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• • REC fi Post Office Box 244027 Anchorage,AK 99524-4027 � ryry Hilcorp Alaska,LLC JUL L 3 0 L Oqq! 3 3800 Centerpoint Drive Suite 100 OGCCAnchorage,AK 99503 Phone: 907/777-8300 July 29, 2015 Fax: 907/777.-8301 SCA LE° AUG 2 9 291 Commissioner Cathy Foerster Alaska Oil & Gas Conservation Commission 333 West 7th Avenue, Suite 100 Anchorage, AK 99501 ! p5'_ / 07 � - 33 Re: Duck Island Unit Well Renaming Request Dear Commissioner Foerster, Hilcorp Alaska, LLC (HAK) requests a change to the naming convention of Duck Island Unit wells to remove the unused suffixes at the end of each well name. Well names currently include a forward slash "I" followed by an obsolete bottom hole location designator. HAK would like to retain the well number as well as the "A, B, C...." sidetrack designations but remove the "/suffix". For example, "DUCK IS UNIT SDI 1-09A/L21" would become "DUCK IS UNIT SDI 1-09A". The attached spreadsheet includes original and new names for all Duck Island wells. While performing the review of Duck Island well names, HAK found a single well, "DUCK IS UNIT SDI 4-20/M35" (PTD # 1861730), that should also be modified to include an "A" label to reflect the fact that the well is a sidetrack from the original "DUCK IS UNIT SDI 4-20/T34" (PTD # 1861500). The original wellbore, abandoned 10/13/1986, was sidetracked to a new bottom hole location completed on 9/9/1987. This well appears to be one of the first sidetracks performed at Endicott. While the bottom hole code was changed, no letter was added to reflect the sidetrack. "DUCK IS UNIT SDI 4-20A" is also included on the attached spreadsheet. Sincerely, Wyatt Rivard Well Integrity Engineer Hilcorp Alaska, LLC CC Dave Roby Victoria Loepp Orig i New API_WeIINo PermitNumber WeliName WeIlNumber WeIlNumber 50029218010000 1880370 DUCK IS UNIT MPI 1-01/119 1-01 50029226010000 1951500 DUCK IS UNIT MPI 1-03/P16 1-03 50029216050000 1861060 DUCK IS UNIT MPI 1-05/020 1-05 50029217430000 1870810 DUCK IS UNIT MPI 1-09/118 1-09 50029217430100 1970290 DUCK IS UNIT MPI 1-09A/L21 1-09A 50029221070000 1901570 DUCK IS UNIT MPI 1-11/SN4 1-11 50029223610000 1930560 DUCK IS UNIT MPI 1-15/P25 1-15 50029221000000 1901500 DUCK IS UNIT MPI 1-17/SN2 1-17 50029221000100 1961990 DUCK IS UNIT MPI 1-17A/117 1-17A 50029225690000 1950930 DUCK IS UNIT MPI 1-19/118 1-19 50029220050000 1900020 DUCK IS UNIT MPI 1-21/K25 1-21 50029225100000 1941280 DUCK IS UNIT MPI 1-23/015 1-23 50029217220000 1870420 DUCK IS UNIT MPI 1-25/N22 1-25 50029217220100 1970750 DUCK IS UNIT MPI 1-25A/K22 1-25A 50029216930000 1870090 DUCK IS UNIT MPI 1-27/P20 1-27 50029216690000 1861810 DUCK IS UNIT MPI 1-29/M25 1-29 50029225620000 1950720 DUCK IS UNIT MPI 1-31/M21 1-31 50029225770000 1951070 DUCK IS UNIT MPI 1-33/M23 1-33 50029225770100 1980870 DUCK IS UNIT MPI 1-33A/L24 1-33A 50029225770200 1982550 DUCK IS UNIT MPI 1-33B/L24 1-33B 50029225770300 2050040 DUCK IS UNIT MPI 1-33C/M24XX 1-33CXX 50029216720000 1861840 DUCK IS UNIT MPI 1-35/025 1-35 50029217480000 1870900 DUCK IS UNIT MPI 1-37/P24 1-37 50029218270000 1880630 DUCK IS UNIT MPI 1-39/P17 1-39 50029218270100 2061870 DUCK IS UNIT MPI 1-39A/N-16 1-39A 50029217130000 1870320 DUCK IS UNIT MPI 1-41/023 1-41 50029218640000 1881050 DUCK IS UNIT MPI 1-43/P26 1-43 50029219910000 1891240 DUCK IS UNIT MPI 1-45/Q26 1-45 50029216250000 1861310 DUCK IS UNIT MPI 1-47/Q21 1-47 50029216250100 1972030 DUCK IS UNIT MPI 1-47A/M20 1-47A 50029218410000 1880780 DUCK IS UNIT MPI 1-49/P21 1-49 50029223040000 1921190 DUCK IS UNIT MPI 1-51/V20 1-51 50029225010000 1941120 DUCK IS UNIT MPI 1-53/Q20 1-53 50029217880000 1880210 DUCK IS UNIT MPI 1-55/R25 1-55 50029218730000 1881140 DUCK IS UNIT MPI 1-57/R23 1-57 50029226440000 1960220 DUCK IS UNIT MPI 1-59/024 1-59 50029225200000 1941420 DUCK IS UNIT MPI 1-61/Q20 1-61 50029219050000 1890060 DUCK IS UNIT MPI 1-63/T22 1-63 50029226270000 1951880 DUCK IS UNIT MPI 1-65/N25 1-65 50029226270100 2032120 DUCK IS UNIT MPI 1-65A/N27 1-65A 50029219850000 1891140 DUCK IS UNIT MPI 1-67/T20 1-67 50029220200000 1900290 DUCK IS UNIT MPI 1-69/V19 1-69 50029215680000 1860630 DUCK IS UNIT MPI 2-02/P18 2-02 50029215850000 1860820 DUCK IS UNIT MPI 2-04/M19 2-04 50029216990000 1870180 DUCK IS UNIT MPI 2-06/122 2-06 50029217710000 1880040 DUCK IS UNIT MPI 2-08/K16 2-08 50029223020000 1921170 DUCK IS UNIT MPI 2-12/Q16 2-12 50029216390000 1861490 DUCK IS UNIT MPI 2-14/016 2-14 50029218850000 1881340 DUCK IS UNIT MPI 2-16/M16 2-16 50029220320000 1900430 DUCK IS UNIT MPI 2-18/L16 2-18 50029220480000 1900600 DUCK IS UNIT MPI 2-20/115 2-20 50029219310000 1890340 DUCK IS UNIT MPI 2-22/L14 2-22 XHVZE Pages NOT Scanned in this Well History File This page identifies those items that were not scanned during the initial scanning project. They are available in the original file and viewable by direct inspection. i ~ ~-""~/~)2 File Number of Well History File PAGES TO DELETE RESCAN Complete Color items - Pages' Grayscale, halftones, pictures, graphs, charts - Poor Quality Original- Pages: [] Other- Pages: DIGITAL DATA [] Diskettes, No. [] Other, No/Type OVERSIZED [] Logs of various kinds [] Other COMMENTS' Scanned by:~Dianna TO RE-SCAN Vincent Nathan Lowell Notes: Re-Scanned by: Bevedy Dianna Vincent Nathan Lowell Date: /si ANNULAR INJECTION DATA ENTRY SCREEN Asset E[tdJ.c.Qtl. .................................... Rig Name D.Qy.q.I~..1.~ .................................. Inj Well Name .I..-.:~.3J. lYI:~:~ ................................. Sur Csg Dep ~.0..'[.3. ................ Cumulative Data Well Total Mud/Ctg Wash Legal Desc 3;~IZ'.bI~.I...;~.I..~.~.'.WELo..S.e~..31~ZJ.?.bL.B.1.6E .................................. Research ~= ....................................................................................................................... B.[.~.~be.~.ir)..19.~5..:..13.Q.a~.~.e ............................................. ~ Permit End .......~.~.3.1/.~t.5. ..... .. Permit Start ........ .~.~J.:~. ....... *Permit Expires in 30 Days or Less* Completion Formation .intermittant Final FlUids, Fluids Freeze Freeze · ~32 ;05 So~e Dated Well Injecli~ -65/N-25 12/13/95 -65/N-25 12/14/95 -65/N-25 12/15/95 -65/N-25 12/16/95 99O RigWash Daily 'Data ~ Fomalion Freeze Freeze Daly .............................................................................................................. : .......................................................................................... :i";i~'~'~ .......................... 732 605 990 3BPM@ 1100PSI 3 BPM @ 900 PSI 3BPM@ 1100PSI 3 BPM @ 1200 PSI ................................................. ~,, §i~...~,....~.~i~.5...i~§i .................................................................. 3 BPM @ 1200 PSI ........................................... §'"§'~'Ei'"'~'""~-~i~"'~'§i .......................................................... _ hare. d . erv ces rilling 900 East Benson Boulevard, MB 8-1 - Anchorage, Alaska 99508 (907) 561-5111 Fax: (907) 564-5193 December 14, 1998 Wendy Mahan Natural Resource Manager Alaska Oil & Gas Conservation Commission 3001 Porcupine Dr. Anchorage, AK 99501-3192 Re: Annular Disposal Information Request Dear Ms. Mahan: RECEIVED DEC 14 1998 Naska 0il & Gas Cons. Commission Anchorage On October 28, 1998 you requested an update from Shared Service Drilling regarding Annular Disposal Records from July 25, 1995 through present time. We compared your list with our records and are able to provide you with the following data: · Individual Annular DiSposal Logs from the SSD database which coincide with the approved wells on your attached AOGCC Annular Log. The.SSD records are provided to you in the same order as listed on your log. · There were some wells on your list which were not injected into. These wells are identified as follows: Endicott wells 1-03/P-16, 1-65AV-25, 1-59/0-24 · EXploration well Pete's Wicked #1 Milne Point wells E-22, E-23, F-01, L-16, J-19, L-25, F-30, L-21, K-38, NMP #1 &//2, K-05, K-02, 1t-07, K-25, K-37, E-17, F-21, K-30, K-34, K-21i, F-66, K-06, K-54, K-33, F-49i, K-18 · PBU Wells E-38, 18-34, 15-42, S-29A, 15-46, B-36, 15-43, 11-38 · The reason many of these annuli were not used is because the waste materials generated from these wells were injected into other approved annuli. Hopefully the injection logs submitted with this letter will clarify this. In addition, please note that our records show: · The wells listed above in italics were permitted but not used for annular disposal. · The wells listed above in BOLD were not permitted for annular disposal. Wells drilled after June 6, 1996 were required by SSD procedure to be permitted with a Sundry ' Approval (10-403) form. Our records show that no Sundry Approval for Annular Disposal was filed for these wells. Wells drilled between July 25, 1995 and June 6, 1996 were automatically approved for annular disposal with the Permit to Drill. We also provide you with a cumulative report from our database of records from July 25, 1995 through the present. From those records, we show the following wells not listed on your report were used for annular disposal: ~Annular Disposal Letter 12/14/98 ! · Endicott wells 1-23/O-15, 1-61/Q-20, 2-40/S-22 EXploration well Sourdough #3 - ~,_. o o ~q Mi~e Point wells F-06, H-05, H-06, J-13, L-24 - ~-~ o PBUwells 18-30, 18-31, 14~,~-43, E-34, E-36, G-04A,~dS-33 ~dividu~ logs ~e provided to you tof these ~ogs as wen. · Finally, our records show that the B-24 outer annulus was left open (see attached correspondence) Thank you for the opportunity to provide clarity to these recordS. If I can be of any further assistance please do not hesitate to contact me at 564-5183, or Karen Thomas, Environmental Advisor at 564-4305. Sincerely, Fritz P. Gunkel Shared Service Drilling Manager FPOmM cc: Dave Wallace - HSE Manager (w/out attachments) RECEIVED Oil-& Gas Cons. Oomm'tssi¢ Anchorago .~cANN~D NOV 1 ~ ~00~ =har¢£d SerVice Drilling t. nn~ar Injection Volumes luly 25, 199~5 until December 1998 :umulative Report Surface Casing Inj Well Depth ig ~tdicott ~yon 15 )yon 15 Cum Mud Legal Desc Cum Total & Ctgs Cum Rig Cum Compl Cum Form Cum Interm Cum Final Disposal Period Annulus Wash Fluids Fluids Freeze , . Freeze Stad End Slatqs · 992 120 12/5/95 12/5/96 Open 1,160 ' 200 120 9/30/95 12/31/95 Open 150 8/31/95 12/31/95 Broached 1-19/I,-18 5000 Sec. 36. T12N. R16E 8,960 7,848 1-23/O-15 4246 2020'FNL, 2087'FEW, SEC.36,T12N,R16E 32,084 30,604 )yon 15 1-33/M-23 5013 3217'NSL, 2114'WEL. Sec 36,T12N, R16E 9,879 9.729 )yon 15 1-61/Q-20 4236 3075'NSL, 2207'WEL, Sec 13,T12N, R16E 25.228 21,379 2 613 1,176 60 12/5/95 12/5/96 Open . ly0n 15 2-40/S-22 4531 2020'FNL. 2289'FEL, Sec 36,T12N, R16E 31,195 29,952 1,063 120 60 7/25/95 12/31/95 Open )A .... ~yon 14 15-47 3515 3648'NSL, 4956'WEL, Sec 22,T11N. R14E 3,002 903 2,009 90 11/7/95 12/31/95 Open ,yon 14 DS 15-45 3829 4749' NSL 5180' WEL Sec 22 T11N 1 882 1 697 134 51 4/4/96 4/4/97 BroaChed .......... ~ ................................................ ~ ................... : ........... .'. ....................... L ........................................... .'. .................................................... '. ..................................................................................................................................................................................................................................................................................................................................................................................................................................... ..yo.n..!4 . DS 15.48 . 3548 Sec, 22, T11N, R14E 3,385 216 820 2,283 66 12/21/95 12/21/96 Open yon 14 DS 15-49 3667 4676' NSL, 5165' WEL, Sec. 22, T11N, 4,669 1,559 1,141 1,904 65 2/21/96 2/21/97 Open ~.0,,?..,.~ ...................................... !,,~,:,,,3,.,,2., ........................................ ,,3,,?,, ............................... ..~3...~"~.3~"2.";."N...."s-L"'~-.~.!.~.~E..~..L~s"~..e.~?.?".~.~.T..!~.1~N-~-R.1LE-.-: ................. ..3,.2!,.,!, .................................. !~,.,8,,~.~ .................................. _2_,o,.,o. .......................... ??_ ................................................................... ? ............ F_2,,ff,~ ................. ?_?/.~.5,. ................... ..o_,~, ~?,~,.,,9,,, ................................... !.~:,.3..3. ............................... ,?.?~ ........................... .~?~..N.~.s`..~.L~.~`~L~w...`~E~....L~`~s.~`_2~.~.T~.~!~1..~N~"~`~..R.~.!iE"~ ....................................... ~.~,,2,,..!,,~, ........................... ,, ,2, , , ~. .o, ,. ,57' ............................... ,,,3,,,,?,,,,5, .................................................................................................................................................. ~,,,o,,, ............................. !.,,2,,,..o_ .............. ~L2.,,~.,/,.~, ...................... .!.~.,3!/,~ ....................... ,9,_p.~_n.. ................ 3ors 18E 12-35 3543 348'NSL, 705'WEL, Sec 18,T10N, R14E 3,723 3,436 137 150 9/1/95 12/31/95 Open )ors 18E 12-36 3452 63'FSL, 899'FEL, Sec 18,T10N, R15E 4,002 1,961 50 1,871 120 10/13/95 12/31/95 Open )ors 18E 13-36 3431 1585'NSL, 5187'WEL, Sec 13,T10N, R14E 4,137 3,523 464 150 10/26/95 12/31/95 Open ~ors 18E 14-44 3288 2829'NSL, 1617'WEL, Sec 9,T10N, R14E 3,974 2,319 1,535 120 8/17/95 12/31/95 Open )loration ,I 4 Sourdough #3 4236 2245'FSL, 5067' FEL, Sec. 29, TgN, R24E 5,786 4,630 1,156 1/26/96 1/26/97 Closed le 'E MPK- 17 3508 3648'NSL,2100'WEL, Sec.03,T12NR 11E 19,608 18,538 285 685 100 4/18/96 4/18/97 Open ors 22E MPC-23 4941 1038 NSL 2404 WEL, Sec 10,T13N. 2,060 1,800 130 .o..r_s._.2.2_E.. ................ .M..p?...-..2_5. ...................... _8__5.9..5._ .................. _!.1.4_~31_F_N.L_,_24..3_6_'F.~_WL:_S_.e.c__10.~,T 137, R !_O_E_ ..... 1.,9_._0._5. ............... _! ,46.___5_ ............ _320 .............. ors 22E MPC-26 4704 1086 NSL, 2419 WEL, Sec 10,T13N, 5,228 4,483 555 130 1/25/96 1/25/97 Open 140 1/5/96 1/5/97 Open 190 12/19/95 12/19/96 Open ors 22E MPC-28 5405 Sec 10 T13N R10E 425 350 75 2/15/96 2/15/97 Open Shar~.;d oervice DHIling Ann[dar InjeCtion Volumes July 25, 199~ until December 1998 Cumulative Report Rig Inj Well ~labors 22E MPF-06 ~labors 22E MPF-14 ~labors 22E MPF-70 ~labors 22E MpH.05' Surface Casing Cum Mud Cum Rig Cum Compl Cum Form Cum Interm,, Cum Final Disposal Period Annulus Depth Lega! Desc Cum Total & Ctgs Wash Fluids Fluids Freeze ...... Freeze start End, Status 8766 , Sec 06,T1'3N, R10E 1,927 1,731, 196 1/25/96 1/25/97 Open 6690 S.eCi.?6~T13N, R10E. UM .... 18,717 17,107 1,270 . 340 6/3/96 6/3/97 open 7919 2189'NSL, 2591'WEL, Sec 6,T13N, R10E 19,775 18,794 735 190 56 6/17/96 6/17/97 Open 5335 2882'NSL, 4028'WEL, Sec 34,T13N, R10E 8,283 7,711 382 190 8/19/95 12/31/95 Open ~labors 22E MPH-06 7304 2824'NSL, 4044'WEL, Sec 34,T13N, R 10E 8,515 8,335 180 8/5/95 12/31/95 Open ~labors 22E MPI-07 2680 2339'NSL, 3906'WEL, Sec 33,T13N, R10E 1,680 1,280 250 80 70 9/21/95 12/31/95 .Open 4abors 22E MPJ-13 2835 2319'NSL, 3179'WEL, Sec 28,T13N, R10E 14,127 13,292 645 60 130 10/17/95 12/31/95 Open ~abors 22E MPJ-16 3112 2317'NSL, 3336'WEL, Sec 28,T13N, R10E 985 915 70 11/12/95 12/31/95 . Open labors 27E B-24 4080 SeC 18,T13N, R11E UM 1,468 1,396 72 . 1/25/96 1/25/97 Open labors 27E MPF-25 3405 1857'NSL 2696'WEL, Sec 6,T13N, RIOE ' 9,89'7 9,357 250 225 65 12/26/95 12/26/96 Open labors 27E MPF-37 6621 1931'NSL 2643'WEL, Sec 6,T13N, R10E 7,032 6,887 70 75 7/25/95 12/31/95 Open !ab.(~.r.s......27.E ................... .M...p.....F.:~ .......................... ~6...! .............................. !.9.~ .4.1N.~!:....2.~'3!..'.W...E..L..,.....s...e(~...6..,..~-?!~..,....R...!...O.!~' .................................... ~.,.~3...2' .................................. 9.,..!.5...7.. .......................................................................................................................................................................................................................................................... ..7..5.. ................. !.76!9..5 .................... !.~3..!.!9..5.. ............................ .°..P.e..n. .............. labors 27E MPF-45 6678 1979'NSL, 2608'WEL, Sec 6,T13N,'R10E 17,562 17,381 181 7/31/95 12/31/95 ' Open labors 27E MPF;53 675O 2028'NSL 2572'WEL, Sec 6,T13N, R10E 6,051 5,671 165 75 60 80 8/19/95 12/31/95 Open '.~.b.o.~:~..~?:.~ ........................ M.....P...F.~.! ............................... 6..5..~.~. ................................. ..2..~.~-7~.s...L........5-.2.?...E?..i...s.~...3..!..~...T-!?........R...?`.°...E.. ................................... 6.:..7.3. r2.. ................................ ~.,..~ .................................................................................................................................................................................................... .7~i ............ ~.!.!~ .................... !.~?_.5.. ............. _.o_p..e.?. ............. abors 27E MPF-62 6059 2141'NSL 2627'WEL, Sec 6,T13N, R10E 386 316 70 10/13/95 12/31/95 Open abors 27E MPF-69 5772 2125'NSL 2502'WEL, Sec 6,T13N, R10E 9,740 91665 . 75 8/31/95 12/31/95 Open abors 27E MPF-78 7085 2237'NSL 2555'WEL, Sec 6,T13N, R10E 8,476 7,456 40 775 65 140 9/12/95 12/31/95 Open abors 27E MPL-24 6515 3654'NSL 5180'WEL, Sec 8,T13N, R10E 6,790 4,900 1,320 165 335 70 11/27/95 12/31/95 Open 'OA ~yon 9 D-30 3456' 3625' NSL, 1066' WEL, SEC. 23, T11N, 5,261 2,811 1,275 1,035 140 1/31/96 1/31/97 Open )yon 9 D-31 3215 SEC. 26, T11N, R13E 150 150 4/20/96. 4/10/97 Open )yon 9 D-33 3222 2965' NSL, 1067' WEL, SEC. 23, .T11N, 4,661 2,425 2,106 130 2/21/96 2/21/97 Open ~bors 18E S-43 3121' 4211'NSL,4503'WEL,SEC35,T12N,R12E 5,943 2,636 1,716 1,511 80 5/7/97 · 5/7/98 OPEN Shared Sei~vice Dr. illing Ann'0ilm'r ~njection Volumes July 25, 1995. until December 1998 Cumulative Report Sudace Casing Rig Inj Well Depth Nabors 28E B-33 3504' Nabors 28E E-34 3664 Nabors 28E E-36 3648 ,, Cum Mud Legal Desc ,~ Cu,m T0t~,! & Ctgs 969'SNL, 1898'EWL, Sec 31, T11N, R14E 3,974 2,842 168'SNL, 500'WEL, Sec 6, T11N, R14E 9,656 7,228 1706'SNL, 822'WEL, Sec 6,T11N, R 14E 9,271 4,417 Cum Rig Cum Compl Cum Form Cum Interm Cum Final Disposal Period Annulus Wash Fluids Fluids Freeze Freeze Start End, Status 857' 195 80 5/1/96 12/31/96 Broached 1,420 858 40 110 8/23/95 12/31/95 Open 1,293 3,096 365 100 7/25/95 12/31/95 Open 374 80 9/16/95 12/31/95 Open Nabors 28E E-37 3810 3391'NSL, 881'WEL, Sec 6,T11N, R14E 4,695 4,241 ..................................................................................... -... ........................................... -- ....................... ~ ........... Nabors 28E E-39 3638 3358'NsL 501'WEL, Sec 6,T11N, R14E 2,250 928 ' 220 1,022 80 8/28/95 12/31/95 Open Nabors 28E G-04A 3509 2917'NSL 1974'WEL, Sec 12,T11N, R13E 5,937 1,798 1,824 2,315 10/20/95 12/31/95 O)en Nal~ors2~E G-21 350'9 2911'NSL 2368'WEL Sec 12T11N R14E 11 430 3956 3,072 4,270 70 '62 9/8/95 12/31/95 O:)en Nab°rs 2.8~ ....... S.'.2,4 ....................... .2,7.~0 .......... !63.3'.S...~..L....4..~8'..w.....E.~-,....S.e...c...:~5..,T..!2..N.,.....F~..!.~.~ .......................... 2...0.,.2...(? .............................. !.!,..~7.:~ ............... ~.,..!.7.7. ......................... .5..~.'~.5..! ~..7..5. ........................... ~Sq ....12/°(,$ ........... 1.2!9!.9..q ....... : .............. ..°...?.~r~ ............ Nabors 28E S-33 2958 1639'SNL. 1487'WEL, Sec 35,T12N, R12E 18,014 6,613 2,431 8,392 270 308 12/1/95 12/1/96 O~en Nabors 28E S-41 3331 4152' NSL 4504' WEL, Sec 35,T12N, 8,062 4,159 2,034 1,754 115 2/8/96 2/8/97 O ~en ~labors 28E S-42 3077 Sec 35, T12N, R12E 168 100 68 3/13/96 3/13/97 O)en qabors2ES H-35 3157 4535'NSL 1266'WEL Sec21 T11N R13E 4,860 3,725 555 480 20 80 10/26/95 · 12/31/95 O3en ~labors 2ES H-36 3550 4478'NSL, 1265'WEL, Sec 21,T11N, R13E 1,452 857 100 410 85 10/26/95 12/31/95 O~en Page 3 h¢sred e lces TO: Blair Wondzell FROM: Chris West DATE: October 27, 1995 SUBJECT: MPB-24 Well Suspension APl # 50-029-22642 Blair; Please find attached a copy of the Form 10-403 to temporarily suspend this well as per AOGCC 20- AAC 25.110. As discussed this morning we propose setting three plugs in this well as detailed in the attached form. This will allow us to retain the wellbore for potential future sidetrack or service well use. We would like to keep the well's 9-5/8" x 7" annulus available for the injection of liquid 'wastes. There are no other well annulii on this pad for injection. The annulus for MPB-24 was approved for injection as part of the permit dated 25 January 1996. The annulus will be freeze protected before moving the rig. . Thank you for your help in this matter. Please call me if I may be of· any assistance. Chris West Drilling Operations Engineer Nabors 27E (907).564-5089 NOV I 2DO2 THE MATERIAL UNDER THIS COVER HAS BEEN MICROFILMED ON OR BEFORE JANUARY O3, 2001 M E PL A T'E I.A L U N TH IS M ARK W D E E R R C-.LORIhMFILM.DOC ' ? REPORT State cf Alaska 0iL & GA~ CONSERVATION COMMISSION Review the well file, and-cc=men: on plugging, well head sca=us, and ;ocs=ion clearance - urcvfde loc. clear, code. , .~arksr 'pos= or plats Location Clearancs: Code Signed · o STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION Plugback, for, Side,~?~k'..., WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1. Status of Well Classification of Se'~¢b"'~'W~ll''' ii.,iii';il,i'-i;-~:.i;,.