 0 9 - 1 2,320 2,300 9 - 1 9 - 1 8 - 2 9 - 1 8 - 2 8 - 2 - 11 - - 161',647 8 2 1 398,600 2,300 9 2 723,512 8 3 1 1,008,028 8 3 1 1,282,797 2~700 8 3 EXIIIBIT IV . (To Accompany Tenth Semi-Annu. al Progress Report) PRESSb~RE M~IA"rENANCE PROJECT TRADING BAY FIELD--"G" AND ICA%IIDCK NORTREAST OIL POOLS--NORTH TRADING BAY IfNIT AREA HIS'fORICAL PRODUCTION ;hN'D INJECTION DATA FaRe Z OX ~ Oil Production Water ProdUction Gas-Oil Water Injection Estimated Rate1 ~:onthly Cum. ulatl~e2 RateA Monthly Cumulative2 Ratio Rate% ~lonthly O~mul~tiYe2 Reservoim Ye~T ~onth ~OPD STB STB ?~I.P~ L~N .. B~? ... SCF/STB B%TPD B~ BW 1972 July 7,674 237,887 11,314,039 4,177 129,499 2,615,415 253 7,869 243,924 11526,721 Aug. 7,646 237,026 11,551,0~5 4,663 144,549 2,759,964 252 7,726 239,516 1,766,237 Sept. 7,073 212,203 11,763,268 4,748 142,447 2,902,411 245 8,212 246,360 2,012,597 2950 Oct. 6,529 202,397 11,965,665 4,698 145,638 3,048,049 243 9,102 282,163 2,294,760 Nov. 6,078 182,350 12,148,015 4,806 144,187 3,192,236 229 11,592 347,749 2,64~,509 Doc° 6,236 193,325~ t2,341,340 6,797 210,717 3,402,953 263 11,813 366,206 3,008,715 ~050 1973 Jan. 6,463 200,360 12,541.700 7,179 222~556 3,625,509 297 11,i07 344,315 3,353~030 - Feb. 6,015 168,409 12,710,109 6,592 184,5~3 3,810,092 284 5,845 163,651 3,516,681 Mar. 5.417 167,917 12.878,026 6,471 200,627 4,010,719 290 8,700 269,709 3,786,390 3080 Apr. 5,396 161,888 13.039,914 5,691 170,741 4,181,460 287 12,736 382,069 4,168,459 May 5,166 160,156 13,200,070 6,334 196,351 4,377,811 ~76 6,825 211,587 4,~80,046 June 4.522 135,964 13,336,034 6,571 197,122 4,574,933 294 2,956 ~,675 4~468,721 3100 July 5,~90 1~2,580 13,51~,614 7,879 244,234 4,819,167 307 8,564 265,494 4,734,215 · .Aug. 5,640 174,849 13.693,463 6,589 204,265 5,023,432 311 5,562 172,418 4,906,633 . Sept. 5.650 169,512 13,862,975 7,053 211,589 5,235,021 297' 8,354 250,615 5,157,248 3100 Oct. 5,484 170,004 14,032,979 7,024 217,745 5,452,766 287 10,552 327,116 5,48,1,364 Nov. 5,402 162,0~0 14,195,049 7,200 215,992 5,668,758 283 9,627 288,816 5,773,180 Dec. 5.438 168,592 14,363,641 7,236 224,303 5,893,061 274 9,912 307,266 6,080,446 3100 · 197~ J~. 5',~81 169,900 1~,533,5~1 7,276 225,548 6,118,609 275 9,661 299,481 6,379,927 Feb. 5,2L2 149,574 14,683,115 6,704 187,708 6,306,317 276 9,~28 263,985 6,643,912 Y~r. 5,212 161,570 14,844,685 7,172 222,326 6,528,643 ' 298 9,259 287,036 6,930,948 ' 3080 Apr. ~,963 11~8,8p5 1~,993,580 6,554 196,622 6,725,265 282 9,035 234,912 7,165,860 M~y 4,936 153,005 15,146,585 7,036 218,129 6,943,394 281 '9,117- 282,641 7,448,501 J,~ne 6,053 182,H82 15,329,067 7,067 212,057 7,155,451 266 9,019 270,573 7,719,074 3050 - July 6,281 194,713 15,523,780 8,533 264,5]0 7,419,961 273 8,933 276,917 7,995,991 .................... Aug. 7,396 229,285 15,753,065 8,810 273,119 7,693,080 268 8,983 278,466 8,274,457 Sept. 6,498 194,934 15,947,999 8,632 258,967 -7,952,047 281 9,264 277,924 8,552,381 3000 Oct. 6,236 193,325 16,141,324 8,901 275,926 8,227,973 286 .8,619 .. 267,177 8,819,558 · Nov. 6,035 181,053 16,322,377 7,978 239,328 8,467,301 296 5~655. 169,656 8,989,214 Dec. 5,445 168,794 16,491,171 6,608 204,863 8,672,164 321 7,278 225,6t5 9,214,829 ... 2950 1975 Jan, 5,473 169,672 16,660,843 6,161 191,015 8,863,179 309 16,180 501,587 9,716,416 Feb. 5,I10 143,070 16,803,913 5,721 160,193 9,023,372 317 16,829 471,212 10,187,628 Mmr. 4,618 143,164 16,947,077 6.354 196,991 9,220,363 298 17,452 226,876 10,414,504 3100 Apr. 4,530 135,894 17,082,971 5,913 177,396 9,397,759 305 17,068 512,039 10,926,543 M~y 4,440 137,642 17,220,613 6,240 193,458 9,591,217 315 18,989 588,656 11,515,199 June 3,999 119,961 17,340,574 7,244 217,332 9,808,549 315 20,310 609,311 12,124,510 3350 Number of Wells Comple%ed Pressure3---PSIO Produc~n~ InJectin~ Shut-in 8 3 '1 8 3 1 8 3 9 3 0 8 3 1 8 3 1 8 3 1 8 3 1 8 3 1 8 3 1 8 3 1 8 3 1 8 3 0 8 3 0 8 3 0 8 3 0 8 3 0 8 3 0 8 " 3 0 8 3 0 8 3 0 8 3 0 7 3 8 3 0 9 ....... 3 ..... 0 3 0 9 9 3 0 ! 9 3 o j 10' 3 0 10' 4* 0 9 4 0 9 4 0 9 4 0 9 4 0 9 4 0 9 4 0 * Well S-5 was completed as both a producer and an injector during December, 19%4. Mont~2y volume divided by number of days in month. C,~_ulative vo!'~-~e at end of month. · 9,800 fee~ subsea from Pressure-Cumulative Oil ProdUction ~lot.' , · EXHIBIT IV (To accompany Tenth Semi-Annual Progress Report) PRESSURE MAINTENANCE PROJECT TRADING BAY FIELD,-"G" AND HEMLOCK NORTHEAST OIL POOLS--NORTH TRADING ~AY UNIT AREA "HISTORICAL PRODUCTION AND INJECTION DATA Page 3 of 3 Year 1975 1976 Month Oil Production Rate! Monthly CumulativeZ BOPD STB STB water Production Gas-Oil Ratel Monthly Cumulative2 Ratio BWPD BW BW 'SCF/STB July Aug. Sept. .Oct. Nov. Dec. 3,717 115,240 17,455,814 3,625 112,365 17,568,179 2,783 113,482 17,681,661 3,713 115,117 17,796,778 3,697 110,908 17,907,686 3,655 113,304. 18,020,990 7,942 8,259 7,353 6,450 6,544 6,344' 246,213 10,054,762 256,023 10,310,785 220,582 10,531,367 199,958 10,731,325 196,317 10,927,642 196,660 11,124,302 · 336 333 294 306 311 318 Jan. Feb. Mar. Apr. May June July Aug. Sep. Oct. Nov. Dec. 3,883 120,371 18,141,361 7,160 3,889 112,787 18,254,148 6,484 3,683 114,176 18,368,324 5,262 2,947 88,405 18,456,729 2,710 2,50! 77,540 18,534,269 1,686 2,537 76,100 18,610,369 1,822 2,684' .'83,215 18,693,584 2,124 2,775 86,032 18,779,616. 2,261 2,482 74,472 18,854,088 1,973 2,909 90,165 18,944,253 1,844 2,761 82,834 19,027,087 1,826 2,894, 89,712 19,116,799 1,857 221,966 11,346,268 188,025 11,534,293 163,120 11,697,413 81,289 11,778,702 52,258 11,830,960 54,648 11,885,608 65,835 70,103 59,196 · 57,153 54,785 57,562 11,951,443 12,021,546 12,080,742 12,137,895 12,192 ,,680 12,250,242 307 310 316 289 276 267 257 301 313 271 285 271 1 Monthly v~lume divided by number of days in month. 2 Cumulative volume at end of month. · 3 At 9,800 feet subsea from Pressure-Cumulative Oil Production plot. Water Injection Estimated Rate] Monthly Cumulati'v'ez' Reservoir BWPD BW BW Pressure3--PSIG 18,132 562,084 12,686,594 18,296 567,168 13,253,762 18,496 554,893 13,808,655 18,049 .559,506 14,368,161 t5,797 '473,904 14,842,065 13,626 422,419 15,264,484 17,985 557,546 15,822,030 17,680 512,718 16,334,748' 18,145 562,484 16,897,232 11,268 338,048 17,235,280 13,839 429,005 17,664,285 13,925 417,749 18,082,034 17,985 425,038 18,507,072 17,680 416,836 18,923,908 18,145 390,844 19,314,752 11,268 313,392 19,628,144 13,839 345,238 19,639,652 13,925 408,154 20,047,806 3475 3550 3650 3750 38O0 3850 Number of Wells Completed Producing Injecting Shut-in 9 '4 0 9 4 -'-~ '9 4 9 4 0 9 4 0 9 4, 0 9 .. 4 .0 8 4 1 8 4 1 7 4 2 6 4 3 6 4 3 6 4 3 7 4 2 8 4 1 6 2 5 6 4 3 6 4 3 EXHIBIT 2~ NORTH TRADING BAY UN IT PRODUCTION AND PRESSURE HISTORY 20 ( ~0 ACCOMPANY . It- SEMIANNUAL PROGRESS REPORT) ' PRESSURE MAINTENANCE PROJECT "G" 19 AND HEMLOCK NORTHEAST OIL POOLS . t r-, 17 5 ............... ]. I .............. RESE[ SSURE · .. . . r- J L[!.- . . WATEI . . .. 19 7.6 19. 4000 3000 2000 '"" I000 Form 10-403 REV. 1-10~73 Submit "1 ntentlons" in Triplicate & "Subsequent Reports" in Duplicate STATE OF ALASKA OIL AND GAS CONSERVATION COMMITTEE SUNDRY NOTICES AND REPORTS ON WELLS (Do not use this form for proposals to drill or to deepen Use "APPLICATION FOR PERMIT--" for such proposals.) 5. APl NUMERICAL CODE 50-133-20l 20 6. LEASE DESIGNATION AND SERIAL NO. ADL-17597 7. IF INDIAN, ALLOTTEE OR TRIBE NAME OIL I~i GAS I--1 WELLL2J WELL L--J OTHER 2. NAME OF OPERATOR Atlantic Richfield Company 3~ ADDRESS OF OPERATOR P. O. Box 360, Anchorage, Alaska 99510 4. LOCATION OF WELL At surface 615' S and 2072' W of NE corner of Section 34, T10N, R13W, SM 13. ELEVATIONS (Show whether DF, RT, GR, etc.) 92' KB 14. Check Appropriate Box To Indicate Nature of Notice, Re 8. UNIT, FARM OR LEASE NAME North Trading Bay Unit 9. WELL NO. TS-1 10. FIELD AND POOL, OR WILDCAT Trading Bay "G" & Hemlock NE 11. SEC., T., R., M., (BOTTOM HOLE OBJECTIVE) Section 27, T10N, RI3W, SM 12. PERMIT NO. 68-48 )ort, or Other Data NOTICE OF INTENTION TO: TEST WATER SHUT-OFF L------J FRACTURE TREAT SHOOT OR ACIDIZE . REPAIR WELL (Other) PULL OR ALTER CASING MU gTI PLE COMPLETE ABANDON* CHANGE PLANS SUBSEQUENT REPORT OF: WATER SHUT-OFF : REPAIRING WELL FRACTURE TREATMENT ALTERING CASING SHOOTING OR ACIDIZING ABANDONMENT* _ (other).Reperforate & Replace Subm. Pump. (NOTE: Report results of multiple completion on Well Completion or Recompletion Report and Log form.) 15. DESCRIBE PROPOSED OR COMPLETED OPERATIONS (Clearly state all pertinent details, and give pertinent dates, including estimated date of starting any proposed work. SEE ATTACHED SHEET 16. I hereby certify that the foregoing I~ true and correct , , . (T~is'space for State of~e use) ' · South Alaska District T,TLE...Operati ons Manager APPROVED BY CONDITIONS OF APPROVAL, IF ANY: TITLE DATE See Instructions On Reverse Side 7~27~76 Commenced workover operations. Rigged up and displaced well with Inlet water. Displaced Inlet water with Dril-S mud. Removed tree, installed and tested BOP. POH with tubing and downhole electric pumping equip- ment. RIH with washpipe and circulated out fill to 10,365' KB. Re- perforated the following intervals: Bench Interval (DIL) G-2 G-3 G-4 H-1 H-2 H-2 10,080 -lO,140 10,155 -10,165 lO,190 -lO,210 10,280 -10,300 10,312 -10,332 10,342 -10,352 (New Perforations ) RIH with 6" bit and 7" casing scraper. Circulate out fill to 10,363' KB. RIH with replacement submersible pump on 3-1/2" tubing. Landed completion assembly with bottom of Reda motor at 10,002' KB. Installed and tested tree. Displaced Dril-S mud with Inlet water. 8/5/76 Started pump and returned well to production. Note' Pump failed again on 8/26/76. Submit "1 ntentlons" in Trlpllcate "Subsequent Reports" In Duplicate Form 10-403 REV. 1-10-73 STAT E 0 F A LAS KA OIL AND GAS CONSERVATION COMMITTEE SUNDRY NOTICES AND REPORTS ON WELLS (Do not use this form for proposals to drill or to deepen Use "APPLICATION FOR PERMIT--" for such proposals.) 1. OIL ~l GAS r'~ WELLL~LI WELL g--J OTHER 2. NAME OF OPERATOR Atlantic Richfield Company 3. ADDRESS OF OPERATOR P. 0. Box 360, Anchorage, Alaska 99510 4. LOCATION OF WELL At surface 2608' N & 2495' W from SE Corner of Section 26, T1ON, R13W., SM 13. ELEVATION5 (Show whether DF, RT, GR, etc.) 115' KB 14. Check Appropriate Box To Indicate Nature of Notice, Re 5. APl NUMERICAL CODE 50-133-20l 58-01 6. LEASE DESIGNATION AND SERIAL NO. ADL-35431 7. IF INDIAN, ALLOTTEE OR TRIBE NAME 8. UNIT, FARM OR LEASE NAME North Trading Bay Unit 9. WELL NO. S-1 RD 10. FIELD AND POOL, OR WILDCAT Trading Bay "G" & Hemlock NE 11. SEC., T., R., M., (BOTTOM HOLE OBJECTIVE) Section 26, TION, R13W, SM 12. PERMIT NO. 74-5 )oft, or Other Data SHOOT OR ACIDIZE REPAIR WELL (Other) NOTICE OF INTENTION TO: TEST WATER 5HUT-OFF [~ PULL OR ALTER CASING FRACTURE TREAT MULTIPLE COMPLETE ABANDON* CHANGE PLANS SuBsEQuENT REPORT OF: WATER SHUT-OFF ~ REPAIRING WELL FRACTURE TREATMENT ALTERING CASING SHOOTING OR ACIDIZING ABANDONMENT* (NOTE: Report results of multiple completion on Well Completion or Recompletion Report and Log form.) 15. DESCRIBE.PROPOSED OR COMPLETED OPERATIONS (Clearly state alt pertinent details, and give pertinent dates, including estimated date of starting any proposed work. 10/6/76 Commenced work, Ran gauge rings from 2-3/8" O.D. work easily past perforations below 10,600'+_ KB. intervals' to 1-1/2" O.D. Unable to Reperforated the following Bench Interval (DIE) G-2 G-2 10,245'-10,2.65' 10,285'-10,305' 10/10/76 Returned well to production. 16. I hereby certify~he !o~,.~e and correct SIGNED ~/~ (This space for State off se) TITLE South Alaska District Operations Manager APPROVED BY CONDITIONS OF APPROVAL, IF ANY: T IT LE DATE See Instructions On Reverse Side Form 10-403 REV. 1-10-73 Submit "1 ntentlons" In Triplicate & "Subsequent Reports" in Duplicate STATE OF ALASKA OIL AND GAS CONSERVATION COMMITTEE SUNDRY NOTICES AND REPORTS ON WELLS (Do not use this form for proposals to drll! or to deepen Use "APPLICATION FOR PERMIT--" for such proposals.) 5. APl NUMERICAL CODE 50-133-20172-01 6. LEASE DESIGNATION AND SERIAL NO. ADL-18776 7. IF INDIAN, ALLOTTEE OR TRIBE NAME WELL g-J OTHER 2. NAME OF OPERATOR Atlantic Richfield Company ADDRESS OF OPERATOR P. 0. Box 360, Anchorage, Alaska 99510 FEL of Section 26, T10N, R13W, SM 4. LOCATION OF WELL At surface 2606' FSL & 2492' 13. ELEVATIONS (Show whether DF, PT, GR, etc.) 115' KB 14. CheCk Appropriate Box To Indicate Nature of Notice, Re 8. UNIT, FARM OR LEASE NAME llorth Tr. ading Bay Unit 9, WELL NO. S-2 RD 10. FIELD AND POOL, OR WILDCAT Trading Bay "G" & Hemlock NE 11. SEC, T., R., M., (BOTTOM HOLE OBJECTIVE) Section 34, T10N, R13W, SM 12. PERMIT NO. 74-24 :}crt, or Other Data NOTICE OF INTENTION TO: TEST WATER SHUT-OFF FRACTURE TREAT SHOOT OR ACIDIZE REPAIR WELL (Other) SUBSEQUENT REPORT OF: MULTIPLE COMPLETE FRACTURE TREATMENT ALTERING CASING ABANDON* SHOOTING OR ACIDIZING ABANDONMENT* cHANGE PLANS (Other) Reperf0rate (NOTE: Report results of multiple completion on Well Completion or Recompletion Report and Log form.) 15. DESCRIBE PROPOSED OR COMPLETED OPERATIONS (Clearly state all pertinent details, and give pertinent dates, including estimated date of starting any proposed work. Commenced work. intervals- 12/10/76 Ran 2-3/8" gauge to ll,215' KB. Reperforated the following Bench I:;.Interval .... H-3 11';078.'-11,098' H-4 11,125'-11,145' Lost gun #3 in the tubing at about 6000' KB. and ran fishing tool. Recovered all of gun. the following intervals' Bench G-2 G-2 G-3 H-1 H-3 Interval 10,570'-10,590' 10,598'-10,618' 10,646'-10,666' 10,800"10,820' 11,010'-11,030' Ran impression block. Built Ran 2-3/8" gauge. Reperforated 12/18/76 Returned well to production. SIGNED _ . = /)' . (Thls space for State offlce~s~') South Alaska District TITLE Operations Manager APPROVED BY I CONDITIONS OF APPROVAL, IF ANY: TITLE DATE See Instructions On Reverse Side ,. ,~anticRi, chfie~dCompany North Arn~it, ~ P~'od~cing Divisio~ A~ask~ Regio~; Post Office ~,ox 360 Anchorage, Alaska 99510 Telepho~e 907 277 5637 J.P.. Johnson South A~s;,(~ District Manage: January 31, 1976 Alaska Oil and Gas Conservation Committee Division of Oil and Gas 3001 Porcupine Drive Anchorage, Alaska 99504 Subject: State of Alaska North Trading Bay Unit Ninth Semi-Annual Pressure Maintenance Progress Report Gentlemen: In compliance with Rule 1 of Conservation Order No. 108, enclosed in duplicate is the Ninth Semi-Annual Progress Report for the "G" and Hemlock Northeast Oil Pools of the Trading Bay Field, North Trading Bay Unit. Very truly yours ~Ji ZJo'hnson JPJ/AOS/de Enclosures cc: Director State of Alaska, Division of Lands 323 East Fourth Avenue Anchorage, Alaska 99501 NINTH SEMI-ANNUAL PROGRESS REPORT PROJECT OPERATIONS AND RESULTS PRESSURE MAINTENANCE PROJECT TRADING BAY FIELD "G" AND HEMLOCK NORTHEAST 0IL POOLS DATA TO JANUARY 1, 1976 CONSERVATION ORDER NO. 108 Prepared by D. F. Scheve/A. 0. Skoog 9th SEMI-ANNUAL REPORT Introduction This ninth semi-annual progress report of water injection pressure maintenance project operations and results for the Trading Bay "G" and Hemlock NE oil pools of North Trading Bay Unit is submitted to the State of Alaska Oil and Gas Conservation Committee, in compliance with Con- servation Order No. 108, Rule No. 1. The period covered by this report is from July 1, 1975, to January 1, 1976. Project Operations Four routine workovers to replace electric submersible pumping equipment were conducted and are summarized on the attached 10-403 forms. As of this report date there were nine producing wells and four injection wells completed in the "G" and Hemlock intervals. The attached Exhibit I, a structure map drawn on the top of the Hemlock interval, shows the location of all the wells in the North Trading Bay Unit area. Results On January 1, 1976, cumulative water injection was 15,264,484 barrels, cumulative oil production was 18,020,990 ST barrels, and cumulative water production was 11,124,302 barrels. During the report period, water injection (17,065 RB/D) exceeded reservoir withdrawals (11,501 RBD/D) by 5,564 RB/D. This does not take into account the effect of aquifer influx into the reservoir. The average reservoir pressure is believed to have continued to increase during the report period from about 3350 psi (9800' SS) to about 3550 psi (9800' SS) or about 1770 psi above the bubble point pressure of the crude oil. Estimates of average reservoir pressure at North Trading Bay Unit are complicated by the layered nature of the reservoir. The attached P-12 form hereby submitted to the State of Alaska, Division of Oil and Gas, shows static pressure data collected during the report period from injection well S-5. The attached Exhibit II (a summary table of the pressure maintenance project), Exhibit III (a plot of well static pressures versus cumulative oil production), Exhibit IV (a summary table of historical production and injection data), and Exhibit V (a production rate and reservoir pressure plot) summarize pertinent North Trading Bay Unit production, injection, and pressure data. SUPERIOR SU~RIOR TEXACO I _ SUPER/ORTExACO ~ '" ' / i ~,~ / /, '- ~ I I I// t/, i// ,/ TS-7~.~' ~ ~"/,' / · . / /I/ SUPERIOR ' ' TEXACO TD 10770 __-r VD ~0352 TO ,06 9606 TD i0972 // TD4i562 TVDI0258 .r-)T B ~ -/ ! '- Ei TDI0950/, / y// /X -~967y TD 12717 TD ~2005 TVD 10229 ADL-35431 ARC~ El tlSKB A./R. Co. ADL-18TT6 //TEXACO~i. TB$~_/ I ~ TVD 10066 / / El 24 KB TD 9104 ~O4 ---~ 1 ' -1 . ........ UNION UN/ON T. 9 N. RI3 W. I i I I I I ! t I I I I i I I I ! UNION M.4BAT'HON ADL- 17596 M.4RATHON MARATHON ADL-18731 ADL - 17596 2 LEGEND ~ EXHIBIT I , .. ,__~,_.1 (TO ACCOMPANY ,.9TH__.~ SEMIANNUAL PROGRESS REPORT) · : :~ ~, '~ i~ '/ - . ~.~ PRESSURE MAINTENANCE PROJECT - ~dANuARY I.t t976 . . : .: _ REVISIONS UNION M4~ATNISW AD{_- 17596 AtlanticRichfieldCompany O. Alosko District NORTH TRADING BAY UN IT IADING BAY FIELD, NORTH~ST OIL O( Cook Inlet, Alaska STRUCTURE MAP 'OP HEI~I'LOCK PRO )U( lNG INTE VI INTERPRETED BY: GEOLOGICAL SUB COMMITTEE C.I.: I00' $calo' I"= I000' Diltribution: UNIT MEMBERS Dote Cocrl: 9-2~-69 d TOP HEMLOCK PRODUCING INTERVAL TRADING BAY FIELD, NORTH~ST OIL POOL EXHIBIT II (To Accompany Ninth Semi-Annual Progress Report) PRESSURE MAINTENANCE PROJECT "G" AND HEMLOCK NORTHEAST OIL POOLS NORTH TRADING BAY UNIT SUMMARY TABLE Dates Date of first oil production Date of first water injection (start of project) September, 1968 February 9, 1972 Production and ,Injection Rates Average oil producing rate--second half of 1975, STBD Average water producing rate--second half of 1975, BD Average water injection rate--second half of 1975, BD Average oil producing rate--December, 1975, STBD Average oil producing rate--December, 1975, RBD @ 3550 psig Average water producing rate--December, 1975, BD Average water injection rate--December, 1975, BD 3,698 7,151 17,065 3,655 4,299 6,344 13,626 Number of Wells Completed in "G" and HemlOck Producing, January 1, 1976 Injecting, January 1, 1976 Shut-In, January 1, 1976 Cumulative Production an~, Injection Cumulative oil produced since first production, STB Cumulative oil produced since project started, STB Cumulative oil produced since project started, RB @ 3550 psig Cumulative free gas produced since first production, RB Cumulative water produced since first production, B Cumulative water produced since project started, B Cumulative water injected since project started, B 18,020,990 8,027,781 9,442,276 0 11,124,302 9,165,451 15,264,484 Pressure at 9800' Subsea Estimated initial average reservoir pressure, psig Estimated current average reservoir pressure, psig Bubble point pressure, psig 4,470 3,550 1,780 EXHIBIT Tn' NORTH TRADING BAY UNIT AREA WELL STATIC PRESSURES versus CUMULATIVE OIL PRODUCTION (TO ACCOMPANY 9 T__H SEMIANNUAL PROGRESS REPORT) PRESSURE MAINTENANCE PROJECT "G" AND HEMLOCK NORTHEAST OIL POOLS ~ ' ";'~-,.'i : i~.'~- l~-l.'U ::=:[":_-? -'---~_J.- /'-~: : =: ! j~-'=',---] ..... ,.."-~:1 .... i:_~_ [ :--:--~---~-'I ~'- --=--~, ..... ~'--'t~-:~:'--~ Injecting Well '~ ~i~:~'[ti'e:'ijO-t°' ...... .,r-:.: '=-'.-:--1 ., ~.. . ~. -.~.~ ! - . ~ - . _ ~ ~ , ~ , - . , ~ .... ............ -, -.-~ ...... ' ...... i- ,~ ..... .,- ~--!. _ .... __ ,,_~. .__~_._,..~_.._ , ._ _-~ .... ~_-,~___~_:~=_~..~- - -. ~,_----, .:_:_.,_, - I_ -,~.-__,~_, --~-"~--':. . ..~ ': =:~-'-I ' I --~-,-'~: .. .... ~ : ~ '-I ' , -i -.!--t - . [ ..... ~ ._ . .-- t .......... , .......... , .... · ........ - .......................... ~ ........ , .......... 1 ......... :~-i .... ~ .......... f ............... ~_. :~.: ,:: ~ ~ ..... -1- ...... !.iii ,: .... [ ' J _. I t ' ' J , , ~ ' ' ' .-~ .... :' ..... , . --w . .'T-'--~ .----T--T-- ~__:T-;--.--r-,~ : ...t.:-_-i~.~., --_ · -~ ...... , ............ .--.-- t.-, ............ , ---,---, ..~ ...... -~ .... t_. . ; - ,~., , -...-~ ,.__ ..... =... ...... ---T .,., ,_.,. _, _,_.._,_.,., ..... ~ .... ,,~ ~,_;..-r.. , .~... ........... t ............. -, J ' , .... _: ~,..~_. i._ :_ , "-,- ;~.. '~, ' -' "-' ~ ' ""-. ' "' = 't ! ~'-~'- --~- ....... ,-m .... 1- .... -~ ........ ~ ....... ~ ........ ., ........ -.4 .... - ....... _. L._: __~ --~ ..... '-q ..... :::_:i_ .... , .... :: :__, _ ,'_ ,,._ ' ' . , ~ ," _ ,~:~=~..=,-__ .~.., .... ,-_-~.,...,...~ .... ~ ..,... ,~.-...~:.. ,..~-~- ..... ~- ~...,.._.,.~.~ .... ,..t....-~...,-....-4----.:..-!~-~=--~, ,---! ..... .-=~ ; i-:= 4- .:~,-;.,-~=t ..:,: --' I ---[;. -: .':- : ~ - , '--'~-' -:-t ::;- '-:;'-i--:'~=::-:; '.: L' I: 'i=' :! '!". I:_- - -- " . '! ~ . ' -' I.':--F_-'-q.,-=H~-.~:,-~.., ,-, ...... ,~ ii' .]-. , ;-- .... , : 'I , ,'--:F---.,-'=t-t-~-~, ..... !-~-' - -. ~ . - .... · ~ ! , . o.- ................ . ............. . ........ =~.. =..,__,._ _, ..... ~ ....... L,~._L ...... :L:__L._~ ......... l ............... _2-.' ~ 0 I 2 3 4 5 6 7 8 9 I0 II 12 13 14 15 16 17 18 19 20 · _ CUMULATIVE OIL PRODUCTION -- MILLION STOCK TANK BARRELS EXHIBIT IV · ,(To Accompany Ninth Semi-Annual Progress Report) P~ESSURE ~INTENANCE PROJECT TRADING BAY FIELD--"G" AND I{EMLOCK NORTHEAST OIL POOLS--NORTH TRADING BAY UNIT AREA Page 1 of 3 HISTORICAL PRODUCTION AND INJECTION DATA Rate1 Year Month BOPD Oil Production Water Production GaS-Oil Water Injection A~nthly Cumulativez Ratel Monthly Cumulative2 Ratio 'Ratei Monthly Cumulativez STB STB BWPD ~¥ BW SCF/STB BWPD BW BW Non-unitized operations September, 1968 to July 1, 1971 1968 1969 Sept. 95 Oct. 532 Nov. 1,715 Dec. 3,673 Jan. 3,826 Feb. 7,706 Mar. 10,432 Apr. 12,891 May 13,435 June 12,401 July 10,536 Aug. 13,081 Sept. 13,388 Oct. 13,938 Nov. 15,301 Dec. 14,580 1970 Jan. 13,690 Feb. 12,479 liar; 9,901 Apr. 9,245 May 9,185 June 8,10~ July 8,222 Aug. 7,134 Sept. 6,607 Oct. 7~141 NOV. 8,151 Dec. 7,707 [ 1971 o 252 480 241 2,760 245 5,417 248 8 126 282 11 493 325 21 796 288 35 087 341 57 952 268 119 675 270 166 325 274 185 166 263 2O3 348 261 218 994 256 239 303 251 261 631 254 289,120 248 331,176 259 396,466 256 448,327 235 510,259 243 576,378 235 617,286 210 646,346 181 687,515 191 723,610 173 766,637 178 814,996 192 2,857 2,857 0 16,500 19,357 15 51,462 70,819 76 113,867 184,686 86 118,620 303,306 87 215,757 519,063 120 323,395 842,~58 332 386,719 1,229,177 443 416,488 1,645,665 738 372,034 2,017,699 2,057 326,615 2,344,314 1,505 405,499 2,749,813 608 401,627 3,151,440 606 432,076 3,583,516 505 459,032 4,042,548 677 451,985 4,494,533 720 424,396 4,918,929 887 349,410 5,268,339 1,502 306,919 5,575,258 2,106 277,357 5,852,615 1,729 284,740 6,137,355 1,998 243,173 6,380,528 2,004 254,870 6,635,398 1,513 221,163 6,856,561 937 198,204 7,054,765 1,372 221,384 7,276,149 1,164 244,519 7,520,668 1,434 238,905 7,759,573 1,560 217,795 7,977,368 1,269 187,370 8,164,738 1,514 200,165 8,364,903 1,756 195,810 8,560,713 2,012 193,827 8,754,540 1,787 154,758 8,909,298 1,811 0 480 2,280 2,657 2,709 3,367 10,303 13,291 22,865 61,723 46!650 !p,841 18;182 15,646 2O,3O9 22,328 27 489 42 O56 65 290 51 861 61 932 60 119 46 908 29 060 41 169 36 095 43027 48,359 '39,350 42,391 54,444 60,350 55,401 54,325 Jan. 7,026 854,346 Feb. 6,692 896.737 Mar. 6,457 951,181 Apr. 6,527 1,011,531 May 6,252 1,066,932 June 5,159 1,121,257 Unitized effective July 1, 1971--North Trading Bay Unit July 4,921 152,561 9,061,859 4,832 149,781 1,271,038 Aug. 4,387 136,009 9,197,868 4,163 129,058 1,400,096 Sept. 4,876 146,291 9,344,159 3,213 96,404 1,496,500 Oct. 4,997 154,901 9,499,060 3,701 114,725 1,611,225 Nov. 5,041 151,223 9,650,283 3,364 100,931 1,712,156 Dec. 4,469 138,538 9,788,821 3,480 107,870 1,820,026 1972 Jan. 5,129 158,987 9,947,808 3,451 106,980 1,927,006 Feb. 5,252 152,304' 10,100,112 3,684 106,832 2,033,838 Mar. 6,218 192,750 i0,292,862 3,338 103,465 2,137,303 Apr. 8,367 251,011 10,543,873 3,596 107,890 2,245,193 May 9,014 279,441 10,823,314 3,659 113,429 _2,358,622 June 8,428 252,838 11,076,152 4,243 127,294 2,485,916 1 Monthly volu~e divided by number o~ days in month. 2 Cumulative volume at end of month. 191 - - - 200 - - - 2&3 - - - 179 - - - 192 - - - 183 .... 223 - - 243 - - 259 - - 240 - - 228 - - 225 - - 226 .- - 223 5,574 161,647 259 7,644 236,953 243 10,830 324,912 264 9,178 284,516 265 9,159 274,769 3 At 9,800 feet subsea from Pressure-Cumulative Oil Production plot. 161',647 398,600 723,512 1,008,028 1,282,797 Estimated Reservoir Number of Wells Completed Pressure3--PSIG Producin~ I~ecting ~hut-I~ 4,470 4,320 3 3 3,870 4 5 5 3,320 '.7 7 7 2,980 8 10 10 2,750 9 9 2,620 9 - 9 - !8 - 2,550 7 - 8 - 2,490 7 - 8 - 9 - 2,430 10 - · -.- :-_' '.' L, ........ 7,7~' , "'.. 8 9 2,380 9 - 9 - 9 - 2,350 9 - 1 0 o 0 1 1 1 1 1 2 3 2 2 3 2 ; 1 0 1 1 1 1 1 2,320 2,300 2,300 2~700 EXHIBIT IV (To Accompany Ninth' Semi-Annual Progress Report) PRESSURE ~INTENANCE PROJECT TRADING BAY FIELD--"G" AND HEMLOCK NOR~{EAST OIL POOLS--NORTH TRADING BAY I/NIT AREA HISTORICAL PRODUCTION AND INJECTION DATA Page 2 of 3 Year Month Oil Production Rate1 Monthly Cumulative2 BOPD STB STB 1972 1973 1974 1975 July 7,674 Aug. 7,646 Sept. 7,073 Oct. 6,529 Nov. 6,078 Dec. 6,236 Jan. 6,463 Feb. 6,015 Mar. 5,417 Apr. 5,396 May 5,166 June 4,532 July 5,890 Aug. 5,640 Sept. 5,650 Oct. 5,484 Nov. 5,402 Dec. 5,438 237,887 237,026 212,203 202,397 182,350 193,325: 200 360 168 409 167 917 161 888 160 156 135 964 182 580 174 849 169 512 170 004 162 070 168 592 11,314,039 11,551,065 11,763,268 11,965,665 12,148,015 12,341,340 12,541,700 12,710,109 12,878,026 13,039,914 13,200,070 13,336,034 13,518,614 13,693,463 13,862,975 14,032,979 14,195,049 14,363,641 Water Production Gas-Oil Water Injection Estimated Rate~ Monthly Cumulative2 Ratio Rat?- Monthly Cumulativ~2 Reservoir BWPD ~V BW SCF/STB BW-PD BW ~V PressureJ---PSIG 4,177 129,499 2,615,415 253 7,869 243,924 1,526,721 4,663 144,549 2,759,964 252 7,726 239,516 1,766,237 4,748 142,447 2,902,411 245 8,212 246,360 2,012,597 2950 4,698 145,638 3,048,049 243 9,102 282,163 2,294,760 4,806 144,187 3,192,236 229 11,592 347,749 2,642,509 6,797 210,717 3,402,953 263 11,813 366,206 3,008,715 3050 7,179 222,556 3,625,509 297 11,107 344,315 3,353,030 6,592 184,5~3 3,810,092 284 5,845 163,651 3,516,681 6,471 200,627 4,010,719 290 8,700 269,709 3,786,390 3080 5,691 170,741 4,181,460 287 12,736 382,069 4,168,459 6,334 196,351 4,377,811 276 6,825 211,587 4,380,046 6,571 197,122 4,574,933 294 2,956 ~8,675 4,468,721 3100 7,879 244,234 4,819,167 307 8,564 265,494 4,734,215 6,589 204,265 5,023,432 311 5,562 172,418 4,906,633 7,053 211,589 5,235,021 297 8,354 250,615 5,157,248 3100 7,024 217,745 5,452,766 287 10,552 327,116 5,484,364 7,200 215,992 5,668,758 283 9,627 288,816 5,773,180 7,236 224,303 5,893,061 274 9,912 307,266 6,080,446 3100 Jan. 5,481 169,900 14,533,541 7,276 Feb. 5,342 149,574 14,683,115 6,704 Mar. 5,212 161,570 14,844,685 7,172 Apr. 4,963 148,895 14,993,580 6,554 May 4,936 153,005 15,146,585 7,036 June 6,083 182,482 15,329,067 7,067 July 6,281 194,713 15,523,780 8,533 Aug. 7,396 229,285 15,753,065 8,810 Sept. 6,498 194,934 15,947,999 8,632 Oct. 6,236 193,325 16,141,324 8,901 Nov. 6,035 181,053 16,322,377 7,978 Dec. 5,445 168,794 16,491,171 6,608 225,548 6,118,609 187,708 '6,306,317 222,326 6,528,643 196,622 6,725,265 218,129 6,943,394 212,057 7,155,451 264,510 7,419,961 273,119 7,693,080 258,967 .7,952,047 275,926 8,227,973 239,328 - 8,467,301 204,863 8,672,164 275 9,661 299,481 6,379,927 276 9,428 263,985 6,643,912 298 9,259 287,036 6,930,948 3080 282 9,035 234,912 7,165,860 281 9,117 282,641 7,448,501 266 9,019 270,573 7,719,074 3050 273 8,933 276,917 7,995,991 .......... 268 8,983 278,466 8,274,457 281 9,264 277,924 8,552,381 3000 286 8,619 .- 267,177 8,819,558 296 5,655 169,656 8,989,214 321 7,278 225,615 9,214,829 ... 2950 Jan. 5,473 169,672 16,660,843 6,161 191,015 8,86~,179 309 16,180 Feb. 5,110 143,070 16,803,913 5,721 160,193 9,023,372 317 16,829 Mar. 4,618 143,164 16,947,077 6,354 196,991 9,220,363 298 17,452 Apr. 4,530 135,894 17,082,971 5,913 177,396 9,397,759 305 17,068 }~y 4,440 137,642 17,220,613 6,240 193,458 9,591,217 315 18,989 June 3,999 119,961 17,340,574 7,244 217,332 9,808,549 315 20,310 501,587 9,716,416 471,212 10,187,628 226,876 10,414,504 3100 512,039 10,926,543 588,656 11,515,199 609,311 12,124,510 3350 Well S-5 was completed as both a producer and an injector during December, 1974. Number of Wells Comple%ed Producing Injecting Shut-in 8 3 1 8 3 1 8 3 1 9 3 0 8 3 1 8 3 1 8 3 1 8 3 1 8 3 1 8 3 1 8 3 1 R 3 1 8 3 0 8 3 0 8 3 0 8 3 0 8 3 0 8 3 0 8 3 0 8 3 0 8 3 0 8 3 0 7 3 1 8 3 0 9 3 0 9 3 0 9 3 0 9 3 0 10' 3 0 10' 4* 0 9 4 0 9 4 0 9 4 0 9 4 0 9 4 0 9 4 0 1 Monthly volume divided by number of days in month. 2 Cumulative volume at end of month. 3 At 9,800 feet subsea from Pressure-Cumulative Oil Production plot. Ye ~r _ 1975 Month Rate1 BOPD _ EXHIBIT IV ,(To Accompany Ninth Semi-Annual Progress Report) PRESSURE MAINTENANCE PROJECT TRADING BAY FIELD--"G"'ANDHEMLOCK NORTHEAST OIL POOLS--NORTHTRADING BAY UNIT AREA HISTORICAL PRODUCTION AND INJECTION DATA' Oil Production Water Production Gas-Oil . Water Injection Monthly Cumulativez Ratel Monthly Cu~ula~ive~/ Ratio 'Ratel Monthly Cumulative2 STB STB - BWPD - BW BW :S~F/STB 'BWPD . BW BW July 3,717 115,240 17,455,814 7,942 246,213 10,054,762 336 Aug. 3,625 112,365 17,568,179 8,259 256,023 10,310,785 333 Sept. 3,783 113,482 17,681,661 7,353 220,582 10,531,367 294 Oct. 3,713 115,117 17,796,778 6,450 199,958 10,731,325 306 Nov. 3,697 110,908 17,907,686 6,544 196,317 10,927,642 311 Dec. 3,655 113,304 18,020,990 6,344 196,660 11,124,302 318 Page ~ of 3 18,132 562,084 12,686,594 18,296 567,168 13,253,762 18,496 554,893 13,808,655 18,049 559,506 14,368,161 15,797 473,904 14,842,065 13,626 422,419 15,264,484 Est imat ed Reservoir Pressure3--PSIG' Producin~ 3475 3550 Number of Wells Completed Injecting Shut-IM 9 4 0 9 4 0 9 4 0 9 4 0 9 4 0 9 4 0 1 Monthly volume divided by number of days in month. 2 Cumulative volume'at end of month. 3 At 9,800 feet subsea from Pressure-Cumulative 0il Production plot. 22 "';'0 iS¸` EXHIBIT ~ NORTH TRADING BAY UNIT PRODUCTION AND PRESSURE HISTORY TO ACCOMPANY 9TH SEMIANNUAL PROGRESS REPORT) PRESSURE MAINTENANCE PROJECT "G" AND HEMLOCk( NOP"r~FAS- O,L PO0-S t.o I0 ~ 8 ..% I 0 ESTIMATED. AGE RESERVOIR PRE SSURE . l '' 11'3 .r-. --/'J - L..r'F LJ ~ i ' ,', LJ ......................................................................... ' ' . . i' " " ..... - ' ' 'i'~''~WATE PR'C~DuC~L. ION: , : ': ' ' ' ' ............ . ' _ ..L__L= ....... --: -.- ................. ~ ~-~ rJ ,- . La.' r~, '~.' ~, ," .,:~-- · ,-~.. / .... :~ ....... .. ......... i ....... ~' ...................... T ......... ~'-'" '~' ' ................ ~ .~ ......... 4. . . , ', , .:'. i.:'.! I ,r-'. L'--L;--,--r--':':..'',:- . -'. ~ - ' .... . ~ t_~ I:~'-" ..... <,':"-'4~ ,_ I 29.... 68. "19..,69 . I 1.9.70. I . _: : ..... i ........... : .......... --4 ;-: ;...L - :-"_L_:_:: .... .-i_:.:_%:-: , ._ __ 2_% _ :_ ..... 4---: ................ ', ; .... ~ .... , -~ ........ ','- ' . -- t-": .... ~ :- ' i . :?.-:.:' _.~ ': .:: _:.~. :'_'_7_ L:-: ',":. :.-' :_ ':' !'+ ......... .. -- . . ~.,. --_~ [. -[-4 '.. I .... ~-- ~ ..... ~ .... ., ..... ~ ............ -_~-?--~- ........ :'-t----; j .-: .;_ , .,-.4 i .. : ~ , " ......... "--:"L" ' ; .:~._:.;.,_'; '_:__:..:.:-:_: ' :, _.:_~_._: _. ::: · , t ........ ~ ....... ? . · t-~ ' - . · · ,I. -- i .......... ..... : , _L ....... :;_ 2 .: : _: : :: ...... i..:.L. _: '. :].9 7L. 19 72.. 19 Z_3 .... 19.._Zar. 5OOO 4000 3000 · -:T-7--: ....... ..... ... [ --- ..._ I000 0 o d~ 2000 '"" Form 10-403 ' Submit "Intentions" in Triplicate l" REV. 1-10-73 & "Subsequent Reports" in Duplicate STATE OF ALASKA OIL AND GAS CONSERVATION COMMITTEE SUNDRY NOTICES AND REPORTS ON WELLS (Do not use this form for proposals to drill or to deepen Use "APPLICATION FOR PERMIT--" for such proposals.) 5. APl NUMERICAL CODE 50-133-20120 6. LEASE DESIGNATION AND SERIAL NO. ADL 17597 7. ,F ,ND,AN. ALLOTTEE OR TR,BE NAME ~' o,L ~ GAS I--1 WELLi~l WELLi i OTHER 2. NAME OF OPERATOR Atlantic Richfield Company ADDRESS OF OPERATOR P. 0. Box 360, Anchorage, Alaska 99510 4. LOCATION OF WELL At surface 615' S and 2072' W of NE corner of Section 34, T10N, R13W, SM 13. ELEVATIONS (Show whether DF, RT, GR, etc.) 92' KB 14. Check Appropriate Box To Indicate Nature of Notice, Re 8. UNIT, FARM OR LEASE NAME North Tradin_~ Bay Unit 9. WELL NO. TS-1 10. FIELD AND POOl, OR WILDCAT Trading Bay "G" & Hemlock NE il. SEC., T., R., M., (BOTTOM HOLE OBJECTIVE) Section 27, T10N, R13W, SM 12. PERMIT NO. 68 - 48 )orr, or Other Data NOTICE OF INTENTION TO= TEST WATER SHUT-OFF FRACTURE TREAT SHOOT OR ACIDIZE REPAIR WELL PULL OR ALTER CASING MULTIPLE COMPLETE ABANDON* CHANGE PLANS (Other) SUBSEQUENT REPORT OF: WATER SHUT-OFF ~ REPAIRING WELL ~ FRACTURE TREATMENT ~ ALTERING CASING ~ SHOOTING OR ACIDIZING I I ABANDONMENT* l"--'--I (Other)Reperf. & Replace Submersible Pum~ X~ (NOTE= Report results of multiple completion on Well Completion or Recompletion Report and Log form.) 15. DESCRIBE~PROPOSED OR COMPLETED OPERATIONS (Clearly state all Pertinent details, and give pertinent dates, including estimated date of starting any proposed work. SEE ATTACHED SHEET 16. I hereby certify tha~t~e~foregolng is t~)ue and correct SIGNED (T his space for State offJ~e/-.~se) South Alaska District TITLE 0per~t~ nn_~ Manager APPROVED BY CONDITIONS OF APPROVAL, IF ANY= T IT LE DATE See Instructions On Reverse Side TS-1 7-27-75 Commenced workover operations. Rigged up and loaded well with diesel. Removed tree, installed and tested BOP. Pulled tubing and downhole electric pumping equipment. RIH with open ended tubing to 9017' MD. Circulated out diesel with Inlet water. Continued to run tubing. Pushed junk to bottom and found fill at 10,373' MD. Picked up tubing to 10,063' MD. Rigged up Dresser - Atlas and reperforated the following intervals with two holes per foot using bar guns: Zone From To (CBL depths) "G" 10,085' - 10,145' "G" 10,152' - 10,172' Hemlock 10,284' - 10,304' Hemlock 10,312' - 10,342' Rigged down Dresser - Atlas and POH with tubing. RIH with replacement submersible pump on 3 1/2" tubing. Landed completion assembly with bottom of Reda motor at 10,006' MD. 8-8-75 Started pump and returned well to production. Form :t 0-403 Submi t "1 ntentlons" in Triplicate REV. 1-10-73 & "Subsequent Reports" in Duplicate STATE OF ALASKA OIL AND GAS CONSERVATION COMMITTEE SUNDRY NOTICES AND REPORTS ON WELLS (Do not use this form for proposals to drill or to deepen Use "APPLICATION FOR PERMIT--" for such proposals.) 5. APl NUMERICAL CODE 50-133-20120 6. LEASE DESIGNATION AND SERIAL NO. ADL 17597 WELLIA~31 WELL OTHER Z NAMEOFOPERATOR Atlantic Richfield Company 3. ADDRESSOFOPERATOR P. O. Box 360, Anchorage, Alaska 4. LOCATION OF WELL At surface 99510 615' S and 2072' W of NE corner of Section 34, T10N, R13W, SM 13. ELEVATIONS (Show whether DF, RT, GR, etc.) 92' KB 14. Check Appropriate Box To Indicate Nature of Notice, Re 8. UNIT, FARM OR LEASE NAME North Trading Bay Unit 9. WELL NO. TS-1 10. FIELD AND POOL, OR WILDCAT Trading Bay "G"& Hemlock NE 11. SEC., T., R., M., (BOTTOM HOLE OBJECTIVE) Section 27, T10N, R13W, SM 12. PERMIT NO. 68 - 48 )ort, or Other Data NOTICE OF INTENTION TO-' TEST WATER SHUT-OFF L--J PULL OR ALTER CASING FRACTURE TREAT MULTIPLE COMPLETE SHOOT OR ACIDIZE ABANDON* REPAIR WELL CHANGE PLANS (Other) SUBSEQUENT REPORT OF: WATER SHUT-OFF ~ REPAIRING WELL FRACTURE TREATMENT ALTERING CASING SHOOTING OR ACIDIZING ABANDONMENT* (Other) R~_nl ~r_~ ,guhTnP. r.~ih'l P_ Pumn (NOTE: Report results of multiple completion on Well Completion or Recompletion Report and Log form.) 15. DESCRIBE.PROPOSED OR COMPLETED OPERATIONS (Clearly state all pertinent details, and give pertinent dates, including estimated date of starting any proposed work. 9-27-75 Commenced workover operations.' Rigged up and loaded well with Inlet water. Removed tree, installed and tested BOP. POH with tubing. Down- hole electric pump equipment left in hole. [Bolts holding pumping equipment to tubing failed.] RIH with fishing tools and recovered all of electric pumping equipment. RIH with replacement submersible pump on 3 1/2" tubing. Landed completion assembly with bottom of Reda motor at 9924' MD. Installed and tested tree. 10-6-75 Started pump and returned well to production. 16. I hereby certify that the foregoing is true and correct SIGNED (This space for State offlZe~use) TITLE South Alaska District Operations Manager APPROVED BY. CONDITIONS OF APPROVAL, IF ANY: TITLE DATE See Instructions On Reverse Side Form 10-403 REV. 1-10~73 Submit "1 ntentions" In Triplicate & "Subsequent Reports" in Duplicate STATE OF ALASKA OIL AND GAS CONSERVATION COMMITTEE SUNDRY NOTICES AND REPORTS ON WELLS (Do not use thls form for proposals to drill or to deepen Use "APPLICATION FOR PERMIT--" for such proposals.) 5. APl NUMERICAL CODE 50-133-20133 6. LEASE DESIGNATION AND SERIAL NO. ADL 17597 7. IF INDIAN, ALLOTTEE OR TRIBE NAME 1. OIL ['~ GAS ~ WE L L L~--~ WELLi I OTHER 2. NAME OF OPERATOR 8. UNIT, FARM OR LEASE NAME Atlantic Richfield Company North Trading ~ ~i~ ~ ADDRESS OF OPERATOR 9. WELL NO. ~. 0. ~ox 360, A~cho~a~e, Ales~a 99510 ~S-3 4. LOCATION OF WELL At surface 618' S and 2068' W of NE corner of Section 34, T10N, R13W, SM 13. ELEVATIONS (Show whether DF, RT, GR, etc.) 92' KB 14. Check Appropriate Box To Indicate Nature of Notice, Re 10. FIELD AND POOl, OR WILDCAT Trading Bay "G" & Hemlock NE 11. SEC., T., R., M., (BOTTOM HOLE OBJECTIVE) Section 34, T10N, R13W, SM 12. PERMIT NO. 68 - 65 )ort, or Other Data NOTICE Of INTENTION TO: TEST WATER SHUT-OFF L--J PULL OR ALTER CASING FRACTURE TREAT MULTIPLE COMPLETE SHOOT OR ACIDIZE ABANDON* REPAIR WELL CHANGE PLANS (Other) SUBSEQUENT REPORT OF: FRACTURE TREATMENT ALTERING CASING SHOOTING OR ACIDIZING ABANDONMENT* (Other).~?] ace Submersible Pump (NOTE: Report results of multiple completion on Well Completion or Recompletion Report and Log form.) 15. DESCRIBE PROPOSED OR COMPLETED OPERATIONS (Clearly state all pertinent details, and give pertinent dates, including estimated date of starting any proposed work. 10- 8-75 Commenced workover operations. Rigged up and loaded well with Inlet water. Removed tree, installed and tested BOP. POH with tubing and downhole electric pumping equipment. RIH with replacement submersible pump on 2 7/8" tubing. Landed completion assembly with bottom of Reda motor at 9664' MD. 10-11-75 Started pump and returned well to production. 16. I hereby certify that the foregoing is true and correct (This space for State off~e-~g) South Alaska District TITLE .Operations Manager APPROVED BY CONDITIONS OF APPROVAL, IF ANY: TITLE DATE See Instructions On Reverse Side Form 10-403 REV. 1-10-73 Submit "1 ntentlons" in Triplicate & "Subsequent Reports" in Duplicate STATE OF ALASKA OIL AND GAS CONSERVATION COMMITTEE SUNDRY NOTICES AND REPORTS ON WELLS (Do not use this form for proposals to drill or to deepen Use "APPLICATION FOR PERMIT--" for such proposals.) ~' O,L ~ GAs [-] WELL I,~ WELL OTHER 2. NAME OF OPERATOR Atlantic Richfield Company 3. ADDRESS OF OPERATOR P. 0. BOX 360~ Anchorage~ Alaska 99510 4. LOCATION OF WELL At surface 2612' N and 2488' W from SE corner, Section 26, T10N, R13W, SM 13. ELEVATIONS (Show whether DF, RT, GR, etc.) 115 ' KB Check Appropriate Box To Indicate Nature of Notice, Re 5. APl NUMERICAL CODE 50-133-20197 6. LEASE DESIGNATION AND SERIAL NO. ADL 18776 7. IF INDIAN, ALLOTTEE OR TRIBE NAME 8. UNIT, FARM OR LEASE NAME North Trading Bay Uni~ 9. WELL NO. s-7 ~ (13-35) 10. FIELD AND POOL, OR WILDCAT Trading Bay "G" & Hemlock NE Po( 11. SEC., T., R., M., (BOTTOM HOLE OBOECT~VE} Section 35; T]0N; R]3W.. SM 12. PERMIT NO. 69 - 83 )ort, or Other Data NOTICE OF INTENTION TO: FRACTURE TREAT MULTIPLE COMPLETE SHOOT OR ACIDIZE ABANDON* REPAIR WELL CHANGE PLANS (Other) SUBSEQUENT REPORT OF: WATER SHUT-OFF r~ REPAIRING WELL FRACTURE TREATMENT~.~ ALTERING CASING SHOOTING OR ACIDIZING ABANDONMENT* (Other)Rep,ff. replace Subm. Pump (NOTE: Report results of multiple completion on Well Completion or Recompletion Report and Log form.) 15. DESCRIBE PROPOSED OR COMPLETED OPERATIONS (Clearly state all pertinent details, and give pertinent dates, including estimated date of starting any proposed work. SEE ATTACHED SHEET SIGNED (This space for State South Alaska District TITLE APPROVED BY CONDITIONS OF APPROVAL, IF ANY: T IT LE DATE See Instructions On Reverse Side S-7 12/2/75 Commenced workover operations. Rigged up and loaded well with Drill-S mud. Removed tree, installed and tested BOP. Pulled tubing and downhole electric pumping equipment. RIH with open ended tubing to circulate out fill at 12,140' CBL MD. Unable to circulate out fill. POH and rig up Dresser-Atlas. Reperforated the following intervals with 2 holes per foot using 4" casing guns: From To Zone (CBL Depths) "G" 11,745' - 11,811' "G" 11,863' - 11,873' "G" 11,918' - 11,938' Hemlock 11,980' - 12,006' Hemlock 12,018' - 12,078' Hemlock 12,104' - 12,137' RIH with replacement submersible pump on 4-1/2" tubing. Landed completion assembly with bottom of Reda motor at 11,731' MD. Installed and tested tree. Displaced mud with Inlet water. 12/18/75 Started pump and returned well to production. Form P--12 STATE OF ALASKA OIL AND GAS CONSERVATION COMMITTEE *See Instructions on Reverso~ Side RESERVOIR PRESSURE REPORT Operator Address Atlantic Richfield Company : P~ O. Box 360~ Anchorage, Alaska 99510 Field I C°unty : 1 Date North Trading Bay Unit :' Kenai - ~' 1-23-76 Producing Formation Oil Gradient,,G,, & Hemlock . Water Gradient0o 43 Initial C°mpleti°n* I Special*: iGeneral Survey* ! Datum Planex I 9800 ' SS [ Gas Gravity ~' ] ~ Shut-In Sonic Instrument Test Data ~ ~ Date Prod. I , , Pressure " '".~ '~ ~ Test W't. of Wt. of ~ ~ © 0~ - Tubing Test B.H. Observed per Day) Liquid Liquid Casihg at Lease ~ ~ ~ ~ Tes[ed (Bbls. Liquid Gas ~' ~ : ~ ~ Pressure Depth Temp. Pressure Oil Wa~e~ ~vel . Gradient Column ColumnPressure_ ~ Datum ~L 18776 S-5 ~.I 12-18-75 ~00 11 160 ] 3970: I [ ' , - ' ....... 3972 11,166 - 397~ - I ...... 3973 ~ rSIC [ . rs~c 9,80 , " I : . rel ! . South Alaska CERTIFICATE: I, the undersigned, state that I am the'D_is ..... Eng ..... oS the .A.tlan.ti_c.__Ri.chfield Company (company), and that I am authorized by said company, to make this report; and that this report was prepared under my supervision and direction and that the facts stated therein are true, correct and ature ...................................................................................... - MINER PUBLISHING CO. AttanticRichfieldCompany North Ameri~ ~r0duci Regii,, ng Division Alaska Post Office Dox 380 Anci~orage, Aisska~ Telephone 90,7 277' 5:3.3:" Jesse P. Johnson South Aiaska District M~nagev August 7, 1975 Alaska Oil and Gas Conservation Committee Division of Oil and Gas 3001 Porcupine Drive Anchorage, Alaska 99504 4 ENG I : i-¢ CONFER= FILE: ..... Subject: State of Alaska North Trading Bay Unit Sixth Semi-Annual Pressure Maintenance Progress Report Gentlemen: In compliance with Rule 1 of Conservation Order No. 108, enclosed in duplicate is the Eighth Seni-Annual Progress Report for the "G" and Hemlock NE Oil Pools of the Trading Bay Field, North Trading Unit. Very tru~ly yours, J. P. Johnson Enclosures cc: Director, State of Alaska, Division of Lands EIGHTH SEMI-ANNUAL PROGRESS REPORT PROJECT OPERATIONS AND RESULTS PRESSURE MAINTENANCE PROJECT TRADING BAY FIELD "G" AND HEMLOCK NORTHEAST OIL POOLS DATA TO JULY 1, 1975 CONSERVATION ORDER NO. 108 PREPARED BY D. SCHEVE INTRODUCTION This eighth semi-annual progress report of water injection pressure maintenance project operations and results for the Trading Bay "G" and Hemlock NE oil pools of North Trading Bay Unit is submitted to the State of Alaska, Oil and Gas Conservation Committee, in compliance with Conservation Order No. 108, Rule No. 1. The period covered by this report is from January 1, 1975, to July 1, 1975. PROJECT OPERATIONS There were no drilling operations or well conversions during the period covered by this report. Benches G-2, G-3, G-4, H-3L, and H-4 in well S-2 RD were through tubing reperforated in an attempt to improve the well's declining productivity. Early test results immediately after the reper- forating indicated the work had been successful, i.e. the rate increased from 447 BOPD and 413 BWPD to 1105 BOPD and 496 BWPD. After three days the rate declined suddenly to 550 BOPD and 450 BWPD indicating plugging of the new perforations. Benches G-2, H-3, and H-4 were therefore reperforated a second time along with 20' in H-1. The test rate after this perforating was 773 BOPD and 583 BWPD. A description of the work is given on'the attached P-3 form dated August 6, 1975. As of this report date there were nine producing wells and four injection wells completed in the "G" and Hemlock intervals. The attached Exhibit I, a structure map drawn on the top of the Hemlock interval, shows the location of all the wells in the North Trading Bay Unit area. RESULTS On July 1, 1975, the cumulative water injection was 12,124,501 barrels, cumulative oil production was 17,340,874 barrels, and cumulative water production was 9,808,549 barrels. During June, 1975, water injection (20,310 RB/D) exceeded reservoir withdrawals (11,977 RB/D) by 8,333 RB/D. This does not take into account the effect of aquifer influx into the reservoir. The attached Exhibit II (a summary table for the pressure maintenance project during the report period), Exhibit IV (a summary table of historical production and injection data) and Exhibit V (a pro- duction, injection rate and reservoir pressure plot) summarize pertinent North Trading Bay Unit area production and injection data. Eighth Semi-Annual Progress Report Page -2- The average reservoir pressure is believed to have increased during the report period from 2950 psi to about 3350 psi (9800' SS), or about 1570 psi above the bubble point pressure of the crude oil. This estimate is based on material balance work that takes into account the location of, and distribution of, injection into well S-5. Estimates of average reservoir pressure at North Trading Bay Unit are complicated by the layered nature of the reservoir. The attached Exhibit III is a plot of reservoir pressure versus cumulative production. Exhibits IV and V show pertinent average reservoir pressure data for North Trading Bay Unit. D. F. Scheve DFS/de Attachments Form 10-403 REV. 1-10~73 Submit "1 ntentions" in Triplicate & "Subsequent Reports" In Duplicate STATE OF ALASKA OIL AND GAS CONSERVATION COMMITTEE SUNDRY NOTICES AND REPORTS ON WELLS (Do not use this form for proposals to drill or to deepen Use "APPLICATION FOR PERMIT--" for such proposals.) 5. APl NUMERICAL CODE 50-133-20172-01 6. LEASE DESIGNATION AND SERIAL NO. ADL-18776 7. IF INDIAN, ALLOTTEE OR TRIBE NAME WELL L~J OTHER 2. NAME OF OPERATOR 8. UNIT, FARM OR LEASE NAME Atlantic Richfield Company North Trading Bay Unit 3. ADDRESS OF OPERATOR 9. WELL NO. P. O. Box 360, Anchorage, Alaska 99510 S-2 RD 4. LOCATION OF WELL Atsurface 2606' FSL & 2492' FEL of Section 26, T10N, R13W, SM 13. ELEVATIONS (Show whether DF, RT, GR, etc.) 115 ' KB 14. CheCk Appropriate Box To Indicate Nature of Notice, Re 10. FIELD AND POOL, OR WILDCAT Trading Bay Unit,G & Hemlock NE Puc 11. SEC., T., R., M., (BOTTOM HOLE OBJECTIVE) Sec. 34, T10N, R13W, SM 12. PERMIT NO. 74-24 )ort, or Other Data NOTICE OF INTENTION TO: TEST WATER SHUT-OFF L--J PULL OR ALTER CASING FRACTURE TREAT MULTIPLE COMPLETE SHOOT OR ACIDIZE ABANDON* REPAIR WELL CHANGE PLANS (Other) SUBSEQUENT REPORT Of: WATER SHUT-OFF r'-'-I REPAIRING WELL FRACTURE TREATMENT~ ALTERING CASING SHOOTING OR ACIDIZING ABANDONMENT* (Other) Reperforate (NOTE: Report results of multiple completion on Well Completion or Recompletion Report and Log form.) :15. DESCRIBE PROPOSED OR COMPLETED OPERATIONS (Clearly state all pertinent details, and give pertinent dates, including estimated date of starting any proposed work. SEE ATTACHED SHEET :16. I hereby certify that the foregoing is true and correct (This space'or'State o~'ce~use, APPROVED BY CONDITIONS OF APPROVAL, IF ANY: TITLE DATE See Instructions On Reverse Side WELL S-2RD 5/3/75 COMMENCED OPERATIONS Rig-up Dresser Atlas. Pressure test lubricator to 2700 psi. RIH with 2-1/2" gauge ring and collar locator, tagged bottom at 11,226'. Picked up 20' bar gun, pressure test lubricator to 2700 psi, run in hole with same. Gun stopped in Otis "x" nipple at 10,466' MD. Could pick up on tool but not go down. Started out of hole and stuck gun in ball valve at approximately 318' wire line measurements. Pulled out of rope socket. Rig-up North Star Engineering's braided line unit and recovered fish. Left one jet perforating charge and an 18" strip of aluminum in hole. 5/4/75 5/9/75 RETURNED WELL TO PRODUCTION. COMMENCED OPERATIONS Rig-up Schlumberger to perforate. Reperforated the following intervals under drawdown conditions using Schlumberger 2" scallop gun loaded with 4 shots per foot. Tagged bottom at 11,226'. Zone From To Ft. of Perforations ~ G-2 10,563' MD 10,618' MD 55' G-3 10,643' MD 10,688' MD 45' G-4 10,694' MD 10,714' MD 20' H-3L 11,078' MD 11,098' MD 20' H-4 11,145' MD 11,165' MD 20' The procedure for perforating each interval was as follows: 1. Pressure test lubricator to 2700#. 2. SI tubing and casing and RIH. Be Put well on production at rate estimated to give 600-800 psi drawdown. 4. Perforate and produce well 10 minutes to clean-up perforations. 5. SI tubing and casing and POH. 6. After perforating a bench, test to evaluate results. 5/13/75 RETURNED WELL TO PRODUCTION D. F. Scheve 8/6/75 DFS/de Form 10-403 t Subml t "1 ntentions" In Triplicate REV. 1-10-73 & "Subsequent Reports" in Duplicate STATE OF ALASKA OIL AND GAS CONSERVATION COMMITTEE SUNDRY NOTICES AND REPORTS ON WELLS (Do not use this form for proposals to drill or to deepen Use "APPLICATION FOR PERMIT--" for such proposals.) WELL L-J OTHER ?_ NAME OF OPERATOR Atlantic Richfield Company ADDRESS OF OPERATOR P. O. Box 360, Anchorage, Alaska 99510 4, LOCATION OF WELL At surface 2606' FSL & 2492' FEL of Section 26, T10N, R13W, SM 13. ELEVATIONS (Show whether DF, RT, GR, etc.) 14. CheCk Appropriate Box To Indicate Nature of Notice, Re 5. APl NUMERICAL CODE 50-133-20172-01 6. LEASE DESIGNATION AND SERIAL NO. ADL-18776 7. IF INDIAN, ALLOTTEE OR TRIBE NAME 8. UNIT, FARM OR LEASE NAME North Trading Bay Unit 9. WELL NO. S-2 1~) 10. FIELD AND POOL, OR WILDCAT Trading Bay Unit,G & Hemlock NE Po( 11. SEC., T., R., M., (BOTTOM HOLE OBJECTIVE) Sec. 34, T10N, R13W, SM 12. PERMIT NO. 74-24 3orr, or Other Data NOTICE OF INTENTION TO: TEST WATER SHUT-OFF ~ PULL OR ALTER CASING FRACTURE TREAT MULTIPLE COMPLETE SHOOT OR ACIDIZE ABANDON* REPAIR WELL CHANGE PLANS (Other) SUBSEQUENT REPORT OF: WATER SHUT-OFF ~ REPAIRING WELL FRACTURE TREATMENT A'LTERING CASING SHOOTING OR ACIDIZING ABANDONMENT* (Other) Reperforate and Perforate (NOTE: Report results of multiple completion on Well Completion or Recompletion Report and Log form.) 15. DESCRIBE PROPOSED OR COMPLETED OPERATIONS (Clearly state all pertinent details, and give pertinent dates, including estimated date of starting any proposed work, SEE ATTACHED SHEET 16. I hereby certify that the foregoing Is true and correct (T his space fo:' ~atT~flc/)e use,' APPROVED BY CONDITIONS OF APPROVAL, IF ANY; T IT LE DATE See Instructions On Reverse Side WELL S-2RD 6/14/75 COMMENCED OPERATIONS Rig-up GO International to perforate. Perforated the following intervals under drawdown conditions using GO International 2-3/8" carrier gun. Tagged bottom at 11,226' MD. Zone From To Shots Per Foot Ft. of Perforations G-2 10,564' MD 10,584' MD 2 20' H-i* 10,794' MD 10,814' MD 4 20' H-3L 11,078' MD 11,098' MD 2 20' H-4 11,125' MD 11,145' MD 2 20' * New Perforations. The procedure for perforating each interval was as follows: 1. Pressure test lubricator to 2700#. 2. SI tubing and casing and RIH. 3, Put well on production rate estimated to give 600-800 psi drawdown. 4. Perforate and produce well 10 minutes to clean-up perforations. 5. SI tubing and casing and POH. 6. After perforating a bench, test to evaluate results. 6/20/75 RETURNED WELL TO PRODUCTION D. F. Scheve 8/6/75 DFS/de 22 SUPERIOR TEXACO SU~ER/OR TEXACO iAOL-,7597' I 27 I I I I SUPEBIOR ~'EXACO TS-5-/~- / + TEXACO / '~ T B. S/-/ / [I ;?4 KB TS 22~ TO 104 TVO 9104 I I / ] /"/ / / / / '~~Ill/ TS-Te.. '~'' '" ,,/'', //34 . 1 . I I I I I I I I / i/ / /, ?_3 SUPER/OR TEXACZ~ T. ION. RI3W - ~ ..... U~ION-- -T. 9 N R 13W. ...... ~RA THOA/ ADL-18731 3 $-4 TO 10770 TVD 10352 I / ' 'i'D 1054~ / I TVD,O,26 TS-9 TO i0387 TVD S-I-ROI TD 11050 TYD 10lB8 TS-I ! TD :C529 T VD lOC 7 ~ ~ ~9~2~ / TD 1i655 TS-J RD i - 9606 i0250 ~ ~-2 / TVDlO094 // T D i097~ / T~U ID 11353 ~D 10128 I I /-- I TVOlOII3 } . . : / T~1562 ~ ~ ~ / TVD~O~5~ iI .x -9808 TO 12717 TVD 10066 NORTH ARCo El .5 KB ,r~_ 8 S -/ I '-El 57KB f~ I ! t' I i ! ,tI II 35 TRADING B~Y UNIT UA/7ON~ ............ MARATHON ADL- 17596 LEGEND · Co/T~j311tl.~ Od Will 0 Locot,en ABANDONED EXHIBIT T (TO ACCOMPANY ~TH_._. SEMIANNUAL PROGRESS REPORT) PRESSURE MAINTENANCE PROJECT JANUARY I~ 1975 ADL-35431 j I I i I I I I I I ! I I I I I I I I ! ADL-18776 J I I I I I I I I I I I I I I I I I I I REVISIONS ,. l D,g JE~ol. Jchk Al:J_- 175~ ! 1 ! I I I I ! ! I I ! UN/ON ADL-17596 U/V/GW MA/~A~ ADL- 17596 AtlanticRichfieldCompany 0 Alosko District NORTH TRADING BAY UN IT TRADING BAY FIELD, NORTHEAST OIL POOL Cook Inlet, Alasko STRUCTURE MAP TOP HEMLOCK PRODUCING INTERVAL INTERPRETED BY: GEOLOGICAL SUB COMMITTEE C.I. = I00' S0431e: I" = I000' Distribution: UNIT MEMBERS Dote C4:h~; 9-Z2~69 File No. lO-D- 5 _ EXHIBIT II (To Accompany Eighth Semi-Annual Progress Report) PRESSURE MAINTENANCE PROJECT "G" AND HEMLOCK NORTHEAST OIL POOLS NORTH TRADING BAY UNIT SUMMARY TABLE 7-1-75 Dates Date of first oil production Date of first water injection (start of project) September, 1968 February 9, 1972 Production and In~ection Rates Average oil producing rate--first half of 1975, STBD Average water producing rate--first half of 1975, BD Average water injection rate--first half of 1975, BD Average oil producing rate--June, 1975, STBD Average oil producing rate--June, 1975, RBD @ 3350 psig Average water producing rate--June, 1975, BD Average water injection rate--June, 1975, BD 4,692 6,278 16,075 3,999 4,733 7,244 20,310 Number of Wells Completed in "G" and Hemlock Producing, July 1, 1975 Injecting, July 1, 1975 Shut-In, July 1, 1975 Cumulative Production and Injection Cumulative oil produced since first production, STB Cumulative oil produced since project started, STB Cumulative oil produced since project started, RB @ 3350 psig Cumulative free gas produced since first production, RB Cumulative water produced since first production, B Cumulative water produced since project started, B Cumulative water injected since project started, B 17,340,874 7,347,365 8,691,933 0 9,808,549 7,849,698 12,124,501 Pressure at 9800' Subsea Estimated initial average reservoir pressure, psig Estimated current average reservoir pressure, psig Bubble point pressure, psig 4,470 3,350 1,780 t-- 4OOO LU W 0 0 .J w 10001 EXHIBIT TIT NORTH TRADING BAY UNIT AREA WELL STATIC PRESSURES versus CUMULATIVE OIL PRODUCTION (1"0 ACCOMPANY 7TH SEMIANNUAL PROGRESS REPORT) PRESSURE MAINTENANCE PROJECT "G" AND HEMLOCK NORTHEAST OIL POOLS Injecting Well .. , · . 5 6 ? e 9 I0 ii cUMULATIVE OIL PRODUCTION.- MILLION -STOCK 12 TANK I$ 14 BARRELS p~o ~ of 2 i-:XIIT P. I T ~V : :f (To Accompany SvventhSemi-Annua] Progress Report) PRESSURE MAiNTEN'ANCE PROJECT 'FIe%DiNG BAY FIEIJ)'-"G" AND tlI'.'MIDCK NORTIiEAS'£ OIL POOLS--NORTII TP~DING BAY UNIT AREA HISTORICAL PRODUCTION AND INJECTION DATA Gi I Pr.qduct ion Waier Product ion Gas-Oil Monthly Cumnl at iv'~'2 Rate1 Monthly Cumulat iv~2 Ratio £T;: STB B?i PD BW BW SCF/STB Water Injection Est imated R~$'eI Monthly Cumulat lye2 Reservoir BW PD BW BW Pre s su re 3 __ps I G Non-unit ized ope?at ions £eptembor, 1~$8 to i9-58 $,~pt. 95 2,857 2,857 Oct. 522 16,500 19,357 Nov. 1.715 51,462 70,819 [~:c. 3,673 I13,867 184,686 Jan. 2, ,~2~1! 1:-;. ,620 F~:b. 7,7o.5 215,757 Ma r. ] O, ,132 222. 395 Apr. 12,891 296,719 M.y I2 ,-1:;5 ,i16,4a:4 ~une 12,,I0! 372,024 July i O, f. 26 326 ,6i5 Aug. 12,0:~1 ,105, ;t99 Sc, pt . 13,3~g .I0~ ,g27 Oc !.. 12,92g .132, t)TG $~v. 15,2ot 459,032 l~:c. 1-t. 5nO451,9.45 303 519 8,t2 458 1,229 !77 i,(;,15 ~;(;5 · 2,017.699 2,344 314 2,7,19 813 3,151 440 3,5g3 516 4,042 548 ! 9'7 G Jan. !3,~590 ,.~2-$, 2¢~ .l, 91-u., 929 Feb. 12.479 3'!9,-I!0 5,26a,339 .'-Jrt r. 9,90! 2i~5,9!9 .5,575,258 Apr. 0,2,15 277,357 5,g52,615 May 9,185 284,7'10 6,137,355 ju~;e a, I~; 2.13, !73 6,380,528 .July ~,222 25,1,870 6,635,298 Au~:. v,, 134 221,163 6,S56 ,561 S,:pt .6 ,g ~7 19a,20.I 7.054,7~5 Oct . 7~i i! 221 ,384 7,276,149 Nov. 8.15i 2'I,1.5i9 7,520,668 ~-c. 7,71~7 23a.905 7,759,573 971 july 1, 1971 0 0 15 480 76 2,280 ' 86 2,657 87 2 709 ~20 3 367 3:;2 IO :'.02 4:13 13 291 738 22 :<45 2,057 61 723 I, 5()5 46 650 608 18 ~41 6O6 18. 182 5:)5 15~ 646 677 20,309 72O 22,328 887 27,489 1 502 42,056 2 106 65,290 1 729 51, ,s61 ] 998 6 1,932 2 O0-i 60,119 1 513 46,908 937 29,060 1,372 4~, 169 1,i6'I 36,095 !, ,13-t43,027 I, 560 48,359 Jan. 7,O26 5:17.795 7,977,3.58 1,269 39,350 F.:b. 6,692 !k;7,370 .q, !6.1,738 _,~ 5~4.49-, 391 M::r. 6 ,.t57200,165 8,26.1,903 1,756 54,4'1-1 Apr. 6,527 !95,810 8,560,713 2,012 60,350 May 6,252 193,827 8,754,540 1,787 55, dO1 june 5,139 15.1,758 g,9OO,298 1,811 54,325 Unltiz!;d cft~ctiv(: July 1, 1971--North Trading Bay Unit 1972 J,~ly .1,921 152,561 9,061,859 4,832 149,781 Aua. 4,3a7 136,009 9,197,868 4,163 129,058 Sopt , 4,M76 !.16 ,29! 9,344,159 3,213 ~,404 Oct. 4,997 !54,901 9, ,t99, Cff;G 3,70i 11,t,725 Nov. 5 ,,)-I! 151,223 9,6S0,2a3 3,364 100, ~31 D,,<.:. ,I, ,l~; 9 13~,538 9,7g~,821 3,,i80 107,870 Jan. 5,129 !58,987 9,qq7.;~O8 3,451 106,980 Fijb. 5,252 152,30.1 !O,IOo,i!Z 3,68-t 1(~ ,832 Mar. ;;,2!8 ! 92 ,Tf, o 10,292,g62 2.228 103,.165 Apr. s,2t;7 22,! ,Oil 10,543,873 2,5~ 107,890 M:~7 ~},ql'l279,'1'1l I0,8g3,31'1 3,659 ].13,'~'*~.- June 8, -128252,838 11,076,152 ,I ,_9-t~,, 127,294 0 480 2,760 5,417 8,126 11 493 21 . 796 35 087 57 , 952 119 675 166 325 185,166 203 348 218 994 239 303 261 631 289 120 331 176 396 466 4.'hS 327 510 259 570 378 617 286 6.16 346 687 515 '723 610 766 637 814 996 854,346 896,737 951,181 1,011,53I 1,066,932 1,121,257 252 - - 241 T - 245 - - 248 - - 282 - - 325 - - 288 - - 341 - - 268 - - 270 - - 274 - - .. 263 - - 261 - - 256 - - 251 - - 254 -. - 248 - - 259 - - 256 - 235 - - 243 - - 235 210 - - 181 - - 191 - 173 - - 178 - - 192 - - 191 - - ~ - 200 - - 203 - 179 192 - - 183 - - 1,271,038 223 - - 1,400,096 243 - - 1,496,500 259 - - 1,611,225 240 - - 1,712,156 228 - - 1,820,026 225 - - 1,927,006 226 - - 2,033,838 223 5,574 161,6,17 2,137,303 259 7,644 236,953 2,245,193 243 10,830 324,912 2,358,622 264 9,178 284,516 2,485,916 265 9,159 274,769 2 Camulat!w- vo!t;m~: aL ~:2d Of month, 3 At .9,HtjO fi:ct ~ub:~*,a from prorisurt,-Cumulativo Oil Production plot. 4,470 - 4,320 3,870 3,320 2,980 2,750 2,620 o 550 2,49O 2,430 2,380 2,32O 2,300 Numbor of WoI ls ('ompleiod Producing Injecl lng S.hu~ -In 7 - 7 - 1 8 - 0 10 - 0 10 - 0 9 - 1 9 - 1 9 - ! 9 - 1 9 - 8 '2 7 - 3 8 - 2 8 - 2 7 - 3 S - 2 9 - l 0 - 0 9 1 9 - 1 9 - 1 9 - 1 9 - 9 - 9 - 1 8 - 2 9 - 1 8 - 2 8 - 2 - Il - - 161,647 8 2 1 398,600 2,300 9 2 1 723,512 8 3 1 1,008,028 8 3 I 1,282,797 2~700 8 3 1 EXHIBIT IV (To Accompany Seventh Semi-Annual Progress Report) PRESSURE ~I~ENANCE PROJECT . TRADING BAY FIELD--"G" ~D HEMLOCK NORTHEAST OIL POOLS--NORTH TRADING BAY UNIT AREA HISTORICAL PRODUCTION AND INJECTION IltTA Page 2 of 2 Year Month Oil Production Rate1 Monthly C~mulative2 BOPD STB STB 1972 1973 1974 1975 July 7,674 237,887 Aug. 7,646 237,026 Sept. 7,073 212,203 Oct. 6,529 202,397 Nov. 6,078 182,350 Dec. 6,236 193,325 Jan. 6,463 200,360 Feb. 6,015 168,409 Mar. 5,417 167,917 Apr. 5,396 161,888 May 5,166 160,156 June 4,532 135,964 July 5,890 182,580 Aug. 5,640 174,849 Sept. 5,650 169,512 Oct. 5,484 170,004 Nov. 5,402 162,070 Dec. 5,438 168,592 11,314,039 11,551,065 11,763,268 11,965,665 12,148,015 12,341,340 12,541,700 12,710,109 12,878,026 13,039,914 13,200,070 13,336,034 !3,518,614 13,693,463 13,862,975 14,032,979 14,195,U49 14,363,641 Water Product ion Gas-Oil Water Injection Estimated RateI Monthly Cumulative2 Ratio Rate.t Monthly Cumulative2 Reservoir BWPD BW BW SCF/STB BV~PD BW BW Pre s sure 3---PS I G 4,177 129,499 2,615,415 253 7,869 243,924 1,526,721 4,663 144,549 2,759,964 252 7,726 239,516 1,766,237 4,7~8 142,447 2,902,411 245 8,212 246,360 2,012,597 4,698 145,638 3,048,049 243 9,102 282,163 2,294,760 4,806 144,187 3,192,236 229 11,592 347,749 2,642,509 6,797 210,717 3,402,953 263 11,813 366,206 3,008,715 7,179 222,556 3,625,509 297 11,107 344,315 3,353,030 6,592 184,5e3 3,810,092 284 5,845 163,651 3,516,681 6,471 200,627 4,010,719 290 8,700 269,709 3,786,390 5,691 170,741 4,181,460 287 12,736 382,069 4,168,459 6,334 196,351 4,377,811 276 6,825 211,587 4,380,046 6,571 197,122 4,574,933 294 2,956 ~,675 4,468,721 7,879 244,234 4,819,167 307 8,564 255,494 4,734,215 6,589 204,265 5,023,432 311 5,562 172,418 4,906,633 7,053 211,589 5,235,021 297 8,354 250,615 5,157,248 7,024 217,745 5,452,766 287 10,552 327,116 5,484,364 7,200 215,992 5,668,758 283 9,627 288,816 5,773,180 7,236 224,303 5,893,061 274 9,912 307,266 6,080,446 Jan. 5,481 169,900 14,533,541 7,276 225,548 6,118,609 275 9,661 299,481 Feb. 5,342 149,574 14,683,115 6,704 187,708 6,306,317 276 9,428 263,985 Mar. 5,212 161,570 14,844,685 7,172 222,326 6,528,643 298 9,259 .287,036 Aor. 4,963 148,895 14,993,580 6,554 196,622 6,725,265 282 9,035 234,912 May 4,936 153,005 15,146,585 7,036 218,129 6,943,394 281 9,117 282,641 J~ne 6,083 182,482 15,329,067 7,067 212,057 7,155,451 266 9,019 270,573 July 6,281 194,713 15,523,780 8,533-264,510 7,419,961 273 8,933 276,917 Aug. 7,396 229,285 15,753,065 8,810 273,119 7,693,080 268 8,983 278,466 Sept. 6,498 194,934 15,947,999 8,632 258,967 .7,952,047 281 9,264 277,924 Oct. 6,236 193,325 16,141,324 8,901 275,926 8,227,973 286 8,619 ..267,177 Nov. 6,035 181,053 16,322,377 7,978 239,328 - 8,467,301 296 5,655 169,656 Dec. 5,445 168,794 16,491,171 6,608 204,863 8,672,164. 321 7,278 225,615 Jan. 5,473 169,672 16,661,143 6,161 191,015 8,863,179 309 16,180 Feb. 5,110 143,070 16,804,213 5,.721 160,193 9,023,372 317 16,829 Mar. 4,618 143,164 16,947,377 6,354 196,991 9,220,363 298 17,452 Apr. 4,530 135,894 17,083,271 5,913 177,396 9,397,759 305 18,287 May 4,440 137,642 17,220,913 6,240 193,458 9,591,217 315 18,989 June 3,999 119,961 17,340,874 7,244 217,332 9,808,549 315 20,310 2950 3050 Number of Wells Comple%ed Producing Injecting Shut-in 8 3 1 8 3 1 8 3 1 9 3 0 8 3 1 8 3 1 8 3 1 8 3 1 3080 8 3 1 8 3 1 8 3 1 3100 8 3 1 8 3 0 8 3 0 3100 8 3 0 8 3 0 8 3 0 3100 8 3 0 6,379,927 6,643,912 6,930,948 3080 7,165,860 7,448,501 7,719,074 3050 7,995,99i ...... 8,274,457 8,552,381 3000 8,819,558 8,989,214 9,214,829 ... 2950 501,587 9,716,416 471,212 10,187,628 226,876 10,414,504 512,039 10,926,543 588,656 11,515,199 609,311 12,124,510 * Well S-5 was completed as both a producer and an injector during December, 1974. 8 3 0 8 3 0 8 3 0 8 3 0 7 3 1 8 3 0 9 3 0 9 3 0 9 3 0 9 3 0 10' 3 0 10' 4· 0 9 4 0 9 4 0 9 4 0 9 4 0 9 4 0 9 4 0 ! Monthly volume divided by n~mber of days in month. 2 Cumulative volume at end of month. 3 At 9,80© feet subsea from Pressure-Cumulative 0il Production plot. 22 20 19 EXHIBIT ~Z~ NORTH TRADING BAY UNIT PRODUCTION AND PRESSURE HISTORY T.O ACCOMPANY 7 TH_ SEMIANNUAL PROGRESS REPORT) PRESSURE MAINTENANCE PROJECT "G" AND HEMLOCK NORTHEAST OIL POOLS ............ I ' ' ' ' ' i ,~ OIL .PRODUCTI. _ lO 9 I .,, · l, . , : I 1. --5000 4000 3000 200O I000 P~SSUR~ ~,F~IL~I~NANC~ PROJEC[ TPU~ING BAY FIELD "G" AND Hi?,[qLOCK NORTUE~.£T OIL POOLS NORYH TI~-IDING ~ ' B.A~ U~IT 'ID JULY !, 1973 CONSER~(aTION OIhDER NO. 108 PREPARE. t) BY L. D. S!.\~':",E'f/R. INTRODUCTION This fourth semia~mual progress report el-' -+= ' ' ~ ~ . ~,, ~r ~n~ection p~ ~,s~ure ~aintenca~ce project operations and results for hhe "frading Bay :G' ~I] anti ~,d. ock N~ oil pools of the North Trading Bay Unit is sub~izted to the State of Aiask~ Oil and Gas Conse~ation Co~nittee in compliance with Conservation Order No. 108, Rule No. 1. PERIOD The period covered by this report is from Jsmuary 1, ]._~q7S, to July 1, 1973. PROJECT OPERATIONS ~Dri 1 ling There were no drilling operations at North Trading Bay U;'~J~ during tJ~e period covered by this report. Well Conversions There were no well. conversions to wa'ret injection service during the period cove. red by this report. Wet1 Work ~d Workovers Five produci~.~g well jobs ~.~ere condu, c~ced during ~.,.~ .... period covered by d~is report. A throUgh-tubing bridge plug was set above the Hemlock zone i.n ~.~ell S-1 on April25 to April29, 1973, in a~ ~successful a'~:'te~:~]?t t.o sbu't--off water production from this well. ~ke attachdd P-S fo?.'~'~ dated July t?, 1973, su~marizes the work. 7~"o "(7' zone ~..,~t~.¥~.is were '{:hrough-t. uo~g reperforatcd in ~'ell S-3 on i~ay 2~, 1973, in a:~ a. tte:~p~ ~o Jr,'~.prove the - .. oil productivity 'D~e oil production rate '=~", ~mchanged after this well ~-°rk. A description of the work is given on the at~cach P-3 foden dated July 17, 1973. A si~ilar atte~pt to ~m[~rove oil productivity from ~ell S-5 b~ throu~h-tubin~ ~ ~ ~ ~~ ~ ~. ~ ~p~o~~ co~enced 5-25-73. A "G" ~zone bench in ~e well was reperforated. ~ring the subsequent nm in ~e ~.~ell for additional, reperforation work, the g~ bec~e stuck in the tubing. After ~uccessfu! tries '~o fish ~che ~ (causing restricted production from ~e ~ell)~ a workover c0m~enced on J~me 26, 1973, to pull the tubing and remove the perforating ~ from the wellbore. ]~e ~ w~ retrieved, the wellbore Hemlo~ zone intem~als were reperforated clewed ou~, ~d selective "G" and ~ wi~ casing ~ns. This work resulted'in restoring ~e lost producing rate . in ~e well. ~e through-aub~no reperforation work ~d the s~sequent workover on well S-S are s~mmarized in ~-~e attached P-5 foden 'dated July 17, 1973. A routine workover '~o replace the electric submersible pumping equipment a~d reperforate selective "G" and Hemlock zone intervals in well S-TRD was performed Jhne 9 to J~.m~e 21, 1973. 1]~is workover was successful in restoring and improving the oil productivity in the ~.~ell. The attad~ed P-3 fo~m~ dated July 17, 1973, s~r~marizes tJ~e ~vorkover. A sJmLilar workover t° replace the electric submersible pmn~p'm~d reperforate selective "G" and . Hemlock zone intervals in ~.~ell TS-3RD occurred Ju~e 23 to June 26,. 