- [] Oil [] Gas I--] Suspended [] Abandoned [] Service 2. Name of Operator 7. Permit Number BP Exploration (Alaska) Inc. 95-107 398-186 3. Address 8. APl Number P.O. Box 196612, Anchorage, Alaska 99519-6612 50-029-22577 4. Location of well at surface ' ~~ 9. Unit or Lease Name 3217' NSL, 2114' WEL, SEC. 36, T12N, R16E, UM,~,~,~,,.~;z~A-f~t;;;;~l~ i Duck Island Unit/Endicott At top of productive interval ~ 10. Well Number 1849' NSL, 3671' EWL, SEC. 31, T12N, R17E, UPM .~ 1-33/M-23 At total depth . .. ' 11. Field and Pool 1685' NSL, 4102' EWL, SEC. 31, T12N, R17E, UPM Endicott Field / Endicott Pool 5. Elevation in feet (indicate KB, DF, etc.) 16. Lease Designation and Serial No. KBE = 56'I ADL312828 12. Date Spudded I 13. Date I.D. Reached ! 14. Date Comp., Susp., or Aband.ll 5. Water depth, i! offshore I16. No. of Completions 9/2/95 9/19/95 7/19/98 6 - 12' MSLI Zero i17. Total Depth (MD+TVD) 118. Plug Back Depth (MD+TVD)119. Directional Survey 120. Depth where SSSV set 121. Thickness of Permafrost 12425 10347 FTI 12314 10259 FTI []Yes [~NoI N/A MD I 1650' (Approx.) 22. Type Electric or Other Logs Run MWD, Gyro, DIL, MSFL, LDT, CNL, GR 23. CASING, LINER AND CEMENTING RECORD CASING SEq-I'ING DEPTH HOLE SIZE WT. PER FT. GRADE TOP BO-FrOM SIZE CEMENTING RECORD AMOUNT PULLED 30" Struct. Drive 40' 130' Driven 10-3/4" 45.5# L-80 42' 5013' 13-1/2" 795 sx Permafrost 'E', 600 sx Class 'G' 7-5/8" 29.7# USS-95 39' 12404' 9-7/8" 500 sx Class 'G' 24. Perforations open to Production (MD+TVD of Top and 25. TUBING RECORD Bottom and interval, size and number) S~ZE DEPTH SET (MD) PACKER SET (MD) None 4-1/2", 12.6#, 13Cr80 11198' 11110' MD TVD MD TVD 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED 11890' P&A #1 with 37 Bbls Class 'G', Sqzd 2000 psi 11816' P&A #2 with 10 Bbls Class 'G', Sqzd 1500 psi 11780' Kick Off Plug, 13 Bbls Class 'G' 27. PRODUCTION TESTD I C'_ I I I Date First Production I Method of Operation (Flowing, gas lift, etc.) V ! ~ I ~,~ [ I ~J ~ b Not on ProductionI N/A Date of Test Hours Tested PRODUCTION FOR OIL-BBL GAS-MCF WATER-BBL CHOKE SIZE IGAs-OIL RATIO TEST PERIOD I Flow Tubing Casing Pressure CALCULATED OIL-BBL GAS-MCF WATER-BBL OIL GRAVITY-APl (CORR) Press. 24-HOUR RATE 28. CORE DATA Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water. Submit core chips. Form 10-407 Rev. 07-01-80 Submit In Duplicate ,'9. Geologic Markers 30. Formation Tests Measured True Vertical Include interval tested, pressure data, all fluids Marker Name Depth Depth recovered and gravity, GOR, and time of each phase. BHRZ 11656' 9739' Kekiktuk 11671' 9751' K2A 11992' 10006' 31. List of Attachments Summary of Daily Drilling Reports 32. I hereby certify that the foregoing is true and correct to the best of my knowledge TerrieHubble Title Technical Assistant Ill Date 0'2~' 1 7' ~ 1-33/M-23 95-107 398-186 Prepared By Name/Number: Terrie Hubble, 564-4628 Well Number Permit No. / Approval NO. INSTRUCTIONS GENERAL: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. iTEM 1: Classification of Service Wells: Gas injection, water injection, steam injection, air injection, salt water disposal, water supply for injection, observation, injection for in-situ combustion. iTEM 5: Indicate which elevation is used as reference (where not otherwise shown) for depth measurements given in other spaces on this form and in any attachments. iTEM 16 AND 24: If this well is completed for separate production from more than one interval (multiple completion), so state in item 16, and in item 24 show the producing intervals for only the interval reported in item 27. Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval. ITEM 21: Indicate whether from ground level (GL) or other elevation (DF, KB, etc.). ITEM 23: Attached supplemental records for this well should show the details of any multiple stage cementing and the location of the cementing tool. iTEM ;2?: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut-In, Other-explain. iTEM ;28: If no cores taken, indicate 'none'. Form 10-407 Rev. 07-01-80 Facility End MPI Progress Report Well 1-33A/N-24 Page 1 Rig ~ DOyOt'l J~ Date 16 March 99 Date/Time 24 Jul 98 25 Jul 98 26 Jul 98 27 Jul 98 28 Jul 98 29 Jul 98 30 Jul 98 19:00-22:30 22:30-00:00 00:00-02:30 02:30-06:00 06:00-09:30 09:30-03:00 03:00-06:00 06:00-09:30 09:30-03:00 03:00-04:30 04:30-05:30 05:30-06:00 06:00-06:30 06:30-13:00 13:00-14:00 14:00-18:00 18:00-18:30 18:30-20:30 20:30-21:00 21:00-01:00 01:00-03:00 03:00-06:00 06:00-06:30 06:30-08:30 08:30-12:00 12:00-18:00 18:00-18:30 18:30-20:00 20:00-20:30 20:30-22:30 22:30-02:30 02:30-03:30 03:30-04:00 04:00-06:00 06:00-06:30 06:30-07:30 07:30-08:00 08:00-09:00 09:00-12:30 12:30-13:00 13:00-18:00 18:00-18:30 18:30-20:00 20:00-00:00 00:00-00:30 00:30-01:30 01:30-06:00 06:00-06:30 06:30-07:00 07:00-15:30 15:30-18:00 18:00-18:30 18:30-20:00 20:00-21:00 Duration 3-1/2 hr 1-1/2 hr 2-1/2 hr 3-1/2 hr 3-1/2 hr 17-1/2 hr 3hr 3-1/2 hr 17-1/2 hr 1-1/2 hr lhr 1/2 hr 1/2 hr 6-1/2 hr lhr 4hr 1/2 hr 2hr 1/2 hr 4hr 2hr 3hr 1/2 hr 2hr 3-1/2 hr 6hr 1/2 hr 1-1/2 hr 1/2 hr 2hr 4hr lhr 1/2hr 2hr 1/2 hr lhr 1/2 hr lhr 3-1/2 hr 1/2 hr 5hr 1/2 hr 1-1/2 hr 4hr 1/2hr lhr 4-1/2 hr 1/2 hr 1/2 hr 8-1/2 hr 2-1/2 hr 1/2hr 1-1/2 hr lhr Activity Rig moved 50.00 % Preloaded rig - 20.00 klb Rig moved 100.00 % Skid rig Rigged up Drillfloor / Derrick Held safety meeting Rigged up Drillfloor / Derrick Rigged up Drillfloor / Derrick Held safety meeting Removed Hanger plug Removed Xmas tree Rigged up BOP stack Held safety meeting Rigged up BOP stack Repaired BOP stack Tested BOP stack Held safety meeting Removed Hanger plug Installed Wear bushing Singled in drill pipe to 4000.0 ft Pulled Drillpipe in stands to 0.0 ft Singled in drill pipe to 4000.0 ft Held safety meeting Pulled Drillpipe in stands to 0.0 ft Made up BHA no. 1 R.I.H. to 8000.0 ft Held safety meeting R.I.H. to 11300.0 ft Circulated at 11300.0 ft Circulated at 11300.0 ft Pulled out of hole to 151.0 ft Pulled BHA Made up BHA no. 1 R.I.H. to 7500.0 ft Held safety meeting Serviced Block line Serviced Top drive R.I.H. to 11387.0 ft Logged hole with LWD: DIR/FE from 11387.0 ft to 11558.0 ft R.I.H. to 11760.0 ft Drilled cement to 11805.0 ft Held safety meeting Drilled cement to 11816.0 ft Pulled out of hole to 151.0 ft Pulled BHA Made up BHA no. 2 R.I.H. to 11750.0 ft Held safety meeting R.I.H. to 11814.0 ft Drilled to 11821.0 ft Pulled out of hole to 4769.0 ft Held safety meeting Pulled out of hole to 147.0 ft Pulled BHA Progress Report Facility End MPI Well 1-33A/N-24 Rig (null) Page 2 Date 16March99 Date/Time 21:00-22:00 22:00-02:30 31 Jul 98 02:30-03:00 03:00-05:00 05:00-06:00 06:00-06:30 06:30-09:00 09:00-10:30 10:30-12:00 12:00-16:30 16:30-17:30 17:30-18:00 18:00-18:30 18:30-06:00 01 Aug 98 06:00-06:30 06:30-18:00 18:00-18:30 18:30-02:00 02 Aug 98 02:00-05:00 05:00-06:00 06:00-06:30 06:30-12:30 12:30-13:30 13:30-15:00 15:00-18:00 18:00-18:30 18:30-20:00 20:00-21:00 21:00-22:30 22:30-23:30 23:30-06:00 03 Aug 98 06:00-06:30 06:30-07:00 07:00-07:30 07:30-08:00 08:00-13:00 13:00-13:30 13:30-16:00 16:00-18:00 18:00-18:30 18:30-23:00 23:00-23:30 23:30-00:30 04 Aug 98 00:30-04:30 04:30-05:30 05:30-06:00 06:00-06:30 06:30-11:00 11:00-11:30 11:30-12:00 12:00-18:00 18:00-18:30 18:30-06:00 05 Aug 98 06:00-06:30 Duration lhr 4-1/2 hr 1/2 hr 2hr lhr 1/2 hr 2-1/2 hr 1-1/2 hr 1-1/2 hr 4-1/2 hr lhr 1/2 hr 1/2 hr 11-1/2 hr 1/2 hr 11-1/2 hr 1/2 hr 7-1/2 hr 3hr lhr 1/2 hr 6hr lhr 1-1/2 hr 3hr 1/2 hr 1-1/2 hr lhr 1-1/2 hr lhr 6-1/2 hr 1/2 hr 1/2 hr 1/2 hr 1/2 hr 5hr 1/2 hr 2-1/2 hr 2hr 1/2 hr 4-1/2 hr 1/2 hr lhr 4hr lhr 1/2hr 1/2 hr 4-1/2 hr 1/2 hr 1/2 hr 6hr 1/2hr 11-1/2 hr 1/2hr Activity Made up BHA no. 3 R.I.H. to 11750.0 ft Circulated at 11750.0 ft Milled Casing at 11814.0 ft Pulled out of hole to 10000.0 ft Held safety meeting Pulled out of hole to 147.0 ft Pulled BHA Made up BHA no. 4 R.I.H. to 11730.0 ft Circulated at 11750.0 ft Drilled to 11833.0 ft Held safety meeting Drilled to 11955.0 ft Held safety meeting Drilled to 12055.0 ft Held safety meeting Drilled to 12132.0 ft Circulated at 12132.0 ft Pumped out of hole to 11750.0 ft Held safety meeting Pulled out of hole to 177.0 ft Pulled BHA Made up BHA no. 5 R.I.H. to 8000.0 ft Held safety meeting R.I.H. to 11760.0 ft Serviced Block line R.I.H. to 11820.0 ft Circulated at 11750.0 ft Pulled out of hole to 1100.0 ft Held safety meeting Pulled out of hole to 177.0 ft Pulled BHA Made up BHA no. 6 R.I.H. to 11750.0 ft Circulated at 11820.0 ft Milled Casing at 11820.0 ft Pulled out of hole to 8000.0 ft Held safety meeting Pulled out of hole to 178.0 ft Pulled BHA Retrieved Wear bushing Tested BOP stack Made up BHA no. 7 R.I.H. to 1500.0 ft Held safety meeting R.I.H. to 11790.0 ft Circulated at 11790.0 ft R.I.H. to 12132.0 ft Drilled to 12195.0 ft Held safety meeting Drilled to 12256.0 ft Held safety meeting STATE OF ALASKA ALAS;~'&..~-u._ AND GAS CONSERVATION COMMIS?---'-- REPORT t.,, SUNDRY WELL OPb,-,ATIONS ..,ons performed: Operation shutdown__ Stimulate__ Plugging__ Pull tubing__ Alter casing __ Repair well __ Perforate__ Other X 2. Name of Operator BP Exploration (Alaska) Inc. 3. Address P. O. Box 196612, Anchora_cle, Alaska 99519-6612 4. Location of well at surface 3217' NSL, 2114' WEL, Sec. 36, T12N, R16E At top of productive interval 1850' NSL, 1610' WEL, Sec. 36, T12N, R16E At effective depth 1710' NSL, 1241' WEL, Sec. 36, T12N, R16E At total depth 1683' NSL, 1188' WEL, Sec. 36, T12N, R16E 5. Type of Well: Development Exploratory __ Stratigraphic __ Service __ 6. Datum elevation (DF or KB) KBE = 56 feet 7. Unit or Properly name Duck Island Unit/Endicott 8. Well number 1-33/M-23 9. Permit number/approval number 95-107/398-186 10. APl number 50- 029-22577 11. Field/Pool Endicott Field/Endicott Pool 12. Present well condition summary Total depth: measured true vertical Effective depth: measured true vertical 12425 feet 10347 BKB feet 12314 feet 10259'BKB feet Plugs (measured) Junk (measured) Casing Length Size Cemented Structural Conductor 91' 30" Driven Surface 4974' 10 3/4 1725 c.f. Permafrost Intermediate 690 c.f. Class "G" Production 12365' 7 5/8" 559 c.f. Class "G" Liner Perforation depth: measured 12080'- 12100'; 12100'- 12120' (squeezed8/26/98) Measured depth True vertical depth BKB BKB 130' 130' 5013' 4390' 12404' 10329' true vertical (subsea) 10019'- 10034'; 10034'- 10050' (squeezed 8/26/98) Tubing (size, grade, and measured depth) 4 1/2" 12.6# tubing set at 11198'. Packers and SSSV (type and measured depth) 7 5/8" TIW HB-BP-Tpacker set at 11110'; 4 1/2 HES "HXO" SVLN set at 1581' 13. Stimulation or cement squeeze summary Intervals treated (measured) Treatment description including volumes used and final pressure 14. Prior t° well operation Subsequent to operation Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure 347 535 11227 0 n/a Tubing Pressure 356 15. Attachments Copies of Logs and Surveys run __ Daily Report of Well Operations X 16. Status of well classification as: Oil X Gas__ Suspended__ Service 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed Jx'~'t~'~fl,-'u- i ~~ i~~~? Titles~eniorT~_chni~,,a.~L,~t~nttVret. 5~4.5234 Date 02/10/99 Form 10-404 Rev 06/15~18 SUBMIT IN DUPLICATE BPX Endicott Production Engineering Department DATE: 1/18/99 WELL N°: 1-33/M-23 TYPE OF OPERATION: BP EXPLORATION REP: SERVICE COMPANY: Operations Report MIT IA Lovelace APC TIME OPERATIONS SUMMARY 925 SIP=100 IA=600 OA=0 Pumped total of 12 bbls down IA Pressured up to 2500 psi and held for 30 minutes MIT looked good Rigged down HB&R Bled down the IA to 0 ps~ Summary: Pressured tested the IA after the Slick line set dummies, tested and IA looked good held 2500 psi for 30 minutes. BPX Endicott Production Engineering Department Operations Report DATE: 4/22/98 WELL N°: 1-33/M-23 TYPE OF OPERATION: MIT on Hanger Seals BP EXPLORATION REP: Lovelace SERVICE COMPANY: APC TIME OPERATIONS SUMMARY SIP=325 IA=300 OA=0 1300 TEST HANGER SEAL PRESSURE UP TEST AREA PORT OF THE WELL HEAD TUBING SEAL 1340 TEST HANGER SEAL TO 300 PSI FOR 30 MINUTES--TEST GOOD Summary: Tested the hanger seals to 3000 psi for 30 minutes, Good BPX Endicott Production Engineering Department Static Survey DATE: 7-15-98 WELL N°: 1-33 / M-23 BP EXPLORATION REP: ROBERTSON SERVICE COMPANY: HES / LAWSON SIWHP (PSIG) lAP (PSIG) OAP (PSIG) TIME/DATE OF SHUT-IN 1500 500 0 2/98 DATE/TIME OPERATIONS SUMMARY 1430 MIRU. 1500 RIH w/3.625 CENT., TTL, BUMPER SUB, DUAL SPARTEK GAUGES. 1600 TAG TAIL @ 11170' WLM. ELM = 11188'. + 18' CORRECTION. 1604 STOP @ 12005' WLM FOR THREE HOURS. GAUGES @ 12012' WLM. 1904 RIH TO TAG PB. TAG PB @ 12259' WLM. HARD BOTTOM. 12277' CORRECTED. POOH. RD. GAUGES DEPTH DEPTH DEPTH BHSIP BHSIT Delta P SPARTEK TVDss MDBKB WLM PSIA deg F PSI/HR 1 I 10000 12030 12012 4294 214 -0.1 2I 10000 12030 12012 FAILED .... SUMMARY: THREE HOUR STATIC. TAG PBTD AT 12,277 BKB. DRIFTED WITH 3.625" CENTRALIZER. POOH. RD. SSSV' OUT From: Operation: 7/18/98 Endicott Production ,....~, ,eering Hoffmann/Clump 1-33/M-23 Rig Prep Cost Code: Detail Code: Endicott AFE # 727029 Sdtrk - Prep - etc Summary 7/18/98 MIRU DS # 2. MU Baker tools. PT to 4k. RIH w/2.875" OD motor w/3.80" mill. Tag XN nipple @ 11193' ctd. PU & start motor. Mill thru XN nipple after 2 stalls. Run thru. Tag TD @ 12291 ctd. Pooh to change over to cmt nozzle. Start BH kill w/183 bbls FSW. CT pump making noises. Shut down & check out. PT cmt pumper hardline to 4000 psig. Come on line w/cement pumper to BH kill well again. Pump 275 bbls FSW & Rih after slowing pump rate. 7/19/98 Dry tag PBTD @ 12288' ctd. Correct depth to slick-line corrected tag of 12277' md. Puh to 12267' and flag pipe. Batch up 1s' plug-19 bbls of neat cmt. Pump 6 bbl fresh water & follow with 18 bbls 17 ppg neat cmt. Displace cmt w/5 bbl fresh & follow w/SW. Lay in cmt, with chokes open, pumping @ 1.5 bpm from 12267'. Pull to safety @ 11600' and gauge returns while ramping to 500, 1000, 1500, & 2000 psig. No significant cmt vol. pushed behind pipe. Hold 2000 psig for 4 mins - looks good. Rih and reverse off neat cmt from 11890' to 11900'. Cmt returns to surface. MI Solids Control spinning out cmt. Pump another crv for cleanup. Shut down and standby for plug #1 to harden. RIH to 11890'. Pump 5 bbls of fresh H20. Pump 2 bbs neat cmt, 6 bbls fiber cmt, 2 bbls neat cmt. Ramp up to 1500 psi. Hold for 10 min. RIH reversing out. Started plugging off @ 11673' (fibers). Had to pump down coil to purge pipe. Pooh. RIH reversing to 11762'. Plugging off. Pooh. Pump down coil to clear nozzle. Reverse down to 11756'. Plugging off. Pooh. Clear nozzle. Getting close to thickening time for cmt. Had to jet down thru final 18' to 11780'. Pooh to 11740. Reverse down to 11780'. Getting cmt returns. Reverse an additional ctv. Getting clean returns. May not have full I.D. in last 18' above TOC @ 11780'. Pooh maintaining 500 psi pos press on plug. Freeze protect tbg w/diesel to 2300'. RD DS. Left 450 psi on tbg. Leave location. 7/18/98 Initial Well Status Siwhp lap 0ap GIp FIp Fit psi psi psi psi psi °F 1379 620 0 0 250 Time Operation 15:00 Miru DS # 2, 14,400' of 1-3/4" (crv 33 bbls). Spill Champion: Bill Nipper 16:27 MU Baker tools. Pull to 15000 lbs. Pt to 4000 psi. Rupture disc sheared. Replace disc and retest. OK. 17:30 PU tools. Stab lub. PT to 4000. OK. Open swab. 18:00 Safety meeting to discuss muster area, spill prevention and scope of work. 7/18/98 Time Depth Rate Ctp Whp Total Remarks ft bpm psi psi bbls 18:15 surf 0 1300 1377 RIH w/Baker tools. ( 2.875" OD motor w/3.80" OD mill ). 19:48 9983 0 0 1484 19 K PU. 20:09 11162 2.8 2454 1520 0 Tag XN nipple @ 11193' -21k PU. Open wing valve. Start up motorwhile picking up hole. FS= 2450 psig. 20:17 11192 2.8/0 3800 1137 27 Stall #1. Shut down, Puh. 20:19 11180 2.8 2500 1020 27 Start up motor again. 20:20 11192.5 2.8 3800 954 34 Stall #2. 20:23 11178 2.8 2560 740 41 Start up motor. 20:42 11205 2.8/0 50 244 91slw Milled through "XN" nipple. Rih for Tag. 20:57 12291 0 70 276 PU wt off PBTD. 21.75k. Pooh. ~eration: 1-33 Rig Prep Page: 2 22:50 surf 0 70 250 OOH. Take off mill, motor, and extra lubricator. MU 2" roll-on connector & 3" combo nozzle. 23:47 surf 4.5 246 281 0 Come on line w/FSW for bullhead kill. 7/19/98 0:37 surf 4.0 463 450 183sw Something wrong w/the pump. Come off line. 1:04 surf 4.25 529 584 0 sw Cementers finish rigging up and get lined to pump. Roll a few barrels and PT to 4000 psig. 2:06 surf 4.9/2 245 274 275sw Slow rate. RIH w/3" nozzle. 4:19 12288 .48 12 56 364sw Tag btm correct to slick corrected depth of 12277' md bkb. 22.5k PU. Pull up hole to 12267' md bkb. Keep pumping @ rain rate. Batch up cmt. 4:36 12267 0.75 351 0 6 Back on line w/SW. Rih up and down in sump to cool while waiting. 5:00 12267 0 48 0 33sw Safety meeting. 5:20 12267 1.7 2304 50 0 Start w/fresh water. 5:23 12267 1.5 1019 9 5.7fw On cmt. 5:25 12267 1.7 2633 15 2 .75 from pump (16.4/gal). 5:32 12267 1.7 3129 12 13 5:35 12267 1.7 2800 13 18cmt Switch to fresh water. See on micro-motion. PU 28.5k. 5:44 12267 1.5 2247 14 33 Cmt at the nozzle. 5:45 12267 1.5 1217 10 35 2 bbls cmt up, lay in cement w/chokes open. PU= 28K. 5:47 12221 1.5 1259 7 37 4 bbls cmt out. 5:49 12134 1.5 1425 9 41 8 bblscmtout 5:51 12088 1.5 1555 12 43 10 Perfscovered 5:52 12067 1.5 1600 16 44 11 cmt out nozzle 5:53 12024 1.5 1747 25 46 13" 5:54 12000 1.5 1723 22 47 14" 5:54 11978 1.5 1727 22 48 15" 5:55 11954 1.5 1729 19 49 16 ". Speed up to 67 fpm. 5:57 11836 0.5 337 0 51 18 out nozzle. Pull to safety. Line up to gauge returns. Maintain 200 psi. 6:01 11600 0.5 511 200 53.5 At Safety. 2.5 bbl return. 6:05 11600 0.5 814 492 54 3.5 bbls ret. 6:07 11600 0.5 821 500 55 4.5 bbls ret. Ramp to 1000 psig. 6:13 11600 0.5 1292 1000 56 7 bbls ret. Ramp to 1500 psig. 6:15 11600 0.5 1738 1500 57 7.5 bbls ret. Move pipe 6:18 11582 0.5 1747 1500 58 9.5 bbls ret. Ramp to 2000 psig 6:20 11582 0.5 1987 2000 59 10 bbls ret. 6:22 11582 0.5 1971 2000 64 Trap 2000 psig. 6:31 11600 1.6 59 2070 67 Rih reversing. 6:38 11720 1.57 70 1920 80 Safety Meeting. Spill champion = Billy Nipper. 6:45 11880 1.5 60 1980 90 TOC @ 11867-118827 Definitely have cmt @ 11890'. 6:48 11895 1.5 60 2010 93 At desired PB for next cmt plug. 7:05 11890 1.5 79 1650 120 Cmt @ surface 7:09 11900 1.5 67 1655 124 Returns cleaning up. Still 8.7 ppg 7:11 11900 1.5 62 1571 128 Density back to normal. 8.1 ppg. Reverse an additional ctv. 7:36 11470 0 504 500 163sw Come down on pumps. Maintain 500 psi on plug. WOC to harden for tag. 12:23 11890 0 684 730 RIH 12:24 11445 1.68 2281 210 Start. Pumping fresh water. Maintain 200 psi positive press. 12:26 11535 1.6 2600 190 5/0 fw Switch to Cement. (16.7 ppg). Pumped 10 bbls 12:32 11824 1.5 2851 220 lOcmt Switch to water 8.3 ppg (8.8bblscmt) 12:38 11858 1.7 2440 215 Cement over gooseneck.. 24k up wt. ~¢eration: 1-33 Rig Prep Page: 3 12:49 11890 1.7 2650 190 25 sw 2 bbls out around pipe. Pooh @ 37.0'/min. 12:52 11700 1.7 2500 185 33sw Pooh 12:56 11498 .48 2000 180 38 sw Ramp up to 1500 psi on top of plug. Reduce pump rate. 12:59 11498 0 1460 1440 39/0 sw Hold 1500 psi for 10 min. Plug holding. SD pumps. 13:10 11498 1.45 63 1700 RIH reversing out. 13:25 11630 1.5 64 2184 19 sw FoundWC TOC high. Pressuring up. POOH 13:32 11608 1.54 58 2158 33 sw Have 1 coil vol back. No cmt returns yet 13:44 11608 1.54 102 2095 49 sw Started getting cmt returns to Micro-motion. Getting fibers to choke. RI H. 14:08 11673 1.51 80 2400 87 sw Starting to pressure up. POOH to 11660'. WHP still coming up. 14:16 11629 1.5 2000 560 Start pumping down coil. Appear to have purged coil. 14:19 11629 1.15 66 1650 101 sw Start reversing again 14:26 11645 1.5 75 1837 108 sw Density climbing. Getting returns. RIH. 14:53 11762 1.35 57 2325 147 sw Nozzle/coil plugging.(possibly w/fiber). Pressuring up again. Pull up to 11748' 14:59 11748 1.45 73 2427 156 sw Density up to 8.6. 15:15 11756 1.5 65 2400 179 sw Plugging off. Down on pumps. Get lined up to pump down coil. 15:18 11756 1.48 2395 563 181 sw Pump down coil. RIH. Had to jet out to requested depth of 11780'. Getting close to cmt thickening time. * Btm 18' may not have full I.D. 15:21 11780 1.48 2300 570 186 sw SD pumps. Get lined up to reverse out 15:23 11740 1.43 62 1776 191 sw Bring up rate. RIH 15:41 11780 1.53 69 2115 214 sw Reverse down to requested TOC. Getting cmt returns. 15:44 11780 1.50 67 2110 217 sw Density coming up ( 8.7 ). 15:57 11780 1.50 69 2024 255 sw Getting clean returns ( 8.1 ). Pooh. Pulling = 17.5k 16:17 10640 .75 48 835 264sw Cut pump rate. Pooh. 17:05 5131 1.0 39 576 293 sw Switch to diesel to FP tbg. 17:40 surf 1.0 35 450 35 d OOH. SD pumps. Well FP to 2300'. SI well. RD DS. 19:30 Secure well and move off location. Final Well Status Siwhp lap 0ap GIp FIp Fit psi psi psi psi psi °F 450 620 0 0 250 Fluid Summary 92 Seawater w/friction reducer. 892 Filtered Seawater 11 Freshwater. 35 Diesel 0 Biozan 0 Methanol Total Milling Assembly BHA # 1 Tool String Descriptions O.D. I.D. Length Comments CT Connector. 2.875" 1.5" 0.96' Check valve 2.875" 1.0" 1.94' Disconnect 2.875" 0.812" 1.90' 7/8" Disconnect ball. Jperation: 1-33 Rig Prep Page: 4 Circ Sub 2.875" 0.562" 1.34' 5/8" Ball Navi Drill Motor 2.875" 6.50' X-O (2-3/8"1~ac box x 2-3/8" pac pin) 2.875" 1.34' Dimple Mill 3.800" 1.34' Total Length 15.32' Squeeze Nozzle BHA # 2 Tool String Descriptions O.D. I.D. Length Comments 2" Roll on CTC 2 0.30 3" combo (.8" center, 4 down, 8 around) 3 0.58 Total Length 0.88 DS Cement Summary Lab 17.00 PPG Class G Cement containing: 0.10 gps D047 0.35 % BWOC D156 1.00% BWOC D065 0.17 % BWOC D800 Thickening Time = 3 hrs and 59 mins. BPX Endicott Production Engineering Department OPERATIONS REPORT DATE: 7/21/98 WELL N°: 1-33/M-23 TYPE OF OPERATION: BP EXPLORATION REP: SERVICE COMPANY: TAG CEMENT D. ROBERTSON HES/TILBURY DATE/TIME I OPERATIONS SUMMARY 073O MIRU. 0815 RIH w/K J, 3.625 CENT & TEL. SAT DOWN & KINKED WIRE. POOH. TIE NEW ROPE SOCKET. 