1973. ~I]~is workoyer, as outlined in. the attached P-3 fo~m~ was successful in restor- ing the'0il productivity in the well. Injection Facilities 'I]~e ~'ater injection system on Platfo~n Spark has been.satisfactorily supply- lng deoxygen, ated, filtered, Cook Inlet ~val~er for injection into wells S-4, TS-8, a~d TS-9 at well surface injection pressures of about 3000 psi ~:md in vol~es a.s dictated by ~e indivi~]ual well water receptivities. Platfo~ S~?ark basic po¥~er turb~.:~e p{~oblems ]~ave resulted in less than capacity water injection rates at ~fI'SU during t}~e report period.' On July I, 1973, ~ere ;.;ere seven ~.;e].ls producing at 'd~e North Trading Bay Unit (S-l, S-3, S-7I-I!!, S-8, TS-i, TS-3Pd), and TS-6). Well S-5 was being worked over and was shut-in. Well S-2 was Mint-in because of its vet7~ low oil producing rate capability. The water injection system on Platform Spark was shut-in due to tJ'~e u.n. availM~i!i~y of sufficient po~ver t° run ~he injection p~.ps. This lack of power resulted from. a .turbine failure that is presently render repair. Ex]~ibit I, ast. ructure map .of 'the North Trading Bay' Unit area dra~ on the top of tJ~e Hemlock inte~al, shows ~d~e location of all of the unit wells. RESULTS Production a~d Injection On Ju].y 1, 1973, cumulative wa%er injection was 4,468,721 barrels, cmm~lative oil production ~ 13,336,034 STB, m~d c~I~ulative water .production ~as 4,574,933 barrels. During J~ue, 1973, reservoir withdrm~als (11,926 RBD)' exceeded ~vater injection (2,956 BD) by 8,970 RBD. This excess of reservoir ~ithdra~als .over reservoir injection does not accoua~t for the effect of aquifer inf.lux into the North Trading Bay Unit oil reservoir. In addition, the avei~age injection rate for 'June was abnormally low due to turbine repair work. This caused a tempora~D~ shutdo~'n of the injection system due to a laM~ of po~ver availability. ~]~e attad~ed Exhibit II (a s~r~ma~ table of the pressure maintenm~ce project), Exhibit IV (a sun~m~.ary 'table of historical production m~d injection data), m~d Exhibit V (a produc'tion rate a]~d rese~woir pressure plot) su]':imarize pertinent North Trading Bay Unit area production injection data. Resenroir ! The average reser~oir pressure has ap.~az',~n~-],i' .e.~lned essentially constcmt dur~ns the report period at about~u~n'~ psi (gg00' SS). Water voltm~es injected into rJ~e rese~n;oir through S-4, TS-8~ m~d TS-9 together with ;.:ater encroachment volt~nes from e~m~sion of the aquifer have exceeded the total reservoir f~tu:~d~ ' vol~.~3withdrawn s~nce' the co,:~.,~n~e~,,un~~.-,'.~, ~ -~ -~ - of water injection. During Jtme, 1973, the average reservoir pressure was estJm~.ated to be approximately 3100 psi (at a datum of 9800' SS), about 50 psi higher thsm was estimated fer January,, 1973, and 1320 psi above the bubble point pressure of the crude oil. ~]ze attached ExJ~ibit II, Exhibit III (a plot of well. static '" pressures versus cumulative oil production), Exhibit IV, m.~d ExJ'tibit V show pertinent average reservoir pressure data for tJte North Trading'Bay Unit area.. The attached P-12 ±'ozmts hereby submitted to the State of Alaska, Division of Oil ~d Gas~ show individual well static pressure, data collected during the report period in producing wells S-l, S-2, S-?RD, and TS-3RD. BStimations of the average reservoir pressure at the North Trading' Bay b~tit are complicated by'the layere'd nature of the resez~mir. R. Iden/ L. D. Sweet P~I/LDS/sr Attachments FILE INVENTORY FOP, C. O. 108 EXH EXH EXH EXH EXH EXH EXH EXH EXH EXH EXH EXH EXH BTA BTB BTC BTD BTE BTF BTG BT H BT I BTJ BTK BIT L BIT M Application with exhibits I through IV. Geological Structure MaD top of Hemlock producing interval Geological Structure Map top of '~G" producing interval Electric log Correlation section Net pay isocore "G" pool Net pay isocore Hem lock pool Relative oil and gas permeability curves Relative oil and water permeabilities Oi I formation volume factor Change in solution gas oil ratio Well static pressures versus field commulative oil production Schematic Completion PROCEEDINGS MR. BURRELL: Good morning, ladies and gentlemen. This is a hearing of the Alaska Oil and Gas Conservation Committee, Conservation File No. 108, Application of Atlantic Richfield Company for a pressure maintenance program on North Trading Bay Unit for the ~'G" and Hemlock NE Oil Pools. This hearing was called by the Alaska Oil and Gas Conservation Committee this date by public notice which was published in the Anchorage Daily News on October 13, 1971. I am Homer Burrell, Chairman of the Alaska Oil and Gas Conservation Committee. To my right is Tom Marshall who is Executive Secretary of the Conservation Committee and Chief Petroleum Geologist of the Division of Oil and Gas. To my left is Mr. O. K. Gilbreth, 3r., who is a member of the Alaska Oil and Gas Conservation Committee and Chief Petroleum Engineer of the Division of Oil and Gas, and to his left is Mr. Lonnie Smith, Petroleum Engineer with the Division of Oil and Gas. I believe that is all the people we have here -- We have Mrs. Keith in the background there, and anybody who has come in, she's from the Division of Oil and Gas, anybody who has come in here and who has not signed in, would they please sign in with her. Mr. Gilbreth advises me we have one mike today, and whoever is talking including myself should speak up as much as possible so we make sure that the mike will pick us all up. Does the applicant have any testimony it wishes to put on? MARK SINGLETARY: Mr. Chairman, with your permission I would like to introduce myself, enter my feelings into this proceeding and make a brief opening statement. I'm Mark Singletary, attorney, during my appearance on behalf of Atlantic Richfield Company who is the applicant in this proceeding. Our presentation in support of the application will consist primarily of the testimony of Mr. Iden and Mr. Rogers, and subject to your accepting their qualifications as experts, we are ready to proceed. Possibly you would like to have them sworn in at this time and state their qualifications preliminary to their-- MR. BURRELL: Mr. Marshall will handle that -- Thank you, Mr. Singletary. Neither one of the gentlemen have qualified previously? MR. SINGLETARY: No, they have not. Mr. Iden. MR. BURRELL: Mr. Iden, would you state your -- why don't you both state your qualifications, individually. That mike is dead -- this is the only live one out in center, so you can sit over there. These are the City Council mikes and I have been unofficially advised they are hooked directly into KENI, so we will avoid that. Mr. Iden, will you state your qualifications, sir? MR, IDEN: I am a Senior Analytical and Operations Engineer for the South Alaska District, Western Region, North American Producing. Division of Atlantic Richfield Company. I attended the Royal School of Mines of the University of London, England, and received a Bachelor of Science degree, First Class Honors, in Oil Technology in June, 1963. In March, 1965, I graduated with a Masters of Science degree in Petroleum and Natural Gas Engineering from Pennsylvania State University. I have since attended company sponsored schools in petrophysics, reservoir engineering, statistics and reservoir modeling. I am a member of the Society of Petroleum Engineers of the A.I.M.E. and an Associate of the Royal School of Mines, London, England. -2- I have six and one-half years of engineering and geologic ex~erience in the oil industry of which five years have been with Shell Oil Company and one and one-half years with Atlantic Richfield Company. From May, 1965, to April, 1966, I worked in exploration well evaluation in California, Oregon, and Washington. From April, 1966, to December, 1969, I worked in Alaska primarily with the primary and secondary development of the Middle Ground Shoal Field. From December, 1969, to June, 1970, I worked in secondary recovery, at Ventura, California. Since Joining Atlantic Richfield Company in June, 1970, I have worked in Alaska in secondary recovery engineering for the Swanson River Field, the Middle Ground Shoal Field, and the Trading Bay Field, "G" and Hemlock Northeast Oil Pools. MR. BURRELL: Mr. Iden, would you be so kind as to spell your full name for the record because we've got to type this up. It makes it much easier for the girls. MR. IDEN: First name Robert, R O B E R T, Iden, I D E N, and I have no middle name or initial. MR. BURRELL: Thank you very much Mr. Iden. Without objection from the committee, your qualifications will be accepted as an expert witness. Mr. Rogers? MR. ROGERS: I am John F. Rogers. I am a Senior Geologist for the South Alaska District, Western Region, North American Producing Division of Atlantic Richfield Company. I attended the University of Tulsa and received a Bachelor of Science degree in geology in June, 1952. I have since taken various graduate or advanced courses in geology and related subjects at the University of Tulsa and the University of Alaska. I am a member of the American Association of Petroleum Geologists and the Alaska Geological Society. -3- I have been employed since 1952 by Atlantic Richfield Company as a Research Geologist in Tulsa, Oklahoma prior to August, 1969, and since that date as a Senior Geologist in the Sou~h Alaska District. During this time, my assignments have included projects in the Cook Inlet and Gulf of Alaska provinces. MR. BURRELL: Thank you, Mr. Rogers. Without any objections from the committee, your qualifications will be accepted as an expert witness. Mr. Marshall, will you swear both witnesses in? MR. MARSHALL: Will you please rise and raise your right hands, please? In the matter now at public hearing, do you swear to tell the truth, the whole truth, and nothing but the truth, so help you, God? MR. IDEN: I do. MR. ROGERS: I do. MR. MARSHALL: You may be seated. Thank you. MR. BURRELL: We're ready to proceed, Mr. Singletary. MR. SINGLETAR¥: Mr. Iden, will you lead off? MR. IDEN: The introduction, the "G" and Hemlock Northeast Oil Pools in the North Trading Bay Unit have reached the stage where development employing the best conservation and engineering practices to maximize the ultimate oil recovery cannot move forward without the application of the proposed water injection pressure maintenance program. The "G" and Hemlock Oil Pools structure of the Trading Bay Field were discovered in June of 1967 by the Atlantic Richfield Company Trading Bay State #1 well, drilled from a jack-up drilling vessel on Atlantic Ridhfield Company Lease ADL 35431. Subsequent development of the structure was from the Texaco-Superior Platform "A", installed in the spring of 1968 to provide for the development of Texaco-Superior Lease ADL 17597, and from the Atlantic -4- Richfield Company Platform Spark, installed in the summer of 1968 to provide for the development of Leases APL 35431 and APL 18776. Development drilling began on Platform "A" in June, 1968, and on Platform Spark in November, 1968. Development drilling has been conducted according to the State of Alaska Oil and Gas Conservation Regulations and according to field rules established by Conservation Order #69 for the Trading Bay Field, dated January 24, 1969. Development drilling ceased on Platform "A" in November, 1969, and on Platform Spark in October, 1969. There are five oil wells completed from Platform "A" and five oil wells completed from Platform Spark in the Trading Bay Field, "G" and Hemlock Northeast Oil Pools. There is one temporarily suspended well drilled from Platform Spark that has not been completed to date. On July 1, 1971, the Commissioner of the Department of Natural Resources of the State of Alaska approved the Unit Agreement for the development and operation of the Hemlock and "G" formation, North Trading Bay Unit area, State of Alaska, as authorized by Alaska Statute 38.05. The Unit Agreement was executed by Atlantic Richfield Company, as operator, and ratified and Joined by Texaco Incorporated and The Superior Oil Company. Currently the daily oil production from the North Trading Bay Unit is approximately 4,900 BOPD from the "G" and Hemlock formations. The cumulative production from the "G" and Hemlock formations and from the area now described by the North Trading Bay Unit, through September, 1971, was approximately 9,300,000 BO. of which the State of Alaska has received a total of one-eighth in value and kind. The prime intent of that certain Unit Agreement was to provide for the further orderly development of the Hemlock and "G" formations of the North Trading Bay Unit area through a water injection pressure maintenance program. -5- The Unit participants agree that a water injection pressure maintenance program must be conducted to maximize the recovery of the resource. In accordance with the provisions of Section 2226 of the State of Alaska Oil and Gas Conservation Regulations, Atlantic Richfield Company, as North Trading Bay Unit Operator, applied for approval of the pressure maintenance program for the "G" and Hemlock Northeast Oil Pools in the North Trading Bay Unit by letter application dated September 24, 1971. I respectfully request that the application for approval of a pressure maintenance program, together with the accompanying Exhibits Roman numerals "I" through "IV", marked in total as Exhibit A, be entered into the record of the hearing, without reading, in the interests of economy of time. MR. BURP, ELL: Without objection, we will enter your applications as Atlantic Richfield Company's Exhibit "A", with exhibits attached thereto Roman numerals "I" through "IV". MR. IDEN: Geologic and engineering testimony in support of the proposed water injection pressure maintenance program in the North Trading Bay Unit for the "G" and Hemlock Northeast Oil Pools will be presented by Mr. J. F. Rogers and by myself. Mr. Rogers will now present the geologic t es timony. MR. BURRELL: Thank you, Mr. Iden. Mr. Rogers? MR. ROGERS: This geologic testimony is presented to support the application for a pressure maintenance program in the North Trading Bay Unit for the "G" and Hemlock Northeast Oil Pools. Exhibit B, on the far left, is a geologic structure map of the top of the Hemlock pruducing interval in North Trading Bay Unit. It shows the fourteen wells drilled int, --6-- this interval and the unit boundary. Exhibit C, to the right, is a geologic structure map of the top of the "G" producing interval in North Trading Bay Unit. It shows the fourteen wells penetrating this interval and the unit boundary. Exhibits B and C show the structure to be a slightly asymmetrical anticline with an axis trending about North 5 degrees East. Dips on the west flank are 20 degrees and 25 degrees West while those on the east flank are 15 and 16 degrees East. The available well data used to produce these maps indicate that the structure is a simple, unfaulted one; the ~'G" and Hemlock producing intervals do not appear to be crossed by any faults. Exhibit D, the log, is the dual induction laterolog of A.R.Co. Trading Bay State No. 1 located on the east flank of the structure. This well penetrated the "G" producing interval between 9,660' (-9,603') and 9,848' (-9,791'). The interval is made up mostly of sandstone with minor conglomerate and siltstone. The well penetrated the Hemlock producing interval between 9,848' (-9,791'), and 10,174' (-10,117'). That interval is made up of conglomerate and sandstone. The proposed water injection pressure maintenance project at the North Trading Bay Unit will affect both the "G" producing and Hemlock intervals as thus identified. Exhibit E is a correlation section showing the logs of all the important wells in this unit. Ail of the logs are marked showing the tops and bottoms of the "G" and Hemlock producing intervals. The correlation section shows that the two producing intervals can be traced throughout the unit and from well to well. Subunits within these intervals made up of beds or groups of beds can likewise be traced from well to well. This provides evidence that the reservoir beds are actually continuous from well to well, and in most cases, continuous throughout the unit. -7- This geologic testimony provides evidence that the geologic structure of North Trading Bay Unit is not faulted through the "G" and Hemlock producing intervals; and that the reservoir beds in question are for the most part continuous throughout the unit. I believe these two factors show that this structure is geologically suited for the establishment of a successful pressure maintenance project. That concludes my testimony. Mr. Iden will now present the Engineering res timony. MR. BURRELL: Thank you, Mr. Rogers. Were Atlantic Richfield Exhibits B, C, D and E prepared under your supervision, sir? MR. ROGERS: No, sir. They were not. I have examined all of the material going into these exhibits and I believe that they represent the true geologic picture as they are shown here, and I wouldn't have changed them had I prepared them myself. MR. BURRELL: You will, then, for the record vouch for their accuracy? MR. ROGERS: Yes, sir. MR. BURP, ELL: Thank you very much, Mr. Rogers. We'll let the record reflect that Exhibits B, C. D and E are accepted. Mr. Iden? MR. IDEN: Engineering testimony, this engineering testimony will support the ., water injection pressure maintenance program proposed for the "G" and Hemlock Northeas! Oil Pools in the North Trading Bay Unit. The testimony will describe the original oil-water contacts in each of the "G" and Hemlock Northeast Oil Pools, the distribution of the pay sand, the reservoir rock and fluid properties, the aquifer properties, the 'past performance of the field, the predicted future performance of the field, and plans to develop the reservoir according to the proposed water injection pressure maintenance program. This testimony will show why pressure maintenance by water injection is expected to recover --8-- additional oil. During the course of my testimony, I will refer to Exhibits identified by A and F through M. These exhibits were prepared either by me or under my supervision. I will also refer to Exhibits B, C and E which have been presented by Mr. John Rogers. Water Oil Contacts: An original, horizontal water-oil contact has been identified for each of the "G~' and Hemlock oil pools. These original water-oil contacts have been identified from an analysis of dual induction laterlogs used in conjunction with either sonic or formation density logs run in the North Trading Bay Unit wells. Based upon these analyses, the original oil productive limits of the field have been selected at a common water-oil contact of 9,700 feet subsea in the "G" pool and 9,900 feet subsea in the Hemlock pool. Exhibit C, the structure map drawn on the top of the "G" oil pool, second map over there, and Exhibit B, the structure map drawn on the top of the Hemlock oil pool, the first exhibit on -- depict these original productive limits of the Trading Bay Field, Northeast Oil Pools. FaY Sand Thickness: Gross well bore sand thicknesses, as they occur in the North Trading Bay Unit wells, are depicted in Exhibit E, a correlation section of the North Trading Bay Unit. Gross well bore sand thicknesses above original oil-water contacts have been corrected to net well bore sand thicknesses by eliminating those intervals that are not believed to produce oil. Net well bore sand thicknesses have thence been corrected to net vertical sand thicknesses. This has been accomplished for each well in the unit and for each of the "G" and Hemlock intervals. Exhibit F, .the first of the two maps, over there, a net pay isochore map of the "G" oil pool, and Exhibit G, the second of the two maps, a net pay isochore map of the Hemlock oil pool, depict these data. The total "G" plus Hemlock oil pools vertical -9- net oil productive sand thickness varies from zero to a maximum of approximately 425 feet as the distance varies from the oil-water contacts towards the crest of the structure. Rock Properties: Core samples in the "G" and Hemlock Pools have been obtained in one North Trading Bay Unit well, the Atlantic Richfield Company Trading Bay State #1 well. Seventy-three and one-half feet of core were recovered in this well, predominantly from the "Gr' pool formation, and fourteen sidewall samples were recovered. Rock matrix densities obtained from analyses' of the core samples have been used to assist in the calibration of the formation density log. Core analysis data have not been used otherwise in the determination of rock properties of porosity, connate water saturation, and effective perme- ability. Poros£ty_: Porosity values for the "G" and Hemlock oil pools have been derived from the formation density log, or where this log has not been available, from the sonic log using a porosity crossplot of density-log-porosity versus sonic-log-porosity determined elsewhere in the North Trading Bay Unit "G" and Hemlock Oil Pools. A foot by foot analysis of the "G" and Hemlock pay intervals in the wells has been made and average well porosities obtained. Average well porosities thus determined range from 9.6 percent to 12.8 percent and the field average porosity in the total oil productive volume is approximately 11.5 percent. Porosities of the oil productive volume are indicated to decrease towards the flanks of the structure. Water Saturation: Connate water saturation values for the "G" and Hemlock oil pools have been derived from dual induction laterologs obtained in the unit wells. The field average connate water saturation of the total oil productive volume is estimated to be approximately 44 percent. -10- Permeability.: Effective oil permeabilities have been calculated for several of the North Trading Bay Unit wells from pressure surveys. Values thus obtained for the combined "G" and Hemlock intervals range from 5 md. to 25 md. A realistic field average is believed to be approximately 15 md. Permeabilities are believed to decrease toward the flanks of the structure. The permeability variation of the combined "G" and Hemlock intervals, a measure of the degree of permeability stratification, is believed to be approximately 0.65. This value is based upon analysis of core data obtained in well Trading Bay State #1 and by analogy with other producing fields in the Cook Inlet Basin. This permeability variation value is indicative of a moderately severe stratifica- tion and, consequently, moderate water injection profile control measures may be necessary during the proposed water injection pressure maintenance program. Relative Permeability_P_at_~a: Exhibit H illustrates the oil and gas relative permeability curves which have been selected to represent the average conditions for the combined "G" and Hemlock producing interval. These curves were obtained from the laboratory analysis of core material from the Trading Bay State #1 well. As illustrated by these curves, an increase in the gas saturation from zero to 10 percent of a hydrocarbon pore volume results in approximately a three-fold decrease in the oil relative permeability. A free gas saturation will not be established throughout the reservoir until the reservoir pressure drops below 1780 psig, which is the bubble point pressure° The current reservoir pressure is estimated to be 2300 psig at 9800' ss. Exhibit I (i) illustrates oil and water "pseudo" relative permeability curves which have been calculated to represent 3-dimensional behavior in the reservoir model of the combined "G" and Hemlock producing interval under a water injection -11- program. These curves were calculated based upon the assumption that a piston-like water-oil displacement process would occur in each of a large number of individual strata, the total of these strata representing the "G" and Hemlock producing interval with a permeability variation of 0.65. As illustrated by the curves, the residual oil saturation is believed to be 18 percent. At this residual oil saturation, the pseudo relative permeability to water is expected to be four tenths of the pseudo relative permeability to oil at connate water saturation. For the expected water viscosity of approximately 0.4 cp. and oil viscosity of approximately 0.9 cp., this represents an effective water-oil mobility ratio of 0.9. This is a favorable water-oil mobility ratio for a good sweep efficiency. Pore Volume Compressibility: A reasonable estimate of the pore volume compressibility of the "G" and Hemlock intervals is believed to be 4.0 X -6 10' vol/vol/psi. Fluid Propertie_p.s: The reservoir fluid properties used to represent the total "G" and Hemlock interval hydrocarbons were determined from 'analyses of recombined fluid samples obtained at the surface separator from the Hemlock zone of the Texaco-Superior No. 1 well. Analysis of "G" zone recombined separator hydrocarbon samples from the same well show very similar reservoir fluid compositions and properties. Hemlock zone fluid samples were physically recombined to a producing gas-liquid ratio of 246 cubic feet of separator gas at 14.696 psis and 60 degrees F. per barrel of separator liquid at 64 psig and 60 degrees F. The saturation or bubble point pressure of the reservoir fluid was measured to be 1,780 psig at 180 degrees F. The average reservoir temperature is 180 degrees F. at a subsea depth of 9,800 feet, which has been established as the field datum depth. -12- Exhibit J illustrates the oil formation volume factor and the reservoir oil viscosity as a function of reservoir pressure. The pressure in the reservoir at the time of discovery has been estimated at 4,470 psig at 9,800 feet subsea. The oil formation volume factor at that pressure was 1.291 reservoir barrels per residual barrel. As illustrated, the oil formation volume factor increases to a value of 1.323 at the bubble point pressure of 1,780 psig. This small increase in the oil formation volume factor as the pressure is decreased 2,690 pounds to the bubble point pressure indicates -6 a low oil compressibility that has been measured to be 8.36 X 10 vol/vol/psi at the initial reservoir pressure. The connate water compressibility in the "G" and Hemlock formations at the initial reservoir pressure is estimated to -6 be 3.5 X 10 vol/vol/psi. The oil viscosity, as illustrated by the exhibit, decreases from 1.035 cp. at the initial reservoir pressure to 0.858 at the bubble point pressure. Exhibit K illustrates the change in the solution gas-oil ratio as the reservoir pressure declines below the bubble point pressure. Above the bubble point pressure, the solution gas-oil ratio remains constant at 427 standard cubic feet per barrel of residual oil. This iow solution gas-oil ratio above the bubble point pressure accounts for the iow compressibility of the reservoir fluid. As a result of the water injection pressure maintenance program proposed for the "G" and Hemlock oil pools, it is not anticipated that the reservoir pressure will be permitted to decline below the bubble point pressure. In summary, the reservoir fluid properties of the "G" and Hemlock Northeast Oil Pools describe a highly undersaturated oil reservoir with a limited amount of energy available to sustain the producing capacity of the reservoir through reservoir fluid expansion. -13- Aquifer Properties: The primary oil production of approximately 9,300,000 STB realized from the field to the end of September, 1971, has been achieved through not only oil reservoir rock and fluid expansion, but also through aquifer rock and fluid expansion. Materials balance calculations have been made both by hand and by computer in an attempt to define the properties of the aquifer. Based upon these calculations, it is believed that the aquifer is limited and fairly small in size, and of low permeability. The size 6 of the aquifer is estimated to be in the order of 1,000 X 10 BW and the permeability of the aquifer is estimated to be in the order of 2-5 md. Primary.. Production Performance: In spite of the presence of a partially active aquifer and peripheral water influx into the oil reservoir, as a result of production from the field to date, the oil reservoir pressure has declined from the initial value of 4,470 psig to the current value estimated at 2,300 psig. Exhibit L, a plot of well reservoir static pressures at the datum of 9,800 fee~ subsea versus cumulative oil production, illustrates the oil reservoir pressure decline as determined from individual well static pressure measurements. As a result of the decline in reservoir pressure, the field production ra~e has declined from a peak rate of 15,300 BOPD and 680 BWPD in November, 1969, to 4,900 BOPD and 3,200 BWPD in September, 1971. Predictions of the future performance of the reservoir under the continued primary producing mechanism have been made both by hand calculations and utilizing sophisticated computer reservoir modeling techniques that include a history match of past well rate and pressure performance information. These studies have shown that the oil reservoir pressure can be expected to continue to decline; and, because producing capacity decreases with pressure, there will be an accompanying decline in the oil production rate. The weak and uncon- trolled aquifer influx will result in a less-than-optimum ultimate recovery. -14- Water In~ectton Pressure Maintenance Performance: Predictions of the future performance of the reservoir under the proposed water injection pressure maintenance program have been made both by hand calculations and by employing sophisticated computer reservoir modeling techniques. These studies have shown that water injection pressure maintenance is needed to maximize the oil to be recovered from the "G" and Hemlock oil pools. The studies have indicated that the injection of 16,000 - 20,000 BWPD into the oil reservoir is both feasible and desirable and that this water injection rate will result in the partial restoration of the reservoir pressure by 750-1000 psi, to a level of approximately 3,050-3,300 psi. It is anticipated that the oil production rate will be increased to a peak water injection response rate of approximately 7,000 BOPD after about nine months of water injection. An increase in the ultimate recovery from the "G" and Hemlock reservoirs of approximately 6,500,000 STBO is expected. There will be an attendant increase in the recovery of solution gas all of which will be beneficially utilized on Platform "A" and Platform Spark. Plans for Water In~ection Pressure Maintenance: With your approval we plan to commence the injection of water into the "G" and Hemlock Northeast Oil Pools at the earliest possible date. Currently it is estimated that injection can commence in mid-to late-November, 1971. The Cook Inlet is the source of water for injection, and the water Will be filtered, treated and injected at a surface injection pressure that is not expected to exceed 3,000 psi. While laboratory tests on core material from the Trading Bay State #1 well have indicated some formation sensitivity to fresh water, it is anticipated that the moderately saline Cook Inlet water can be used for injection as it is in other fields, with a minimum effect on formation permeability. -15- Ultimately it is anticipated that water injection will proceed into four North Trading Bay Unit wells - S-4, TS-8, TS-9 and an additional well currently expected to be selected from S-2 or S-5. Exhibits B and C illustrate the location of the wells selected for water injection. We believe that this flood pattern will provide for both an adequate injection volume and distribution of the injected water. Well S-4, a temporarily suspended well, is scheduled for completion as a water injector at the earliest possible time. Selective cement squeezing may be conducted if necessary in this well to assure isolation of each of the "G" and Hemlock intervals. The casing in the well will be tested to 1,500 psi. The total "G" and Hemlock producing interval will be perforated and the well completed with a single tubing string and two packers, one above the "G'* oil pool and one separating the "G" and Hemlock intervals. Provision will be made within the tubing string to allow for injection rate control into each of the "G" and Hemlock intervals. The casing-tubing annulus will be equipped with a pressure measuring device that will enable the detection of a tubing or packer leak during water injection. The well will be production tested and the reservoir pressure determined in the well prior to the commencement of water injection. The conversions of the three further wells planned for water injection service are currently scheduled to be made during the next three months. Ultimately it is expected that these wells will be recompleted in a manner similar to that proposed for S-4 and as shown on Exhibit M, the schematic S-4 injection well casing, cementing, and completion diagram. Initially the wells may be simply "turned-around" and water injection commenced into the current well completions so that full-scale water injection can be commenced -16- at the earliest possible date. Atlantic Richfield Company, as North Trading Bay Unit Operator, will appropriately notify the Oil and Gas Committee of "Additional Recovery" operations as required by the State of Alaska Oil and Gas Conservation Regulations, Subchapter 6. Appropriate descriptions of the casing and method of testing the casing for the proposed water intake wells S-4, TS-8, and TS-9 and included as a part of Exhibit A. A description of the casing and method of testing the casing in the fourth proposed injection well, will be furnished to the Oil and Gas Committee for their approval prior to its conversion. Following the initiation of the proposed water injection pressure maintenance program, the project performance and individual well injection and production rates will be monitored closely. Downhole injection and production well profile surveys will be run from time to time to determine the need for injection well profile control work and eventually, possible production well profile control work. It is expected that reservoir pressure determinations will be made in the injection wells from time to time as required to assist in the evaluation of the project performance. Studies of the reservoir performance will be continued to determine the need to convert additional wells to water injection or to vary the well spacing in some areas by the drilling of an additional producing or injection well to further improve upon the ultimate field recovery. One such study that indicates the desirability of a crestal producing well to develop the basal Hemlock interval in the field and to further improve upon the ultimate field recovery is currently being finalized. -17- Conclusion: In conclusion, this testimony in support of the proposed water injection pressure maintenance program shows that the proposed program will substantially increase the recovery of oil from the :'G" and Hemlock Northeast Oil Pools in the North Trading Bay Unit. During the course of the proposed pressure maintenance program, there will be strict compliance with all applicable Federal, State, and other applicable laws, regulations, and standards, to protect the environment. As a consequence, we believe that the approval of this pressure maintenance project will be in the best interests of conservation and optimum engineering practices and will benefit the State of Alaska. We therefore respectfully request that you approve this project at the earliest possible time to assure maximum efficient development and to prevent waste of our natural resource. That concludes my testimony; thank you for your consideration. MR. BURP, ELL: Thank you, Mr. Iden. MR. SINGLETARY: Mr. Chairman, at this time we would like to offer into evidence Exhibits "A" through "M" inclusive. MR. BURP, ELL: Thank you very much. Mr. Iden has already testified as to his responsibility to preparation of F, G, H through M. We will accept that into the record. May I ask you a question? Are the copies of these exhibits provided in the packets which you supplied the committee, are they duplicates of those which are on the wall, or the slides? MR. SINGLETARY: Yes, they are. MR. BURRELL: In that case, unless you object, we will accept these as copies which you provide in the packets as the official committee exhibits, and mark them so that you can keep your slides. Does that complete your testimony, then? -18- MR. ROGERS: That concludes our testimony, subject to questions. MR. BURP, ELL: I suggest we take about a fifteen minute break before we go into the examination. BREAK MR. BURP, ELL: We'll reconvene the hearing at this time and ask the witnesses to respond to the questions of the committee. Does any member of the committee have any questions of either Mr. Iden or Mr. Rogers? MR. GILBRETH: Yes, sir, I have a question. MR. BURP, ELL: Mr. Gilb re th ? MR. GILBRETH: Mr. Rogers, on exhibit F near the crest of the -- or the maximum thickness of the net'~...pay,sectton, I notice an abrupt droppin~ off in a northeast southwest direction. Is this because of the stratification factor that Mr. Iden testified to? MR. ROGERS: May I take a look at the exhibit? MR. GILBRETH: Yes, please. I am referring to the contour labelled 100', I believe it is. I'm sorry -- it's 150' -- 125'. MR. IDEN: This map was actually developed by the engineering subcommittee of the unit participants and the stratification variation that I was referring to represents different permeability for different layers of the total section, and this is not shown in this exhibit. This exhibit essentially Just contours the net pay determinations made on the individual wells and the abruptness there is caused by the control points with which the map was drawn. MR. GILBRETH: Then on exhibit G you apparently do not have that type of a situation, then, you have a smooth contour all the way around. MR. IDEN: That' s correct. MR. GILBRETH: Mr. Iden, I believe in your testimony you mentioned that there was moderately severe stratification and that this would probably -19- require some selective downhole injection at some future date. Do you have any idea, at this time, how you will control injection at that time? MR. IDEN: We are providing in the first conversion, the S-4 well, for a downhole choke that would limit injection into the Hemlock interval and a manderal between the two packers that isolate the G interval for the gain -- a choking device could be installed then with which to vary injection into that interval, so we will have injection controlled by those two intervals. MR. GILBRETH: Do you anticipate using a similar type control in most of the wells if it becomes necessary? MR. IDEN: Yes, if it becomes necessary. MR. GILBRETH: I believe your testimony indicated that the saturation pressure is around 780 psig and at the present pressure is about 2300. The present pressure is that based on an arithmetic average? MR. IDEN: This is based upon individual well measurements. These have been plotted off as shown on exhibit L and a reasonable line that would represent the average reservoir pressure has been drawn through those individual points, so these are the control points, from which the average reservoir pressure was estimated. MR. GILBRETH: The 2300, then, would be a figure you would take from the dotted line shown on Exhibit L? MR. IDEN: Right. MR. GILBRETH: With the pressure in the order of 2300 psig and dropping now, did I understand you to say that your plans are to build the pressure back up in the reservoir? MR. IDEN: Yes, that is correct. We expect with an injection of 16,000 - 20,000 barrels per day to increase the reservoir pressure over the -20- level of about 750 to 1,000 pounds, so that would take the pressure up to about 3,050 or 3,300 pounds. MR. GILBRETH: I notice from the data in the exhibit that you submitted that the viscosity increases as the pressure builds up, of course, and the RUF decreases, both of these would indicate that building pressure up might be detrimental to recovery. Do you anticipate lowering the pressure at some time before completion of the reservoir? MR. IDEN: Currently, no. The effect of pressure on the oil-water mobility ratio, I have worked with it for a number of different pressures, and the effect is not too large. I don't think the effect of building the pressure up will be detrimental. MR. GILBRETH: I believe you testified that it is approximately nine- tenths now, is that right? MR. IDEN: That is our current estimate -- MR. GILBRETH: What would it be at the pressure range that you anticipate,,~ going to Just approximately? MR. IDEN: May I refer to -- I believe I had a range on that parameter of .85 to .92, something in that magnitude. MR. GILBRETH: Within the pressure limit? MR. IDEN: Yes. MR. GILBRETH: Alright. I believe you testified that your material balance had indicated an aquifer with a limited effectiveness. Can you give us any idea about what the effectiveness of the aquifer is if it furnished 10% of your energy now, at 50%? MR. IDEN: Yes. Currently, I think the aquifer is furnished probably -21- more like 70% of the total recovery. However, the pressure, as I indicated on the -- exhibit L, has declined, so it has a limited effect. MR. GILBRETH: To the best of your knowledge, is the aquifer active in all directions around the field? Is it a peripheral type driving mechanism? MR. IDEN: The predominant aquifer movement would be indicated to be from the east towards the west along the eastern edge, -- there is also aquifer movement probably in the north and south. MR. GILBRETH: From the injection well that you've indicated you plan to utilize, I don't see anything in the south end of the field with a fairly large area -- quite a bit of net bay shown -- and no injection well or anything like that. What are your plans there? MR. IDEN: Right now the plans with TS-8 and possibly S-5 may be the fourth injector, would provide somewhat southerly injection. MR. GILBRETH: Both those wells are fairly high on the structure, aren't they? MR. IDEN: They are about one-third of the way up, slightly over one-third of the way up. It's hoped that by maintaining iow bottom hole flowing pressures -- in those two southerly wells on TS-6 and S-7 that we will have continued aquifer movement in from the south and, of course, the TS-$ and S-2 or S- 5 will provide the sweep down toward those southerly range points. MR. GILBRETH: I was curious as to why you had chosen the particular pattern that you have -- the particular wells that you have, if your water is coming from the east. Could you tell us a little about that? MR. IDEN: Well, it's a small fieldand there aren't too many choices -- there aren't too many wells. Our intent was to provide for a good squeeze, if you like, in this central portion of the reservoir that contains the large -22- portion of the oil with pay thickness and that is provided by S-4 and TS-9 on the north and TS-8 and S-2 or S-5 in the southcentral area. Another factor influencing the decision have been the individual well characteristics as far as making sure, after converting a number of wells, we do provide for adequate withdrawals. I think that is mainly what I have to say. MR. GILBRETH: Alright, sir. I believe you mentioned that there is a study underway, or some studies underway, with regard to feasibility of drilling an additional well. At this late stage in the life of the reservoir in the platforms,is it feasible to drill a well now, from a recovery standpoint? MR. IDEN: We have a plan in its final stages to drill a crestal well. This would provide drainage in the most deepest Hemlock bed that is currently drained in the field. We need it at a crestal location to get that drainage. Our studies indicate that this is a feasible and an economic venture. MR. GILBRETH: I didn't see in your aQplication with regard to this project any request for provision of future administrative approval for infill location or anything like that. Is it your intent to request such a provision as other projects have? MR. IDEN: Regarding the specific well, we will be requesting spacing exception and minimum distance between wells exception from you and we will be approaching you for this particular well, and we would plan to do so in the future at any other possible wells that our studies might indicate feasible. MR. GILBRETH: Alright, sir. How are you lifting your production at the present time off of each of the platforms? MR. IDEN: On platform Spark we have a gas lift system and all of the produced wells are gas lifted. Platform A we have gas lift and TS-6 and TS-8, and we have Reda submergible pumps in TS-1 and TS-3, so we have a combination of lifting. -23- MR. GILBRETH: Do you have enough of a supply of ~as to lift the anticipated increase in production and fluids? MR. IDEN: I am not sure if I can answer that fully. I am aware that we will be purchasing gas from Mobil to make up the total platform requirements, so it's used for both fuel and gas lift, so I presume some of it would be for gas lift purposes, and the future predicted gas production from the field is not adequate for the fields total needs. MR. GILBRETH: I realize that, and of course, as you know there are problems of flaring of gas in other fields and we understood you were taking gas from Mobil. I simply wondered if you had been able to obtain all the gas that you might need for future lifting. Any problems in that? MR. IDEN: We don't anticipate any problems. MR. GILBRETH: Alright. By