1030 RIH w/SAME. LOCATE TT @ 11169' WLM, (ELMD=11188'). TAGGED TOC @ 11733' WLM, (11752' CORRECTED). POOH. 1215 RIG UP TRI-PLEX & PRESSURE TUBING TO 2500 PSI, (PUMPED 1 BBL DIESEL). MONITOR. TIME TUBING IA TIME TUBING IA 1310 2500 625 1330 2460 625 1315 2490 625 1335 2460 625 1320 2475 625 1340 2460 625 1325 2460 625 1400 RDMO. SI-2460 IA-625 CA-0 SUMMARY: RAN 3.625" CENTRALIZER AND TEL. TAGGED TOP OF CEMENT AT 11752' CORRECTED DEPTH. PRESSURED TUBING TO 2500 PSI AND MONITORED FOR 30 MINUTES. GOOD TEST. NOTE: AOGCC REPRESENTATIVE JOHN SPAULDING VERBALLY WAIVED RIGHT TO WITNESS TEST ON 7/20/98. ALSO INDICATED THAT CHART RECORDER WAS NOT REQUIRED, BUT TEST MUST BE OTHERWISE DOCUMENTED. dbr SSSV: OUT STATE OF ALASKA AL,~ '~ OILAND GAS CONSERVATION COMMI )N REPORT SUNDRY WELL OPI='RATIONS 1. Operations performed: Operation shutdown__ Stimulate__ Plugging__ Pull tubing Alter casing __ Repair well __ Perforate.__ Other X 2. Name of Operator BP Exl~loration (Alaska) Inc. 3. Address P. O. Box 196612, Anchora.qe, Alaska 99519-6612 4. Location of well at surface 3217' NSL, 2114' WEL, Sec. 36, T12N, R16E At top of productive interval 1850' NSL, 1610' WEL, Sec. 36, T12N, R16E At effective depth 1710'NSL, 1241' WEL, Sec. 36, T12N, R16E At total depth 1683' NSL, 1188' WEL, Sec. 36, T12N, R16E 5. Type of Well: Development Exploratory Stratigraphic Service 6. Datum elevation (DF or KB) KBE = 56 feet 7. Unit or Property name Duck Island Unit/Endicott 8. Well number 1-33/M-23 9. Permit number/approval number 95-107/398-186 10. APl number 50- 029-22577 11. Field/Pool Endicott Field/Endicott Pool 12. Present well condition summary Total depth: measured true vertical Effective depth: measured true vertical 12425 feet 10347 BKB feet 12314 feet 10259'BKB feet Plugs (measured) Junk (measured) Casing Length Size Cemented Structural C o n d u cto r 91' 30" Driven S u trace 4974' 10 3/4 1725 c.f. Perma frost Intermediate 690 c.f. Class "G" Production 12365' 7 5/8" 559 c.f. Class "G" Liner Perforation depth: measured 12080'- 12100'; 12100'- 12120' (open_ true vertical (subsea) 10019'- 10034'; 10034'- 10050' (open) Tubing (size, grade, and measured depth) 4 1/2" 12.6# tubing set at 11198'. Measured depth BKB 130' 5013' True vertical depth BKB 130' 4390' 12404' 10329' ;.~laska Oil & Gas Cons. Commission Anchorage Packers and SSSV (type and measured depth) 7 5/8" TIW HB-BP-Tpacker set at 11110'; 4 1/2 HES "HXO" SVLN set at 1581' 13. Stimulation or cement squeeze summary MIT to test tubing and cement plug prior to sidetrack (7/21/98) Intervals treated (measured) ORIG!['~AL Treatment description including volumes used and final pressure 14. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation 347 535 11227 0 Subsequent to operation n/a 15. Attachments I 16. Status of well classification as: Copies of Logs and Surveys run I Daily Report of Well Operations X Oil ~ Gas Suspended 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed i: ~~q~ ]~ ~/~"~ Title Senior Technin~l A-~-~i-~t~nt IV Form 10-404 Rev 0(~(15/88 356 Service Date 7/30/98 SUBMIT IN DUPLICATE BPX Endicott Production Engineering Department DATE: 7/21/98 WELL N°: 1-33/M-23 TYPE OF OPERATION: BP EXPLORATION REP: SERVICE COMPANY: OPERATIONS REPORT TAG CEMENT D. ROBERTSON HES/TILBURY DATE/TIME 0730 0815 1030 1215 1400 OPERATIONS SUMMARY MIRU. RIH w/KJ, 3.625 CENT & TEL. SAT DOWN & KINKED WIRE. POOH. TIE NEW ROPE SOCKET. RIH w/SAME. LOCATE TT (~ 11169' WLM, (ELMD=I 1188'). TAGGED TOC (~ 11733' WLM, (11752' CORRECTED). POOH. RIG UP TRI-PLEX & PRESSURE TUBING TO 2500 PSI, (PUMPED I BBL DIESEL). MONITOR. TIME TUBING IA TIME TUBING IA 1310 2500 625 1330 2460 625 1315 2490 625 1335 2460 625 1320 2475 625 1340 2460 625 1325 2460 625 RDMO. S1=2460 IA=625 OA=0 SUMMARY: RAN 3.625" CENTRALIZER AND TEL. TAGGED TOP OF CEMENT AT 11752' CORRECTED DEPTH. PRESSURED TUBING TO 2500 PSI AND MONITORED FOR 30 MINUTES. GOOD TEST. NOTE: AOGCC REPRESENTATIVE JOHN SPAULDING VERBALLY WAIVED RIGHT TO WITNESS TEST ON 7~20~98. ALSO INDICATED THAT CHART RECORDER WAS NOT REQUIRED, BUT TEST MUST BE OTHERWISE DOCUMENTED. dbr SSSV: OUT ~ STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVAL REVISED: 07/08/98 Type of Request: [] Abandon [] Suspend [] Plugging [] Time Extension [] Perforate [] Alter Casing [] Repair Well [] Pull Tubing [] Variance [] Other [] Change Approved Program [] Operation Shutdown [] Re-Enter Suspended Well [] Stimulate Plug Back for Sidetrack 2. Name of Operator BP Exploration (Alaska) Inc. 3. Address P.O. Box 196612, Anchorage, Alaska 99519-6612 4. Location of well at surface 3217' NSL, 2114' WEL, SEC. 36, T12N, R16E, UM At top of productive interval 1850' NSL, 1610' WEL, SEC. 36, T12N, R16E, UPM At effective depth 1710' NSL, 1241' WEL, SEC. 36, T12N, R16E, UPM At total depth 1683' NSL, 1188' WEL, SEC. 36, T12N, R16E, UPM 5. Type of well: [~] Development [] Exploratory E~ Stratigraphic I-]Service 6. Datum Elevation (DF or KB) Plan KBE = 56' 7. Unit or Property Name Duck Island Unit/Endicott 8. Well Number 1-33/M-23 9. Permit Number 95-107 10. APl Number 50-029-22577 11. Field and Pool Endicott Field / Endicott Pool 12. Present well condition summary Total depth: measured 12425 feet true vertical 10347 BKB feet Effective depth: measured 12314 feet true vertical 10259 BKB feet Casing Length Size Structural Conductor 91' 30" Surface 4974' 10-3/4" Intermediate Production 12365' 7-5/8" Liner Plugs (measured) Junk (measured) Cemented MD TVD BKB BKB Driven 130' 130' 1725 c.f. Permafrost, 690 c.f. Class 'G' 5013' 4390' 559 c.f. Class 'G' 12404' 10329' Perforation depth: measured true vertical ORIGINAL 12080'-12100', 12100-12120' (subsea) 10019'-10034', 10034'-10050' Tubing (size, grade, and measured depth) 4-1/2" 12.6# 13CR80 at 11198' Packers and SSSV (type and measured depth) RECEIVED JUL 09 1998 Alaska 0il & 6as Cons. 00remission Anchorage 4-1/2" HES "HXO" SVLN at 1581' · 7-5/8" TIW HB-BP-T Packer at 11110' 13. Attachments 14. Estimated date for commer~Cr~0peration dul~,2'1, 1998 [] Description summary of proposal I--] Detailed operations program FI BOP sketch Date approved 16. If proposal was verbally approved Name of approver 15. Status of well classifications as: [~ Oil E~] Gas [-I Suspended Service Contact Engineer Name/Number: Jeff__¢Hupp, 564-5480~ ~, Chris West, 564-5089 Prepared By Narne/Numbec 1 7. I hereby certify that the for/e'/~oing is true and correct to the best of my knowledge Signed ,'-~..~' - Lowell Oran,.e ~_,z..~..~f tie Drilling Engineering Supervisor L~/ Commission Use Only Carol Withey, 564-4114 Date ?-~) Conditions of Approval: Notify Commis,,si.on so representativ~ m,.,ay witness Plug integrity ~Y~ BOP Test ~ Location clearance ~ Mechanical Integrity Test~ Subsequent form required 10- ~ Oq drlglnal 3~g~u~..,., of the Commission David W, Johnston Commissioner I Approval NO.,.~ Submit/in Tliplicate Form Rev. 06/15/88 SUMMARY PROCEDURE COMMENTS 1. The 7-5/8" x 4-1/2" production packer is a TIW permanent packer with a tubing ~eal assembly above. The packer and tubing will not be recovered. 2. The existing perforations will be plugged with cement. 3. This well will be sidetracked at app. 11,829 md. PRE-RIG OPERATIONS 1. Test 4-1/2' tbg hanger void area to 3500 psi. Test 7-5/8' packoff to 3500 psi. 2. Pressure test IA and wellhead packoff (tubing and annulus) to 3,500psi. 3.RU slickline, Pull the WL SSSV. Drift and dummy off gas lift mandrels. 4.RU and run coil tubing across perforations to PBTD at 12275'+/-, establish circulation. 5. Spot 17.0 ppg fiber cement from 12275 to 11680', pull CT to 11000' and squeeze cement if possible up to 1500 psi maximum surface pressure. 6. Jet out excess cement down to 11790'md (39' above KOP @ 11829' MD). 7. Displace well to seawater while POH wi CT. Freeze protect last 1500' of well w/diesel. 8. RU Slickline. Tag cement top and correct top tbg tail depth. 9. After monitoring well for no pressure, set BPV. Remove flowline, level pad, dig out cellar. RIG OPERATIONS (SUMMARY) 1. Mobilize Doyon 15. Review Endicott Simultaneous Operations Plan concerning rig moves. 2. Check that the well is dead. Pull BPV. If not circulate well w/brine or milling fluid until dead. 3. Run TWC and test. ND the tree, and NU the BOPE. Test the BOPE and pull TWC. (1/2 day). 4. Pick up 3.80' HC pilot hole mill, 1° 2-7/8' bent motor, Sperry 2-7/8' directional assembly and 2-3/8" SLH-90 Drill pipe. 5. RIH & mill XN nipple to 3.80" ID using slick seawater. Record depth of XN nipple. 6. Tag cement top. Correlate cement top to collar Icg. Mill Iow side pilot hole to 11819' (10' above planned KOP) using SW. MPI 1-33A/N-24 4 07/09/98 , . 10. 11. 12. 13. 14. 15. 16. Roll tool face 180° and mill 10 ft ramp to the casing wall @ 11829' MD. Open PBL sub and displace well to 10.0 ppg mud. POH. Pick up 3.80" HC window mill, 3° 2-7/8" motor w 1.5° bent sub, Sperry 2-7/8" directional assembly on 2-3/8" SLH-90 Drill pipe. RIH and mill window through 7-5/8" casing and 5 feet of new hole. POH. ' RIH w/Baker finishing mill on 3° motor assembly. Back ream window to top of pilot hole. Pick up directional assy to build and turn @ 32°/100 feet to 86° at appx 12036' MD. Drop angle to 41 ° at TD Drill ahead as specified by the rig supervisor to 12774' md (TD). POOH. (12 days) If there are hole problems, run a 3.75" Baker fixed blade HO over whole interval and spot lubricant in OH section. POOH. Run a 2.875" solid liner from 11150 to 12774 MD, cement as per plan. Pump plug w/KW brine. POOH and WOC. RIH to 1500' and freeze protect well. Test the tubing to 3500 psi. Test the packer and IA to 3500 psi. Set the BPV. ND the BOPE, and NU the tree. Turn the well over to Production. MPI 1-33A/N-24 5 07/09/98 · l. ELEV = 56.0' BF. ELEV = 18.7' MAX DEV = 40° AT 3742' 10-3/4", 45.5#/ft, L-80, BTC. CSG. 5013' I TREE: i/2" ,CAMERON W 5000 psi WELLHEAD: 13 5/8" 5000 psi FMC HES 'HXO' SVLN (3.813" MIN. ID) SSSV reoved 1581' 4-1/2", 13-CR, 12.6#/ft, NSCT tubing GAS LIFT MANDRELS (HES) 'KBMGM' w. 1" BK' LATCH NO. MD-BKB TVD-SS #7 3946' 3490' #6 6122' 5238' #5 7447' 6302' #4 8323' 7001' #3 9185' 7705' #2 10051 8391' #1 10956' 9099' 4-1/2", 12.6#/ft, L-80 TAILPIPE PERFORATION SUMMARY REF. LOG. DIL 9/20/95 Interval ¢.,-, Ri?c, RPF AWS 3-3/8 6 12,100' - 12,120' SWS 3-3/8" 6 12,080' - 12,100' PRESENT SCHEMATIC 4/20/98 PBTD I 12;~14' ! 7-5/8", 29.7#/ft, I 4o4' I L-80 NSCC DATE 9/29/95 :REV. BY GAM 4-1/2" 'X' NIPPLE (HES) (3.813" MIN. ID) 7-5/8" PACKER ( TIW HB-BP-T ) 4-1/2" 'X' NIPPLE (HES) (3.813" ID) 4-1/2" 'XN' NIPPLE (HES) (3.725" ID) 4-1/2" WLE G New Style 11110' 11175' 11186' 11198' 11188. :OMMENTS INITIAL COMPLETION 10/4/95 JTP INITIAL PERFORATIONS 10/4/97 DAV ADD-PERFS ENDICOTT WELL 1-33/M-23 APl NO: 50-029-22577 COMPLETION DIAGRAM BP N. INC. ,i ELEV =56.0' BF. ELEV = 18.7' MAX DEV = 40° AT 3742' 10-3/4", 45.5#/ft, L-80, BTC. CSG. 5013' 4-1/2", 13-CR, 12.6#/ft, NSCT tubing 8.4 ppg seawater TREE: 4-',/2" ,CAMERON W 5000 psi WELLHEAD: 13 5/8" 5000 psi FMC HFS 'HXO' SVLN (3.813" MIN. ID) SSSV reoved I 1581' GAS LIFT MANDRELS (HES) 'KBMGM' w. 1" BK' LATCH NO. MD-BKB TVD-SS #7 3946' 3490' #6 6122' 5238' #5 7447' 6302' #4 8323' 7001' #3 9185' 7705' #2 10051 8391' #1 10956' 9099' 8.4 ppg seawater 4-1/2", 12.6#/ft, L-80 TAILPIPE PERFORATION SUMMARY REF. LOG. DIL 9/20/95 Interval ~-~ -~i?¢ RPF AWS 3-3/8 6 12,100' - 12,120' SWS 3-3/8" 6 12,080'- 12,100' 4-1/2" 'X' NIPPLE (HES) (3.813" MIN. ID) 7-5/8" PACKER ( TIW HB-BP-T ) 4-1/2" 'X' NIPPLE (HES) (3.813" ID) 4-1/2" 'XN' NIPPLE (HFS) (3.725" ID) 4-1/2" WLE G New Style 11099' 11110' 11175' 11186' 11198' 11188' PROPOSED CT PLUG BACK 17.0 ppg fiber cmt f/12276' (PB tag) to 11790' md (22 bbls cmt) PBTD I 12314' I 7-5/8", I I L~80 NSCC DATE 9/29/95 REV. BY GAM I O/4/95 JTP I O/4/97 JTP 4/14/98 JLH IOMMENTS INITIAL COMPLETION INITIAL PERFORATIONS ADD PERFORATIONS Proposed P&A ENDICOTT WELL 1-33/M-23 APl NO' 50-029-22577 COMPLETION DIAGRAM BP EXPLORATION. INC. STATE OF ALASKA ALASK~---31L AND GAS CONSERVATION COMMISSF REPORT SUNDRY WELL OPE'HATIONS 1. Operations performed: Operation shutdown__ Stimulate__ Plugging__ Pull tubing__ Alter casing __ Repair well __ Perforate__ Other X 2. Name of Operator BP Exploration (Alaska) Inc. 3. Address P. O. Box 196612, Anchora.cle, Alaska 99519-6612 4. Location of well at surface 3217' NSL, 2114' WEL, Sec. 36, T12N, R16E 5. Type of Well: Development Exploratory __ Stratigraphic __ Service __ 6. Datum elevation (DF or KB) KBE = 56 feet 7. Unit or Properly name Duck Island Unit/Endicott 8. Well number 1-33/M-23 At top of productive interval 1850'NSL, 1610' WEL, Sec. 36, T12N, R16E At effective depth 1710'NSL, 1241' WEL, Sec. 36, T12N, R16E At total depth 1683' NSL, 1188' WEL, Sec. 36, T12N, R16E 9. Permit number/approval number 95-107/Not Required 10. APl number 50- 029-22577 11. Field/Pool Endicott Field/Endicott Pool 12. Present well condition summary Total depth: measured true vertical Effective depth: measured true vertical 12425 feet 10347 BKB feet 12314 feet 10259'BKB feet Plugs (measured) Junk (measured) Casing Length Size Cemented Structural Conductor 91' 30" Driven Surface 4974' 10 3/4 1725 c.f. Permafrost Intermediate 690 c.f. Class "G" Production 12365' 7 5/8" 559 c.f. Class "G" Liner Perforation depth: measured 12080'- 12100'; 12100'- 12120' (open_ Measured depth BKB True vertical depth BKB 130' 130' 5013' 4390' true vertical ¢ubsea) 10019'-10034'; 10034'-lO050'(open) 12404' 10329' Tubing (size, grade, and measured depth) 4 1/2" 12.6# tubing set at 11198'. .... Packers and SSSV (type and measured depth) 7 5/8" TIW HB-BP-T packer set at 11110'; 4 1/2 HES "HXO" SVLN set at 1581' 13. Stimulation or cement squeeze summary MIT on I/A 3/31/98; MIT on I/A 4/18/98; MIT on hanger seals 4/22/98. Intervals treated (measured) Treatment description including volumes used and final pressure 14. Prior to well operation Subsequent to operation Representative Daily Average Production or Injection Data OiI-Bbl Gas-Mcf Water-Bbl Casing Pressure 347 535 11227 0 n/a Tubing Pressure 356 15. Attachments Copies of Logs and Surveys run Daily Report of Well Operations 16. Status of well classification as: Oil X_ Gas__ Suspended__ Service 17. I he(r, EC~Acertify that the foregoing is true and correct to the best of my knowledge. Signe~//.,¢_~ . _.,,,~ Title 5~nior r~chnic~l 4~i.~tant IV Form 10-4 4(~/R~ 06/15/88 / Date 5/5/98 SUBMIT IN DUPLICATE BPX Endicott Production Engineering Department DATE: 3/31/98 WELL N°: 1-33/M-23 BP EXPLORATION REP: D. Williams SERVICE COMPANY: A.P.C. MIT ON I/A COST CODE: AFE: 727022 DETAIL CODE: DATE/TIME OPERATIONS SUMMARY 1408 1414 1420 1430 1447 1449 MIRU to I/A. P.T. Hard line to 3500 psi. Start pumping diesel down I/A, 13 bbls away, Switch to Seawater. 20 bbls away, @ 3.0 bpm, 625 ps~. 50 bbls away, @ 3.0 bpm, 625 ps~. 91 bbls away, @ 3.0 bpm, 650 psi. Switch to 60/40 meth. @ 4 bbls away, 1 bpm, 2500 psi held for 30 mins. Loss 50 psi. in 30 mins. 1529 RDMO. SUMMARY: * Pumped a total of 13 bbls of diesel & 91 bbls of seawater, 4 bbls of 60/40 meth. * Held 2500 psi for 30 mins. Lost 50 psi. ending up with 2450 psi. Bleed back to 700 psi. BPX Endicott Production Engineering Department DATE: 4/18~98 WELL N°: 1-33/M-23 BP EXPLORATION REP: D. Barba SERVICE COMPANY: HB & R MIT ON I/A COST CODE: AFE: 727022 DETAIL CODE: Sidetrack/Fluid Pack/Pump DATE/TIME OPERATIONS SUMMARY 1815 1830 1841 1910 1915 MIRU to I/A. Pressure test hard line to 4000 psig. Start pumping diesel down I/A @ 1.5 bpm. 10 bbls away. Pressure = 3550 psig. Hold for 30 minutes. Lost 100 ps~. RDMO. SUMMARY: * Pumped a total of 10 bbls of diesel. * Held 3550 psig for 30 mins. Lost 100 psi ending up with 3450 psig. Bleed back to 500 psi. BPX Endicott Production Engineering Department DATE: 4/22/98 WELL N°: 1-33/M-23 TYPE OF OPERATION: BP EXPLORATION REP: SERVICE COMPANY: Operations Report MIT on Hanger Seals Lovelace APC TIME 1300 1340 OPERATIONS SUMMARY SIP=325 IA=300 OA=0 TEST HANGER SEAL PRESSURE UP TEST AREA PORT OF THE WELL HEAD TUBING SEAL TEST HANGER SEAL TO 300 PSI FOR 30 MINUTES--TEST GOOD Summary: Tested the hanger seals to 3000 psi for 30 minutes, Good STATE OF ALASKA ALASKA u,L AND GAS CONSERVATION COM~VllSSION APPLICATION FOR SUNDRY APPROVAL Type of Request: [] Abandon [] Suspend [] Plugging [] Time Extension [] Perforate [] Alter Casing [] Repair Well [] Pull Tubing [] Variance [] Other [] Change Approved Program [] Operation Shutdown [] Re-Enter Suspended Well [] Stimulate Plug Back for Sidetrack 12. Name of Operator BP Exploration (Alaska)Inc. 3. Address P.O. Box 196612, Anchorage, Alaska 99519-6612 4. Location of well at surface 3217' NSL, 2114' WEL, SEC. 36, T12N, R16E, UPM At top of productive interval 1850' NSL, 1610' WEL, SEC. 36, T12N, R16E, UPM At effective depth 1710' NSL, 1241' WEL, SEC. 36, T12N, R16E, UPM At total depth 1683' NSL, 1188' WEL, SEC. 36, T12N, R16E, UPM 5. Type of well: [~ Development I--i Exploratory [--I Stratigraphic [--~Service 6. Datum Elevation (DF or KB) KBE = 56' 7. Unit or Property Name Duck Island Unit/Endicott 8. Well Number 1-33/M-23 9. Permit Number 95-107 10. APl Number 50-029-22577 11. Field and Pool Endicott Field / Endicott Pool 12. Present well condition summary Total depth: measured 12425 feet true vertical 10347 BKB feet Effective depth: measured 12314 feet true vertical 10259 BKB feet Casing Length Size Structural Conductor 91' 30" Surface 4974' 10-3/4" Intermediate Production 12365' Liner 7-5/8" Plugs (measured) Junk (measured) Cemented MD TVD BKB BKB Driven 130' 130' 1725 c.f. Permafrost, 690 c.f. Class 'G' 5013' 4390' 559 c.f. Class 'G' 12404' 10329' Perforation depth: measured true vertical 12080'-12100', 12100-12120' (subsea) 10019'-10034', 10034'-10050' Tubing (size, grade, and measured depth) 4-1/2" 12.6# 13CR80 at 11198' Packers and SSSV (type and measured depth) 4-1/2" HES "HXO" SVLN at 1581 '; 7-5/8" TIW HB-BP-T Packer at 11110' 13. Attachments [~ Description summary of proposal [--J Detailed operations program I--I BOP sketch 14. Estimated date for commencing operation April 22, 1998 16. If proposal was verbally approved Name of approver Contact Engineer Name/Number: Jeff Hupp, 564-5480 17. I hereby certify that the(ko ,~going is t Signed Steve Shultz [~Oil Service Date approved Chris West, 564-5089 15. Status of well classifications as: I--I Gas [--I Suspended Prepared By Name/Number: Kathy Campoamor, 564-5122 ri I'm. iandicorrect to the best of my knowledge \,(.~,~... ¢' \ 1,~.~ \--.__ Title Drilling Engineering Supervisor ' "--'" ' ' ~ .... Commission Use Only Conditions of Approval: Notify Commission so representative may witness Plug integrity ~ BOP Test ~ Location clearance I Approval No. ~ Mechanical Integrity Test Subsequent form required 1 ApproVed by order of the Commission 'Original Signed By " Form 10-403 Rev. 06/15/88 ,~aVi~ W. ,Johnston , o~~tmis~ioner Date ¢--' _,,.~J - ~(~ Submit In Triplicate SUMMARY PROCEDURE COMMENTS 1. The 9-5/8" x 4-1/2" production packer is a TIW permanent packer with a tubing seal assembly above. The packer and tubing will not be recovered. 2. The existing perforations will be plugged with cement. 3. This well will be sidetracked at app. 11,500 md. PRE-RIG OPERATIONS 1. Pressure test IA and wellhead packoff (tubing and annulus) to 3,500psi. 2. RU slickline, Pull the WL SSSV. Drift and dummy off gas lift mandrels. 3. RU and run coil tubing across perforations to PBTD at 12275'+/-, establish circulation. 4. Spot neat 17.0 ppg cement from 12275 to 11700', pull CT to 11000' and squeeze cement if possible up to 1500 psi maximum surface pressure. POOH. 5. Clean out excess neat cement down to 11700' md. Spot fiber cement f/11700-11360'. Jet out excess cement down to 11470'md (35' above KOP @ 11505' MD). 6. Displace well to seawater while POH w/CT. Freeze protect last 1500' of well w/diesel. 7. RU Slickline. Tag cement top and correct top tbg tail depth. 8. After monitoring well for no pressure, set BPV. 9. Remove wellhouse and flowlines, level pad, dig out cellar. RIG OPERATIONS (SUMMARY) 1. Mobilize Doyon 15. Review Endicott Simultaneous Operations Plan concerning rig moves. 2. Check that the well is dead. Pull BPV. If not circulate well w/brine or milling fluid until dead. 3. Run TWC and test. ND the tree, and NU the BOPE. Test the BOPE and pull TWC. (1/2 day). 4. Pick up 3.80" HC pilot hole mill, 1° 2-7/8" bent motor, Sperry 2-7/8" directional assembly and 2-3/8" SLH-90 Drill pipe. 5. RIH & mill XN nipple to 3.80" ID using slick seawater. Record depth of XN nipple. 6. Tag cement top. Correlate cement top to collar Icg. Mill Iow side pilot hole to 10495' (10' above planned KOP) using SW. Endicott MPI 1-33/M-23 1 10. 11. 12. 13. 14. 15. 16. 