injecting water on essentially the west side of the structure here, do you anticipate or foresee any problem and interference or watering out of other operators' wells -- wells not included in the unit? MR. IDEN: No, we don't. Our structural interpretation shows this North Trading Bay Unit structure to be separate from other structures. MR. GILBRETH: Is it completely isolated from a pressure communication standpoint, for example, from the Texaco wells or the Union wells to the south and west? MR. IDEN: Yes. Ail of our indications are that it is completely separate. MR. GILBRETH: There would be no danger, then -- MR. IDEN: No. MR. GILBRETH: I believe you testified that you expected an increase -24- of something on the order of 6-1/2 million stock tank barrels because of this project. Can you tell us if this project will return the cost of the additional investment that is required and make an adequate return to your company? MR. IDEN: It will. MR. GILBRETH: That looks like a pretty slim margin of increase there is why I was questioning it. Can you tell us what the physical location of the injection and producing equipment will be for the project, where will the injection pumps be located? MR. IDEN: Yes, the injection pumps and filtering and deoxigenating equipment will be on Platform Spark and water for injection into the wells TS-8 and TS-9 will reach Platform A through a 6 inch pipeline that connects the two platforms. This is a-- this pipeline has adequate capacity for the injection into these two wells and has been pressure tested, I believe, to 4,000 pounds. We don't anticipate quite that high a pressure for sending the water over there. MR. GILBRETH: What will be the disposition of produced water, then, on Platform A? MR. IDEN: I believe the produced water on Platform A is shipped to shore and I believe that is the situation, as it is on Platform Spark. MR. GILBRETH: And what are your plans there to clean the water up and dispose of it in the inlet, or return it to the platform, or what? MR. IDEN: As far as the water that is produced on the two platforms amd shipped to shore is cleaned up at the onshore facilities, and beyond that point I am not aware of the disposition of that water. I don't know if the -- MR. GILBRETH: Mr. Singletary could -- ~' MR. SINGLETARY: If I may suggest, that Mr. Anderson who is here present today, I think he could probably answer this for you, Mr. Gilbreth, if you would permit him to -- MR. GILBRETH': Alrigh t. -25- MR. BURRELL: Mr. Anderson, would you identify yourself, please, for the record? MR. ANDERSON: B. C. Anderson, the south Alaska Engineer for the Atlantic Richfield Company. The water is produced on the platform and taken to shore to our onshore facilities where it Dasses through heater treaters. At the present time it is going from this point into some skimmer type pits, settling pits, which have a skimming type pump on the surface that takes the oil off, and the oil is then returned to the system. The water then discharges and goes back into the Inlet. We, at the present time, are -- have approval from our co-owners and are in the process of designing and upgrading or improving of that particular system, b~t the ultimate discharge of the water would still go to the Cook Inlet. MR. GILBRETH: I assume that it will be cleaned up sufficiently to meet the water standard. The water quality standards. MR. ANDERSON: Yes, Mr. Gilbreth. MR. GILBRETH: Thank you, Mr. Anderson. Mr. Iden, I assume that you will be making routine progress reports on this project as the unit operator. Would you have any objection to making, say quarterly reports to the committee? I'm not speaking of, you know, a long report, but giving statistical data on the injected volumes as you normally do. MR. IDEN: Yeah, we would, of course, be submitting the T-13, I believe, which is the monthly report of injection and, of course, be notifying you of the commencement of injection and further operations, as required by the Oil and Gas Conservation Regulations. As far as a routine report, I had in mind something less frequent than quarterly. MR. GILBRETH: How frequently? MR. IDEN: I was thinking in terms of annually. Annual reports of operations. -26- MR. GILBRETH: I see. In the past we have requested annual reports in one or two cases, and we find that it is a long time in between. A lot of things happen and they are not covered in the annual report --we simply get a brief summary saying that we injected so many barrels last year and it looks good, and we're completely out of touch with the project, and this is the only reason that I mention it. We'll certainly take that into consideration. I believe that is all I have right now, Mr. Burrell. Thank you. MR. BURRELL: Thank you, Mr. Gilbreth. Mr. Iden, there is a couple of points that I am not sure Mr. Gilbreth covered. I guess really my question is directed to Mr. Gilbreth, with your cooperation. Mr. Gilbreth, are you satisfied that you're getting adequate tests, such as bottom hole pressure tests. Have you made provision for those, or have you mentioned them? If you did, I missed them. MR. GILBRETH: No, I haven't mentioned them. We have a pressure survey required in this field on demand of the committee and I see no reason why this couldn't continue to function. MR. BURRELL: You believe that would suffice, without any additional requirements ? MR. GILBRETH: Yes. MR. BURRELL: And no further tests or reports other than what you Just mentioned, in the nature of an annual report, or more frequent project report, would suffice. MR. GILBRETH: That's the only thing I visualize now that would be worth discussir here. MR. BURRELL: The other point that I didn't quite hear covered again was, in the past on these injection projects -- secondary recovery projects -- we have made provision in the orders for the committee's approval of drilling of additional wells including the purpose of the project, conversion of wells from -27- injection to production, or vice versa, abandonment of wells, all on the basis of administrative approval, rather than by public hearing. Would this suit you? MR. IDEN: Yes, it would. MR. BURP, ELL: I think that is all I had in mind. Mr. Marshall, do you have a question, too? MR. MARSHALL: Yes, I have a question about exhibits E and F. I would like to know if the correlation section of the logs has been corrected to scale so that the vertical thicknesses apparent are true vertical. MR. IDEN: No, the correlation section is Just the actual well logs as they were obtained, so they are gross well bore thicknesses, in essence. MR. MARSHALL: that leads me to ask the question about exhibit F, then, then the Net Pay Isocore, is this the result of stratigraphic thinning or a decrease in permeability below that necessary for oil production, or could you put more light on that? MR. IDEN: I think mainly it is the result of slight changes in the sand mambers,.?p~esent. For instance, in S-7 ali hold on the left hand side of the correlation section a sand has, that is present farther to the north, has salted out and I think it is also not present in S-7 Redrill and TS-6. It would?~be~ab~u~ the,~.,=~i,i~,Wo~ld!'~be the second sand down in the G interval. I think this primarily results in a less regular looking map. MR. MARSHALL: I see. Then it's primarily stratigraphic thinning of the pay. MR. IDEN: That's correct. MR. MARSHALL: Thank you. MR. BURRELL: Are you through, Mr. Marshall? MR. MARSHALL: I 'm through. MR. GILBRETH: Mr. Iden, I want to pursue one more, one little bit more, this business of injection on the south end. What is going to determine whether or not you will back up injection, back up the water drive with an injection well or fluid in the south end of the field? -28- MR. IDEN: We are planning to study this in some more detail, probably with the benefit of some injection information. Studies have been made in the past regarding the feasibility of an injection well to be drilled toward the south end of the field. The problem -- this has been generally shown to be at the time we investigated it -- an uneconomic venture primarily because of the predicted permeability deteriation around the flanks of the structure, and that it cannot provide for sufficient injection. We will plan to review that study and update it in the light of new information. MR. GILBRETH: I see. And the well , I believe you mentioned that you are currently studying the feasibility of converting number S-2 or S-57 MR. IDEN: Correct. MR. GILBRETH: And when will those studies be completed? MR. IDEN: Shortly, within the next two months. The choice of S-2 or S-5 is mainly dictated by the committee's approval of a crestal well that would be located about 700' from S-2, and would then suggest to us that S-5 should be chosen as the injection point. MR. GILBRETH: I see. This, then, would come before the project were too far underway to create imbalances or things of this nature? Is that right? MR. IDEN: That is correct. We are planning to approach you very shortly with this crestal well proposal. MR. GILBRETH: I see. I think that we probably will be interested in watching the performance in the southern area there, and would be interested in discussing it with you from time to time,~i.what the performance really indicates. That's all I have, sir. -29- MR. BURRELL: Mr. Smith, do you have any questions? MR. SMITH: No. MR. BURP, ELL: Does anybody in the audience have any testimony, or wish to make any comments, or ask any questions, or object in any way to any portion of this hearing? MR. GILBRETH: I might observe that we finally got Mr. Anderson on the stand. LAUGHTER MR. BURP. ELL: We'll note that for the record. With Mr. Slackly, we were not as fortunate with him. Is there any further testimony or comments that you would like to make, Mr. Singletary? MR. SINGLETARY: None at all. MR. GILBRETH: One other question. What about your timing? Are you set right now to go on this project? MR. IDEN: That is correct, sir. We anticipate that the water injection equipment will be ready for start up and for delivery of water toward the end of November and we are planning on commencing the S-4 conversion to a water injector at the earliest possible time, to meet that timetable. MR. GILBRETH: Thank you~ sir. MR. BURRELL: I would like to note for the record that this will then result in every oil field in the Cook Inlet being under water injection, or pressure maintenance. If there be no further comments or questions, we'll adjourn. Thank you very much, gentlemen. -30- TESTIMONY AND EXHIBITS TO SUPPORT THE APPLICATION FOR A PRESSURE MAINTENANCE PROGRAM IN THE NORTH TRADING BAY UNIT FOR THE "G" AND HEMLOCK NORTHEAST OIL POOLS CONSERVATION FILE NUMBER 108 PRESENTED AT A PUBLIC HEARING OCTOBER 27, 1971 IN ANCHORAGE, ALASKA J. F. ROGERS QUALIFICATIONS FOR EXPERT WITNESS -STATE OF ALASKA October 27, 1971 I am a Senior Geologist for the South Alaska District, Western Region, North American Producing Division of Atlantic Richfield Company. I attended the University of Tulsa and received a Bachelor of Science degree in geology in June, 1952. I have since taken various graduate or advanced courses in geology and related subjects at the University of Tulsa and the University of Alaska. I am a member of 'the American Association of Petroleum Geologists and the Alaska Geological Society. I have been employed since 1952 by Atlantic Richfield Company as a Research Geologist in Tulsa, Oklahoma prior to August, 1969, and since that date as a Senior Geologist fn the South Alaska District. During this time, mY assignments have included projects in the Cook Inlet and Gulf of Alaska provinces. R. IDEN QUALIFICATIONS FOR EXPERT WITNESS - STATE OF ALASKA October 27, 1971 I am a Senior Analytical and Operations Engineer for the South Alaska District, Western Region, North American Producing Division of Atlantic Richfield Company. I attended the Royal School of Mines of the University of London, England, and received a Bachelor of Science degree, First Class Honors, in Oil Technology in June, 1963. In March, 1965, I graduated with a Masters of Science degree in Petroleum and Natural Gas Engineering from Pennsylvania State University. I have since attended company sponsored schools in petrophysics, reservoir engineering, statistics and reservoir modeling. I am a member of the Society of Petroleum Engineers of the A.I.M.E. and an Associate of the Royal School of Mines, London, England. ~ I have six and one-half years of engineering and geologic experience in the oil industry of which five years have been with Shell Oil Company and one and one-half years with Atlantic Richfield Company. From May, 1965, to April, 1966, I worked in exploration well evaluation in California, Oregon, and Washington. From April, 1966, to December, 1969, I worked in Alaska primarily with the primary and secondary development of the Middle Ground Shoal Field. From December, 1969, to June, 1970, I worked in secondary recovery at Ventura, California. Since joining Atlantic Richfield Company in June, 1970, I have worked in Alaska in secondary recovery engineering for the Swanson River Field, the Middle Ground Shoal Field, and the Trading Bay Field, "G" and Hemlock Northeast Oil Pools. -1- INTRODUCT ION (R. Iden) The "G" and Hemlock Northeast Oil Pools in the North Trading Bay Unit have reached the stage where development employing the best conservation and engineer- ing practices to maximize the ultimate oil recovery cannot move forward without the application of the proposed water injection pressure maintenance program. The "G" and Hemlock Northeast Oil Pools structure of the Trading Bay Field were discovered in June of 1967 by the Atlantic Richfield Company Trading Bay State #1 well, drilled from a jack-up drilling vessel on Atlantic Richfield Company Lease ADL 35431. Subsequent development of the structure was from the Texaco-Superior Platform "A", installed in the Spring of 1968 to provide for the development of Texaco-Superior LeaSe ADL 17597, and from the Atlantic Richfield .Company Platform Spark, installed in the summer of 1968 to provide for the development of Leases ADL 35431 and ADL 18776. Development drilling began on Platform "A" in June, 1968, and on Platform Spark in November, 1968. Development drilling has been conducted according to the State of Alaska Oil and Gas Conservation Regulations and according to field rules established by Conservation Order #69 for the Trading Bay Field, dated January 24, 1969. Development drilling ceased on Platform "A" in November, 1969, and on Platform Spark in October, 1969. There are five (5) oil wells completed from Platform "A" and five (5) oil wells completed from Platform Spark in the Trading Bay Field, "G" and Hemlock Northeast Oil Pools. There is one temporarily suspended well drilled from Platform Spark that has not been completed to date. On July 1, 1971, the Commissioner of the Department of Natural Resources of the State of Alaska approved the Unit Agreement for the development and operation of ,the Hemlock and "G" format ion, North Trading Bay Unit area, State of Alaska, as authorized by Alaska Statute 38.05. The Unit Agreement was executed by Atlantic ~Richfield -2- Company, as operator, and ratified and joined by Texaco Incorporated and The Superior Oil Company. Currently the daily oil production from the North Trading Bay Unit is approximately 4,900 BOPD from the "G" and Hemlock formations. The cumulative production from the "G" and Hemlock formations and from the area now described by the North Trading Bay Unit, through September, 1971, was approximately 9,300,000 BO. of which the State of Alaska has received a total of one-eighth in value and kind. The prime intent of that certain Unit Agreement was to provide for the further .orderly development of the Hemlock and "G" formations of the North Trading Bay Unit area through a water injection pressure maintenance program. The Unit participants agree that a water injection pressure maintenance program must be conducted to maximize the recovery of the resource. In accordance with the provisions of Section 2226 of the State of Alaska Oil and Gas Conservation Regulations, Atlantic Richfield Company, as North Trading Bay Unit Operator, applied for approval of the pressure maintenance program for the "G" and Hemlock Northeast Oil Pools in the North Trading Bay Unit by letter application dated September 24, 1971. I respectfully request that the application for approval of a pressure maintenance program, together with the accompanying Exhibits Roman numerals I through IV, marked in total as Exhibit A, be entered into the record of the hearing, without reading, in the interests of economy of time. Geologic and Engineering testimony in support of the proposed water injection pressure maintenance program in the North Trading Bay Unit for the "G" and Hemlock Northeast Oil Pools will be presented by Mr. J. F. Rogers and by myself. Rogers will now present the geologic testimony. -1- GEOLOGIC TESTIMONY (John F. Rogers) This geologic testimony is presented to support the application for a pressure maintenance program in the North Trading Bay Unit for the "G" and Hemlock Northeast Oil Pools. Exhibit B is a geologic structure map of the top of the Hemlock producing interval in North Trading Bay Unit. It shows the fourteen wells drilled into this interval and the unit boundary. Exhibit C is a geologic structure map of the top of the "G" producing interval in North Trading Bay Unit. It shows the fourteen wells penetrating this interval and the unit boundary. Exhibits B and C show the structure to be a slightly asymmetrical anticline with an axis trending about North 5° East. Dips on the west flank are 20° and 25° W while those on the east flank are 15© and 16© East. The available well data used to produce these maps indicate that the structure is a simple, unfaulted one; the "G" and Hemlock producing intervals do not appear to be crossed by any faults. Exhibit D is the dual induction laterolog of A.R.Co. Trading Bay State No. 1 located on the east flank of the structure. This well penetrated the "G" producing interval between 9~660' (-9,603') and 9,848' (-9,791'). The interval is made up mostly of sandstone with minor conglomerate and siltstone. The well penetrated the Hemlock producing interval between 9,848' (-9,791'), and 10,174' (-10,117'). That interval is made up of conglomerate and sandstone. The proposed water injection pressure maintenance project at the North Trading Bay Unit will affect both the "G" producing and Hemlock intervals as thus ident if ted. -2- Exhibit E is a correlation section showing the logs of all the important wells in this unit. Ail of the logs are marked showing the tops and bottoms of the "G" and Hemlock producing intervals. The correlation section shows that the two producing intervals can be traced throughout the unit and from well to well. Subunits within these intervals made up of beds or groups of beds can likewise be traced from well to well. This provides evidence that the reservoir beds are actually continuous from well to well, and in most cases, continuous throughout the unit. This geologic testimony provides evidence that the geologic structure of North Trading Bay Unit is not faUlted through the "G" and Hemlock producing intervals; and that the reservoir beds in question are for the most part ,, continuous throughout the unit. I believe these two factors show that this structure is geologically suited for the establishment of a successful pressure maintenance project. That concludes my testimony. Mr. Iden will now present the Engineering t e st imony. -1- ENGINEERING TESTIMONY (R. Iden ) This engineering testimony will support the water injection pressure maintenance program proposed for the "G" and Hemlock Northeast Oil Pools in the North Trading Bay Unit. The testimony will describe the original oil-water contacts in each of the "G" and Hemlock Northeast Oil Pools, the distribution of the pay sand, the reservoir rock and fluid properties, the aquifer properties, the past performance of the field, the predicted future performance of the field, and plans to develop the reservoir according to the proposed water injection pressure maintenance program. This testimony will show why pressure maintenance by water injection is expected to recover additional oil. During the course of my testimony, I will refer to Exhibits identified by A and F through M. These exhibits were prepared either by me or Under my supervision. I will also refer to Exhibits B, C and E which have been presented by Mr. John Rogers. Water Oil Contacts An original, horizontal water-oil contact has been identified for each of the "G" and Hemlock oil pools. These original water-oil contacts have been identified from an analysis of dual induction laterlogs used in conjunction with either sonic or formation density logs run in the North Trading Bay Unit wells. Based upon these analyses, the original oil productive limits of the field have been selected at a common water-oil contact of '9,700 feet subsea in the "G" pool and 9~900 feet subsea in the Hemlock pool. Exhibit C, the structure map drawn on the top of the "G" oil pool, and Exhibit B, the structure map drawn on the top of the Hemlock oil pool, depict these original productive limits of the Trading Bay Field, Northeast Oil Pools. -2- Pay Sand Thickness Gross wellbore sand thicknesses, as they occur in the North Trading Bay Unit wells, are depicted in Exhibit E, a correlation section of the North Trading Bay Unit. Gross wellbore sand thicknesses above original oil-water contacts have been corrected to net wellbore sand thicknesses by eliminating those intervals that are not believed to produce oil. Net wellbore sand thicknesses have thence been corrected to net vertical sand thicknesses. This has been accomplished for each well in the Unit and for each of the "G" and Hemlock intervals. Exhibit F, a net pay isocho~map of the "G" oil pool, and Exhibit G, a net pay isochore map of the Hemlock oil pool, depict these data. The 'total "G" plus Hemlock oil pools vertical net oil productive sand thickness varies from zero to a maximum of approximately 425 feet as the distance varies from the oil-water contacts towards the crest of the structure. Rock Properties Core samples in the "G" and Hemlock Pools have been obtained in one North Trading Bay Unit well, the Atlantic Richfield Company Trading Bay State #1 well. Seventy-three and one-half feet of core were recovered in this well, predominantly from the "G" pool formation, and fourteen