17. Roll tool face 180° and mill 10 ft ramp to the casing wall. Open PBL sub and displace well to 10.0 ppg 6% KCI % GEM mud. POH. Pick up 3.80" HC window mill, 3° 2-7/8" motor w 1.5° bent sub, Sperry 2-7/8" directional assembly on 2-3/8" SLH-90 Drill pipe. RIH and mill window through 7-5/8" casing and 5 feet of new hole. Do a FIT to 12.0 PPG EMW. POH. RIH w/Baker finishing mill on 3° motor assembly. Back ream window to top of pilot hole. Pick up to turn and build @ 17°/100 feet to 92° at appx 12,523' MD. Drop angle to 78°. Drill ahead as specified by the rig supervisor to 13,143. POOH. (12 days) If there are hole problems, run a 3.75" Baker fixed blade HO over whole interval and spot lubricant in OH section. POOH. Run a 2.875" solid liner from 10,311 to 13,143 MD, cement as per plan. Pump plug w/ KW brine. POOH and WOC. RIH to 1500' and freeze protect well. Test the tubing to 3500 psi. Test the packer and IA to 3500 psi. Set the BPV. ND the BOPE, and NU the tree. Turn the well over to Production. Alaska Oil & Gas Co~. Commis",~'? /~c~o~. ~ Endicott MPI 1-33/M-23 2 CURRENT WELL INFORMATION Well Name: AP1 Number: 1-33/M-23 50-029-22577 Well Type: Current Status: Producer Shut-in, High WOR Last H2S Sample: TD / PBTD: Last Tag: BHP: BHT: Kekiktuk: Open Perfs: Yes No x H2S___PPM 12404 / 12314' 12275' SLM 4330 psi (ppg EMW) @ 10000' TVDss 215°F @ 9850' ss Perforated? Yes 12080-12120' (Will be p&a'd with coil tbg.) Original KB - MSL: Casing Test: Tubing Test: Casing Hanger: Tubing Hanger: BPV Information: Adapter: Tree: Tubing Fluid: Annulus Fluid: 56' (Doyon 15) Will be tested prior to p&a. Not known FMC FMC Cameron BPVG FMC ll"x 4-1/16", 5M Cameron 4-1 / 16", 5M (4-1/8" bore) Freeze protected with diesel to _+ 1500' MD Inner: Diesel freeze protection, 8.4 ppg seawater KOP: Maximum angle: Maximum dogleg: 1050' MD 40.4° @ 3742' MD 4.2°/100' @ 1234' MD MECHANICAL CONDITION Tubing: 4-1/2" w/4-1/2" tailpipe. Will be drifted prior to p&a. Casing: 7-5/8" 29.7#/ft. L-80 IA 7-5/8" x 4-1/2". No problems. Will be tested prior to p&a. OA 13-3/8" x 7-5/8". Down squeezed with cement. Tested to 2000 psi. Endicott MPI 1-33/M-23 3 f.-~-._ TREE?'` 1/2" ,CAMERON W 5000 psi . = 56.0' WELU O: 13 5/8" 5000 psi FMC ,.:LEV = 18.7'i ...... M~ DEV = 40© AT 3742' 10-3/4", 45.5#/ft, L-80, BTC. CSG. ..~I_ i (3.813" MIN. ID) I lg81' I5013'I · · SSSVreoved I 4-1/2", 13-0R, 12.6#/ft, ~. GAS LIFT MANDRELS (HFS) NSCT tubing 'KBMGM' ~v. 1" BK' LATCH ,~ ~~ NO. MD-BKB -I-VD-SS F' #7 3946' 3490' #6 6122' 5238' #5 7447' 6302' #4 8323' 7001' #3 9185' 7705' i #2 10051 8391' , #1 10956' 9099' i 4-1/2" 'X' NIPPLE (HFS) 11099' - (3.813" MIN. ID) 7-5/8" PACKER 11110' ~;;~,--~~ ~ ~ ( TI.VV HB-BP-T ) , 4-1/2", 12.6#/ft, L-80 TAILPIPE IlO' 4-1/2" 'x' N~PPLE 4-1/2" 'XN' NIPPLE il I / PERFORATION SUMMARY REF_ I C)G_ DIL ~ New Style ELMD 11188' C:n ~i?~ ~PF Intp. rvnl ~ I c~ I AWS 3-3/8 6 12,100' - 12,120' SWS 3-3/8" 6 12,080' - 12,100' , I - ! PBTD I 12314' I 29.7#/ft, 12404' L-80 NSCC DATE REV. BY (:OMMENTS ENDICOTT WELL 1-33/M-23 9/29/95 INITIAL COMPLETION GAM APl NO- 50-029-:22577 10/4/95 JTP INITIAL PERFORATIONS COMPLETION DIAGRAM 10/4/97 DAV ADD-PERFS BP EXPLORATION, INC. GAS LIFT MANDRELS (HFS) 'KBMGM' ~v. 1" BK' LATCH NO. MD-BKB -I-VD-SS #7 3946' 3490' #6 6122' 5238' #5 7447' 6302' #4 8323' 7001' #3 9185' 7705' #2 10051 8391' #1 10956' 9099' C:,n Ri?o ,qPF Int~.rvnl AWS 3-3/8 6 12,100' - 12,120' SWS 3-3/8' 6 t2,080' - 12,100' -,-:~/ -- 56.0' · .ELEV = 18.7' MAX DEV = 40° AT 3742' 10-3/4", 45.5#/ft, L-80, BTC. CSG. I 5013' I TREE: 2" ,CAMERON W 5000 psi WELLHEad,- 13 5/8" 5000 psi FMC HES 'HXO' SVLN (3.813" MIN. ID) I SSSV reoved 1581' 4-1/2", 13-CR, 12.6#/ft, NSCT tubing 8.4 ppg seawater GAS LIFT MANDRELS (HES) 'KBMGM' w. 1" BK' LATCH NO. MD-BKB TVD-SS #7 3946' 3490' #6 6122' 5238' #5 7447' 6302' #4 8323' 7001' #3 9185' 7705' #2 10051 8391' #1 10956' 9099' 8.4 ppg seawater 4-1/2", 12.6#/ft, L-80 TAILPIPE PERFORATION ~UMMARY REF_ I Oh E)IL ~ Intc_rv~l c.,-, ,~i?¢ ,~PF AWS 3-3/8 6 12,100' - 12,120' SWS 3-3/8" 6 12,080' - 12,100' 4-1/2" 'X' NIPPLE (HES) (3.813" MIN. ID) 7-5/8" PACKER ( TIW HB-BP-T ) 4-1/2" 'X' NIPPLE (HES) (3.813" ID) 4-1/2" 'XN' NIPPLE (HES) (3.725" ID) 4-1/2" WLE G New Style 17.0 ppg fiber cmt f/ 11700' to 11430' md 11099' 11175' 11186' 11198' 11188' 17.0 ppg cmt f/12276' (PB tag) to 11700' md PBTD 112314'I 7-5/8", I 12,404' I L-80 NSCC DATE 9/29/95 REV. DY GAM 10/4/95 JTP I 0/4/97 JTP 4/14/98 J LH OMMENTS INITIAL COMPLETION INITIAL PERFORATIONS ADD PERFORATIONS Proposed P&A ENDICOTT WELL 1-22/M-22 APl NO: 50-029-22577 COMPLETION DIAGRAM BP EXPLORATION. INC. STATE OF ALASKA ALASK-~'31L AND GAS CONSERVATION COMMISSI''~-'-I REPORT O. SUNDRY WELL OPEi..ATIONS ,~rations performed: Operation shutdown__ Stimulate__ Plugging~ Pull tubing__ Alter casing __ Repair well __ Perforate X Other 2. Name of Operator BP Exploration (Alaska) Inc. 3. Address P. O. Box 196612, Anchora_cle, Alaska 99519-6612 4. Location of well at surface 3217' NSL, 2114' WEL, Sec. 36, T12N, R16E 5. Type of Well: Development __ Exploratory __ Stratigraphic Service __ 6. Datum elevation (DF or KB) KBE = 56 feet 7. Unit or Property name Duck Island Unit/Endicott 8. Well number 1-33/M-23 At top of productive interval 1850' NSL, 1610' WEL, Sec. 36, T12N, R16E At effective depth 1710'NSL, 1241' WEL, Sec. 36, T12N, R16E At total depth 1683' NSL, 1188' WEL, Sec. 36, T12N, R16E 9. Permit number/approval number 95-107~Not Required 10. APl number 50- 029-22577 11. Field/Pool Endicott Field/Endicott Pool 12. Present well condition summary Total depth: measured true vertical Effective depth: measured true vertical 12425 feet 10347 BKB feet 12314 feet 10259'BKB feet Plugs (measured) Junk (measured) ORIGINAL Casing Length Size Cemented Structural Conductor 91' 30" Driven Surface 4974' 10 3/4 1725 c.f. Permafrost Intermediate 690 c.f. Class "G" Production 12365' 7 5/8" 559 c.f. Class "G" Liner Perforation depth: measured 12080'- 12100'; 12100'- 12120' (Open) true vertical (subsea) 10019'- 10034'; 10034'- 10050' (Open) Tubing (size, grade, and measured depth) 4 1/2" 12.6# tubing set at 11198'. Measured depth BKB True vertical depth BKB 130' 130' 5013' 4390' 12404' 10329' RECEIVED NOV 19 1991 Naska 011 & Gas Cons. Commission Anchorage Packers and SSSV (type and measured depth) 7 5/8" TIW HB-BP-Tpacker set at 11110'; 4 1/2 HES "HXO" SVLN set at 1581' 13. Stimulation or cement squeeze summary Intervals treated (measured) Treatment description including volumes used and final pressure 14. Prior to well operation Subsequent to operation Representative Daily Average Production or Injection Data OiI-Bbl Gas-Mcf Water-Bbl Casing Pressure 359 239 5730 0 613 252 5518 0 Tubing Pressure 329 361 15. Attachments Copies of Logs and Surveys run __ Daily Report of Well Operations X 16. Status of well classification as: Oil X Gas__ Suspended__ Service J 17. I hereby certify tha. t/t~f~ foregoing is _true and correct to the best of my knowledge. Form 10-~0~ Rev06/15/88 - -- J Date 11/14/97 SUBMIT IN DUPLICATE BPX Endicott Production Engineering Department ADD- PERF DATE: 10/4/97 WELL N°: 1-33/M-23 BP EXPLORATION REP: SERVICE COMPANY: VARBLE SWS (C. YON) DATE/TIME OPERATIONS SUMMARY 1445 MIRU SWS FWHP= 300 lAP= 1700 OAP= 0 1500 Hold safety meeting 1505 Arm gun 1515 Shut in well & RIH with GUN-GR/20' GUN with SAFE PKG. 1625 Out of tbg. Open choke to 40 beans to underbalance. 1630 Log tie in pass. Tie into DIFL dated 9/25/95. Add 6' 1635 Log confirmation pass. On depth. Log into place & hang CCL @ 12074' md. (6' from CCL to top shot) 1644 Shoot gun from 12080'-12100' md. No indication gun fired. 1648 Log off & POOH. (gun pulling a little heavier) 1743 OOH. 1755 Confirm all shots fired. Lift radio silence. 1810 POP to FOC with G/L & request test ASAP. 1900 RDMO SWS. PERFORATION SUMMARY: SUBZONE DEPTH INTERVAL 2A 12,080'-12100' MD 20' ALL PERFORATIONS WERE SHOT WITH 3-3/8 HSD, 20.5 GRAM CHARGES, 6 SPF, 60 DEGREE PHASING, RANDOM ORIENTATION. GeoQuest 500 Wo International Airport Road Anchorage, AK 99518-1199 ATTN: Sherrie NO. 11334 Company: Field: Alaska Oil & Gas Cons Comm Attn: Lori Taylor 3001 Porcupine Drive Anchorage, AK 99501 Endicott (Cased Hole) Well Job # Log Description Date BL RF Sepia LIS Tape 1-31/M-21 ~ 7~3 o"7 97395 TDT~" - 970817 I I ,! '1'33/M'23 ~ '"7'~ O '~ 97396 TDTP , 970818 1 1 1 ..... 4-10/M-28-~-- 77~ ~ 97397 !TDTP " 970819 1 1 1 · 9/8/97 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING ONE COPY EACH TO: BP Exploration (Alaska) Inc. Petrotectnical Data Center MB3-3 900 E. Benson Blvd. Anchorage, Alaska 99519-6612 Date Delivered: RECEIVED SEP 1 1 1997 0il & Gas L~ns. L:ommi,~i~ Schlumberger GeoQuest 500 W. International Airport Road Anchorage, Alaska 99618-1199 F' E R h'i l T D A T,':\ T D A T A ....F' L. LIS ~'j ,5,50 -' i '2 a. 'i 3 .._~. -'J'i67()" i24.'i'/ ~ L.-C~'i 'i 8 7 0 .... 'i 2 4. 'i 7 ~'i 1SbU .... 'i2'iSO ,~--~'i'J050 .... J2279- ~'i0500 ..... ii-2.282 ~i670 .... i24'i7 r , ~' 'J'i670-i'24.'i7 · . . i7;, T.. F I /' Z D L/" C i,.l/' ,3 ., . 'i 0 .... 4 0 7 ~ C O H P L. E T 1,3, N B, A T F: (O/' c~ /, ~.)-.,,." ~? ,'"',~ (o ,,"~I(o W a s 't h e ',,,~ e i 1 c: o r" :a d ? y e s ~--A n a 'i y: '¥ s & d e s c r' 'i' r-" t. 'i <.> n r" :? c e 'i' v :~. d '? ',:/,~:>~ ff~.::, C O H H E N T S ~- [::: :e c e '¥ v e <.:! ? STATE OF ALASKA AL. ..~r,,A OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Opera~ions performed: Operation shutdown ~ Stimulate ~ Plugging.__ Perforate__ Pull tubing__ Alter casing __ Repair well Other X 2. Name of Operator BP Exploration (Alaska) Inc. 3. Address P. 0. Box 196612, Anchorage, Alaska 99519-6612 4. Location of well at surface 3217' NSL, 2114' WEL, Sec. 36, T12N, R16E 5. Type of Well: Development Exploratory Stratigraphic Service 6. Datum elevation (DF or KB) KBE = 56 feet 7. Unit or Property name Duck Island Unit/Endicott 8. Well number 1-33/M-23 At top of productive interval 1850' NSL, 1610' WEL, Sec. 36, T12N, R16E At effective depth 1710' NSL, 1241' WEL, Sec. 35, T12N, R16E At total depth 1683' NSL, 1188' WEL, Sec. 36, T12N, R16E 9. Permit number/approval number 95-107/Not Required 10. APl number 50- 029-22577 11. Field/Pool Endicott Field/Endicott Pool 12. Present well condition summary Total depth: measured true vertical Effective depth: measured true vertical 12425 feet 10347 BKB feet 12314 feet 10259'BKB feet Plugs (measured) Junk (measured) ORIGINAL Casing Structural Conductor Surface Intermediate Production Liner Perforation depth: Length Size Cemented Measured depth True vertical depth BKB BKB 91' 30" Driven 130' 49 74' 10 3/4 1725 c.f. Permafrost 5013' 690 c.f. Class "G" 12365' 7 5/8" 559 c.f. Class "G" 12404' measured 12100'- 12120' 130' 4390' 10329' R C IVED true vertical (subsea) 10034'- 10050' /~ U G 1 4 19 9 ~ Tubing (size, grade, and measured depth) 4 1/2" 12.6# tubing set at 11198'. Alaska 0il & Gas Cons. Commission Anchorage Packers and SSSV (type and measured depth) 75/8" TIWHB-BP-Tpackersetat 11110~ 4 1/2 HES "HXO"SVLNsetat 1581' 13. Stimulation or cement squeeze summary Down Squeeze (3/2/96) description below Scale Inhibitor Treatment (4/19/96) description attached Intervals treated (measured) 12100'-12120' Treatment description including volumes used and final pressure 162 bbls Class 'G' cement, 17 bbls cold set cement, 240 bbls Seawater, 57 bbls Fresh Water, 117 bbls Diesel, 20 bbls 60/40 MEOH. 14. Prior to well operation Subsequent to operation Representative Daily Average Production or Injection Data OiI-Bbl Gas-Mcr Water-Bbl Casing Pressure 1820 980 4246 0 1004 425 2858 0 Tubing Pressure 331 319 15. Attachments 16. Status of well classification as: Copies of Logs and Surveys run __ Daily Report of Well Operations X .. Oil X Gas__ Suspended 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. ,' (1/./"-, z/ /.,',-,/..-? :I' SignedL_.~':-L,~? /: (~.-/~::' / /:.--(' :'~-.C.,':' . Title Senior Technical Assistant IV Form 10-49'4 Rev 06/15/88 Service Date 8/12/96 SUBMIT IN DUPLICATE Endicott Production Engineering Department DATE: 4/19/96 WELL N-°: 1-33/M-23 BP EXPLORATION REP: SERVICE COMPANY: Scale Inhibitor Treatment R. Clump HB&R / APC LAST TEST DATA (4/09/96) OIL RATE CHOKE GOR BS&W WEEP WHET (BPD) (BEANS) (SCF/STB) (%) (PSIG) (DEG F) 965 176 654 79 343 174 Gas lift was 0.G MMCFD. TIME OPERATIONS SUMMARY 093O 0957 TGSM. MIRU HB & R to pump down tbg. PRESSURE TEST LINES TO 3000 PSIG. CURRENT WELL DATA (WELL HEAD) FWHP FWHT lAP OAP CHOKE (PSIG) (DEG F) (PSIG) (PSIG) (BEANS) 300 175 1700 0 176 I 1000 SHUT IN WELL. 1001 PUMP FOLLOWING TREATMENT. FILTERED ALL FLUIDS TO 3 MIC ON THE FLY. TREATMENT PROGRAM VOLUME (BBLS) FLUID Sea water w/ BPCI SS-5206 mutual solvent. Seawater mixed with BPCI SI-4004 scale inhibitor. 141 150 Overflush of seawater with 0.2% NE-18 non-ionic surfactant. 2 04 Seawater tubing displacement. PUMP DATA TIME RATE (BPD) PRESS (PSIA) TOTAL BBLS COMMENT I 001 1.0 700 0 Solvent I 01 6 3.0 975 I 3 Switch to Inhibitor 1051 5.0 1200 155 Switch to Overflush 1120 5.0 1030 300 Tb~l Displac 1201 5.0 1400 504 Freeze protect 1211 1.5 200 509 Finish 1211 FINISH PUMPING TREATMENT. 1230 RDMO VAC TRUCKS AND HB&R. NOTIFY CONTROL ROOM TO LEAVE WELL SHUT IN FOR 12 HOURS & SCHEDULE FOR SAMPLING. Memorandum State of Alaska Oil and Gas Conservation Commission To: Tuckcrman Babcock Dave Norton Jack Hartz Bob Crandall Blair Wondzell From: David W,~~ Chairma~---"~ Date: March 27, 1996 Telephone: 279-1433 Fax number: 276-7542 Subject: Cementing/Surface Casing Blair Wondzell and our inspectors are reporting more problems with cementing of surface casing. See attached reports. A_.A.~s y~ntly met with BP to discuss the Endicott problem with annular disposal in~,.~l 1-33/M-23, wh~wwwwwwwwwwwww~as caused by inadequate cementing of surface casing. Since then additional p~ come to light, including Sourdough #3 and MPK-25. In reviewing Blair's report, I am struck ~vith the seriousness of the problem, which goes beyond annular disposal and into the category of well control. I am calling a meeting for 9:00 a.m. Friday, March 29 to discuss possible Commission action. FYI--Draft regulation language for cementing surface casing is as follows. OFFSHORE (A) Cementing of surface casing. Surface casing shall be cemented with a quantity of cement that fills the calculated annular space to the surface, however if drilling from a mobile bottom-founded jack-up or floating vessel, the top of the cement must be brought to the mudline datum. (i) The operator shall evaluate the adequacy of the cementing operations by a cement evaluation log or other means approved by the commission. If cement does not circulate to the surface or if the cement evaluation shows an inadequate cementing job, the casing will be perforated just above the top of cement and cement circulated to ensure integrity of cement to surface. (ii) Cement may be washed out to a depth not exceeding 100 feet above the conductor casing shoe, to facilitate removal upon well abandonment. ONSHORE (A) Cementing of surface casing. Surface casing shall be cemented with a quantity of cement that fills the calculated annular space to the surface. (i) The operator shall evaluate the adequacy of the cementing operations by a cement evaluation log or other means approved by the commission. If cement does not circulate to the surface or if the cement evaluation shows an inadequate cementing job, then the operator shall present a plan for remedial action for commission approval on the form entitled Application for Sundry Approval (Form 10-403). STATE OF ALASKA ALA,sKA OIL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMP LETION REPORT AND LOG 1. Status of Well Classification of Service Well OIL [] GAS [] SUSPENDED [] ABANDONED [] SERVICE [] 2. Name of Operator 7, Permit Number BP Exploration (Alaska) Inc 95-107 3. Address 8. APl Number P. 0. Box 196612, Anchorage, Alaska 99519-6612 50- 029-22577 4. Location of well at surface 9. Unit or Lease Name 3217' NSL, 2114' WEL, SEC. 36, T12N, R16E ........... ~' ~_:~::~- ......... ~.~ Duck Island Unit/Endicott At Top Producing Interval .:. . 1-33/1V1-23 1849' NSL, 3671' EWL, SEC. 31, T12N, R17E i ~ Endicott Field/Endicott Pool 5. Elevation in feet (indicate KB, DF, etc.) 6. Lease Designation and Serial No. KBE = 56' ADL 312828 12. Date Spudded 13. DateT. D. Reached 14. Date Comp., Susp. or Aband. 115. Water Depth, if offshore 116. No. of Completions 09/02/95 09/19/95 10/04/95 6-12'AMSL feet MSL lOne 17. Total Depth (MD+TVD) 18. Plug Back Depth (MD+TVD) 19. Directional Survey ]20. Depth where SSSV set ~21. Thickness of Permafrost 12425' MD/10347' TVD 12314' MD/10259' TVD YES [] NO []I 1581 feet MD' ] 1650' (Approx.) 22. Type Electric or Other Logs Run G YRO, DIL, MWD, MSFL, LD T, CNL, GR 23. CASING, UNER AND CEMENTING RECORD SETRNG DEPTH MD CASING SIZE WT. PER FT. GRADE TOP BOTTOM HOLE SIZE CEMENTING RECORD AMOUNT PULLED 30" Struct. Drive 40' 130' Driven 10-3/4" 45. 5# L-80 42' 5013' 13-1/2" 795 sx PF 'E', 600 sx 'G' 7-5/8" 29. 7# USS-95 39' 12404' 9-7/8" 500 sx Class 'G' 24. Perforations open to Production (MD+TVD of Top and Bottom and 25. TUBING RECORD interval, size and number) SIZE DEPTH SET (MD) PACKER SET (MD) 3-3/8" gun diameter, 6 spf 4-1/2", 13CR80 11198' 11110' MD TVD 12100'- 12120' 10090'- 10106' 26. ACID, FRACTURE, CEMENT SQUFF'-/F, ETC. DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED Freeze protected w/21 bbl diesel to 1500' 27. PRODUCTION TEST Date First Production ]Method of Operation (Flowing, gas lift, etc.) 10/04/95 I Flowing Date of Test Hours Tested PRODUCTION FOR OIL-BBL GAS:MCF WATER-BBL CHOKESIZE IGAS-OIL RATIO TEST PERIOD II~ Flow Tubing Casing Pressure CALCULATED..~ OIL-BBL GAS-MCF WATER-BBL OIL GRAVITY-APl (corr) Press. 24-HOUR RATE ''~ 28. CORE DATA Brief description of lithology, porosity, fractures, apparent dips, and presence of oil, gas or water. Submit core chips. RECEIVED ORIGINAL Alaska 0it & 6as Cons. commission Anchorage Form 10-407 Submit in duplicate Rev. 7-1-80 CONTINUED ON REVERSE SIDE -~. 30. GEOLOGIC MA~_,, ,,eRS FORMATION TESTS NAME Include interval tested, pressure data, all fluids recovered and gravity, MEAS. DEFq'H TRUE VERT. DEPTH GOR, and time of each phase. ~ BHRZ 11656' 9739' Kekiktuk 11671' 9751' K2A 11992' 10006' 31. LIST OF A'I-I'ACHMENTS 32. I hereby certify that the foregoing is true and correct to the best of my knowledge Signed-/'/~~~ v ~ Title SeniorD#llin.qEn.qineer Date INSTRUCTIONS General: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. Item 1' Classification of Service Wells: Gas injeCtion, water injection, steam injection, air injection, salt water disposal, water supply for injection, observation, injection for in-situ combustion. Item 5: Indicate which elevation is used as reference (where not otherwise shown) for depth measurements given in other spaces on this form and in any attachments. Item 16 and 24: If this well is completed for separate production from more than one interval (multiple completion), so state-in item 16, and in item 24~how the~producing intervals for only the interval reported in item 27. Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval. Item 21' Indicate whether from ground level (GL) or other elevation (DF, KB, etc.). Item 23: Attached supplemental records for this well should show the details of any multiple stage cement- ing and the location of the cementing tool. Item 27: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water In- jection, Gas Injection, Shut-in, Other-explain. Item 28: If no cores taken, indicate "none". Form 10-407 BP/AAI SHARED SERVICE DAILY OPERATIONS PAGE: 1 WELL: 1-33/M-23 BOROUGH: NORTH SLOPE UNIT: ENDICOTT FIELD: ENDICOTT LEASE: API: 50- PERMIT: APPROVAL: ACCEPT: 09/01/95 10:00 SPUD: 09/02/95 12:00 RELEASE: OPERATION: DRLG RIG: DOYON 15 WO/C RIG: DOYON 15 09/02/95 (1) TD: 555'( 0) 09/03/95 (2) TD: 2659'(2104) 09/04/95 (3) TD: 4855' (2196) DRILLING MW: 0.0 VIS: 0 MOVE RIG TO 1-33/M-21. ACCEPT RIG AT 1000 HRS ON 09/01/95. SKID RIG OVER WELL. NU RISER AND FLOWLINES AND MIX SPUD MUD AND RU ROCK WASHER. RU ATLAS WIRELINE FOR GYRO. STRAP BHA AND MIX SPUD MUD. FUNCTION TEST DIVERTER AND CONDUCT ACCUMULATOR TEST. FILL RISER WITH MUD AND CHECK OUT SYSTEM. PU BHA ASSEMBLY AND STAND BACK IN DERRICK. PU MUD MOTOR, MWD, LC AND BIT AND ORIENT. SPUD AT 0000 HRS, 09/02/95. DRILLING FROM 109' TO 278' AND CIRCULATE FOR GYRO. RU AND RUN GYRO. GYRO WOULD NOT FALL, ADDED WEIGHT BARS AND CIRC. DRILLING FROM 278' TO 555'. RUNNING GYRO EVERY 90'. DRILLED T/2659' MW: 0.0 VIS: 0 BHA #1, DRILL F/555' TO 1127' RUNNING GYRO SURVEY EVERY 90'. AT 1127' GYRO SURVEY NOT ACCEPTABLE. TOOL FACE 190 OUT. POOH T/0'. OBSERVED WELL PRIOR TO PULLING OUT. CHANGE OUT ORIENTING SUB, CLEAN STABS AND INSPECT BIT. RIH T/1127'. CIRC, GYRO SURVEY STILL NOT ACCEPTABLE. CHANG EOUT GYRO AND RIH WITH GYRO. SURVEY STILL NOT ACCEPTABLE. P/U SWIVEL, BOW SPRING CENTRALIZER AND CHANGE SINKER BARS. GOOD SURVEY. DRILL F/1127' TO 2563'. RUN GYRO EVERY 90' TO 1619'. DRILLED T/4855' MW: 0.0 VIS: 0 BHA #1. CIRC AT 2659'. CBU AND OBSERVED WELL. POOH T/941' SHORT TRIP TO WIPE KICK OFF. RIH T/2659'. ON BOTTOM. DRILLED F/2659' TO 3997'. TAKING SURVEYS WITH MWD. CIRC AT 3997', PUMP HI-VIS SWEEP. HOLE SWEPT WITH SLUG. POOH T/2400'. RIH T/3997'. DRILLED F/3997' TO 4855' WELL : 1-33/M-2 OPERATION: RIG : DOYON 15 PAGE: 2 09/05/95 ( 4) TD: 5033'( 178) 09/06/95 (5) TD: 5043' ( 10) 09/07/95 (6) TD: 6679' (1636) DISPLACE SLURRY MW: 0.0 VIS: 0 RUN BHA #1. DRILL F/4855' T/5033'. CBU @ 5033',100% ANNULUS VOLUME. POOH T/3809'. AT TOP OF CHECK INTERVAL. RIH T/5033'. ON BOTTOM. CBU @ 5033'. OBSERVE. POOH T/464',PULL 10 STDS,OBSERVE WELL & SLUG PIPE. PULLED BHA. SERVICE DRILLFLOOR/DERRICK. RUN 10-3/4" OD CASING. RU DRILLFLOOR/DERRICK & CASING TOOL TO RUN CASING T]5013'. RAN 116 JTS, 45.5# L-80 BTC CASING & LANDED @ 5018'. HANGER LANDED. FLUID SYSTEM. CBU @ 5018',250% HOLE ANNULUS OBTAINED CLEAN RETURNS. BROKE CIRC & SLOWLY BROUGHT UP PUMP RATE TO 14 BPM WITH NO LOSSES. PUMPED SPACERS,VOLUME 100 BBL. PUMP 10 BBLS WATER. TEST LINES T/3500 PSI. PUMPED 90 BBLS WATER. REQ'D VOLUME SPACER MIXED & PUMPED SLURRY, 430 BBL-795 SX PF 'E' CMT @ 12 PPG FOLLOWED BY 600 SX OF PREMIUM CUT MIXED @ 15 PPG. RELEASE TOP PLUG. DISPLACE SLURRY, 468 BBLS. DISPLACING CEMENT WITH RIG PUMPS @ 14 BPM. DRILL T/5043' MW: 0.0 VIS: 0 DISPLACE SLURRY, 468 BBL. BUMPED PLUG @ 0625 HRS.,130 BBLS CEMENT RETURN TO SURFACE. TEST CASING. BUMPED PLUG T/2000 PSI FOR 30 MIN. OK. BLED OFF PRESSURE,FLOATS HELD. ND DIVERTOR. RD DRILLFLOOR/DERRICK. RD CASING EQUIP. RD DIVERTOR. NU BOP STACK. TEST BOP STACK. TEST ALL RAMS & VALVES 250/5000 PSI. TEST ANNULAR 250/3500 PSI. OK. WELLHEAD WORK. INSTALL WB. RUN BHA #2. SERVICE KELLY/TOP DRIVE HOSE. RIH T/4155'. RIH T/4922' & TAGGED TOP OF FLOAT COLLAR. CBU @ 4922',100% ANNULUS VOLUME OBTAINED BOTTOMS UP. TEST CASING T/3000 PSI FOR 30 MIN. OK. REPAIR/WELD STANDPIPE MANIFOLD. OK. RUN BHA #2. DRILLED T/5043'. DRILL FLOAT COLLAR, CEMENT, SHOE & 10' OF NEW HOLE T/5043'. DRILLED T/6679' MW: 0.0 VIS: 0 RUN BHA #2. CBU @ 5043',200% HOLE VOLUME OBTAINED REQ'D FLUID PROPERTIES. PERFORM TEST. OBTAINED LEAK OFF 12.7 PPG EMW. RU BHA #2. DRILLED T/5487'. PISTONS FAILED-CIRCULATE. REPAIR PISTONS #1 MUD PUMP. OK. RUN BHA #2. DRILLED T/6061' START WIPER TRIP. CBU @ 6061',100% HOLE VOLUME HOLE SWEPT WITH SLUG. POOH T/5013'. AT TOP OF CHECK TRIP INTERVAL. RIH T/6061'. NO PROBLEMS ON WIPER TRIP. ON BOTTOM. DRILLED T/6679' WELL : 1-33/M-2 OPERATION: RIG : DOYON 15 PAGE: 3 09/08/95 (7) TD: 7781' (1102) 09/09/95 (8) TD: 8668' ( 887) 09/10/95 (9) TD: 9151'( 483) 09/11/95 (10) TD: 9563'( 412') 09/12/95 (11) TD:10136' ( 573) POOH T/4500' MW: 0.0 VIS: 0 DRILLED T/7303'. CBU @ 7303',100% HOLE VOLUME HOLE SWEPT WITH SLUG. POOH T/5872'. TOP OF CHECK TRIP INTERVAL. OK. RIH T/7303'. ON BOTTOM. OK. DRILLED T/7385'. STOP TO CIRCULATE. SHALE SHAKERS UNABLE TO HANDLE SAND & CUTTINGS LOAD FROM WIPER TRIP. UNUSUAL AMOUNT OF SAND FOR THIS HOLE SECTION. CBU @ 7385',100% HOLE VOLUME OBTAINED CLEAN RETURNS. DRILLED T/7399'. MUD PUMPS FAILED. CIRCULATE. REPAIR VIBRATION DAMPNER ON MUD PUMP #1. OK. RUN BHA #2. DRILLED T/7781'. ROP DROPPED F/120' PER HR T/40' PER HR. BIT QUIT. CBU @ 7781',100% HOLE ANNULUS OBTAINED BOTTOMS UP. POOH T/4500'. DRILLED T/8668' MW: 0.0 VIS: 0 SERVICE TOP DRIVE. OK. RUN BHA #2. POOH T/1030'. PULLED BHA. CHANGE OUT MUD MOTOR. RUN BHA #3. RIH T/5000'. PU 30 JTS OF 5" DP. SERVICE BLOCK LINE. LINE SLIPPED & CUT. RUN BHA #3. RIH T/7721'. WASHED T/7781'. ON BOTTOM. DRILLED T/8668' DRILLED T/9151' MW: 0.0 VIS: 0 RUN BHA #3. CBU @ 8688',100% ANNULUS VOLUME OBTAINED BOTTOMS UP. POOH T/6184'. TOOK MWD SURVEY @ 6184'. OBTAINED ACCEPTABLE SURVEY. RIH T/8668'. BENCH MARK SURVEY @ 8478' ON BOTTOM. NO HOLE PROBLEMS. DRILLED T/8890'. MWD TOOL FAILED. END BHA RUN & REPAIR. CBU @ 8890',100% ANNULUS VOLUME OBTAINED BOTTOMS UP. POOH T/1030'. AT BHA. REPAIRED MWD TOOL. CHANGE OUT TOOL. OK. RIH T/8774' BENCH MARK SURVEY @ 6184'. WASHED T/8890'. ON BOTTOM. RUN BHA #4. DRILLED T/9151'. ROTATE 2 HRS. SLIDE 1-1/2 HRS. DRILLED T/9563' MW: 0.0 VIS: 0 RUN BHA #4. DRILLED T/9476'. BUILD RATE UNACCEPTABLE-BHA. UNABLE TO SLIDE WITH OUT BIT STALLING OUT THE MOTOR. THE HTC AG45 BIT MAY BE TOO AGGRESSIVE FOR THIS FORMATION. ANGLE IS DOWN TO 35.9 & HOLE IS 30' BELOW LINE. CBU @ 9486', 100% HOLE VOLUME HOLE SWEPT WITH SLUG. POOH T/1030'. AT BHA. PULLED BHA. LAY DOWN MWD MOTOR & BIT. MU & RUN BHA #5. SERVICE TOP DRIVE. RUN BHA #5. RIH T/5000'_ SERVICE BLOCK LINE. LINE SLIPPED & CUT. RUN BHA #5. RIH T/9411'. WASHED T/9486'. ON BOTTOM. DRILLED T/9563'. ROP WHILE ROTATING IS 55'/HR. SLIDING IS 25'/HR. ARE NOW ABLE TO GET GOOD STEADY SLIDES. DRILLED T/10136' MW: 0.0 VIS: 0 RUN BHA #5. DRILLED T/9795'. MUD PUMP FLUID END FAILED. REPAIR. POOH T/5000' @ 10-3/4" CASING SHOE. MUD PUMP FLUID END CHANGED OUT. OK. RIH T/9795'. ON BOTTOM. RUN BHA #5. DRILLED T/10136'. WELL : 1-33/M-2 OPERATION: RIG : DOYON 15 PAGE: 4 09/13/95 (12) TD:10551' ( 415) 09/14/95 (13) TD:10842' ( 291) 09/15/95 (14) TD:ll144' ( 302) 09/16/95 (15) TD:11354' ( 210) 09/17/95 (16) TD:11879' ( 525) 09/18/95 (17) TD:12007' ( 128) TEST BOP STACK MW: 0.0 VIS: 0 RUN BHA ~5. DRILLED T/10551'. MAX HOURS ON BIT. CBU @ 10551',100% ANNULUS VOLUME OBTAINED BOTTOMS UP. POOH T/1007'. OK. PULLED BHA. RETRIEVE WEAR BUSHING. TEST BOP STACK. WITNESS WAIVED BY JOHN SPALDING W/AOGCC. PRESSURE TEST COMPLETED SUCCESSFULLY T/5000 PSI. DRILLING MW: 0.0 VIS'~ 0 PRESSURE TEST BOP STACK T/5000 PSI. OK. INSTALL WEAR BUSHING. RUNNING TOOL RETRIEVED. RUN BHA #6. RIH T/367'. TOP DRIVE FAILED,END BHA RUN. REPAIR TOP DRIVE. CHANGED OUT VALVE & SEQUENCE ON SAVER SUB. RUN BHA #6. RIH T/6155'. PU 30 JTS OF 5" DP. TAKE MWD BENCH MARK SURVEY @ 6155' OK. RIH T/10463'. REAM T/10551'. ON BOTTOM. DRILLED T/16584' & ROTATE 2 HRS. PISTONS FAILED. END BHA RUN. CHANGE OUT PISTONS ON #1 PUMP. RUN BHA #6. DRILLED T/10842'. MW/) SURVEY AT 6156' MW: 0.0 VIS: 0 BHA #6. DRILLED T/11144'. BIT QUIT. CIRC, HOLE SWEPT WITH SLUG. POOH T/1007'. BHA #7, RIH T/6156'. TOOK MWD SURVEY, ACCEPTABLE SURVEY OBTAINED. RIH T/6156';TAKE SURVEY MW: 0.0 VIS: 0 RUN BHA #7. RIH T/10900'. OBSERVED 50000 KLB RESISTANCE. REAM T/11144'. ON BOTTOM. DRILLED T/11354'. DRILL RATE SLOW THIS SECTION. UNABLE TO HOLD OR BUILD ANGLE. SUSPECT BIT MIGHT HAVE BEEN PINCHED IN TIGHT SPOT WHILE TRIPPING IN HOLE. CBU @ 11354',100% ANNULUS VOLUME OBTAINED BOTTOMS UP. OBSERVE WELL. POOH T/1007'. PULLED BHA. BIT IN GAUGE NOT PINCHED. RUN BHA #8. TEST MWD TOOL VIA STRING. FUNCTION TEST OK. RIH T/6156'. TAKE BENCHMARK SURVEY. DRILLING MW: 0.0 VIS: 0 RUN BHA #8. TOOK BENCHMARK SURVEY @ 6156'. ACCEPTABLE SURVEY OBTAINED @ 6156'. RIH T/10900'. REAM T/11354'. ON BOTTOM. 2' OF FILL ON BOTTOM. DRILLED T/11778'. CBU @ 11778, 100% HOLE VOLUME OBTAINED REQ'D FLUID PROPERTIES. MUD WT GAS CUT F/10.5 PPG T/10.0 PPG. MUD WT 10.5 PPG IN & OUT OF HOLE. WELL STABLE. DRILLLED T/11829'. ROTATE 1 HOUR. CBU @ 11829,100% HOLE VOLUME OBTAINED REQ'D PROPERTIES. RAISED MUD WT T/10.7 PPG. GAS CIRCULATED OUT. WELL STABLE. DRILLED T/11879'. ROTATE 1-1/2 HOURS. REAM TO BOTTOM MW: 0.0 VIS: 0 DRILL F/11879' T/11926'. CIRC GAS CUT MUD. CUT F/10.7 PPG T/10.2 PPG. DRILL F/11926' T/12007'. CIRC HI & LO VIS SWEEP. TOH FOR BIT & BHA. PULL BHA. LD MWD & MOTOR. MU BHA #9. SERVICE RIG. TIH T/6000'. CUT & SLIP DRILLING LINE. TIH T/11124'. TIGHT HOLE. REAM HOLE F/11124' T/12007'. HOLE WAS TIGHT F/11837' T/BOTTOM @ 12007' WELL : 1-33/M-2 OPERATION: RIG : DOYON 15 PAGE: 5 09/19/95 (18) TD:12231' ( 224) 09/20/95 (19) TD:12425' ( 194) 09/21/95 (20) TD: 12425' ( 0) 09/22/95 (21) TD:12425' ( 0) 09/23/95 (22) TD:12425' ( 0) 09/24/95 (23) TD:12425' ( 0) DRILLING MW: 0.0 VIS: 0 RUN BHA #9. DRILL T/12114'. HAD CHANGE IN TORQUE F/23500 FT/LB T/28500 FT/LB. BIT QUIT, BIT UNDER GAUGE. CBU @ 12114, 100% ANNULUS VOLUME OBTAINED BOTTOMS UP. POOH T/952' o PULLED BHA. CHANGED BIT & GAUGE STABILIZERS. BIT IS 3/16 UNDER GAUGE & NB STABILIZER 1/16 UNDER. RUN BHA #10. RIH T/12014'. REAMED T/12114'. ON BOTTOM, NO FILL. DRILL T/12231'. POOH T/3000' MW: 0.0 VIS: 0 BHA #10, DRILLED T/12425'. REACHED PLANNED END OF RUN. CBU, POOH T/9520'. TIGHT HOLE FROM 12425' TO 11750'. WORKED CLEAN. RIH T/12425', NO PROBLEMS. CIRC, PUMPED HIGH AND LOW VIS SWEEPS. HOLE SWEPT WITH SLUG. POOH T/3000' CIRC AT 12425' MW: 0.0 VIS: 0 BHA #10, POOH T/952'. BHA STOOD BACK. RU ATLAS WIRELINE. RAN TRIPLE COMBO. COMPLETED LOGGING RUN WITH FORMATION LOGS FROM 12420' TO 11670'. RAN FMT-GR-CHT. COMPLETED MISRUN WITH FMT T/11737'. FIRST SET FAILED. PULLED TOOL FREE. TOOL DRAGGING. RD ATLAS WIRELINE. TESTED WELL CONTROL EQUIPMENT. BHA #11, RIH T/5000', 10-3/4" CASING SHOE. RIH T/11843', BEGAN TAKING WEIGHT. WASHED T/12425', NO PROBLEMS WITH PUMP ON. WASHED FROM 11843' TO 12032'. CIRC AT 12425'. PUMP LO/HI VIS SWEEP WHILE WORKING PIPE. RUN CASING MW: 0.0 VIS: 0 RUN BHA #11. POOH T/792'. OBSERVE WELL, PULL 10 STDS & SLUG PIPE. STOOD 80 STDS IN DERRICK & LD 120 JTS. PULLED BHA. WELLHEAD WORK, RETRIEVED WEAR BUSHING. SET TEST PLUG. NU TOP RAM. INSTALL 7-5/8" CASING RAM. TEST SEALS T/2500 PSI. OK. RUN 7-5/8" OD CASING T/11715'. RAN 270 JTS OF 7-5/8" 29.7# USS-95 BTC MOD CASING. LOST APPROX 108 BBLS MUD. R/U ATLAS AND RUN GYRO MW: 0.0 VIS: 0 RAN CASING T/12404'. HANGER LANDED. CBU. MIXED AND PUMPED CEMENT SLURRY. PLUG BUMPED. TESTED CASING, TEST WELL CONTROL EQUIPMENT. FREEZE PROTECT WELL. R/U ATLAS WIRELINE AND RUN GYRO SURVEY. RAN DP T/11272' MW: 0.0 VIS: 0 COMPLETED LOGGING RUN WITH GYRO FROM 12314' TO 0'. POOR BOND LOG. RD AND RELEASE ATLAS WIRELINE. COMPLETED LOGGING RUN WITH CEMENT BOND LOG FROM 12282' TO 10500'. R/U DRILLSTRING HANDLING EQUIPMENT. RAN DP T/373', CIRC. RAN DP T/11272'. WELL : 1-33/M-2 OPERATION: RIG : DOYON 15 PAGE: 6 09/25/95 (24) TD: 0 PB: 0 09/26/95 (25) TD:12425' ( o) PERFORATE MW: 0.0 RAN DP T/12314', FLOAT COLLAR. WEIGHT UP MUD. CIRC AT 12314'. DISPLACE SEAWATER FROM WELL WITH MUD. PULL DP. R/D BELL NIPPLE, R/U LUBRICATOR, SHOOTING NIPPLE. R/U ATLAS WIRELINE AND TEST LUBRICATOR. PERFORATED: RUN #1 WITH 3-3/8" GUN. CORRELATED AND FIRED GUN. GUN MISFIRED AND RUPTURED SIDE OF HOLLOW CARRIER. CASING GUNS RETRIEVED. RUN #2, RIH WITH 3-3/8" GUN. CORRELATED AND FIRED. GUN.~'6 SPF WITH 60 DEGREE PHASING. GUNS RETRIEVED, FIRED SUCCESSFULLY FROM 12070' TO 12080'. RUN #3, RIH WITH GAUGE RING AND JUNK BASKET TO 12150'. COMPLETED LOGGING RUN WITH JUNK BASKET/GAUGE RING FROM 12150' TO 0'. RUN #4, SET HOWCO 7-5/8" EZSV CEMENT RETAINER AT 12050'. RUN #5, RIH WITH 3-3/8" GUN. POOH T/373' MW: 0.0 VIS: 0 WIRELINE WORK. PERFORATED RUN #5, FINISH RIH WITH 3-3/8" GUN. CORRELATED & FIRED GUN. 6 SPF WITH 60 DEGREE PHASING. GUN RETRIEVED-FIRED SUCCESSFULLY F/12005' T/11995'. RIGGED DOWN LINES/CABLES. RD ATLAS WIRELINE. RD LUBRICATOR & SHOOTING FLANGE. RU BELL NIPPLE. NU BOP STACK. CHANGE TOP & BOTTOM RAMS TO 3-1/2 RAMS. INSTALL WEAR BUSHING. RUN 3-1/2" DP T/12050' TOP OF PACKER. CBU @ 12050'. CIRC & ESTABLISH RATES & PRESSURES PRIOR TO STABBING INTO CEMENT RETAINER. STABBED INTO RETAINER & ATTEMPTED TO ESTABLISH CIRC. PRESSURE T/1500 PSI. PRESSURE BLED T/1000 PSI IN 15 MIN. NO RETURNS TO SURFACE. SLOW CIRC RATES COMPLETED. PULLED DP, OBSERVE. OK. RUN BHA %12. PU NEW BIT. RIH T/11971'. SERVICE BLOCK LINE. LINE SLIPPED & CUT. RUN BHA #12. DRILLED T/12314'. BREAK CIRC, TAG CEMENT RETAINER @ 12050'. DRILL RETAINER & PUSH T/12314'. CBU @ 12314', 100% ANNULUS VOLUME OBTAINED BOTTOMS UP. POOH T/373' @ BHA. WELL : 1-33/M-2 OPERATION: RIG : DOYON 15 PAGE: 7 09/27/95 (26) TD:12425' ( 0) 09/28/95 (27) TD: 0 PB: 0 09/29/95 (28) TD:12425 PB: 0 09/30/95 (29) TD:12425 PB: 0 CBU @ 12100' MW: 0.0 VIS: 0 RUN BHA #12. PULLED 3-1/2" BHA. CEMENT STINGER WORKSTRING RUN. RAN DP T/12150'. SPOT SAMPLE. RU DRILLFLOOR/DERRICK. CHANGE BAILS & RU CEMENT LINE. CEMENT SQUEEZE. MIX & PUMP SLURRY. SPOT 15 BBL BALANCED PLUG F/12150' T/11825'. CEMENT STINGER WORKSTRING RUN. PULLED DC IN STDS T/11216'. CBU @ 11216', 100% ANNULUS VOLUME OBTAINED BOTTOM UP. WOC. CLOSE RAMS. PRESSURE UP T/500 PSI. RU DRILLFLOOR/DERRICK~ CHANGE BAILES. CEMENT STINGER WORKSTRING RUN. PULLED DP. RUN BHA #13. RIH T/il018'. SERVICE LINES/CABLES. LINE SLIPPED & CUT. RUN BHA #13. RIH T/11825'. WASHED T/11985'. WASHED TO TOC @ 11971'. WASH & REAM F/11971' T/11985'. TOP SET OF PERFS 11970'-11976'. CBU @ 11985', 100% ANNULUS VOLUME OBTAINED BOTTOMS UP. TEST CSG T/1500 PSI. PRESSURE BLED DOWN T/1450 PSI. BUMP PRESSURE TO 1500 PSI & PRESSURE STABILIZE @ 1450 PSI. OBSERVED LEAK. RUN BHA #13. DRILLED CEMENT T/12050'. TEST CSG. CBU @ 12050', 100%' ANNULUS VOLUME OBTAINED BOTTOMS UP. TEST CSG T/1500 PSI. STABILIZED @ 1450 PSI. OBSERVE LEAK. RUN BHA #13. DRILL CEMENT T/12100' WITHOUT ROTARY. NO FIRM CEMENT. TEST CSG. CBU @ 12100'. RUN TUBING MW: 0.0 EXTENSION GIVEN FOR BOP TEST BY DOUG AMOS WITH AOGCC. TEST CASING. RUN BHA #13. DRILLED CEMENT T/12314'. CBU @ 12314' TWICE WHILE ROTATING & RECIPROCATING PIPE & DISPLACING MUD FROM HOLE WITH BRINE. POOH T/373'. PULLED BHA. RETRIEVE WEAR BUSHING, INSTALL TEST PLUG, CHANGE RAMS & TEST T/5000 PSI. CHANGE TOP DRIVE & IRON ROUGHNECK FROM 3-1/2" TP 5' PIPE. INSTALL WEAR BUSHING. CONDUCT SLICKLINE TO INSURE FISH @ BOTTOM. RD CAMCO. REMOVE WEAR BUSHING. RU TUBING HANDLING EQUIP & RUN TUBING T/600' INSTALL XMAS TREE MW: 0.0 RUN 4-1/2" TUBING T/9700'. SC SSSV NIPPLE ASSEMBLY INSTALLED AND TESTED. RAN TUBING T/11198'. INSTALLED TUBING HANGER. CIRC. RAN TUBING T/11198' LANDED HANGER AND RUN IN , LOCK DOWN SCREWS. INSTALLED HANGER PLUG. ND BOP STACK. INSTALLED XMAS TREE. RELEASED @ 1230 HRS.,9/29 MW: 0.0 REMOVE HANGER PLUG. DROPPED 2-1/4" BRASS BALL. RUN SINGLE COMPLETION. SET PACKER @ 11110'. FREEZE PROTECT WELL. INSTALL HANGER PLUG & BPV. MOVE & SKID RIG FLOOR. RIG RELEASED @ 1230 HRS., 09/29/95. SIGNATURE: (drilling superintendent) DATE: B.P. EXPLORATION MPI UNIT 1-33/M-23 ENDICOTT FIELD, ALASKA Gyro Multishot Survey Of 7 5/8" CASING Survey date · 23 September, 1995 RECEIVED MAR 2 G 1996 Alaska Oil & Gas Cons. Commission Anchorage Job number · AK0995G295 ORIGINAL Date ~.~~-~b~ SR295.DOC Gyrodata Incorporated P.O. Box 79389 Houston, Texas 77279 713/461-3146 Fax: 713/461-0920 October 4, 1995 BP Exploration (Alaska) Inc. Petrotechnical Data Center, MB 3-3 900 East Benson Blvd. Anchorage, Ak. 99519-6612 Re: MPI Unit 1-33/M-23, Endicott Field, Alaska Enclosed please find one (1) original and eight copies (8) of the completed survey of Well 1- 33/M-23, along with one data disk. We would like to take this opportunity to thank you for using Gyrodata and we look forward to serving you in the furore. Operations Manager RJS/gr Serving the Worldwide Energy Industry with Precision Survey Instrumentation gyro/data CONTENTS JOB NUMBER :AK0995G295 1. DISCUSSION, SURVEY CERTIFICATION SHEET 2. SURVEY DETAILS 3. OUTRUN SURVEY LISTING 4. QUALITY CONTROL 5. EQUIPMENT AND CHRONOLOGICAL REPORT SR295.DOC gyro/data 1. DISCUSSION , SURVEY CERTIFICATION SHEET SR295.DOC gyro/data DISCUSSION JOB NUMBER' AK0995G295 Tool 713 was run in 1-33/M-23 on ATLAS 5/16" Wireline inside 7 5/8". The survey was run without problems. SR295.DOC gyro/data SURVEY CERTIFICATION SHEET JOB NUMBER: AK0995G295 The data for this survey and the calculations for this survey were obtained and performed by me according to standards and procedures as set forth by Gyrodata Limited, true and correct to the best of my knowledge. TOM STODDARD OPERATIONS ENGINEER The data and calculations for this survey have been checked by me and conform to the standards and procedures as set forth by Gyrodata Limited. This report represents a directional survey of this well based on the original data obtained at the wellsite. Checked by :- ROB SHOUP OPERATIONS ENGINEER SR295.DOC gyro/data 2. SURVEY DETAILS SR295.DOC gyro/data SURVEY DETAILS JOB NUMBER: AK0995G295 CLIENT: B.P. EXPLORATION RIG: LOCATION: MPI UNIT, ENDICOTT FIELD, ALASKA WELL: 1-33/M-23 LATITUDE: 70.3525 N LONGITUDE: SURVEY DATE: 23-September, 1995 SURVEY TYPE : MULTISHOT IN 7 5/8" Casing DEPTH REFERENCE: MAX. SURVEY DEPTH: ROTARY TABLE ELEVATION 56' 12265 SURVEY TIED ONTO: N/A SURVEY INTERVAL: 100' from 12265 to 2500 feet. 50' from 2500 to 1200 feet. 100' from 1200' to Surface. UTM CO-ORDINATES: TARGET DIRECTION: 110.0 GRID CORRECTION: CALCULATION METHOD: MINIMUM CURVATURE SURVEYOR: STODDARD SR295.DOC gyro/data 3. OUTRUN SURVEY LISTING SR295.DOC A Gyrodata D irect iona i Survey for Bo P. EXPLORATION WELL: 1-33/M-23, 7 5/8" CASING Location: MPI UNIT, ENDICOTT FIELD, ALASKA Job Number: AK0995G295 Run Date: 23-Sep-95 17:02:55 Surveyor: TOM STODDARD Calculation Method: MINIMUM CURVATURE Survey Latitude: 70.352500 deg. N Sub-sea Correction from Vertical Reference: 56 ft. Azimuth Corrected:: Gyro: Bearings are Relative to True North Proposed Well Direction: 110.000 deg Vertical Section Calculated from Well Head Location Closure Calculated from Well Head Location Horizontal Coordinates Calculated from Local Horizontal Reference A Gyrodat a Directional Survey B.P. EXPLORATION WELL: 1-33/M-23, 7 5/8" CASING Location: MPI UNIT, ENDICOTT FIELD, Job Number: AK0995G295 ALASKA Page MEASURED I N C L AZIMUTH DEPTH feet deg. deg. DOGLEG VERTICAL SUBSEA VERTICAL SEVERITY DEPTH DEPTH SECTION deg./ feet feet feet 100 ft. CLOSURE DIST. AZIMUTH feet deg. HORIZONTAL COORDINATES feet 0.0 0.00 0.00 0.00 0.0 -56.0 GYRO SURVEY FROM 12265' TO SURFACE IN 7 5/8" CASING. ALL DEPTHS REFERENCED TO R.K.B. OF 56'. 0.0 0.0 0.0 0.0 N 0.0 E 100.0 .03 342.76 .03 100.0 44.0 200.0 .06 114.84 .08 200.0 144.0 300.0 .60 151.24 .55 300.0 244.0 400.0 2.74 155.13 2.14 399.9 343.9 500.0 3.92 153.81 1.18 499.8 443.8 -.0 .0 342.8 .0 .0 59.6 .5 .6 143.8 2.6 3.5 152.7 6.7 9.3 153.7 .0 N .0 W .0 N .0 E .5 S .3 E 3.1 S 1.6 E 8.3 S 4.1 E 600.0 2.70 149.64 1.24 599.6 543.6 700.0 2.24 146.65 .47 699.5 643.5 800.0 1.31 119.00 1.24 799.5 743.5 900.0 1.12 67.63 1.07 899.5 843.5 1000.0 1.32 67.77 .20 999.4 943.4 11.0 15.1 153.1 14.4 19.3 152.0 17.1 22.3 150.0 18.9 23.4 146.1 20.5 23.9 141.1 13.4 S 6.8 E 17.1 S 9.1 E 19.3 S 11.1 E 19.5 S 13.1 E 18.6 S 15.0 E 1100.0 2.83 107.38 2.00 1099.4 1043.4 1200.0 6.90 120.92 4.20 1199.0 1143.0 1250.0 8.21 123.50 2.70 1248.5 1192.5 1300.0 8.52 121.31 .89 1298.0 1242.0 1350.0 8.92 117.17 1.48 1347.4 1291.4 23.8 26.4 135.8 32.2 34.5 131.3 38.6 41.0 129.8 45.7 48.3 128.7 53.2 55.8 127.4 18.9 S 18.5 E 22.8 S 26.0 E 26.3 S 31.5 E 30.2 S 37.7 E 33.9 S 44.3 E 1400.0 9.63 114.65 1.64 1396.8 1340.8 1450.0 10.71 112.07 2.35 1446.0 1390.0 1500.0 11.57 112.00 1.71 1495.1 1439.1 1550.0 13.05 111.17 2.98 1543.9 1487.9 1600.0 13.75 109.90 1.52 1592.5 1536.5 61.2 63.7 126.0 70.0 72.3 124.4 79.7 81.8 123.0 90.3 92.2 121.7 101.9 103.6 120.4 37.4 S 51.5 E 40.9 S 59.6 E 44.5 S 68.6 E 48.4 S 78.5 E 52.5 S 89.3 E 1650.0 14.13 110.09 .77 1641.1 1585.1 114.0 115.5 119.3 56.6 S 100.7 E A Gyrodata D ir ect iona i Survey B.P. EXPLORATION WELL: 1-33/M-23, 7 5/8" CASING Location: MPI UNIT, ENDICOTT FIELD, Job Number: AK0995G295 ALASKA Page MEASURED I N C L AZIMUTH DEPTH feet deg. deg. DOGLEG VERTICAL SUBSEA VERTICAL CLOSURE SEVERITY DEPTH DEPTH SECTION DIST. AZIMUTH deg./ feet feet feet feet deg. 100 ft. HORIZONTAL COORDINATES feet 1700.0 15.30 109.53 1750.0 16.70 108.92 1800.0 18.26 108.02 1850.0 19.64 107.03 . 2. 3. 2. 36 83 16 84 1689.4 1737.5 1785.2 1832.5 1633 1681 1729 1776 .4 .5 .2 .5 126.6 140.4 155.4 171.7 128.0 118.4 141.6 117.5 156.5 116.7 172.5 115.8 60.9 S 112.6 E 65.4 S 12506 E 70.2 S 139.9 E 75.1 S 155.3 E 1900.0 21.38 105.45 1950.0 22.43 105.52 2000.0 23.59 105.53 2050.0 24.01 106.04 2100.0 25.40 104.04 . 65 10 33 93 25 1879.3 1925.7 1971.7 2017.5 2062.9 1823 1869 1915 1961 2006 .3 .7 .7 .5 .9 189.1 207.7 227.2 247.3 268.1 189.8 114.9 208.3 114.1 227.6 113.3 247°6 112.7 268.3 112.1 80.0 S 172.2 E 84.9 S 190.1 E 90.2 S 209.0 E 95.7 S 228.4 E 101.1 S 248.6 E 2150.0 26.70 103.87 2200.0 28.08 103.97 2250.0 28.71 103.66 2300.0 30.13 102.95 2350.0 30.78 103.83 . 2. 1. 2. 1. 61 75 30 92 57 2107.8 2152.2 2196.2 2239.7 2282.8 2051 2096 2140 2183 2226 .8 .2 .2 .7 .8 290.0 312.9 336.5 360.9 386.1 290.1 111.5 312.9 111.0 336.5 110.5 360.9 110.0 386.1 109.5 106.4 S 269.9 E 111.9 S 292.2 E 117.6 S 315.3 E 123.2 S 339.2 E 129.1 S 363.9 E 2400.0 32.71 103.38 2450.0 34.15 102.37 2500.0 35.60 102.51 2600.0 35.38 102.97 2700.0 36.03 103.12 . 90 07 92 35 66 2325.4 2367.1 2408.1 2489.5 2570.7 2269 2311 2352 2433 2514 .4 .1 .1 .5 .7 412.2 439.5 467.9 525.5 583.4 412.3 109.2 439.6 108.8 468.1 108.4 525.9 107.8 584.1 107.3 135.3 S 389.4 E 141.4 S 416.3 E 147.6 S 444.2 E 160.4 S 500.8 E 173.6 S 557.7 E 2800.0 36.54 103.35 2900.0 37.44 103.55 3000.0 36.99 105.22 3100.0 36.67 104.63 3200.0 37.80 105.90 . ° 54 90 10 48 37 2651.3 2731.2 2810.8 2890.9 2970.5 2595.3 2675.2 2754.8 2834.9 2914.5 642.2 701.9 762.1 821.8 882.1 643.1 106.9 703.2 106.6 763.6 106.4 823.5 106.3 884.0 106.3 187.1 S 615.3 E 201.1 S 673.8 E 216.1 S 732.4 E 231.6 S 790.3 E 247.5 S 848.7 E A Gyrodata Directional Survey B.P. EXPLORATION WELL: 1-33/M-23, 7 5/8" CASING Location: MPI UNIT, ENDICOTT FIELD, Job Number: AK0995G295 ALASKA Page MEASURED I N C L AZIMUTH DEPTH feet deg. deg. DOGLEG SEVERITY deg. / 100 ft. VERTICAL DEPTH feet SUBSEA DEPTH feet VERTICAL CLOSURE SECTION DIST. AZIMUTH feet feet deg. HORIZONTAL COORDINATES feet 3300.0 38.76 105.93 3400.0 37.82 106.84 3500.0 37.87 104.97 3600.0 38.93 102.97 3700.0 39.85 98.67 . 1. 1. 1. 2. 96 10 15 63 88 3049.0 3127.5 3206.5 3284.8 3362.1 2993.0 3071.5 3150.5 3228.8 3306.1 943.9 1005.8 1067.0 1128.7 1191.3 946.0 106.2 1007.9 106.2 1069.3 106.2 1131.3 106.1 1194.5 105.8 264.5 S 908.2 E 282.0 S 967°7 E 298.8 S 1026.7 E 313.8 S 1087.0 E 325.6 S 1149.3 E 3800.0 39.91 97.18 3900.0 39.22 98.72 4000.0 38.67 98.79 4100.0 38.61 100.07 4200.0 38.53 101.82 96 20 55 8O 09 3438.9 3516.0 3593.7 3671.8 3750.0 3382.9 3460.0 3537.7 3615.8 3694.0 1254.0 1316.3 1378.0 1439.3 1500.9 1258.0 105.4 1321.2 105.1 1383.7 104.8 1445.9 104.5 1508.1 104.4 334.5 S 1212.8 E 343.3 S 1275.8 E 352.9 S 1338.0 E 363.1 S 1399.6 E 374.9 S 1460.8 E 4300.0 37.44 102.79 4400.0 37.68 104.49 4500.0 37.29 102.96 4600.0 36.67 101.74 4700.0 36.37 103.06 . 25 06 01 96 84 3828.8 3908.1 3987.5 4067.4 4147.7 3772.8 3852.1 3931.5 4011.4 4091.7 1561.9 1622.5 1683.0 1742.6 1801.6 1569.6 104.3 1630.6 104.3 1691.4 104.3 1751.5 104.2 1811.0 104.1 388.0 S 1520.9 E 402.4 S 1580.1 E 416.8 S 1639.3 E 429.7 S 1698.0 E 442.5 S 1756.1 E 4800.0 33.89 101.46 4900.0 33.73 101.64 5000.0 33.82 102.87 5100.0 33.59 102.80 5200.0 33.63 102.57 . . . e 65 19 69 24 14 4229.5 4312.6 4395.7 4478°9 4562.2 4173.5 4256.6 4339°7 4422.9 4506.2 1858.6 1913.6 1968.7 2023.8 2078.7 1868.5 104.1 1924.1 104.0 1979.7 104.0 2035.2 103.9 2090.5 103.9 454.7 S 1812.4 E 465.9 S 1866.9 E 477.7 S 1921.2 E 490.0 S 1975.3 E 502.1 S 2029.3 E 5300.0 34.30 99.91 5400°0 35.35 97.53 5500.0 35.73 97.91 5600.0 36.58 97.97 5700.0 37.12 97.60 . 