sidewall samples were recovered. Rock matrix densities obtained from analyses of the core samples have been used to assist in the calibration of the formation density log. Core analysis data have not been used otherwise in the determination of rock properties of porosity, connate water saturation, and effective permeability. Po ros ity Porosity values for the "G" and Hemlock oil pools have been derived from the formation density log, or where this log has not been available, from the sonic log using a porosity crossplot of density-log-porosity versus sonic-log-porosity detenuined elsewhere in the North Trading Bay Unit "G" and Hemlock O~l Pools. A foot by foot analysis of the "G" and Hemlock pay intervals in the wells has been made and average well porosities obtained. Average well porosities thus dete~nined range from 9.6 percent to 12.8 percent and the field average porosity in the total oil productive volume is approximately 11.5 percent. Porosities of the oil productive volume are indicated to decrease towards the flanks of the structure. Water Saturation Connate water saturation values for the "G" and Hemlock oil pools have been derived from dual induction laterologs obtained in the unit wells. The field average connate water saturation of the total oil productive volume is estimated to be approximately 44 percent. Pe ~ne ab i 1 ity Effective oil permeabilities have been calcUlated for several of the North Trading Bay Unit wells from pressure surveys. Values thus obtained for the com- bined "G" and Hemlock intervals range from 5 md. to 25 md. A realistic field average is believed to be approximately 15 md. Permeabilities are believed to decrease toward the flanks of the structure. The permeability variation of the combined "G" and Hemlock intervals, a measure of the degree of permeability stratification, is believed to be approximately 0.65. This value is based upon analysis of core data obtained in well Trading Bay State #1 and by analogy with other producing fields in the Cook Inlet Basin. This permeability variation value is indicative of a moderately severe stratification and consequently moderate water injection profile control measUres may be necessary during the proposed water injection pressure maintenance program. Relative Permeability Data Exhibit H illustrates the oil and gas relative permeability curves whi'ch x -4- have been selected to represent the average conditions for the combined "G" and Hemlock producing interval. These curves were obtained from the laboratory analysis of core material from the Trading Bay State #1 well. As illustrated by these curves, an increase in the gas saturation from zero to 10 percent of a hydrocarbon pore volume results in approximately a three-fold decrease in the oil relative permeability. A free gas saturation will not be established throughout the reservoir until the reservoir pressure drops below 1780 psig, whick is the bubble point pressure. The current reservoir pressure is estimated to be 2300 psig at 9800' ss. Exhibit I (i) illustrates oil and water "pseudo" relative permeability curves which have been calculated to represent 3-dimensional behavior 'the reservoir model of the combined "G" and Hemlock producing interval under a water injection program. These curves were calculated based upon the assumption that a piston-like water-oil displacement process would occur in each of a large number of individual strata, the total of these strata representing the "G" and Hemlock producing interval with a permeability variation of 0.65. As illustrated by the curves, the residual oil saturation is believed to be 18 percent. At this residual oil saturation, the pseudo relative permeability to water is expected to be four tenths of the pseudo relative permeability to oil at connate water saturation. For the expected water viscosity of approximately 0.4 cp. and oil viscosity of approximately 0.9 cp., this represents an effective water-oil mobilirF ratio of 0.9. This is a favorable water-oil mobility ratio for a good sweep efficiency. Pore Volume Compressibility A reasonable estimate of the pore volume compressibility of the "G" and Hemlock intervals is believed to be 4.0 x 10 vol/vol/psi. · Flu id Properties The reservoir fluid properties used to represent 'the total "G" and ttemlock -5- interval hydrocarbons were determined from analyses of recombined fluid samples obtained at the surface separator from the Hemlock zone of the Texaco-Superior No. 1 well. Analysis of "G" zone recombined separator hydrocarbon samples from the same well show very similar reservoir fluid compositions and properties. Hemlock zone fluid samples were physically recombined to a producing gas-liquid ratio of 246 cubic feet of separator gas at 14.696 psia and 60°F per barrel of separator liquid at 64 psig and 60°F. The saturation or bubble point pressure of lhe reservoir fluid was measured to be 1,780 psig at 180°F. The average reservoir temperature is 180°F at a subsea depth of 9,800 feet, which has been established as the field datum depth. Exhibit J illustrates the oil formation volume factor and the reservoir oil viscositl as a function of reservoir pressure. The pressure in the reservoir at the time of discovery has been estimated at 4,470 psig at 9,800 feet subsea. The oil formation volume factor at that pressure was 1.291 reservoir barrels per residual barrel. As illustrated, the oil formation volume factor increases to a value of 1.323 at the bubble point pressure of 1,780 psig. This small increase in the oil formation volume factor as the pressure is decreased 2,690 pounds to the bubble point pressure indicates a low oil compressibility that has been -6 measured to be 8.36 x l0 vol./vol/psi at the initial reservoir pressure. The connate water compressibility in the "G" and Hemlock formations at the initial reservoir pressure is estimated to be 3.5 x l0 volJvoZ/psi. The oil viscosity, as illustrated by the exhibit, decreases from 1.035 cp. at the initial reservoir pressure to 0.858 at the bubble point pressure. Exhibit K illustrates the change in the solution gas-oil ratio as the reservoir pressure declines below the bubble point pressure. Above the ~ubble -6- point pressure, the solution gas-oil ratio, remains constant at 427 standard cubic feet per barrel of residual oil. This Iow solution gas-oil ratio above the bubble point pressure accounts for the low compressibility of the reservoir fluid. As a result of the water injection pressure maintenance program proposed for the "G" and Hemlock oil pools, it is not anticipated that the reservoir pressure will be pennitted to decline below the bubble point pressure. In summary, the reservoir fluid properties of the "G" and Hemlock Northeast Oil Pools describe a highly undersaturated oil reservoir with a limited amount of energy available to sustain the producing capacity of the reservoir through reservoir fluid expansion. Aquifer Properties The primary oil production of approximately 9,300,000 STB realized from the field to the end of September, 1971, has been achieved through not only oil reservoir rock and fluid expansion but also through aquifer rock and fluid expansion. Materials balance calculations have been made both by hand and by computer in an attempt to define the properties of the aquifer. Based upon these calculations, it is believed that the aquifer is limited and fairly small in size, and of low permeability. The size of the aquifer is estimated to be 6 in the order of 1,000 x l0 BW 'and the permeability of the aquifer is estimated to be in the order of 2-5 md. Primary Production Performance In spite of the presence of a partially active aquifer and peripheral water infl'~x into the oil reservoir, as a result of production from the field to date, the oil reservoir pressure has declined from the initial value of 4,470 psig to the current value estimated at 2,300 psig. Exhibit L, a plot of well reservoir static pressures at the datum of 9,800 feet subsea versus cumk~la~tive oil production, illustrates the oil reservoir pressure decline as determined from individual well static pressure measurements. As a result of the decline in reservoir pressure, the field production rate has declined from a peak rate of 15,300 BOPD and 680 BWPD in November, 1969, to 4~900 BOPD and 3~200 BWPD in September, 1971. Predictions of the future performance of the reservoir under the continued , primary producing mechanism have been made both by hand calculations and utilizing sophisticated computer reservoir modeling techniques that include a history match of past well rate and pressure performance information. These studies have shown that the oil reservoir pressure can be expected to continue to decline; and, because producing capacity decreases with pressure, there will be an accompanying decline in the oil production rate. The weak and uncontrolled aquifer influx will result in a less-than-optimum ultimate recovery. Water Injection Pressure Maintenance PerfOrmance Predictions of the future performance of the reservoir under the proposed water injection pressure maintenance program have been made both by hand calculations and by employing sophisticated computer reservoir modeling techniques. These studies have shown that water injection pressure maintenance is needed to maximize the oil to be recovered from the !'G" and Hemlock oil pools. The studies have indicated that the injection of 16,000 - 20,000 BWPD into the oil reservoir is both feasible and desirable and that this water injection rate will result in the partial restoration of the reservoir pressure by 750-1000 psi, to a level of approximately 3,050-3,300 psi. It is anticipated that the oil production rate will be increased to a peak water injection 'response rate of approximately 7,000 BOPD after about nine months of water injection, An increaSe in the ultimate recovery from the "G" and Hemlock reservoirs of approximately 6,500,000 STBO is expected. There will be an attendent increase in the recovery of solution gas all of which will be beneficially utilized on Platform "A" and Platform Spark. Plans for Water Injection Pressure Maintenance With your approval we plan to commence the injection of water into the "G" and Hemlock Northeast Oil Pools at the earliest possible date. Currently it is estimated that injection can commence in mid-to late-November, 1971. The Cook Inlet is the source of water for injection, and the-water will be filtered, treated and injected at a surface injection pressure that is not expected to exceed 3,000 psi. While laboratory tests on core material from 'the Trading Bay State #1 well have indicated some formation sensitivity to fresh water, it is anticipated that the moderately saline Cook Inlet water can be used for injection as it is in other fields, with a minimum effect on formation permeability. Ultimately it is anticipated that water injection will proceed into four North Trading Bay Unit wells - S-4, TS-8, TS-9 and an additional well currently expected to be selected from S-2 or S-5. Exhibits B and C illustrate the location of the wells selected for water injection. We believe that this flood pattern will provide for both an adequate injection volume and distribution of injected water. Well S-4, a temporarily suspended well, is scheduled for completion as a water injector at the earliest possible time. Selective cement squeezing may be conducted if necessary in this well to assure isolation of each of the "G" and Hemlock intervals. The casing in the well will be tested to 1,500 psi. The total "G" and Hemlock producing interval will be perfo~-ated and the well completed with a single tubing ~tring and two packers, one above the "G" oil pool and one separating the "G" and Hemlock intervals. Provision will be made within the tubing string to allow for injection rate control into~ ea~ch of the "G" and Hemlock intervals. The casing-tubing annult]s will be equipped with a pressure measuring device that will enable the detection of a tubing or packer leak during water injection. The'well will be production tested and the reservoir pressure determined in the well prior to the commencement of water injection. The conversions of the three further wells planned for water injection service are currently scheduled to be made during the next three months. Ultimately it is expected that these wells will be re completed in a manner similar to that proposed for S-4 and as shown on Exhibit M, the schematic S-4 injection well casing, cementing, and completion diagram. Initially the wells may be simply "turned-around" and water injection commenced into the current well 'completions so that full-scale water injection can be commenced at the earliest possible date. Atlantic Richfield Company, as North Trading Bay Unit Operator, will appropriately notify the Oil and Gas Committee of "Additional Recovery" operations as required by the State of Alaska Oil and Gas Conservation Regulations. Subchapter 6. Appropriate descriptions of the casing and method of testing the casing for the proposed water intake wells S-4, TS-8, and TS-9 are included as a part of Exhibit A. A description of the casing and method of testing the casin in the fourth proposed injection well, will be furnished to the Oil and Gas Committee for their approval prior to its conversion. Following the initiation of the proposed water injection pressure maintenance program, the project performance and individual well injection and production rates will be monitored closely. Downhole injection and production well profile surveys will be run from time to time to determine the need for injection well profile control work and eventually, possible production well profile control work. It is expected that reservoir pressure determinations will be made in the injection · wells from time to time as required to assist in the evaluation of the project -lO- performance. Studies of the reservoir performance will be continued to determine the need to convert additional wells to water injection or to vary the well spacing in some areas by the drilling of an additional producing or injection well to furrhe] improve upon the ultimate field recovery. One such study that indicates the desir- ability of a crestal producing well to develop the basal Hemlock interval in the field and to further improve upon the ultimate field recovery is currently being finalized. Conclusion In conclusion, this testimony in support of the proposed water injection .pressure maintenance program shows that the proposed program will substantially increase the recovery of oil from the "G" and Hemlock Northeast Oil Pools in the North Trading Bay Unit. During the course of the proposed pressure maintenance program, there will be strict compliance with all applicable Federal, State, and other applicable laws, regulations, and standards, to pro- tect the environment. As a consequence, we believe that the approval of this pressure maintenance project will be in the best interests of conservation and optimum engineering practices and will benefit the State of Alaska. We therefore respectfully request that you approve this project at the earliest possible time to assure maximum efficient development and to prevent waste of our natural resource. That concludes my testimony; thank you for your consideration. NOTICE OF PUBLIC HEARING STATE OF ALASKA DEPARTMENT OF NATURAL RESOURCES Alaska Oil and Gas Conservation Committee Conservation File No. 108 Re: Application of the Atlantic Richfield Company for a pressure maintenance program in the North Trading Bay Unit for the "G" and Hemlock Northeast Oil Pools. Notice is hereby given that the Atlantic Richfield Company has petitioned tile Alaska Oil and Gas Conservation Committee for approval of a pressure maintenance program for the referenced pools. On its own motion, the Alaska Oil and Gas Conservation Committee is calling a hearing on the referenced application at 9:30 a.m., October 27, 1971, in the City Council Chambers of the Z. J. Loussac Library, 5th Avenue and F Street, Anchorage, Alaska, where the applicant and others may be heard. Thomas R. Marshall, Jr. Executive Secretary Alaska Oil and Gas Conservation Committee 3001 Porcupine Drive Anchorage, Alaska 99504 Publish October 13, 1971 AFFII AVIT OF PUBLICATION STATE OF ALASKA, ) THIRD JUDICIAL DISTRICT, ) ss. being first duly sworn on oath deposes and says that ..... ~.h..e. ..... is the ....... ..L..e.~..1...?..:]:.?..z-.~. of the Anchorage News, a daily news- paper. That said newspaper has been approved as a legal news- paper by the Third Judicial Court, Anchorage, Alaska, and it is now and has been published in the English language continually as a daily newspaper in Anchorage, Alaska, and it is now and during all of said time was printed Jn an office maintained at the aforesaid place of publication of said news- paper. That the annexed is a true copy of a ....L..e.~.~...Z._~?...~.~.c..e-....Z..LL3'~ as it was published in regular issues (and not in supplemental form) of said newspaper for. a period of .... o.~a ........ insertions, commencing on the ....:]:3. .... day of .... ~.a.~.a...b.?.~ ....... ,19 ..7..]:.., and ending on the ........ ..1.~. ...... day of of ..... ~'.a..t..o..b..~.r.. ........... , ] 9...7.1., both dates inclusive, and that such newspaper was regularly distributed to its subscribers dur- ing all of se,id period. That the full amount of the fee charged for the foregoing publication is. the sum of $ 10.00 which amount has been paid in full at the rate of 25¢ per line; Mini- mum charge $7.50. Subscribed ~, sw:rn to before me this .:1:.~. .... day of...~g..~..o.~.e.~.., 19 7~f the State of Alaska, Third Division, Anchorage, Alaska MY COAAMISSION EXPIRES .... .~~;..'. ......... Z../.., 19....~./ IAt?nticRichtieldCompany North Americ:ln Producing Division Alaska Expj¢ ion & Producing Operations Post Oil',ce box 360 Anchorage, Alaska 99501 Telephone 907 277 5637 Howard A. Slack South Alaska District Manager b~iVl~LOh' O~ ©',L AND GAS ANCHORAG~ September 24 1971 A~sk~ O~Z a~d G~s Oo~se~tto~ Co~$ttee ." DSv~s$o~ o~ 0~ a~d Gas 300~ Po~oup~e D~ve Anc hor~e, A l~sk~ 99504 State of Alaska Proposed Pressure Naintenance Program Trading Bay Field, "G" and Hemlock Northeast Oil Pool North Trading Bay Unit Gentlemen: In accordance with the provisions of Section 9.9~9.6 of the Oil .and Gas Conservation Regulations, Atlantic Richfield Company, as North Trading Bay Unit Operator, requests approval of the pressure maintenance program for the Trading Bay Field, "G" and Hemlock Northeast Oil Pool hereinafter set forth. Geological studies and engineering studies utilizing a mathe- matical reservoir model indicate that reservoir pressure can be maintained and that oil recovery.will be substantially increased by the injection of water into the "G" and Hemlock producing zones of the Northeast Oil Pool of the Trading Bay Field. The attached Exhibit I is a structure map of the top of the Hemlock formation on which is shown the North Trading Bay Unit area for which this project is proposed. Exhibit I also shows the following: .. a. Leases included within the proposed project and lease ownership in the proposed project and offset thereto; b. The location of all oil wells together with notation indicating those wells proposed for conversion to water inject ion. All producing oil wells within the field are completed in the "G" producing and Hemlock intervals. The "G" producing interval is the basal sandstone interval of the "G" marker as designated by the McArthur River Field Geological Subcommittee and is identified as those sands appearing between 9,660 (-9,603) feet and 9,848 (-9,791) feet on Exhibit II. Exhibit II is the dual Alaska 0 _ and Gas Conservation Committe~ Page 2 September 24, 1971 induction laterolog of the Atlantic Richfield Company TBS #1 which is located in Section 26, T10N, R1SW, SM. The Hemlock producing interval is in the conglomeratic sands of the Hemlock formation and is identified as those sands appearing between 9,845 (-9,~791) feet and 10,174 (-10,117) in the Atlantic Richfield Company TBS #1 (Exhibit II). The proposed water injection pressure maintenance project at North Trading Bay Unit will affect both the "G" producing and Hemlock intervals as thus identified. Water injectivity tests into these intervals at the North Trading Bay Unit have not been conducted. Thus information relating to existing water intake wells is not available. Present plans are to inject filtered, treated Cook Inlet water, commencing during the last quarter of 1971 and possibly the first quarter of 1972, into four injection wells. Wells proposed for water injection service are TS-S, TS-9, S-4, and an additional well not yet determined. All of the proposed water intake wells will be converted from production status except well S-4. Well S-4 is a "suspended" well which was never completed after the casing was set. Exhibits IIA, IIB, and IIC are dual induction latero logs of the planned water intake wells TS-S, TS-9, and S-4, respectively. These logs show the "G" producing and Hemlock intervals which will be affected by water injection. Exhibits IIIA, IIIB, and IIIC are the Well Completion reports of the same three wells--TS-S, TS-9, and S-4, respectively--which describe the proposed intake wells' casing completions. The casing in each of these wells will be pressure tested to 1,500 psi during the conversion of the wells to water injection service. Each injection well will be equipped with a packer above the injection perforations which will accommodate the single tubing string through which water will be pumped from the surface to the injec- tion perforations. The casing-tubing annulus will be equipped with pressure monitoring equipment during water injection to pro- vide for the detection of a tubing or packer leak. Present plans also include the packer segregation of the "G" interval from the Hemlock interval in the proposed water intake wells to permit water injection profile control. Injection rates into the proposed intake wells will be based upon reservoir requirements and the ability of the wells to take water. Ultimately the total water injection rate into the North Trading Bay Unit project area is anticipated to be approximately 20,000 BWPD into the entire "G" and Hemlock intervals at surface injection pressure not expected to exceed S,000 psi. The possibility exists that a further production and/or injection well may be required to improve the sweep oil recovery of the proposed water injection pressure maintenance program. The ~ionthly Oil Production Report for August, 1971, is attached as Exhibit IV and shows the gas-oil ratio and oil and water pro- duction rates for each of the producing wells in the Northeast Oil Pool of the Trading Bay Field. Alaska Oil and Gas Conservation Committee Page 3 September 24, 1971 Atlantic Richfield Company, as Unit Operator for the North Trading Bay Unit participants listed below, will conduct the pressure maintenance program proposed herein: : Participants in North Trading Bay Unit Atlantic Richfield Company P. O. Box 360 Anchorage, Alaska 99510 Texaco Inc. P. O. Box 4-1579 Anchorage, Alaska 99509 The Superior Oil Company Box 1521 Houston, Texas 77001 A copy of this letter of application will be sent, simultaneously with this letter, to the following offsetting operators of Oil and Gas Leases ADL 17596 and ADL 18731: Union Oil Company 909 West Ninth Street Anchorage, Alaska 99501 Marathon Oil Company Box 2380 Anchorage, Alaska 99510 As indicated by Atlantic Richfield's testimony at the public 'hearing before you on May 27, 1971, this project will not result in.the production of excess casinghead gas. There will be strict compliance with all applicable Federal, State, and other applicable laws, regulations, and standards to protect the environment. In this connection, applications for discharge permits from the Department of the Army, Corps of Engineers and the related State certification have already been filed. We believe that the approval of this pressure maintenance project will be in the best interests of conservation and optimum engineer- ing practices and will benefit the State of Alaska. We therefore respectfully request that you approve this project without the necessity of holding a hearing. Very truly yours, ATLANTIC RICHFIELD COMPANY OPERATOR By ...... Howa~-d 'A "'SlaCk Attorney-in-Fact DISTRIBUTION LIST Mr. Robert T. Anderson (2) Union Oil Company of California 909 West Ninth Street Anchorage., Alaska 99501 Mr. M. L. Lowman (2) Marathon Oil Company Box 2380 Anchorage, Alaska 99510 Mr. M. U. Broussard (2) The Superior Oil Company Box 1521 Houston, Texas 77001 Mr. Leo McCann (2) .