63 72 44 85 59 4645.1 4727.2 4808.6 4889.3 4969°3 4589.1 4671.2 4752.6 4833.3 4913.3 2133.9 2146.3 103.8 2189.9 2203.2 103.7 2246.7 2261.0 103.5 2304.4 2319.7 103.4 2363.0 2379.4 103.3 513.0 S 2084.1 E 521.7 S 2140.5 E 529.5 S 2198.1 E 537.6 S 2256.6 E 545.7 S 2316.0 E A Gyr odata D ir ect iona i Survey B.P. EXPLORATION WELL: 1-33/M-23, 7 5/8" CASING Location: MPI UNIT, ENDICOTT FIELD, ALASKA Job Number: AK0995G295 Page MEASURED I N C L AZIMUTH DOGLEG VERTICAL DEPTH SEVERITY DEPTH feet deg. deg. deg./ feet 100 ft. SUBSEA DEPTH feet VERTICAL CLOSURE SECTION DIST. AZIMUTH feet feet deg. HORIZONTAL COORDINATES feet 5800.0 37.63 98.90 .94 5048.8 5900.0 38.73 99.08 1.10 5127.4 6000.0 38.23 100.48 1.00 5205.7 6100.0 37.79 99.49 .75 5284.5 6200.0 37.74 99.91 .26 5363.5 4992 5071 5149 5228 5307 .8 .4 .7 .5 .5 2422.4 2483.1 2544.3 2605.0 2665.2 2439.9 103.1 2501.6 103.0 2563.7 103.0 2625.2 102.9 2686.3 102.8 554.5 S 2376.1 E 564.1 S 2437.1 E 574.7 S 2498.4 E 585.4 S 2559.1 E 595.7 S 2619.5 E 6300.0 37.54 99.27 .44 5442.7 6400.0 37.13 98.55 .59 5522.2 6500.0 36.91 98.85 .29 5602.1 6600.0 37.13 97.90 .61 5681.9 6700.0 36.40 98.18 .75 5762.0 5386 5466 5546 5625 5706 .7 .2 .1 .9 o0 2725.3 2784.8 2843.8 2902.8 2961.4 2747.3 102.7 2807.8 102.7 2867.9 102.6 2928.0 102.5 2987.6 102.4 605.8 S 2679.7 E 615.2 S 2739.6 E 624.4 S 2799.1 E 633.1 S 2858.7 E 641.5 S 2918.0 E 6800.0 36.79 97.86 .43 5842.3 6900.0 36.32 97.85 .47 5922.6 7000.0 35.16 98.98 1.33 6003.8 7100.0 35.42 98.93 .26 6085.4 7200.0 35.43 99.55 .36 6166.9 5786 5866 5947 6029 6110 .3 o6 .8 .4 .9 3019.7 3077.9 3135.1 3191.8 3248.8 3047.1 102.3 3106.5 102.2 3164o7 102.2 3222.4 102.1 3280.3 102.0 649.8 S 2977.0 E 657.9 S 3036.0 E 666.5 S 3093.8 E 675.5 S 3150.8 E 6'84.8 S 3208.0 E 7300.0 36.06 98.94 .72 6248.1 7400.0 36.70 100.03 .91 6328.6 7500.0 36.56 99.31 .46 6408.8 7600.0 37.09 99.17 .53 6488.9 7700.0 37.09 99.10 .04 6568.7 6192 6272 6352 6432 6512 .1 .6 .8 .9 .7 3306.2 3364.5 3423.2 3482.1 3541.3 3338.7 102.0 3397.9 102.0 3457.5 101.9 3517.4 101.9 3577.7 101.8 694.2 S 3265.7 E 704.0 S 3324.2 E 714.0 S 3383.0 E 723.6 S 3442.2 E 733.2 S 3501.7 E 7800.0 37.69 100.42 1.00 6648.1 7900.0 37.33 100.14 .40 6727.4 8000.0 37.07 100.54 .35 6807.1 8100.0 36.95 100.33 .18 6886.9 8200.0 36.90 102.46 1.28 6966.9 6592.1 6671.4 6751.1 6830.9 6910.9 3601.1 3661.1 3720.7 3780.0 3839.4 3638.3 101.8 3699.2 101.8 3759.6 101.7 3819.8 101.7 3879.9 101.7 743.5 S 3561.6 E 754.4 S 3621.5 E 765.2 S 3680.9 E 776.1 S 3740.1 E 788.0 S 3799.0 E A Gyrodata Directional Survey B.P. EXPLORATION WELL: 1-33/M-23, 7 5/8" CASING Location: MPI UNIT, ENDICOTT FIELD, Job Number: AK0995G295 ALASKA Page MEASURED I N C L AZIMUTH DOGLEG DEPTH SEVERITY feet deg. deg. deg./ 100 ft. VERTICAL SUBSEA VERTICAL CLOSURE DEPTH DEPTH SECTION DIST. AZIMUTH feet feet feet feet deg. HORIZONTAL COORDINATES feet 8300.0 36.60 102.33 .31 8400.0 35.42 102.22 1.19 8500.0 35.31 103.07 .51 8600.0 35.38 103.55 .29 8700.0 34.96 104.09 .52 7047.0 7127.9 7209.5 7291.0 7372.8 6991 7071 7153 7235 7316 .0 .9 .5 .0 .8 3898.7 3957°0 4014.4 4071.8 4129.1 3939.7 101.7 3998.5 101.7 4056.4 101.7 4114.2 101.8 4171.8 101.8 800.8 S 3857.5 E 813o3 S 3914.9 E 826.0 S 3971.4 E 839.3 S 4027.7 E 853.1 S 4083.6 E 8800.0 35.34 105.06 .67 8900.0 35.41 105.69 .37 9000.0 35.33 105.57 .11 9100.0 35.72 105.99 .47 9200.0 35.55 106.12 .18 7454.5 7536.1 7617.6 7699.0 7780.3 7398 7480 7561 7643 7724 .5 .1 .6 .0 .3 4186.4 4244.1 4301.8 4359.8 4417.9 4229.3 101.8 4287.0 101.9 4344.8 101.9 4402.8 102.0 4460.9 102.0 867.6 S 4139.3 E 882.9 S 4195.1 E 898.5 S 4250.9 E 914.3 S 4306.8 E 930.4 S 4362.8 E 9300.0 35.64 105.79 .21 9400.0 35.56 106.78 .58 9500.0 35.93 106.17 .52 9600.0 37.64 102.96 2.57 9700.0 38.86 104.03 1.39 7861.6 7942.9 8024.1 8104.2 8182.7 7805 7886 7968 8048 8126 .6 .9 .1 .2 .7 4476.0 4534.1 4592.4 4652.0 4713.5 4519.0 102.1 4577.0 102.1 4635.3 102.2 4695.1 102.2 4757,0 102.2 946.4 S 4418.8 E 962.7 S 4474.6 E 979.3 S 4530.7 E 994.3 S 4588.6 E 1008.8 S 4648.8 E 9800.0 38.73 104.23 .18 9900.0 38.90 104.48 .23 10000.0 38.37 104.18 .56 10100.0 38.61 104.75 .42 10200.0 38.39 104.77 .22 8260.6 8338.5 8416.7 8494.9 8573.2 8204 8282 8360 8438 8517 o6 .5 .7 .9 .2 4775.8 4838.2 4900.3 4962.2 5024.2 4819.6 102.3 4882.2 102.3 4944.6 102.3 5006.8 102.3 5069.0 102.4 1024.1 S 4709.6 E 1039.6 S 4770.3 E 1055.1 S 4830.8 E 1070.6 S 4891.0 E 1086.5 S 4951.2 E 10300.0 38.87 105.77 .79 10400.0 39.59 107.00 1.06 10500.0 38.95 106.96 .64 10600.0 39.22 107.88 .63 10700.0 38.70 108.92 .84 8651.3 8728.8 8806.2 8883.8 8961.6 8595.3 8672.8 8750.2 8827.8 8905.6 5086.4 5149.6 5212.8 5275.7 5338.6 5131.4 102.4 5194.5 102.5 5257.6 102.5 5320.4 102.6 5382.9 102.6 1102.9 S 5011.5 E 1120.8 S 5072.1 E 1139.2 S 5132.7 E 1158.1 S 5192.8 E 1178.0 S 5252.5 E A Gyrodata Directional Survey B.P. EXPLORATION WELL: 1-33/M-23, 7 5/8" CASING Location: MPI UNIT, ENDICOTT FIELD, Job Number: AK0995G295 ALASKA Page MEASURED I N C L AZIMUTH DOGLEG DEPTH SEVERITY feet deg. dego deg./ 100 ft. VERTICAL SUBSEA VERTICAL DEPTH DEPTH SECTION feet feet feet CLOSURE DIST. AZIMUTH feet deg. HORIZONTAL COORDINATES feet 10800.0 37.73 108.39 1.03 10900.0 36.34 110.16 1.75 11000.0 35.13 109.07 1.36 11100.0 34.84 109.21 .30 11200.0 34.61 109.01 .26 9040.1 8984.1 9120.0 9064.0 9201.1 9145.1 9283.1 9227.1 9365.3 9309.3 5400.4 5444.5 102.7 5460.6 5504.3 102.8 5519.1 5562.3 102.9 5576.4 5619.3 102.9 5633.3 5675.9 103.0 1197.7 S 5311.1 E 1217.6 S 5367.9 E 1237o2 S 5422.9 E 1256.0 S 5477.1 E 1274.7 S 5530.9 E 11300.0 34.20 110.31 .84 11400.0 35.18 110.16 .99 11500.0 35.12 110.04 .09 11600.0 35.62 110.54 .58 11700.0 36.20 110.49 .58 9447.8 9391.8 9530.0 9474.0 9611.8 9555.8 9693.3 9637.3 9774.3 9718.3 5689.8 5746.7 5804.3 5862.2 5920.9 5732.0 103.0 5788.5 103.1 5845.7 103.2 5903.1 103.3 5961.3 103.3 1293.7 S 5584.1 E 1313.3 S 5637.5 E 1333.1 S 5691.6 E 1353.2 S 5745.9 E 1373o7 S 5800.8 E 11800.0 36.90 111.14 11900.0 38.11 110.84 12000.0 38.70 110.65 12100.0 38.43 110.59 12200.0 38.02 110.62 12265.0 37.52 111.22 Final Station Closure: .80 9 1.22 9 .60 10 .27 10 .41 10 .95 10 Distance: 854.6 9798.6 934.0 9878.0 012.3 9956.3 090.5 10034.5 169.1 10113.1 220.5 10164.5 6305.10 ft 5980.4 6020.3 103.4 6041.3 6080.7 103.5 6103.4 6142.3 103.5 6165.7 6204.2 103.6 6227.6 6265.6 103o7 6267.4 6305ol 103.7 Az: 103.73 deg. 1394o9 S 5856.5 E 1416.7 S 5913.3 E 1438.7 S 5971.4 E 1460.7 S 6029.8 E 1482.5 S' 6087.7 E 496.7 S 6124.9 E A Gyr odata D irect iona i Survey for B.P. EXPLORATION WELL: 1-33/M-23, 7 5/8" CASING Location: MPI UNIT, ENDICOTT FIELD, ALASKA Job Number: AK0995G295SS Run Date: 23-Sep-95 17:02:55 Surveyor: TOM STODDARD Calculation Method: MINIMUM CURVATURE Survey Latitude: 70.352500 deg. N Sub-sea Correction from Vertical Reference: 56 ft. Azimuth Corrected:: Gyro: Bearings are Relative to True North Proposed Well Direction: 110.000 deg Vertical Section Calculated from Well Head Location Closure Calculated from Well Head Location Horizontal Coordinates Calculated from Local Horizontal Reference A Gyrodata Directional Survey B.P. EXPLORATION WELL: 1-33/M-23, 7 5/8" CASING Location: MPI UNIT, ENDICOTT FIELD, Job Number: AK0995G295SS ALASKA Page SUBSEA I N C L AZIMUTH VERTICAL DOGLEG DEPTH DEPTH SEVERITY feet deg. deg. feet deg./ 100 ft. VERTICAL CLOSURE SECTION DIST. AZIMUTH feet feet deg. HORIZONTAL COORDINATES feet -56.0 0.00 0.00 0.0 0.00 GYRO SURVEY FROM 12265' TO SURFACE IN 7 5/8" ALL DEPTHS REFERENCED TO RoK.B. OF 56'. 0.0 0.0 0.0 CASING o 0.0 N 0.0 E 100.0 .05 215.13 156.0 .06 200.0 .36 135.23 256.0 .35 300.0 1.80 153.42 356.0 1.44 400.0 3.40 154.39 456.0 1.60 500.0 3.23 151.46 556.0 1.22 .0 .0 184.2 .3 .6 106.8 1.6 3.5 148.8 4.9 9.3 153.3 9.1 15.1 153.4 .0 N .0 E .3 S .2 E 1.9 S 1.0 E 6.0 S 3.0 E 11.2 S 5.6 E 600.0 2.44 147.95 656.0 .81 700.0 1.71 131.02 756.0 .91 800.0 1.20 89.96 856.0 1.14 900.0 1.24 67.71 956.0 .57 1000.0 2.18 90.19 1056.0 1.22 12.9 19.3 152.5 15.9 22.3 150.9 18.1 23.4 147.8 19.8 23.9 143.3 22.4 26.4 138.1 15.5 S 8.1 E 18.3 S 10.2 E 19.4 S 12.2 E 19.0 S 14.2 E 18.8 S 17.0 E 1100'.0 5.15 115.08 1156.0 3.25 1200.0 8.26 123.17 1256.0 2.43 1300.0 9.04 116o73 1356.0 1.51 1400.0 10.89 112.05 1456.0 2.22 1500.0 13.22 110.85 1556.0 2.61 28.6 34.5 133.2 39.7 48.3 129.7 54.6 63.7 127.2 72.0 81.8 124.1 93.2 103.6 121.4 21.1 S' 22.7 E 26.9 S 32.4 E 34.5 S 45.5 E 41.6 S 61.5 E 49.4 S 81.2 E 1600.0 14.49 109o92 1656.0 1.26 1700.0 17.30 108.57 1756.0 2.95 1800.0 20.51 106.24 1856.0 3.25 1900.0 23.19 105.53 1956.0 2.25 2000.0 25.19 104.34 2056.0 2.90 117.9 128.0 119.1 146.3 156.5 117.2 180.4 189.8 115.4 220.6 227.6 113.6 265.0 268.3 112.2 57.9 S 104.3 E 67.3 S 131.1 E 77.5 S 163.8 E 88.4 S 202.5 E 100.3 S 245.5 E 2100.0 28.14 103.94 2156.0 2.63 314.9 336.5 110.9 112.4 S 294.2 E A Gyr odata Directional Survey B.P. EXPLORATION WELL: 1-33/M-23, 7 5/8" CASING Location: MPI UNIT, ENDICOTT FIELD, Job Number: AK0995G295SS ALASKA Page SUBSEA DEPTH feet I N C L AZIMUTH VERTICAL DEPTH deg. deg. feet DOGLEG SEVERITY deg. / 100 ft. VERTICAL CLOSURE SECTION DIST. AZIMUTH feet feet deg. HORIZONTAL COORDINATES feet 200.0 300.0 400.0 500.0 30.38 103.28 2256.0 33.77 102.64 2356.0 35.47 102.78 2456.0 35.91 103.09 2556.0 2.41 3.29 1.41 .60 370.4 432°3 501.8 572.9 386.1 109.8 439.6 108.9 525.9 108.0 584.1 107.4 125.4 S 348.5 E 139.8 S 409.1 E 155.1 S 477.5 E 171.2 S 547.4 E 600.0 700.0 800.0 900.0 000.0 36.60 103.36 2656.0 37.30 104.07 2756.0 36.81 104.88 2856.0 37.59 105.67 2956.0 38.67 106.01 3056.0 .56 .96 .75 1o21 .97 645 720 795 871 949 .7 .7 .8 .2 .4 703.2 106.9 763.6 106.6 823.5 106.4 884.0 106.3 1007.9 106.2 187.9 S 618.7 E 205.8 S 692.0 E 224.8 S 765.1 E 244.6 S 838.0 E 266.0 S 913.5 E 100.0 200.0 300,0 400.0 5OO.0 37.84 106.17 3156.0 38.54 103.71 3256.0 39.78 99.01 3356.0 39.75 97.52 3456.0 38.94 98.75 3556.0 1.12 1.45 2.78 1.01 .86 1027 1106 1186 1267 1348 .8 1069.3 106.2 .0 1131.3 106.1 .4 1194.5 105.8 .9 1321.2 105.3 .0 1383.7 104.9 288.0 S 989°0 E 308.2 S 1064.8 E 324.7 S 1144.3 E 336.4 S 1226.8 E 348.2 S 1307.8 E 3600.0 38.63 99.81 3656.0 3700.0 38.45 101.89 3756.0 3800.0 37.52 103.37 3856.0 3900.0 37.44 103.56 3956.0 4000.0 36.76 101.91 4056.0 .75 1.11 1.18 1.03 .97 1426 1505 1582 1659 1734 .9 1445.9 104.6 °5 1569.6 104.4 .6 1630.6 104.3 .0 1691.4 104.3 .1 1751.5 104.2 361.0 S 1387.1 E 375.9 S 1465.3 E 392.9 S 1541.2 E 411.1 S 1615.8 E 427.9 S 1689.7 E 100.0 200.0 300.0 400.0 500.0 36.12 102.90 4156.0 33.84 101.52 4256.0 33.78 102.28 4356.0 33.65 102.82 4456.0 33.63 102.59 4556.0 1.03 1.87 .45 .36 .14 1807 1876 1942 2008 2074 .3 1868.5 104.1 .1 1924.1 104ol .4 1979.7 104.0 .6 2035.2 103.9 .6 2090.5 103.9 443.7 S 1761.8 E 458.3 S 1829.7 E 472.0 S 1895.2 E 486.6 S 1960.4 E 501.2 S 2025.3 E A Gyrodata D ir ect i ona i Survey B.P. EXPLORATION WELL: 1-33/M-23, 7 5/8" CASING Location: MPI UNIT, ENDICOTT FIELD, Job Number: .AK0995G295SS ALASKA Page SUBSEA DEPTH feet I N C L AZIMUTH VERTICAL DEPTH deg. deg. feet DOGLEG SEVERITY deg. / 100 ft. VERTICAL CLOSURE SECTION DIST. AZIMUTH feet feet deg. HORIZONTAL COORDINATES feet 4600 4700 4800 4900 5000 .0 34.44 99.60 4656.0 .0 35.49 97.66 4756.0 .0 36.23 97.94 4856.0 .0 37.03 97.67 4956.0 .0 37.73 98.92 5056.0 1.64 1.27 .68 .63 .95 2141.3 2210.0 2280.5 2353.2 2428.0 2203.2 103.8 2261.0 103.6 2319.7 103.5 2379.4 103.3 2501.6 103.1 514.2 S 2091.6 E 524.4 S 2160.9 E 534.2 S 2232.5 E 544.4 S 2306.1 E 555.3 S 2381.7 E 5100 5200 5300 5400 550O .0 38.55 99,59 5156.0 .0 37.95 99.85 5256.0 .0 37.75 99.87 5356.0 .0 37.47 99.15 5456.0 .0 37.04 98.68 5556.0 1.07 .84 .31 .47 .46 2505.4 2583.0 2659.5 2735.2 2809.8 2563.7 103.0 2625.2 102.9 2686.3 102.8 2807.8 102.7 2867.9 102.6 568.0 S 2459.5 E 581.5 S 2537.2 E 594.7 S 2613.7 E 607.4 S 2689.7 E 619.1 S 2764.8 E 5600 5700 5800 5900 6000 .0 37.06 98.21 5656.0 .0 36.45 98.15 5756.0 .0 36.71 97.86 5856.0 .0 35.84 98.31 5956.0 .0 35.33 98.95 6056.0 .51 .74 .44 .82 .64 2883.7 2957.0 3029.6 3101.4 3171.4 2928.0 102.5 2987.6 102.4 3106.5 102.3 3164.7 102.2 3222.4 102.1 630.3 S 2839.4 E 640.9 S 2913.5 E 651.2 S 2987.0 E 661.5 S 3059.7 E 672.2 S 3130.2 E 6100 6200 6300 6400 6500 .0 35.43 99.47 6156.0 .0 36.12 99.05 6256.0 .0 36.66 99.79 6356.0 .0 36.87 99.23 6456.0 .0 37.09 99.11 6556.0 .35 .74 .76 .50 .12 3241.2 3311.9 3384.5 3457.9 3531.9 3280.3 102.1 3397.9 102.0 3457.5 101.9 3517.4 101.9 3577.7 101.8 683.5 S 3200.4 E 695.1 S 3271.5 E 707°4 S 3344.3 E 719.7 S 3417.9 E 731.7 S 3492.3 E 6600 6700 6800 6900 7000 .0 37.65 100.40 6656.0 .0 37.24 100.29 6756.0 .0 37.00 100.41 6856.0 .0 36.90 102.17 6956.0 .0 36°47 102.31 7056.0 .94 .38 .25 1.13 .40 3607.0 3682.4 3757.0 3831.3 3905.2 3699.2 101.8 3759.6 101.8 3819.8 101.7 3879.9 101.7 3998.5 101.7 744.6 S 3567.5 E 758.2 S 3642.8 E 771.9 S 3717.2 E 786.4 S 3791.0 E 802.2 S 3863.8 E ~A Gyrodata Direct iona i Survey B.P. EXPLORATION WELL: 1-33/M-23, 7 5/8" CASING Location: MPI UNIT, ENDICOTT FIELD, Job Number: AK0995G295SS ALASKA Page SUBSEA DEPTH feet I N C L AZIMUTH VERTICAL DEPTH deg. deg. feet DOGLEG VERTICAL CLOSURE SEVERITY SECTION DIST. AZIMUTH deg./ feet feet deg. 100 ft. HORIZONTAL COORDINATES feet 7100 7200 7300 7400 7500 .0 .0 .0 .0 .0 35.38 102.51 7156.0 35.35 103.34 7256.0 35.05 103.98 7356.0 35.34 105.07 7456.0 35.39 105.66 7556.0 .95 .38 .47 .67 .31 3976.8 4056.4 101.7 4047.2 4114.2 101.8 4117.4 4171.8 101.8 4187.5 4287.0 101.8 4258.2 4344.8 101.9 817.7 S 3934.4 E 833.6 S 4003.5 E 850.2 S 4072.1 E 867.8 S 4140.3 E 886.7 S 4208.8 E 7600 7700 7800 7900 8000 .0 .0 .0 .0 .0 35.51 105.77 7656.0 35.61 106.08 7756.0 35.63 105.81 7856.0 35.62 106.68 7956.0 36.61 104.89 8056.0 .28 .27 .21 .57 1.34 4329.2 4402.8 102.0 4400.6 4460.9 102.0 4472.0 4519.0 102.1 4543.5 4635.3 102.2 4616.1 4695.1 102.2 906.0 S 4277.3 E 925.6 S 4346.1 E 945.3 S 4414.9 E 965.4 S 4483.7 E 985.3 S 4553.8 E 8100 8200 8300 8400 8500 .0 .0 .0 .0 .0 38.44 103.67 8156.0 38.74 104.22 8256.0 38.78 104.42 8356.0 38.49 104.47 8456.0 38.44 104.76 8556.0 1179 .25 .31 .49 .26 4692.6 4757.0 102.2 4772.1 4819.6 102.3 4852.1 4944.6 102.3 4931.4 5006.8 102.3 5010.6 5069.0 102.4 1003.9 S 4628.3 E 1023.2 S 4705.9 E 1043.1 S 4783.8 E 1062.9 S 4861.1 E 1083.'0 S 4938.0 E 8600 8700 8800 8900 9000 .0 .0 .0 .0 .0 38.92 105.84 8656.0 39.36 106.99 8756.0 39.12 107o55 8856.0 38.74 108.84 8956.0 37.45 108.74 9056.0 .81 .91 .64 .82 1.17 5090.3 5194.5 102.4 5171.8 5257.6 102.5 5253.2 5320.4 102.6 5334.1 5382.9 102.6 5412.4 5504.3 102.7 1104.0 S 5015.1 E 1127.3 S 5093.4 E 1151.4 S 5171.3 E 1176.5 S 5248.2 E 1201.7 S 5322.4 E 9100 9200 9300 9400 9500 .0 .0 .0 .0 .0 35.81 109.67 9156.0 34.94 109.16 9256.0 34.63 109.03 9356.0 34.29 110.29 9456.0 35.16 110.12 9556.0 1.58 .65 .27 .86 .70 5486.6 5562.3 102.8 5557.4 5619.3 102.9 5626.9 5675.9 103.0 5695.5 5788.5 103.1 5765.1 5845.7 103.1 1226.3 S 5392.3 E 1249.8 S 5459.2 E 1272.6 S 5524.9 E 1295.6 S 5589.5 E 1319.6 S 5654.7 E A Gyr odata D irect i ona i Survey B.P. EXPLORATION WELL: 1-33/M-23, 7 5/8" CASING Location: MPI UNIT, ENDICOTT FIELD, Job Number: AK0995G295SS ALASKA Page SUBSEA DEPTH feet I N C L AZIMUTH VERTICAL DEPTH deg. deg. feet DOGLEG VERTICAL CLOSURE SEVERITY SECTION DIST. AZIMUTH deg./ feet feet dego 100 ft. HORIZONTAL COORDINATES feet 9600.0 35.39 110.31 9656.0 9700.0 36.07 110.50 9756.0 9800.0 36.92 111.14 9856.0 9900.0 38.27 110.79 9956.0 10000.0 38.55 110o62 10056.0 .36 5835.7 5903.1 103.2 .58 5907.6 5961.3 103.3 .80 5981.5 6080.7 103.4 1.05 6058.7 6142.3 103.5 .42 6138.2 6204.2 103.6 1344.0 S 5721.1 E 1369.1 S 5788.4 E 1395.3 S 5857.5 E 1422.9 S 5929.7 E 1451.0 S 6004.0 E 10100.0 38.09 110.61 10156.0 10164.5 37.52 111.22 10220.5 .38 6217.3 6265.6 103.7 .95 6267.4 6305.1 103.7 1478.8 S 6078.1 E 1496.7 S 6124.9 E Final Station Closure: Distance: 6305.10 ft Az: 103.73 deg. gyro/data 4. QUALITY CONTROL SR295.DOC Quality control Comparisons B.P. EXPLORATION WELL: 1-33/M-23, 7 5/8" CASING Location: MPI UNIT, ENDICOTT FIELD, ALASKA Job Number : AK0995G295 / AK0995G295 INRUN/OUTRUN Comparison INRUN OUTRUN Depth Inc Inc Delta 1000o0 1.30 1.32 -.019 2000.0 23.46 23.59 -.135 3000.0 37.01 36.99 .019 4000.0 38.78 38.67 .111 5000.0 34.00 33.82 .180 6000.0 38.17 38.23 -.061 8000.0 37.14 37.07 .072 9000.0 35.39 35.33 .059 10000.0 38.47 38.37 .102 11000.0 35.15 35.13 .015 12000.0 38.69 38.70 -.004 12265.0 37.53 37.52 .000 INRUN Az 68.11 106.45 104.93 99.38 103o42 99.58 101.21 106.20 104.64 109.81 111.44 110o69 For Inclinations Greater than 10 degrees: Average Inclination Difference = .03254 deg. Average Azimuth Difference = .33131 deg. OUTRUN Az 67.77 105.53 105.22 98.79 102.87 100.48 100.54 105.57 104.18 109.07 110.65 111.22 Delta .346 .918 -.285 .588 .553 -.893 .673 .632 .454 .741 .792 -.529 gyro/data QUALITY CONTROL REPORT JOB NUMBER: AK0995G295 TOOL NUMBER: 713 MAXIMUM GYRO TEMPERATURE: 76.99 C MAXIMUM AMBIENT TEMPERATURE: 89.7 C MAXIMUM INCLINATION: 39.59 AVERAGE AZIMUTH: 103,73 WIRELINE REZERO VALUE: REZERO ERROR / K: .005 CALIBRATION USED FOR FIELD SURVEY: 1248 CALIBRATION USED FOR FINAL SURVEY: 1248 PRE JOB MASS BALANCE OFFSET CHECK: -,20 POST JOB MASS BALANCE OFFSET CHECK~: CONDITION OF SHOCK WATCHES -.29 USED -.25 UPON ARRIVAL AT RIG: OK UPON COMPLETION OF SURVEY: OK UPON RETURN TO ATLAS OK BOTTOM LINE COMPARISIONS M.D. INC AZIMUTH TVD NORTHING EASTING FIELD SURVEY 12265.0 37.53 111.15 10221.4 1498.2 S 6121.0 E FINAL SURVEY 12265.0 37.52 111.22 10220.5 1496.7 S 6124.9 E SR295.DOC gyro/data FUNCTION TEST JOB NUMBER' AK0995G295 5 Survey stations were collected at the measured depth shown below. The tables show the repeatability of the gyro tool in both inclination and azimuth at one measured depth. INCLINATION M.D. ff 1 2 3 4 5 2900 37.44 37.44 37.44 37.44 37.44 AZIMUTH M.D. ft 1 2 3 4 5 2900 103.48 103.55 103.55 103.78 103.53 SR295. DOC gyro/data 5. EQUIPMENT AND CHRONOLOGICAL REPORT SR295.DOC gyro/data EQUIPMENT REPORT JOB NUMBER' AK0995G295 DOWNHOLE ELECTRONICS SURFACE ELECTRONICS PRIMARY TOOL No. 713 GYRO SECTION A0088 DATA SECTION C0031 POWER SECTION C0006 BACKUP TOOL No. 080 GYRO SECTION A0099 DATA SECTION C0023 POWER SECTION C0022 COMPUTER POWER SUPPLY PRINTER INTERFACE COMPUTER POWER SUPPLY PRINTER INTERFACE A0153 A0085 A0029 A0035 A0213 A0055 A0079 A0071 WIRELINE COMPANY' CABLE SIZE · ATLAS WIRELINE 5/16" RUNNING GEAR 2 1/2" SYSTEM TOTAL LENGTH OF TOOL · MAXIMUM O.D.' 17.5 feet 2.5 INCHES TOTAL WEIGHT OF TOOL ' 240Lbs SR295.DOC gyro/data CHRONOLOGICAL REPORT JOB NUMBER: AK0995G295 9/02/95 0000 0230 0300 O55O 0700 0900 1000 1200 LEAVE ATLAS ARRIVED AT LOCATION SPOT UNIT, MAKE UP TOOL RUNNING IN HOLE 7830' SURVEYING OUT LAY DOWN AND BREAK DOWN TOOL PROCESS SURVEY. RETURN TO ATLAS. SR295.DOC MEMORANDUM State of Alaska OIL AND GAS CONSERVATION COMMISSION, . ;,~ ~,,~. <~,' ~,~vlarch 26, 1996 To: Commissioners ¢2~,0~ ¢0~¢,~ j, ~~ ,a,rWo dze,, Subject: Surface casing cement~g, North Slope problems. The Alaska state regulations, 20 AAC 25.030, require that surface casing be set below the base of the freshwater and be cemented to the surface. Up until about 1990 there were few indications that surface casing was not being fully cemented (top jobs were not common and were not included as part of the planned cementing program). Since about 1990 there have been several incidents that demonstrate that the surface casing is not being fully cemented, e.g.; flows to surface outside of the surface casing and top jobs engineered as part of the surface casing cementing plan. This memo provides data on specific wells to demonstrate that poor surface casing cement jobs are occurring in all fields on the North Slope - in all probability, the actual number of such incidents is much greater than the ones we know about. During well drilling, a cellar is installed to collect fluids from the rig floor associated with pulling pipe and from rig wash-down. A conductor casing to prevent sloughing of surface grovel is normally installed at 80' below pad level by driving, jetting, or drilling and is cemented to the surface unless it is driven. Typically, thru-out the United States and I believe in most other petroleum provinces, a surface casing is set at a sufficient depth to protect fresh water sands and to provide good anchorage for the blowout prevention equipment (BOPE). A review of 37 state and 3 other governments' requirements discloses that we have surface casing setting and cementing data on 37 states and 3 other government entities (hereafter referred to as "states"). The data shows that 1 9 specify the setting depth be below fresh water, 2 specify a BOP anchor and the others refer to a rule or some other criteria (10 simply say "Yes" its required). Fourteen states specify the cement "circulate" or "circulate to surface" and 14 specify "fill to surface" or "full length" As early as 1 969 Alaska's oil and gas regulations required "Surface casing shall be set into an impervious formation, and shall be cemented with sufficient cement to circulate to the top of the hole" Current, 1986 regulations require "the casing must be set into a competent stratum and cemented with sufficient cement in the annulus to circulate to the surface. If cement does not circulated to the surface, the open annulus must be cemented to the surface before drilling ahead." Prior to about 1 990, the cement on the surface casing normally circulated to surface, if it fell back, the operator ran a small diameter (1 ") pipe in the annulus, located the top of cement and filled the rest of the annulus to the surface - a so called "top job". In recent years the operators have cut way back on the volume of cement they pumped and the cement virtually never reached the surface; they would then do a "top job" by putting a little dab at the surface. The uncemented intervals are probably extensive, but just how long is unknown because cement bond logs were not run. My calculations show that on BPs Endicott well 4-38/k-34 they used a ~~+4~~"~, vc!umc of 2.~_5.~¢~¢~~H~cementing the surface casing - they subsequently had fluid in the cellar resulting from annular disposal into well 4- 38/K-34 (5 locations away). There have been several incidents of annular disposal coming to the surface as well as water and gas in the cellars. Incidents reported to or investigated by the AOGCC that probably occurred because of poor surface casing cement job are listed below. BPX Prudhoe Bay - West Operating Area' Well PTD No. Date A-18 81-101 6/3/94 E-18 81-133 7 H-16 81-062 10/27/90 H-25 82-268 6/18/94 J-01 69-040 7 K-11 87-117 ~ K-13 87-101 ~ N-20 85-058 4./27/94 P-18 90-145 6/18/93 R-34. 93-153 6/16/94 W-08 89-007 3~2~95 Description of Incident OA to surface - operator report Gas bubbling in cellar- operator report IA to OA to surface - operator report OA to surface - operator report OA to surface - operator report OA to surface - operator report OA to surface - operator report IA to OA to surface - operator report OA to surface - operator report OA to surface - operator report IA to OA to surface - operator report ARCO - Prudhoe Bay - Eastern Operating Area Well No PTD NO Date 9-23 84-003 3/15/95 11-27 86-148 3/15/95 1.4-39 88-138 6/16/94 1 6-26 92-044 sum 94 1 6-27 92-036 ? ARCO - Kuparuk River Field Well PTD NO. Date 2T-21 95-01 3 5/95? Description Water flow into cellar - BF report Sudden release of gas lifted well house - JS Conductor slipped down hole, well house fell against flowline-JS Gravel sloughed, lost conductor-tree leaning-BF. Description of incident Lost circulation early while cmt'g sfc csg, no remedial action taken - operator reported. BPX - Endicott Field Well PTD NO. 1-33/M-23 95-107 1-41/O-23 87-032 1-53/Q-20 94-112 Date 12/30/95 9/16/94 12/19/94 Description Annular disposal fluids to sfc - JS & BPX Fluid in cellar, stopped annular disp.- BPX Gas to surface outside sfc csg - BF & BPX 1-61/Q-20 94-142 12/19/94 Note' the production string was not adequately cmt'd, formation gas to sfc (2000 psi) inside surface casing - BF report. 4-38/K-34 94-074 9/26/94 Fluid in cellar- stopped annular disp. - BPX BPX - Milne Point Well PTD NO. Date E-4 90-005 8/90? K-25 96-032 3/22/96 Description Broached from disposal in E-5 - BPX Bubbles in cellar from outside sfc csg - JS BPX - Exploratory Well PTD Date Badami 4 94-1 60 3/15/95R Badami 5 94-161 ~ Sourdough 3 96-008 2/28/96 Description Sfc and prod csg slipped down hole, 320 sx top job - BF Both strings slipped down hole when annular disposal started - 390 sx T job - BF Returns to sfc during annular disposal- BPX The inspectors have written detailed reports on several of the above incidents and they can be reviewed for further information. Recently, and especially at Endicott, there have been a number of instances of annular disposal fluids coming to the surface; these flows on the North Slope may not create an actual environmental problem, but they could jeopardize the future of annular disposal. Perhaps, more important are the instances of formation fluids, especially gas, coming to the surface.. The above data shows that water, mud, gas, and disposal fluids have surfaced in various cellars after coming up the outside of the surface casing. Considering that the conductor is only 80' deep, when the conductor/surface casing annulus is blocked at the surface, formation flow is then around the outside of the conductor pipe. This occurred at the Endicott 1-53/Q-20 fiasco - gas surfaced outside of the cellar and it was only by quick action to reduce pressures that a pathway thru the pad did not develop; had a pathway developed, the rig would have been lost and the blowout would have been stopped only by drilling a relief well. The inspection group would like to see 20 AAC 25.030 (C)(4)(A) read as follows: Cementing of Surface casing. Surface casing shall be cemented with a quantity of cement that fills the annular space to the surface. If partial returns (over 10%) are lost at any time during the cementing operation or if an excessive amount of cement is circulated out (based on a caliper log and theoretical fill) the operator Shall evaluate the adequacy of the cementing operation by a cement evaluation log or other means approved by the commission. If the cement evaluation shows an inadequate cementing job, then the operator shall present a remedial action plan for commission approval on the form entitled Application for Sundry Approval (Form 10-403). MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: David Johnston, DATE: Chairman THRU: Blair Wondzell, ~.6 I,~6 FILE NO: P. I. Supervisor FROM: John Spauldi g~,~,~ SUBJECT: Petroleum Insp. March 22, 1996 gwqlcvdd.doc Casing Cement Integrity BPX MPK-25 Milne Point Unit Friday March 22, 1996: The surface casing had been set at a depth of 3935.45 feet md and cemented, cement was not circulated to surface. A "top job" was performed. While witnessing the BOPE Test on the rig it was noted that gas cut mud and water was bubbling up around and out of the wash ports on the conductor pipe. While drilling the surface section of the hole, suspected hydrates were encountered at 2172' md, 2329' md, 2350' md, 2761' md. At 2761' md gas cut mud was encountered lowering the mud weight from 11 ppg. to 7.8 ppg. at this point the mud was weighted up to 11.5 ppg. and circulated out. Typically hydrates are not always controlled by weight, they are influenced more by temperature. BPX is not convinced that the gas that they are seeing in the surface portion of the well is all hydrates. On the next well gas monitoring and testing equipment will be installed in an effort to define what type of gas is being encountered Summary: I reccommended that a cement evaluation tool be run to determine the top of the parent cement in the annular area. Once the top of cecment has been determined BPX will need to devise a plan on how to get cement to surface. MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: David Johnston DATE' March 6, 1996 Chairman ~ THRU: Blair Wondzell -¢~~ FILE NO: Case-Cmt. doc P.I. Supervisor '~/¢'415~ Bobby Fos~ Petroleum Inspector FROM' SUBJECT: Casing Cementing March 6, 1996: This memo is to express the inspectors concern about the cementing of the various casing strings being set in the wells in the State of Alaska and to have the commission inform us of its opinion on how this problem should be taken care of. (1) The largest of our concerns are with the surface casing since this string is the "anchor" for the BOPE. in AOGCC regulation 20 AAC 25.030 (d) (2) (B) it states that "cement must be circulated to the surface~ or" if cement does not circulate out surface the open annulus must be cemented to the surface before drilling ahead". In the past if cement returns did not reach the surface a "top job" - a small pipe being run down 80' +- between the conductor and the surface pipe and cement being circulated back to surface- was performed. It is the opinion of the inspectors that this does not meet the regulation stating "the open annulus must be cemented to the surface". The "top job" is only cementing the top 80'+- and does not take in to consideration where the top of the cement is in the annulus. Circulation may have been lost as soon as the cement started back up the outside of the casing or only half way up the length of the casing. In AOGCC regulation 20 AAC (5) (D) (g) Pressure Testing of Casing and Casing Surveys (1) it states "if there are indications of improper cementing, such as lost returns, cement channeling, or mechanical failure of equipment, corrective measures must be taken~. The question is, does the Commission approve of the "top job" method or should the oil producers be informed that this method is no longer acceptable and in the future if cement is not circulated back to surface on the initial cement job verification logs to find the top of the cement must be run? As documented in reports by the inspectors in previous memos and reports concerning hydrocarbon and water flow back to surface, these cement jobs could become a negative issue and indicate that the Commission is not having the oil companies comply with the regulations set forth in ACC Title 20- Chapter 25. (2) The next concern is with "cementing casing" is the intermediate casing and the production casing. As documented, there has been a case when, after the rig was moved off the well and the well (DIU 1-61/Q-20) placed on production for less than a week the surface pipe h~d 2,000+ psig on it. The rig was moved back to the well and after the tubing was pulled a log was run showing that there was no cement above the production zone. Another cement job was performed and a log was run and it showed that there was approximately '100+- of cement above the producing zone, which does not meet AOGCC regulation 20 AAC 20 (3) (C) yet the well is producing, apparently with the Commission's approval. (3) Another concern that the inspectors have is "leak-off test". We have had reports, undocumented, that some wells have been drilled out below the casing shoe over 50' with out a leak-off test being obtained for one reason or the other. These reports are being checked at this time and as soon as they can be verified a report will be issued. (4) Leak off test during Coil Tubing Drilling is another point that needs to be addressed. At this time no test is being done and without cement bond logs we have no way of knowing where the cement is in comparison with the drill out point assuming that the AOGCC regulation of "500' of cement above the production zone" is in effect. ($) Leak off test when a well is being side-tracked. Is a test required to be performed when the new formation is drillled? z3P RECOrvj,,.....:NDED PRACTICES FOR IN'i,.:HMEDIATE HOLE NOTE-pertaining te FIT testing' PBDriiling is not'exempt frorr the reouirement of conducting a FIT after the intermediate casing is drilled out. However by cefault, PBDrilling typically salisfies the FIT requiremen[ due to the difference of MWs used in .th,; intermediate and production-hole-sections when mud changeovers are required atter 10' of new hole is' drilled, i The FIT Requirement fPSOrillina inferred}.: After drilling 10' of new h°le, the formation should be tested to an EMW c,f 0.5 ppg above the required MW for the production hole section. However, if the 10' of new hole is drilled with the MW required to drill ihe intermediate hole section and this MW is at lea ~t 0.5 ppg heavier than the production hole mud requirements, then the FIT requirement has bee~, satisfied by default, lhus a "formal" FIT (surface pressure applied to the driilstring) is not required. Refer to the Summary of Operations of the Well Plan for the specific FIT requirements/procedure of your well. RP-lnterrned Hole VI.O Page 414 Last Revision' 12/20/94 (4) (C) Formation integrity test. After drilling 10 feet but not more than 50 feet of new formation (new formation means area not previously drilled and verified with uncontaminated cutting circulated to surface) a formation leak off test must be obtained to a predetermined equivalent mud weight or to formation leak-off to aid in determining a formation fracture gradient. The results of this test ~nd any subsequent test of the formation must be recorded as required by 20 AAC 25.070 (a)(1). ;lb ENDICOTT DEVP · STATE OF ALASKA ALA~,,,,A OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS P.1/4 1. Type of Request: Abandon __ 8[~spend Operatlol3 Shutdown ~ Re.ante ? suspendad well ~ ~ter ~slng Re,Ir we]l_ P~ggi~ __ ~me extension ~ $tl~late __ Change appmv~ p~ram ~11 t~lng Variance ~ Pedo~ate __ Other__ 2. Name of Operator BP Exploration (Alaska) Inc. 3. Address P. O. Box 196612, Anchorage, Alaska 9951~.6612 4. Locatior~ of well at sudace 3217'NSL, 2114' WEL, Eec. 36, T12N, R16E At top of productive interval 1850'NSL, 1610' WEL, Sec. 3E, T12N, R16E At effective depth 1710' NSL, 1241' WEI_, Sec. 36. T121V, R16E At total depth 1683' IVSL, 1188' WE/., Sec. 35, T12N, R16E Type of Well: Developmen~ x Exploratory $ ffatlgraphlc Service __ ORIGINAL 6. Datum elevation (DF or KB) KBE = 56 feet - 7. Unit or Property name Duck Island Unit/Endicott 8. Well number 1-33/M.23 9. Permit number 95-107 10. APl number 50- 02.9-22577 11. Field/Pool Endicott Meld/Endicott Pool 12. Present well condition summary Total depth: measured true verdcal Effective depth: measured true vertical 12425 feet 10347 BKB feet 12314 feet 10258BK8 feet Plugs (measured) Junk (measured) Casing Length Size StrUctural Conductor ~1' 30" Surface 4974' 10 3/4 Intermediate Production 12365' 7 5/8" Liner Perforation depth: measured 2.2100'- 12120' Cemented Driven 1725 c.f. Permafrost 690 c.f. Cia,s "G" 559 c.f. C/ass "G" true vertical (subsea) 10034'- 10050' Tubing (size, grade, and measured depth) 4 1/2~ 12.6# tub/ng set at 11198'. Measured d~ 130' 5015' 12404' Tru~/~rtical depth 130' 4390' 10329' Packers and $$$V (type and measured depth) 7 5/8" TIW HB.BP. Tpacker ser at 11110~ 4 1/2 HES "HXO~ ~L'l~J~ at 15o1' 13. Attachments Description summa~ of proposal. W Detailed operations program __ BOP sketch 14. Estimated date for commencing operation 18. Status of well classification as: February 1~, 1996 16: If proposal was verbally approved Oil × _ Gas __ Suspended Name of approver Date approved Service 17~ I hereby certify that the f~3regoing is true and corr~t to the best of my knowledge. Sig ned ~~¢~~.. ,,~. ~-.,,~:¢~Tit I e ,~~ ~ ~ ~---~ Date '~//~//~ ~ · -- ,,,,'~' ' FOR COMMISSION USE ONLY -Conditlo'~s of approval:'Noti~ Commission so repr~entative may witness' ! Approval No.,~ Plug Integrity ~,~ BOP Test _ Location clearance Approved, Copy.'. David W. Johnston '- =,u/.,z.J .t Approved by' order of the Commission ,..omi,,;~;o,~ - Date - Form 10.4-03 Rev 06/15/88 SUBMIT IN TRIPLICATE J6 O~:~OPH SP× EHDICOTT DEVP SUNDRY APPLICATION FOR VARIANCE ENDICOTT POOL WELL 1-33/M-23 February 7, 1996 Background Well 1-33/M-23 was drilled and completed in October 1995 as an IVIPI area subzone 2A producer. The current production rate is 1,700 bopd at 68% water cut utilizing 2.3 mmscf/d lift gas. CumulatiVe production to date is 0.25 mmbbls of oil. On December 29th, 1995 mud was found to be coming out of the conductor/ surface casing annulus in well 1-33/M-23 while pumping drilling mud and cuttings from well 1-65/N~25 down the outer annulus of 1-33/M-23. Annular disposal of drilling mud and cuttings from 1-65/N-25 had commenced down the outer annulus of 1-33/M-23 on December 13th 1995, and over a 17 day period a total of 9,879 bbJs out of 35,000 bbls permitted had been pumped to the annulus. Initial actions taken were to cease annular disposal on 1-33/M-23, remove the well from the list of approved wells for annular injection, and notify the AOGCC of the incident. A review team was then set up to determine the cause of the mud returns to surface and recommend appropriate remedial action. Summary of Investigations , A total of 130 bbls of cement were returned to surface during the 10-3/4" surface casing cement job. This is considered excessive; a more typical number is nearer to 30 bbls. This suggests that a potential channel exists behind the 10~3/4" casing. However, a good Leak Off Test of 12.8 ppg EMW was obtained subsequent to the cement job. . From a Hydrolog run in the well, no leak in the 10-3/4" casing was identified. All flow appeared to be tiowing out through the 10-3/4" casing shoe at 5013 ffmd. , The Hydrolog also identified upward flow behind the 10-3/4" casing at 4900 ffmd (i,e., c.100 ft above the shoe) but only at a high pump rate of 5 bpm. No flow behind casing could be identified at 4750 ffmd even at high pump rates. Note that on two separate occasions, fluids were pumped to the outer annulus in attempts to locate the flow path to surface. In both cases flow to surface could not be obtained, suggesting that the path to surface had either bridged or packed off. FEB 0 9 1996 ~6 OB:BiPM BP× EMDICOTT DEVP P.3×4 Proposed Remedial Action The investigations carried out to date point to a poor initial cement job on the 10-$/4" surface casing, suggesting a channel exists behind casing, in addition, the upward flow behind casing suggests that the cement around the 10-3/4" casing shoe has broken down, thus allowing the injected fluids a flow path to the channel behind casing. The remedial action proposed is to down squeeze the 10-3/4" by 7-5/8" outer annulus with sufficient cement to fill up the suspected channel around the 10- 3/4" casing shoe and to leave approximately 600 ff of cement in the annulus. An alternative, less likely theory that the leak path is a shallow thread/casing leak could be tested once the cement squeeze has been performed. A positive pressure test of the outer annulus against the cement plug will confirm integrity of the 10-3/4" casing above the plug, Recommendation We request approval to down squeeze the outer annulus on well 1-33/M-23 in the manner outlined above. We believe this action will ensure formation integrity around the 10-3/4" casing shoe, while leaving the upper section of the outer annulus available for pressure monitoring, in this way the well may be utilized without compromising safety. Your concurrence is sought on this remedial action. P.4/4 'KI~M(3M' ?,uUtTC:H PL=RFO{a, AT{ O M $1IMMAIqY {~,,~ I,-,' INffiAL , INITIAL PE.qPOPlRTION~ -, -{ ' E N O IC_O_I~_W E L L 1-33/~-2~ AP! NO: $0-029-2~577 COMPS.ETlON DIAGRAM BP FXP,LORAT{ON, {NC, WELL NAME 1-33/M-23 LOG/DATE DIL 9/20/'99 ZONE TOP M.D, BOT M.D. 2A 12100 12120 H TOP TVD BOT 1'VD 20 10034 10050 LARRY GRANT Attn. ALASKA OIL + GAS CONSERVATION 3001 PORCUPINE DRIVE ANCHORAGE AK, 99501. Date: 10 October 1995 RE: Transmittal of Data Sent by: HAND CARRY Dear Sir/Madam, Enclosed, please find the data as described below: WELL DESCRIPTION I'GR/CCL FINAL BL+RF 1 PLS FINAL BL+RF 1PFC/PERF FINAL BL+RF 1 PFC2PERF FINAL BL+RF Run ~ 1 Run # 1 Run # 1, Run # 1 ECC No. .. 5958.02 6446.05 6483.03 Please sign and return to: Attn. Rodney D. Paulson Atlas5600 BWirelinestreet Services Suite 201 ~ Anchorage, AK 99518 . Received b LARRY GRANT Attn. ALASKA OIL + GAS CONSERVATION 3001 PORCUPINE DRIVE Date: RE: 29 September 1995 Transmittal of Data ANCHORAGE AK, 99501. Sent by: HAND CARRY Dear Sir~Madam, ~~ ~'~" ~/~~/~ /~ Enclosed, please find the data as described below: 1-33/M-23 1LDWG TAPE+LIS Run # 1 6483.00 Please sign and return to: Attn. Rodney D. Paulson Atlas Wireline Services , 5600 B Street Suite 201 'Anchorage,/% 9£C£iv1.:D' Or FAX~. (907) 563-7803 4nChomgo' Cbn~miSsion LARRY GRANT Attn. ALASKA OIL + GAS CONSERVATION 3001 PORCUPINE DRIVE ANCHORAGE AK, 99501. Date: 29 September 1995 RE: Transmittal of Data Sent by: HAND CARRY Dear Sir/Madam, · Enclosed, please find the data as described below: DESCRIPTION 1PLS FINAL BL+RF 1 GR/CCL FINAL BL+RF 1PLS FINAL BL+RF 1 PFC/PERF FINAL BL+RF 1 PFC/PERF FINAL BL+RF 1 PFC/PERF FINAL'BL+RF ECC No. Run # 1 2628.09 Run # 1 Run ~ 1 5709.05 Run # 1 5723.06 Run # 1 5933.03 Run # i 6483.02 Please sign and return to: Attn. Rodney D. Paulson Atlas Wireline Services 5600 B Street Suite 201 RECEIVED Received by: Anchorage, AK 99518 r FAX ~o (907) 563-7803 0C~ 0 Alaska Oil & Gas Cons. Commission /- V . .... LARRY GRANT Attn. ALASKA OIL + GAS CONSERVATION 3001 PORCUPINE DRIVE ANCHORAGE AK, 99501. Date: 27 September 1995 RE: Transmittal of Data Sent by: HAND CARRY Dear Sir/Madam, Enclosed, please find the data as described below: WELL # DESCRIPTION ECC No. 1-33/M-23 DIFL/GR FINAL BL+RF Run # 1 6483.00 ZDL/CN/GR FINL BL+RF Run ~ 1 CN/GR FINAL BL+RF Run # 1 BH PRO FINAL BL+RF Run # 1 1 SSVD FINAL BL+RF Run # 1 1-33/M-23 1 SBT/GR FINAL BL+RF Run # 1 6483.01 Please sign and return to: Attn. Rodney D. Paulson Atlas Wireline Services 5600 B Street Suite 201 Anchora. ge, AK 99518 Received b : ~-/ / /~.~~ Date ALASKA OIL AND GAS CONSERVATION COMMISSION 3001 Porcupine Drive Anchorage, AK 99501-3192 ph: (907) 279-1433 fax: (907) 276-7542 Date TELECOPY TRANSMITTAL Number of pages including cover sheet: If you do not receive fax in its entirety, please call (907) 279-1433 immediately. MESSAGE: fl jo 3/93 ALASKA OIL AND GAS CONSERVATION COMMISSION 3001 Porcupine Drive Anchorage, AK 99501-3192 ph: (907) 279-1433 , . fax: (907) 276-7542 TELECOPY TRANSMITTAL Date /8 .~-/o ~--- TO: FROM: Number of pages including cover sheet: If you do not receive fax in its entirety, please call (907) 279-1433 immediately. MESSAGE: jo 3/93 _ '95 08:~3~M SH~RE~_D~ SERVICES DRILLIM~ ~ P~I I~P EXPLORATION BP Exploration (Alaska) I~10, PO Box 196612 Anchorage, Alaska 99519-6612 TELECOPY COMMUNICATIONS CENTER MESSAGE# TO; FROM: Name: 'Company: Location: Fax # Confirm # 'Name & Ext.: Department: Mai! Stop: PAGES TO FOLLOW (Do Not Include Cover Sheet) SEP 1 8 1995 & Gas Cons. Commission Anchorage SECURITY CLASSIFICATION PRIVATE SECRET CONFIDENTIAL Telecopy # Confirm # For Communications Center Use Only Time In Time Sent Time Confirmed Confirmed By Operator BP Memorandum To: Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage Alaska, 99501-3192 Attn. Blair Wondzell Date: Fri, Sep 15, 1995 From: Robert Laule ~. 