~Te×aco ~.~nc. P. O. Box 4-1579 Anchorage, Alaska 99509 Mr. D. S. Pierson (1) Texaco Inc. 3350 Wilshire Boulevard Los Angeles, California. 90005 ' ' SUBMIT IN DIIPLI ' "' OIL AND .~"'~'~*"~" COMMITTEE ~,.~.,~ ,.~ ~. ~m NUM~.:mc:,u, 50-133-201.82 .... WE~bh~LET ..... ION OR RECOMPLETION REPORT AND LOG* RDB '17597 . · ' ...... - ...... - I~. TYP~ ~ ~: o11. ~,.~s WgLL WI:t4. DR~ Other ~. IF INDI~. AL~%'I'~ Olt . . ~ TYP~ OF COMPLE~ON: BACK ~ENVR, ' OVER 2. ~ State 6f Alaska '-: ~EXACO Inc.. Box 4-1579, ~nchorage, Alaska 99503 ~. LOCATION O~ WELL (Report location clcarIF and in accordance tcith o~ Store ,-./':~t,~e Platform Leg 3A, Pile No. 2 or 664' S and :";"2000''W of the 'NE corner of Sec. 34, 10N-13W, S.M. . "'At top prod. Interval reported below ".~'~-~;;"G"': Sand-1659' S and 698s W of the ~E corner of .,.L" At total dep~ SOC. 34-10ff-13~, S.H. . s . and 618' W of the NE corner of Sec. 34, . '" 8-24-~9~ '-~-. [0-21-69 ~ KB = 92' + H.S.h. .a 32s KB -' ., ' 1~05~ 9,943 uow~sx,. ~o~ ~., was ~ ~, PRODUCING IN~BtlV~(S), OF Tttl8 CO~IPb~'I'IOS--TOP, BglS~OM_,_.~'AMZ (MD AND '1~)' ' '"G" Sand ' 9,920 (9;636) to.~9,900~.(9,705')- ], suav~:v~m~ .~. . . Hemlock _10,135 (9,846). to 10,220 (9,92.9') No '24. ~>E E~CTRiC AND OTHI~ I~G$ RUN '. .. " None '. ' ....... ~. - - -' ~. ~ ~ ~ ~ ~ ~,, ~ ,, i , , ~ ,,,, , :: ...... :--~ ..... ~. CASING ~ECORD (l'te~t all strings set in v.'ell~ Trading Bay {N.E. Pcc! j ~. TUBING RE3OI~D SCnEEN (AID) SIZE J DE~I'}.T Sift (hID) ~ PAC]<ER SUP :- CASING S.I7'~ .WEIGItT, LB P.T. l GRADE DEPTH SET '(~i1-~)' 1{OI:~', Sift,. ~ ' ' 'CEi~.iILxTING ~E~:°l.[b '" ~II~J'N'T PuLLrD }~-~13 3/~" '54.5 ~ .... 1,378' 17.5 2,000 Sx. cias~ "G" ~' .......... . . 9 5/8" ~,5 & 47 N&S 10,3~5.~ 12~ 1,200 Sx. Cla..~.. ".G" ' ...... 1,_2'~0 sx. Class "G" (Stab'ed . A. CID, Si!C,T, Fi(AC'i GI,'E, C :EL.1EN'I' SQUr'r;~'E_. .... ,, ETC. 056- _9~o86[,., fi_84 cu._ DEPI'II 1N'!EIIVAL (MD) A.",IDU.N F AND KIND OF AIA~I~EiLIZ',~., 1 I,!LD 2,934 559 cu. ft. Cia*,' "G" 25. LIN~Ig F~;COt~I) SIZB . ~ TOP(MD) 4-½" holes/ft. 9,920 to 9,990 . 4-½" holes/ft. 10,135 to 10,220 .2-½" holes/ft. 10,135 to 10,220 PI ~O D UCTI OX 10,325 86 cu. ft. DATE FIRST PRODUC'I*ION' [ I'~ODUCTION 51131 ltO1) il,'lowing, t.a:~ lift, purnp[ng.-Mzu and type of purr p iV. ELL STATUS (ih'o::"' '. ' 10-13-69 ' J Gas Lift (606 MCFD Inj.) ' ~ [ P[oducinc !~,-~2-a!_l_ _24 . ! !2E~E .... L ~' J .340.._ r~.ow. 'rumxa Ic~sr~ rm:ssuns IcaLcu~,..v~¥~ om-mm, aAs.-:,mn -wA'rm'~-m ~,: jam a~Avr}E:L.. '' as'I-9oo j-- I 34o · I9 I ].o1 TEST %~ I'fNI';SS~I} Vented and used for fuel -- Completion Report , ...... ~,:] h~,reby c.r1?y that the furegc, l,~gjh[J attacln'd lnf.rmatl.n 1, Coml)lUt~; and correct as d,.tc;i~JuJVd ir,,m alUakdi~i,t,Ie rt.c~;i~s --' smsm) : ~ ~,~,~, Dzst Superzntendent ,~,x'r,' 11-," *(See Instructions and Spaces for Additional Data on Reverse Side) · '. , , , , .., ,: · : ; ; , ~ f'- ....~ :.7-.'.i?. '" :, ~ ~ ' ' ~: · i , · ·-.-;.. . ,'-* "' *. ' .:--i ·:'*' '. '~; ": . · ' ~.,'.. ' ' - ~- '"'" '. *' - . ':'~. .:: -. " . " - .,~'" TM~ --i,.i C,:; ~. : ,_ -. .-;...?, '. : ,. :'. , ,' -- :'..' ,~,.- r.:..-: ,..,,_. ,,' . _ - .. ',-* . :' '. ....... -',' ' . · .- .,....;.- .... ::~ ~. ,. ,..,~.....- . ,.:... ..... -, .:* .:.~:. :.. :. ,.--;. . ..... , .... ...-._ _ : .... ,. , ...-..,,; . · ~ -~ .-" .-;,:,:;:all types of~lan.~s and:'Jepses rn Alaska.-- '.,,:~:' ? ~' ;-'": : '.'~. ::; ' i . :'.:' . · - - ,. ; ; · ,--.. ..:; .... . .-...~:-:~ · ...... . ........... . --..- ... --:.z._,.~.,. ....... - ...... ~ ....... · r,. :'::..".-.i.'."' ";' '?t .4- ..-" ,~.:. '-,----. i~'. ru'-- _':. -~;- ',.. .!- :-...d.,.¢ r'i :- .-' : '..' r:- r' -:'i 7' - -:-~' : · ---;:. ( .' .. ':'..' ..,.l.ern:i 16: Indicate which' elevation-:i_s Used as'.referen~:e (Where'not otherwise~sha~n) for depth meas~Jre- ~ _- ..:. : .(,.¥.-...':--..:~ . .: ~ ...... .. ,.. ..... . ...... . . . .... -- -o - ' .... .:. :..-'~ ' ' ::E '~ment$'given'. in _clher sp~ces an this forth ,~d inI ~ny' ',~itac'hme'ntsl-. ': -.._,: .-.-r:-".:... ~;... c'-. ~- :- .-. . : .' · ,-' ' ''- - , ' ;.; . '" _] ..... : _- . ; ,,. . ..... - C . .- 'l'~'' .....--.' ¢- .,.-.', : - '~- ~ ~ C,]:' ........"'- '~' ( _- .. ..... - · · . .,. ' [ ' ...._. ,~ · . , ~ -. . . · . · - .... '.' ~'f:'- ;:' ;"Item,'20, ~nd 22:i.'iifl.th'is well is c.c_'omple~ed'' -. ~ -.. ;.. :: ' for separ~tc:'~raduction from im~)reZ-th~n or~e interval zone :-: ' -z. " · - :~- .,-- - ,i . ,r . · ;. . · ''- . :' ' (multiple'-comp!.etionii.'.~o state in. item'20,' '~nd in item''2,2 show 'the prcducing ': interval' or. imerv~ls, . ,: " .',-. ' .:.;' "..:i: top(s), bottom(s) and,nar~e (si '(if eny) ~r c~nly-the interv~'l"reported in item 30..Sub. mit a separate rePort -- ' . (page) on. th. is for,m, :,~deq'uately identified, for each a6tciitional inte, val to be'seper~tely produce~ st~ow- ~ .... .. . _ . .. -_ . " '- '-' lng the ac~litionaJ:data pertinent.t° such._...--_interval" - ·, · .. . · '' "i ' It(~m26: ~'S~cks C(~ment": Attached supplemental records for this well should show the details of'any mul- :=~,. ~, tiple stage Eem..e.nling and the Ioc~tion of the cementing.tool. ':' . V . " Item 28: Submit a separate completion-report on this~form for each interval to-be-separately .produced. (See"instruction-.for it. ems 20.'and 22 above).- '" " ' ' l: '~ · :- -" " . '~' --~ ,- o..o --,., r'--:--~:--~'~,, " .: ' SUBMIT IN DUPI,IC ',. "' ,rE OF ALASKA ,,s,,,,o~'. ,,,. ,, M ruer h,.~ ~m ..'-'. O[i. AND GA5 CONSEEVATION ¢OFA~ITTEE .... - ~-~,~ _ _ ~ _.r~ 'L' ~ ELI W[I.I. [._.J [mr Olh,.r b. TYP~ OF COMPLE~ON: - TF~[ACO Inc. ~ -- .; .... ,,'i -P. 'O. Box 4-1579, Anchorage, Alaska 99503' ~. LOCATION OF IV£LL (Rrport /ctd/;o:; cl(arllI and in accordance with at~ 8late rcquircmCnts)~ · ~t,,~e~ Platform Leg lA, Pile No. 5 or 2,076' W and '618' S of %he NE~ ~orner of .Sec. 3~-10N-13W. · t top proa. ate,~ ,~0m= o~;.~-Hemlock'-',l; 600 N and 622 West o: t~e SE corner of Sec. 27-10N-13W, S.M. t0ta~ aec=1 606 ' .' .. .. .., N and 620' West of the SE corner of . . ExHiB fT' ~' , · * ,, q : , , .f · %,.I' 5. APl NU3.11-:II. IC/k.I-~ COD17, ', .'. 50-133-200200 'i'. ':'" ': 6. LI'.ASE I)t2~lt3NATION /%3,~D $~2]tl[&l. NO. ADL 1.7597 2. IF INDIAN, AIA.O'I~I'EE OI}'~'[{.]llE NAAIE . '__ . ',.:' .~ 8. UNIT,FAI~I C)¥t. L}L%S~ N~kME , State of Alaska' -..... TS ~9 ',' "< Trading Bay '~E 11. SEC., T.. OB! ECq'IVE) · Sec. 27, 10N-13W, S.M. % 12. PIS'F~NI1T NO. " . 10N- 1 m., ' . Sec 27- ..,,,, S M. ~" a _ · ' : "', i' 9 92 .' 9-4-69' .' 10-!7-69 11-12-69 KB = 92' M.S.L.. ...... ~ 32' KB , 10,' 387,:_'9,962 ~l..0.= 369, 9,.944 ../ ~ow ~uuwY.___ ao~,,-AllrOOnS , ' .' c,.,,s ~oo,.s ..i ,"' ." ig. PItODUClNO ~mlvac{s.,, O,.="T;-!tS COMP~mUON--TOP, BOSOM. 5ASm tMD ANo ~1' ' '".. ~. was mlu.:cnox~. ." Hemlock:. '10,300, 9,875 Top "G" Sand:". 10;090, 9,670 ToPI 'l' .:...:t.. .. '"; ';'10, 3_75.~_~, 950 Bottom* 10,150,.'9, 727_.B~tom Yes .~': :'.'.:-'. 124. ~E E~CT[~lC AND OTIiE?~ LOGS I~UN . ' ; ' ' I ' -,"; , ,- ,, CASING RECORD (Report ail stz. m~s set Jn w~U) ~2% .... ......... ., · , , , -'1 . J ., ! ,. -:-, : ,, ,, .... , ~ , , ~. PEI~'OT~ATZONS OPEN TO PKODUC;.<.:2, (intcrvol, size and number) "G" Sand: 10,090 to 10,150--12"%" . :. holes/ft. (Sho~ 3 times) Hemlock:' 10,300 to 10, 375=-82%" ' . :' holes/ft. (Shot twice) '* Wire' line measur.~.j~2?~.~:: _ PRODUCTION DATE FIRST PIIODUCTION J PIICDi't : :t.'N "~I;IIIOD (Flo;;i;'i:, :;:,.: lilt. V,;r:aping--size and type of pump) V, . 11-1-69~ Gas !,J.i~ ~""~';"~ .[ DATE OF /EBT, iiOUtIS TI'iS'fED ' . <:ZE PIIOD'N FOIL OII~-EUL. G:kS--.MCF. TE>I' 1't.;!{ !OD '11-1-69 8.5 ] 72/(,.5 ~' } 64.1 { 17.7 FI~W, TUBING C~%[NG I*I'IESSUi'~: [C.-51.~ ~ x ~ i.:D OlI,-.-IgBI.,. GA~.-?,ICF. gVATEtl.. 70 8oo .... L' 5o I 3I.DIEI'0SI'IION OF~A~ (801d, u~cd Tor J~Cl, ,~.:, ' CE.MLNTING /~F, CO~D AMOUN~T PULleD ' 1,.350 Sx..C.].as_s _ '.'G'~' 1,850 Sx.~ ~~q ?.G" SIZE ' DE~I SET (~ID) JPACKER S~ (~) 3a ..... ~0,056 i~..9,9s3 29. 'ACID, si:eT, F,iA.C]'UI.IE, CESII '~ l' SQUEEZE, EI'C. DE211I INT~V.kL (MD) [ AMOUNt A:~D I;!ND OF 5~%7~F~AL'US~ ...".' · 1~,292..4,~ !~les-S~ueezed 34 Sx. Class''G'' ~0, os7'.:?L~'"7~~~~0~es'-s&,'.iee~ed 37" Ac ELL :5'rATUS (Pz-oducin~ or SI ' V,'..','I I';ll--:?.13L. J GAS-OIL II.Y'FiO J, 5.7_ . 'J 275" · 1;I ti, J OIL GI{AVI'I'Y-J%PI (COFOI.) ] 6 J_ __ &6..o°,,.,, '. 'il'"e.l WI'II.N}:SSKD i;'t Vented and used for ftlel 32, LIST oF ATTACIi.'.IENf8 · .. Completion Report c~n,:.! Directional Survey '-" 3~. I hereby ccrqfy that.th(, f,rvgoi~g :,~]".'.~,...~:.,,t ll:f,,rlnall,m Is comPl,;{~/ and corr,.ct as d(;tcrmim.d I,..m all-~txa]~:~ rct'nrds . sioN}ch ~ ~:"2~C~J'~' Trna.' Dist. Superinten(;c'nt ,~'n.: 12-10-69 ..... *(See Ir;s}ruct;,',ns and Spaces for Additional Data on Reverse Side.) '.; '~-__zener'al: Thi~ fc~rm is2designed fa~ subrmit~ing:-a comp-I~te, an'd Correct well.co'ropier}on report and log on :: ' ftem:'16: In'dicate which elevatioa is used' as~ieferer~ce-(where not Otherwise"shown) ~for depth.measure ..... · .- merits giYent'in ether spaces on this-form and iri:.any a~lachmems ....... -'- "<- ' ' " ::' "i-'!~om~ 20,'"'and 22:.-..If'fl, is well is Comp~'~!o'd for'separatc, production *rom-m&r.e..~han ~ne interval zone ~mulliple. co~mpleli6n).~~ ~o stare ia item 20;' and in-item :22 show the.p~c.ducin~ 'interval, or imervals, lop(s), boHqm(s)' and ..name (s) (if aa,/) for only~the interval repormd in item 30. Submi~ ~ separate re,or: (pa~e) on 'lhis form, adequately identified flor each addilioaal interval to be :seperat~l~, producod~ shew- ing the ac,r, ditional data .pertinent, 1"o such 'interval. 7. ' .. . Item26: "Sacks Cement": Attached supplemental records for this well should show the details of _any mul- tiple ~ta§e cementin~ and the location of the cementing tool. - . ' Itom :28: Submit 'a separate completion report on this form for each interval to'b~., separately producod. {See instruction f~r items 20 and 29 above). " -. Please refer the 0omp&etion Report 35. GEOLOGIC' :~. COIIE DATA. A~'I'A('il BITIIgF D~,SCRI'PITIONS OF LITIIOI-OG¥. POROSITY. FRACTURES. APPA.RENT DIPS T. op .He. mlock . ~. o- . , 10,300 9,875 WELL COMPLETION OR RECOMPLETION REPORT AND LOG '~ ~u,~tlr ~N t,,~.,; ' EXHIBIT III C TE OF ALASKA ~S~oi., t,,- ~tru¢~ ~n .,. OIL AND G ~,ONSERVA'flON COMMITTEE re,,¢,'~ ,~ I ~' Ai'~ Nu~m~uc~ cous J_APT ~flr133-201~4 i ii - i i i ii i ~ m ~ ~__ ] i i i 6, I,EASE DP~IGNATION ~D S[~ ADL 35431 ~'.I~IAME OF OprRITOR Atlantic Richfield Com~an~ 3. ADDP. I;.~$ OF OPLRATO~ : P.O. Boz 360,__g~cho~a~e_ ~ka_ .- ~OCA~ION O~ W~LL (]~epor[ localion cleori~ =n6'i~ occor'donce ~ilh an~ ~tole rcquir~e~tl)* 7. IF INDI,'~"~. ~LJ.~OT'I'EE OR TI{IBE 8. UNIT,F2kI~Xt OI{ L~ASE N~ME Trading Bay Field WELL NO. S-4 .#22-26 1O...FIEL,I~ A~D Y,l,)OL. O,!iJ,;'LI-,I~¢A3~. . · rao~ ng ~ay r~ e~o--Hem[ock _~,E, 0i_l Pool ' At aurface :. 2615'N &.2492'W fr S,E, cr, Sec 26,"TlON, R13W, SM At top prod. lnter~ral reportedbelo tot ; . perforated .tota~ depth 2065'S & 776'E fr NW cr, Sec 26, TION, R13W, SM 11. SEC.. T.. Ii.., l~,l., (13. O'17I'OM tlOI.~Ei OBJECTIVE) Sec 26, TION, R13W, 'SM 12. pERAilT NO. 69-34 ' 6-3-69 { 6-27-69 6-29-69 I 115 KB '=_ ~_- .,~. 40' 18. T~ D~H. A~ & TVD~9. PLUG, ~CK ND & 'iN'D~. ~' I~LTH>LE COS~L.. ] 21. INTER%'AI,8 DRILLED BY . .... V~/ 1.0_66~ MO f -~ ... All ~ , Not perforated ~ ~ 24. TYPE ELECTHIC AND OTHEI~ LOGS RUN DIL, FDC · CASING RECORD (Report all strings set in w~ll) ;.. 13-3/8_ _ '[ 61~ .[ J-55 2.132' _ 17-1/~'l lnnn ~v ,,a,, w/latz n~.l +. mn sx ,,n,, ~;t ]--g-S/a, I_ 4~ _ I N-an ln[7 ]~/ _ '~ I' . ....... I... ~'.i~_ .'.'..' 't ......... 5 ~" ....... .-. . '" -) ., [ i . DE2YII I!CY~VAL (MD) aAtOUN'F Z~D I'~IND OF },illZ~i US~ None ' '" ' , · . P~%uc~,o DATE FIRST PP. oDUcTION { PIIODUCTION Mt;IIiOD iF]owing, gas lift, pumping--size and type of pump) None Ito be completed later as water injector { ' I t~S'l' i'~OD F~W, TUIUN~ [C~.NG rrir~suim [CA~:~_~) OZ~UU~. . OA~MCF. I ; l' "' ~.'~,s~o~i'~i6~ or 0.s i~°~u, ,,~a lo~ y.,i, ,.,'~r~, ~,~.) , " '- · I%:'ELL STATUS (Producing or I 5,tut-bi) I temp. sus.pended GAE~--AtCF. ~'A'rEI1,---BBL. I GAS-OIL Il,VI'lO IgBT WITNESSED .... r .............. -si. Cie, o, ~Tf;~U.qi".~Yb .............. ,q3-.'l-hereby ¢~rti~y that the foregoi,ig and attached in/ohuaFi;~' 1, c6~plci~ aud correct a, determh,['d lrou~ all available ~:ecOrds , s,~.~o ;: R. Wz-McCteskeTT-~r. ?,~L~ ~ Senioy__Ilri 1 ]~no_En.gineer_ - . · z - ~ ..... ~ ..... i i I i ~, _ i i itl · (See Instr~¢tion~ and Spaces [or Additional Data on eve~$¢ Side) STATE OF Ab'\SKA OIL AND GAS ~ ," o ',,--, Cf.. N o E,. VA1 ~ ,~, N ,COMM I 1T E E August 19 71 (month) 'TO'FAI~ ,",IONTIiLY PI'~ODUCTI('~N OIL 3,859 !3,350 209 O! I, V, fATI~iR 43,271 12,588 FOF,}.'IATIO N GAS 342 1,275 DAYS PRODUCED 31 31 S S, 859 1,617 6-2 '.',- ? :A, DAILY AYEHAGE PiiOiJ,JC'I'iON OIL t24 431 W.-',,T~T~ GAS 1,396 406 Trading Bay I(cnai & I!emlock N.E. _Fit'ld and Pool - -- .... 5'_._= AtJ. ant~ c R..da~-.zeld Co.mnanx~ Operator North Trad].n~ Ba,[ Un5.~ APL 35431 I,~aae or Property Cook In.l. e t Pip~!.ine Comp2~Z~ GAS O INPUT % W'fR. ' ....... I RATIO / GAS [74 TOTAY. ~'~ ~.,~,~7~- ~'-/~;'N- ~o~. \'.' ~.'LI, 0 COG .';T [~ -- 11 89 41 96 97,54.6 62,931 91.8 48.5 I. FLO'~Vi.X G $. P. OD PU?.IP WELL S-2 S-7 4'T' Fi 2 2 2 iq{O ;'~T! SI'ATE 0[: Al~.o,xA OIL ANi) GAS COl,,ot_;-,V~. ION .COA'%L%I ['Icc a ~ ,;. ~:: ,] 'J~ ~ :-;':h ~ ~%'?.~ ~ ;~ ~ 4~L,~X~ ~ ;- ;~ ;~%. % b ~ ~,~' -~ --~ ~ ~',;') :'~ ~% ~ OIL BAi%RE[JS OR 4O 11,880 37,506 49,426 14,595 27,340 17,45.3 59,388 ;%'][ C I.,' .?ORMA.'F1ON GAS DAYS PI~ODUCED 9 31 71 ,. North Trr~. , , '( '[M'i.t ,~Br 18776 ~ '~J )1~ _ . Cook ]:nlet 383 1,015 1,347 8~2!5 _ ].622 882 563 1210 113 43 265 ......... iCVI.'i O 2U. l."F.l i; 1~;I ,.[ (;,\8 Vt)r,. 25,375 1.13 219 21,576 96,59 4 91,51.5 99.7 69.7 31.8 COD¥'~ FO'.~. 3AY';]'IfOD C'." TSCL 2 5s7 Tota~ :-~iddl~ Ko TS2 2 TS4U 2 Total :,"~. il . ]_ 1 'idl S TS5 5 'I,% 2 '.1'S8 2 TS9 2 Total STATE OF AI_ASKA Auqus t ~___ 19 _~7]_ (,~6~'tF,) · f, 17597 .':,ok I~let 1>.il;e].hte Cc, mp;;u'~y ',f,iONTiiL¥ PRODUCTiO;~ (Non-Un it ) -0- il 11 ~ai D ~ E Pools b,b56 809 )cols ] L ,()N~(~TH T] 4-1,9.'!9 -0- 69 ,~74 .lbO, 19 4 IVATER -0- 1 1 (Non-Uni) 6~076 92 6,t68 FO-~--M !rTl ON GAS -0- 2- 2 576 1,072 1,648 DAYS PRODUCED :AD ING BAY 3,4:i9 8,955 494 15,811 19,980 IINTT Z,753 1.2,766 4,228 1,174 -0- 20,921. 22,571 31 29 60 31 50 28 "0- 102 164 DALLY ~.V~RAG!~ PRODJCi'iON OIL -0- 6 6 81S 191 1006 1353 429 1.04 -0- 2784 W ATEI{ GAS 1 1 1 1 196 19 · '3 37 i99. 56 70 2 i 2 111 412 299 ]41 18 42 -0- -0- 498 805; I-' f .c) ".5 __ -0 86 ? 7"/ -0 -0- 182 23 194 256 3.9 :]{)5 ' .-,: .((; ............... ~0.- ]. ~ 356 1,356 -0- ]6,556 76 356 -O- 'l.I) ~ 5!iG 48,6 $9 :b :',' £.'f f'..~'l'.'% L !.'L~5 t iJS -0- 8 19.4 1.6 7.5 7.6 41.. ] 14.6 · ,7 ',:. '.'.'i 1.1" EXHIBIT H NORTH TRADING BAY UNIT "G"AND HEMLOCK FORMATIONS · GAS ~ND OIL RELATIVE PERMEABI LILIES To accompany application for a pressure maintenance project. _1 t.O O, 0.4 0.2-- ,0 0 2o 4o 60 8o I00 GAS SATURATION- FERCENT HYDROCARBON PORE VOLUME AVERAGED LABORATORY DATA l.O 08 EXHIBIT I NORTH TRADING BAY UNIT "G"AND HEMLOCK FORMATIONS OIL AND WATER PSEUDO RELATIVE PERMEABILITIES To acoompany application for a pressure maintenance project. 0.6 0.4 0.2 -;- i--., - - :-, . ! :. ' -]__; ...... L . ii~i~S..-IiC il,r_E!!lL'Eii!i fiii-J_L_[ ii% .L ~-i l: .... ~._:_..i ~ ~':_i.. ,..L__;~ i'. L Ii I__ _'_. ::._~L_, _,i ,I l_l_l_.L_t 2 _t~i AI. 2__L_~ .... ', =, 'f, ' '-~ ~ 11. ,-','-~-¥'-l'r-,-,-' F-y, r ~-%' t' i--J'-F ..... ~ ..... ~j .~/? [ · ' ;- -i-', '~'T F'} .... F; '}'f-T'-~-I'--r--r--~ .... '~i'-i'-Tiy_--t'-i- l/ ...... ', 7-t ..... F ..... r-"F-'f .... ~' F;"'I '--T-";-' ',', ; , 7" , , ' '. · ~ I ! ', ~ I · i LI' ' ' , ' ' ' . ' ' i' 'ri-",'~'N. ....... ,' ', ~-I'-!"11 4"i-:-L'-_'~-i~--F-. F't-'J-+"-F( ........ !"'t-J-t-(.'"[--' F-': ', :'!'1 ....... L [' ; .... i ?"[-! .... J l ": --,-T" i" i-I-;-~-'!"~,~,;.~[J'!-'-'['"'l ...... i-' '["l'"-r-T"¥ ..... ·" .... ";. ..... ~:~ ,~ .............. . i :.. ~.' l ............. -j~ ,--, ,l -~ ........ j.l'-' ............ ..~.~.i j .~ -] .~1 ..... i- i ................. .q i-1-- .i'-. ........... , 'i~! +,,-,--I ................. ~L,i,:,' : !i~i'iiii:i~'j L~-~, 7~,:~jq ............ t~['t~¢!, : .... *-Y-I ....... "- ~'-i 'r F'Ti-"T-I""F .... ~ "mF',r' ': ...... ~"'-'7 .... I .... I" ~ 7-1-"F'l ..... F; .............. F/'""r 'i % ~ ~, ~ "t"rl .... i ! ..... rr-'~'F~-i--'~ ........ [-- '~t:! 21-, ..... r ,"-n-"N-r~ .... ~1"'--?-'!'-'?-"-I .... [ T"' r .............. ~'q- -r -~'-" n'l .................... ~ ................................ , ~' ' t ~r--~ % , ~- i , : ~ ~- , ~ i, , H ...... i'--' ...... j.--t-=-~.~-~* ...... ~ ........ ~ ...... t .............. ;t.!.._j ...... -~---.1.-i ...... r-*---~ .... ~---~' ......... · 2 ........... ' ....... l ....... ~- I · '.-~ i L .............. J ............. · '! '~r "]- *-IF --I .- -: I ' ............................ !-.i ......... :....: .......... ] ....... : ....... I ........ il-1- ..... ti-'!,*'1 ~"i ,Z'" '[--i"-I-F ......... [-"i'" '[-]-"]- % Z %~.2 ~ ~ ~'",'~J-I-i-'F!"' hi" ~' 1-i-'1 --'I- , j ~ j F I .iL I :, ' : ill I I l I ~[ l}'J[ 'Il J J ............. ~ ................. : I ~ I ~ ~' ' I ' ~ j~ll[~l~'[iJ--'l: I''ll'''--[.............. ?'i"~+.........l'~'J'''-'b...... ~"_I-'I-!........ l...l!,il-. IiI: ' !yll i.i[~ i~. ii~.i '-- ~i ~ lilill[ .."i] l ifF'il I .ii'liT ].ll-] ij i-~;.i}ll';,.i-~- i-" _--;.-.ii'ljl~ ii[il ,~ 2~ ~. i.I + ~l ~. ~ i'iN-i,Y~ .... [-"r' i-!---:-,---[ ............... _, ................. :...,..., .... i..lt_r_., ...... +, .......... ............ ,'"H-! ....... i"t .¥l..-:__~...ll-.l.I ............. ~ ....... 1 ........................ ] 'E ............ -'t'--r ....... :-. ~.r.t.l. ...... , _~ .......... ZT'TT'I" ...... F-, .... -t- ................ _: ............... : ...........-J :-%-f ...... ..... ...... : .......... ' .....t ' ' ' ! t '", ......... l ....... : .~ ~ --.~ .......... i..,[ ~ :-4 ' ~'- [' t ..~ .... ~ I J ' t ~ ~- ~ "!---~"-+- r t ......~ .............. ;' ............. ........ ; ~ , ! ~ ........ ~ ~"[-'"] . '[ I i I , I ; ] , i , , ; I ~J i i ~ J i i, :,'' ' ....... F ................. ~ .... 1 ! ...... J-'l'-/'"[ ..... I ........ ," 0 20 40 60 80 tO0 WATER SATURATION- PER CENT TOTAL PORE VOLUME EXHI BIT J NORTH TRADING BAY UNIT "G"AND HEMLOCK FORMATIONS OIL FORMATION VOLUME FACTOR AN D OIL VISCOSITY versus PRESSURE To accompany application for a pressure maintenance project 1.80 o z o o 1000 2000 3000 4000 PRESSURE- Pounds per square ~nchgauge 5000 1.60 1.40 1.20 i.OO ~ 0.60 EXHIB IT K NORTH TRADING BAY UNIT "G"AND HEMLOCK FORMATIONS SOLUTION GAS-OIL PATIO versus PRESSURE To accompany application for a pressure maintenance project z I000 2000 3O00 4O0O 5O00 PRESSURE - Pounds per SCluore inch gouge EXHI BIT L NORTH TRADING BAY UNIT "G"AND HEMLOCK FORMATIONS WELL STATIC PRE SSU R E S versus FIELD CUMULATIVE OIL PRODUCTION To occompeny oppliootion for e pressure mointenonce ,pro?ct II I ~ : .... , ., _ , _, ., ..... : ......... ~.--~ _ ~ ___,__J _',___~'. I ' -- r :- ;- ~ ~ ~-; : ; "r'.-'-:-: I" ' :-;-:-:-7-r-r ~ ~-~-'i~-~- ~7~ .... ;4~--~-~-~'-~'- ; f-i--:'-~ . . . ~-- -- ..... ~-, ' ; .... , ....' ........ ~-'-:-~ r~ ~--:--~-,-: .... :-- ~- ~-~--~4-~ ~ ~_: ~ ...... i ;_~.: .~ .~ {: -:-:_ ~-~ ~--_~.~_L~4 : ~_-~ ~-'-~'~-~ ~ ~- --r .... ~ '~ '- '--; ': ~-:~ ~ -: -'- ~'-;-~ ~--r-~-~=-~:--~-~ -~-ff-;--~-t~F __c~ ~ ; i i / ~ ' I;, ~ ' ' ' ~ ~ Ill l~ I I i i ~ : ; J i ' ";- F'; ....... ' ~-"-' ...... ~ ' -7'-~-~;~7--- ~'~~ i ~ .... : . - : - -~ ,- - · r '-~- · , .... r- ~' ~-"~ ~ -~-~ ~- i-~- ,-~ ~ , , ~ ; ; ,~ ',: : '~ : i ' I ~ ; , ; ~ : , !~ ~ ', i ! ~%%~ rtl;- ~ ~ l ' ;-?'-I-[- ~ --r- ~ ~ ~ ~ ; ~ i '' ' ' ' ' ' ......... : ' ' - ~ ' ~ o o I 2 5 4 5 FIELD CUMULATIVE OIL P~DUCTION- Million RT 115' Above MLLW EXHIBIT M "' NORTH TRADING BAY UNIT "G"AND HEMLOCK FORMATIONS PROPOSED WATER INdECTOR S-4 SCHEMATIC OOMPLETIO N To accompany applicatic~ for a pressure maintenance p~ject O! 13-3/8" Cemented to Surface with 1400 SAX Pressure. Test Casing to 1500 PSIG · Hydraulic Packer at 10,090-+' Squeeze and Test if Necessary-_ Perforate in Interval 10,126'-10,337' Mandrel and N - Ntppl Squeeze and Test if Necessa Permanent Packer at 10,345' . ~ , , , Perforate in Interval 10,356'-10,592' 9-5/8" Cemented with 1050 SAX , , \\\\\\\\\\\\\\\\\ \\~\\\x\\x- 40' 13-3/8" J-55 61# Casing at 2132' 4-1/2" N-80 12.6# Tubing G Producing at Hemlock at 10,354' ~Base Hemlock at 10.683' 9-5/8" P-110 & N-80 47~ Casing at 10,744'