'r...,. ~ ;, ~ D Subject: Permit to Drill for 1-33/M-23 Endicott SEP '/8 1995 At~s~ Dit & 6as Cons. Commission Anchorage Please amend the submission to the Permit to Drill 1-33/M-23 to allow annular injection in well 1-33/M-23 upon completion of cementing of the long string. This permit was approved by AOGCC prior to AOGCC's assumption of the regulating Authority for Annular Injection, _M_P_I wells ou_r_rentlv ava!lab, l_e for iniection 2-40/S-22 & 1-23/O-15,1-19/I-18 (Amendment requested under separate cover) Inform__ation onU_SDW's:(Underground Source of Drinking Water) As referenced in Area Injection Order #1, there are no drinking water aquifers in the Duck Island Unit which encompasses the Entire Endicott, Ivishak, and Alapah Oil Pools, as the average level of Total Dissolved Solids (TDS) of the ambient water within the proposed project area is above 10,000 ppm, There are no domestic or industrial use water wells located within one mile of the project area, .S_u rfaoe~Casinq. SettJn_g_D_ epth Since there is no USDW, the surface casing setting depth is set based on recommendation to prevent communication to surface. These require setting the surface shoe at least 250' tvd below "the 3200-3500' tvd shale" Surface Casino design Burst of 10-3/4" 45.5#/ft NT80LHE 5210 psi Collapse 7-5/8" 29.7#/ft USS-95 7200 psi BP Recommended Cuffing Injection Procedure restrict the pumping rate to 3 BPM or less with a maximum pressure of 2000 psi when disposing of solids laden fluid. A determination hae been made that the pumping operat .... ~ will not endanger the integrity of the well being drilled by the submission of data to AOGCC detailing the confining layers ,porosity and permeability of the injeotion zone on 7-24-95. Pumping into the hydrocarbon reservoir will not occur, ALASKA OIL AND GAS CONSERVATION COMMISSION TONY KNOWLE$, GOVERNOR 3001 PORCUPINE DRIVE ANCHORAGE, ALASKA 99501-3192 PHONE: (907) 279-1433 FAX: (907) 276-7542 August 31, 1995 Steve Shultz, Senior Drlg. Engineer BP Exploration (Alaska), Inc. P O Box 196612 Anchorage, AK 99519-6612 Re: Well # Duck Island Unit/Endicott'1:33/M-23 Company BP Exploration (Alaska), Inc. Permit # 95-107 Surf Loc 3217'NSL, :~114'WEL, Sec 36, T12N, R16E, UM Btmhole Loc 1671'NSL, 765'WEL, Sec 31, T12N, R17E, UM Dear Mr Shultz: Enclosed is the approved revised application for permit to ddll the above referenced well. The provisions of the odginai approved permit dated August 3, 1995, are in effect for this revision. Chairman ~ BY ORDER OF THE COMMISSION /encI c: Dept of Fish & Game, Habitat Section - w/o encl Dept of Environmental Conservation - w/o encl STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION PERMIT TO DRILL 2O AAC 25.005 la. Type ofwork Drill E'I Redrilll-Illb. Type ofwelI. Exploratoryl~l Stratigraphic Test[-1 DevelopmentOil[;1 Re-Entry [] DeepenI-II Service [] Development Gas [] Single Zone [] Multiple Zone [] 2. Name of Operator 5. Datum Elevation (DF or KB) 10. Field and Pool BP Exploration KBE=56 feet Endicott Field/Endicott Pool 3. Address 6. Property Designation P. O. Box 196612, Anchorage, Alaska 99519-6612 ADL 312828 4. Location of well at surface 7. Unit or property Name 11. Type Bond(see 20 ^AC 25.025) 3217' NSL, 2114' WEL, SEC 36, T12N, R16E UM Duck Island Unit/Endicott At top of productive interval 8. Well number Number 1736' NSL, 942' WEL, SEC 31, T12N, R 17E UM 1-33/M-23 2S 100302630-277 At total depth 9. Approximate spud date Amount 1671' NSL, 765' WEL, SEC 31, T12N, R17E UM 09/03/95 $200,000.00 12. Distance to nearest 13. Distance to nearest well 14. Number of acres in property15. Proposed depth (MD and TVD) 'property line f2,408 ADL 047502 1671 feet No Close Approach feet 4300 MD/10,321 TVD feet 16. To be completed for deviated wells 17. Anticipated pressure (see 20 A^C 25.035 (e)(2)) Kickoff depth 1050 feet Maximum hole angle 37 o Maximum sudace 3900 psig At total depth (TVD) 10000~4890 psig 18. Casing program Setting Depth raze Specifications Top Bottom Quantity of cement Hole Casing Weight Grade Coupling Length MD TVD MD TVD (include stage data) 30" Struct. Drive Pipe 90' 40' 40' 130' 130' Drive 13.5" 10.75" 45.5 L-80 B TC 5030' Surface Surface 5030' 4426' 795 sx Type 'E', 412 sx 'G', 150 sx Type 'E' 9.875" 7.625" 29.7 USS-95 BUTT 12408' Surface Surface 12408' 10321' 488 sx Class 'G' 19. To be completed for Redrill, Re-entry, and Deepen Operations. Present well condition summary Total depth: measured feet Plugs (measured) true vertical feet Effective depth: measured feet Junk (measured) true vertical feet Casing Length Size Cemented Measured depth True Vertical depth StructuralEL'iT. iVED Conductor Surface Intermediate AUG 2 9 1995 Production Liner Alaska 0il & Gas Cons. Commission Perforation depth: measured Anchorage true vertical 20. Attachments Filing fee [] Property plat [] BOP Sketch [] Diverter Sketch [] Drilling program[] Drilling fluid program [] Time vs depth plo, t [] Refraction analysis [] Seabed reportE] 20 AAC 25.050 requirementsCl 21' ' hereby certify/'~h¢(i the f°re~'r~ is ~?ue and c°rrect t° the best °f mY kn°wledge"?;~.c.' /~ !/, /'i ~'-~- ~; ~-~ ~/~_O~ Signed ,~.,,,,'~ .~.¢._/~.- --L .,/! ~'.,,;~,,~', ,,,\ - Title Senior Drilling Engineer ~/ _ . Date ' ..... '"~J' .... %.. Commission Use Only Permit Number IAPI number APl~Oval date_ _.- See cover letter 95-107 150-029-22577 ~:~-~_.//.--¢,,.~ for other requirements Conditions of approval Samples required [] Yes [] No Mud log required []Yes [] No Hydrogen sulfide measures [] Yes [] No Directional survey required [] Yes [] No [] ZM;,.,.[]3M,; J~SM; []10M; I-I15M; Required working pressure for BOPEdriginal Other: ~lgnea B Y order o, Approved by 0aV~ W. Johnston Commissioner tne commission Date / Form 10-401 Rev. 12-1-85 Submit in~ ',ate BP EXPLOR.~I'ION Memorandum To: Alaska Oil & Gas Conservation Commission Date: August 25, 1995 From: Terrie Hubble Shared Services Drilling Tech Asst Subject: Permit 95-107, Endicott 1-33/M-23 This Revised Permit to Drill is being submitted due to a change in the bottom hole location. This change is necessary to provide optimal placement within surrounding faults. /tlh Gas Cons. Commission Anchorage TONY KNOWLE$, GOVERNOR ALA IiA OIL CONSI R¥ ITION CO MI SIOt 3OO1 PORCUPINE DRIVE ANCHORAGE, ALASKA 99501-3192 PHONE: (907) 279-1433 FAX: (907) 276-7542 August 3, 1995 Steve Shultz, Ddlling Engineer Supervisor BP Exploration (Alaska), Inc. P O Box 196612 Anchorage, AK 99519-6612 Re: Duck Island Unit/Endicott 1-33/M-23 BP Exploration (Alaska), Inc. Permit NO 95-107 Surf Loc 3217'NSL, 2114'WEL, Sec. 36, T12N, R16E, UM Btmhole Loc 1883'NSL, 1031'WEL, Sec. 31, T12N, R17E, UM Dear Mr Shultz: Enclosed is the approved application for permit to drill the above referenced well. The permit to drill does not' exempt you from obtaining additional permits required by law from other governmental agencies,-and does not authorize conducting drilling operations until all other required permitting determinations are made. Blowout prevention equipment (BOPE) must be tested in accordance with 20 AAC 25.035. Sufficient notice (approximately 24 hours) of the BOPE test performed before ddlling below the surface casing shoe must be given so that a representative of the Commission may witness the test. Notice may be ~ ~ petroleum field inspector 659-3607. . BY ORDER OF THE COMMISSION /encl c: Dept of Fish & Game, Habitat Section - w/o enCi Dept of Environmental Conservation - w/o encl AUG 2 Gas Cons. Commission Anchorage 1-33/M-23 Hazards Pressure: Abnormal pressures in the 3A are not anticipated. M-23 is approximately 3600' ESE of gas injection at 1-05/O-20. Gas: The GCC is expected in the 2B, howerver gas underrun K2M in the upper 2A may be present Faults Datum: Top 2A1 Fault Distance Throw from target 1 400 ft north- <50' down to south Geologic Notes · Depth uncertainties for tops estimated at +/- 15 feet · OWC & GCC uncertainty estimated at +/- 20 ft · Target must be maintained to avoid faulting to the north&south. · 2A3 production has dominated over 2A1 in nearby horizontal well 1-25/N-22, leaving 2A1 reserves behind. · Associated Injectors Gas 2-06/J-22 (2A Gas Inj) 2400 ft NNE 5-01/SD-07 (2B Gas inj) 2500 ft WNW 1-05/O-20 (3A Gas lnj) 3200 ft ESE Water 5-02/SD-10 (2A wtr inj) 1700 ft SW 1-23/O-15 (2A wtr inj) 5500 ft NW (no inj to date) · 3A2 may be overpressured due to injection at 1-05/O-20 as witnessed in 1- 31/M-21 drilling. · Location is east of 3A4 pinch out. · Possible Injected Water Breakthrough in 2A1 (est 11 ft) as evidenced in M-21 results. · 2A2 ("D" Shale) may be thin at M-23 (ie<10 ft thick) · 100 foot target radius requested due to drainage area constraints. · Expected max. hole angle is 35 deg. ~UG 2 8 199-5 6as Cons. Commission 'Anchorage lx\¢ka Ot~, & G&s Cons. commis¢Or~ I WellName: I 1-33/M-23 Well Plan Summary Type of Well (producer or injector): I Producer Surface Location: 3217 FSL 2114 FEL S36 T12N R16E UM Target Location: 1736 FSL 942 FEL S31 T12N R17E UM Bottom Hole Location: 1671 FSL 765 FEL S31 T12N R 17E UM I AFE Number: 1717498 I Estimated Start Date: 19-3-95 IMD: 1 12408 I Rig: I DOYON 15 I I Operating days to complete: 124 ITvD: 11°32~ I IK~E: 156 Well Design (conventional, sHmhole, etc.): I SLIMHOLE Formation Markers: Formation Tops MD TVD (BKB) UPPER SV SHALE 3672 3341 BASE UPPER SV 4073 3661 TOP SV MARINE 4630 4106 SHALE BASE SV 4805 4246 MARLINE SHALE SV-5 4805 4246 BASE SV-5 5130 4506 TOP UGNU 6602 5682 TOP WEST SAK 8072 6856 TOP 9229 7781 SEABEE/AYLYAK TOP SHALE 10669 8931 WALL/TUFFS HRZ 11326 9456 BASE HRZ 11658 9721 PUT RIVER Absent Absent LCU 11658 9721 KEKIKTUK 11723 9773 4704 psi Zone3A 4624psi Zone2B 4370 psi Zone 2A AUG 2 8 1995 Well Plan SumInary Alaska 0il & Gas Cons. Commission Anchorage Page 1 Casing ubin Program: Hole Size Csg/ Wt/Ft Grade Conn Length Top Btm Tbg O.D. MD/TVD MDfrVD 13.5 10.75 45.5 L-80 BTC 5030 0 5030/4426 9.875 7.625 29.7 USS-95 Butt 12408 0 '" 12408/10321 Logging Program: Open Hole Logs: DIIJMSFL/LDT/CNL/GR FMT 10-15 points Cased Hole Logs: SBT (optional) Mud Program: I Special design considerations Surface Mud Properties: I SPUD Density Marsh Yield 10 sec 10 min pH Fluid (PPG) Viscosity Point gel gel Loss 8.7 300 40-60 30-60 60-80 9-10 15-25 to to to tO tO to .' tO 9.2 1 O0 20-40 15-20 20-30 9-10 ! 5-25 Production Mud Properties: I Density Marsh Yield 10 sec 10 min pH Fluid (PPG) Viscosity Point gel gel Loss 9.8-10.2 50-6- 20-30 12-15 25-30 9.5-10.0 <6 to to to to to to to Well Control: Well control equipment consisting of 5000 psi W.P. pipe rams, blind rams, and annular preventer will be installed and is capable of handling maximum potential surface pressures. Diverter, BOPE and drilling fluid system schematics on file with AOGCC. Directional: I goP: I1050 [ Maximum Hole Angle: ] 37.0 Close Approach Well: None The above listed wells will be secured during the close approach. AUG 2 Alaska Oil & 6as Cons. Commissiorl I^nch0rag0 Well Plan Summary Page 2 Deep well intersection guidelines met on 1-25/N-22. C0mIp. lool0ri Gas Cons,'~.~' m Anchorage. Well Plan Summary Page 3 1-33/M-23 CEMENT PROGRAM- HALLIBURTON 10-3/4" SURFACE CASING CASING SIZE: 10-3/4", 45.5~ CIRC. TEMP: 40°F LEAD CEMENT TYPE: Type 'E' Permafrost ADDITIVES: retarder WEIGHT: 12.0 ppg YIELD: 2.17 ft/sx MIX WATER: 11.63 gps APPROX. SACKS: 795 THICKENING TIME: 5+ hrs TAIL CEMENT TYPE: Premium ADDITIVES: 2% Calcium Chloride WEIGHT: 15.8 ppg YIELD: 1.15 ft3/sx MIX WATER: 5.00 gps APPROX. SACKS: 412 THICKENING TIME: 4 hrs TOP JOB CEMENT TYPE: Type 'E' Permafrost ADDITIVES: retarder WEIGHT: 12.0 ppg YIELD: 2.17 ft3/sx APPROX. SACKS: 150 MIX WATER: 11.63 gps SPACER: 100 bbls fresh water ahead of lead slurry. The mixing temperature should be as cold as possible to prevent acceleration-approximately 40 - 45 F. CEMENT VOLUME The objective is to get cement back to surface 1. Le'ad slurry w/30% excess over gauge hole. 2. Tail slurry to 3650 w/30% excess over guage hole. 3672 'MD = top of SV shale 2. Top job volume 150 sx. 7 5/8" PRODUCTION CASING CASING SIZE: 7-5/8", 29.7# CIRC. TEMP 135°F TAIL CEMENT TYPE: Premium ADDITIVES: 0.2% CFR-3 (Dispersant) + 0.45% Halad-344 (Fluid Loss) + HR-5 (Retarder) WEIGHT: 15.8 ppg YIELD: 1.15 ft3/sx MIX WATER: 5.0 gps SACKS: 488 PUMP TIME: 4 h_rs Retarder (HR-5) concentration will be based on actual lab tests. SPACERS: Pump 20 bbls Fresh Water; 70 bbls NSCI (Halliburton) spacer @ 11 ppg. OTHER CONSIDERATIONS: Displace at 14 bpm with rig pumps. CEMENT VOLUME: Tail Slurry to 1000' above the Kekektuk w/50% excess over gauge hole + 80 ft. shoe. The estimated MD of the Kekektuk is 11,723. Alaska 0il & Gas Cons, Commission Anchorage 1-33/M-23 OPERATIONS SUMMARY: Dig out cellar, Weld on landing ring. Ensure landing ring is the proper height with Endicott Field personel. Install diverter. MIRU Doyon 15. Hold pre spud meeting with crew. 1. Test diverter. Drill 13-1/2" surface hole. Use gyro for close approach until magnetic interference is past. Check with Anadfill & Gyrodata to insure they are following JORPS. Drill hole to 4426' TVD. 2. Run 10-3/4" 45.5 ppf surface casing 3. Cement surface casing. 4. Perform top job, if necessary with 150 sx Type "E" Permafrost cement. 5. ND diverter. NU Bop's & test. 6. Drill out shoe and perform LOT. 7. Direcfionally drill production hole to 10,321' TVD. Well site geologist will help pick final TD (175' below lower most possible perforation in 2Al 10120' tvdss).. 8. Have sample catchers and well site geologist on site before drilling the Kekiktuk. 9. Use key seat wiper for Tuffs and HRZ. 10. RU E/Line & run open hole logs ("Triple Combo" ).+ FMT. 11. Run 7-5/8" production casing. Turbolators should be 2 per joint on the bottom 1000' of casing. 12. Run bond logs.(opfional dependent on the mechanics of the cement job). 13. Run 4-1/2" 13CR-80 completion with hydraulic set permanent packer with WLEG 350' above the top of Kekiktuk (estimated WLEG @ 11,200' MD). 14. ND Bop's. NU 4-1/16" SM# tree. Set packer and test. 15. Freeze protect tbg. 16. RD MO Rig. AlaSka Oil & Gas Cons. Commission Anchorage _5-95 09:29 Anad~-ill DPC 90---344 2160 P.05 SHARED SERVICES DRILLING t-33/M-23 (P6) VERTTOAL SECTZON VZEW Section at: ]10.00 TVD Scale.: 1 inch = lO0 feet Der Scale.: ~. inch -- ]00 feet :Drawn ..... :08/~4/95 Marker Identification MD BKB SECTN INCLN A) TARGET-tO0 FT RADIUS 12096 10071 6190 36.97 B) TO 12408 lOCi 6378 36.97 5800 5850 5900 5950 6000 6050 6JO0 6150 6200 6250 6300 6350 6400 6450 6500 Section Departure (AnadPiil (c)~ 133~3l~6 2.5l~.0~ 2:54 p~ P) ~ J-g5 09:30 Anadr~ll DPC 907--344 2160 P-06 -- ]-33/M-23 (p6] VERTICAL SECTION VIEW 'Section a~: llO.O0 TVD Scale.: ! inch : 1200 feet Dep Scale.: 1 inch = I200 feet Drawn ..... :08/24/95 Nanken Identification ND BKB SECTN INC£N Al KB 0 0 o 0.00 8) NUDGE BUILD ].5/100 300 300 0 0.00 C) END i,5/tO0 BUILD 600 600 9 4.50 D) START DROP l/lO0 600 600 § 4.50 EJ END 1/100 DROP 1050 1049 23 0.00 F] KOP CURVE 2.5/100 1050 104g 23 0.00 G) END 2.5/~00 CURVE 2529 2428 479 36.97 HJ SURFACE CASING POINT 5030 4426 1970 36.97 I) CURVE 2.5/t00 t04i2 8726 5]78 36.97 dj END 2.5/100 CURVE 10596 8873 5288 36.97 K] TARGET-tO0 FT RADIUS ]2096 10071 6i90 36.97 L) TD 12408 J032] 6378 36.97 {Ana~ci] 1 (c)95 600 ~eO0 ~800 2400 3O00 3600 4200 4800 5400 6000 6600 Section ure 7200 7800 1-33/M-23 (P6) PLAN VIEW CLOSURE · 6414 feet at Azimuth .103,g2 DECLINATION,' +29,742-(E) SCALE · I inch = 800 feet DRAWN '08/24/§5 400 0 400 BO0 <- NEST' EAST -> (Ana~r~]J (¢)95 133N23P6 2.~.0! ~53 ~ P) 1200 1600 2000 SHA ED i i 'S ' ERVICES Marker Identification MD N/S' E/W A) KB 0 0 0 B) NUDGE BUILD 1.5/100 300 0 0 C) END 1.5/t00 BUILD 600 10 6 D) START DROP 1/100 600 10 6 E) END i/lO0 DROP i050 25 ~5 F) KOPCURVE 2.5/100 t050 25 15 G) END 2.5/100 CURVE 2529 124 465 H) SURFACE CASING POINT 5030 446 1934 I) CURVE 2.5/100 10412 1140 5096 J) END 2.5/t00 CURVE ~0596 tt70 5202 K) TARGET-lO0 FT RADIUS 12096 ~479 6049 L) TD 12408 1543 2400 2800 3~0 3600 DRI'LLIN6 6226 iANAD RiL~--~ AK",-DPC FEASIBILITY PL/ NOT APPROVED EXECUTION 4000 4400 4800 5200 5600 6000 6400 6800 01 0 ALASKA OIL AND GAS CONSERVATION COMMISSION TONY KNOWLE$, GOVERNOR 3001 PORCUPINE DRIVE ANCHORAGE, ALASKA 99501-3192 PHONE: (907) 279-1433 FAX: (907) 276-7542 August 3, 1995 Steve Shultz, Drilling Engineer Supervisor BP Exploration (Alaska), Inc. P O Box 196612 Anchorage, AK 99519-6612 Re: Duck Island Unit/Endicott 1-33/Mo23 BP Exploration (Alaska), Inc. Permit NO 95-107 Surf Loc 3217'NSL, 2114'WEL, Sec. 36, T12N, R16E, UM Btmhole Loc 1883'NSL, 1031'WEL, Sec. 31, T12N, R17E, UM Dear Mr Shultz: Enclosed is the approved application for permit to drill the above referenced well. The permit to drill does not exempt you from obtaining additional permits required by law from other governmental agencies, and does not authorize conducting drilling operations until all other required permitting determinations are made. Blowout prevention equipment (BOPE) must be tested in accordance with 20 AAC 25.035. Sufficient notice (approximately 24 hours) of the BOPE test performed before drilling below the surface casing shoe must be given so that a representative of the Commission may witness the test. Notice may be ~ ~ petroleum field inspector 659-3607. BY ORDER OF THE COMMISSION /encl c: Dept of Fish & Game, Habitat Section - w/o encl Dept of Environmental Conservation - w/o enci STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION PERMIT TO DRILL 2O AAC 25.OO5 la. Type of work Drill [] Redrill I-]llb. Type of well. Exploratoryl-'l Stratigraphic Test [] Development Oil [] 2 Name Re-Entry [] Deepen []1 Service [] Development Gas [] SingleZone [] Multiple Zone[] of Operator 5. Datum Elevation (DF or KB) 10. Field and Pool BP Exploration KBE=56 feet Endicott Fie/d/Endicott Pool 3. Address 6. Property Designation P. O. Box 196612, Anchorage, Alaska 99519-6612 ADL 312828 4. Location of well at surface 7. Unit or property Name 11. Type Bond(see 20 AAC 25.025) 3217' NSL, 2114' W£L, SEC 36, T12N, R16E UM Duck/s/and Unit/Endicott At top of productive interval 8. Well number Number 1921' NSL, 1206' W£L, SEC 31, T12N, R17E UM 1-33/M-23 2S100302630-277 At total depth 9. Approximate spud date Amount 1883'NSL, 1031' WEL, SEC 31, T12N, R17E UM 08/10/95 $200,000.00 12.propertyDistancelinetO nearest 13. Distance to nearest well 14. Number of acres in property15. Proposed depth (MO and'rVD) ADL 047502 1883 feet No Close Approach feet 4300 f2,224 MD / 10,324 TVD feet 16. To be completed for deviated wells 17. Anticipated pressure (see 20 AAC 25.035 (e)(2)) Kickoff depth 1050 feet Maximum hole angle s6 o Maximum surface 3900 psig At total depth (TVD) 10000Y4890 psig 18. Casing program Setting Depth s~ze Specifications Top Bottom Quantity of cement Hole Casing Weight Grade Coupling Length MD 'I-VD MD TVD (include stage data) 30" Struct. Drive Pipe Surface Surface Drive 13.5" 10.75" 45.5 L-80 BTC 4958' Surface Surface 4958' 4406' 795 sx Type 'E', 412 sx 'G; 150 sx Type 'E' 9.875" 7.625" 29.7 USS-95 BUTT 12224' Surface Surface 12224' 10324' 488 sx Class 'G' 19. To be completed for Redrill, Re-entry, and Deepen Operations. Present well condition summary Total depth: measured feet Plugs (measured) true vertical feet Effective depth: measured feet Junk (measured) true vertical feet Casing Length Size Cemented Measured depth True Vertical depth Structural Conductor RECEIVED Surface Intermediate Production JUL ! 4 1995 Liner Aiask~ 0ii & Gas Cons. Commission Perforation depth: measured true vertical 20. Attachments Filing fee [] Property plat [] BOP Sketch [] Diverter Sketch [] Drilling program[] Drilling fluid program [] Time vs depth plot [] Refraction analysis [] Seabed report[] 20 AAC 25.050 requirementsl-I 21.1 hereby certify~tha, t the foregoing is t~e_/~nd/"cprr~bt to the best of my knowledge Signed .,/~d..~-~..~ ~-~ ~'""l ~/~M.~" ~"/4~,~Title Drilling Enginee#ng Supervisor Date ~ -//'-~J--- · "-" - ~3omm~sion Use Only Permit Number IAPI number Approval date,, .., See cover letter ~-/07 ]50-~---,~-' .2_. ~_, ~ ~7 ~-~- ~ for other requirements Conditions of approval Samples required [] Yes J~ No Mud Icg required []Yes [] No Hydrogen sulfide measures ~ Yes [] No Directional survey requ~recl [] Yes [] No Required working pressure for BOPE [] 2M; []3M; J~5M; I-I10M; 1-115M; Other: Original Signed By by order of Approved by David W. dohnston Commissioner me commission Date Form 10-401 Rev. 12-1-85 Submit in tril:,licate 1-33/M-23 Hazards Pressure: Abnormal pressures in the 3A are not anticipated. M-23 is approximately 3600' ESE of gas injection at 1-05/O-20. Gas: The GOC is expected in the 2B, howerver gas underrun K2M in the upper 2A may be present Faults Datum: Top 2A1 Fault Distance from target 1 400 ft north Throw <50' down to south Geologic Notes · Depth uncertainties for tops estimated at +/- 15 feet · OWC & GOC uncertainty estimated at +/- 20 ft · Target must be maintained to avoid faulting to the north&south. · 2A3 production has dominated over 2A1 in nearby horizontal well 1-25/N-22, leaving 2A1 reserves behind. · Associated Injectors Gas 2-06/J-22 (2A Gas Inj) 2400 ft NNE 5-01/SD-07 (2B Gas Inj) 2500 ft WNW 1-05/O-20 (3A Gas Inj) 3200 ft ESE Water 5-02/SD-10 (2A wtr inj) 1700 ft SW 1-23/O-15 (2A wtr inj) 5500 ft NW (no inj to date) · 3A2 may be overpressured due to injection at 1-05/O-20 as witnessed in 1- 31/M-21 drilling. · Location is east of 3A4 pinch out. · Possible Injected Water Breakthrough in 2A1 (est 11 ft) as evidenced in M-21 results. · 2A2 ("D" Shale) may be thin at M-23 (ie<10 ft thick) · 100 foot target radius requested due to drainage area constraints. · Expected max. hole angle is 35 deg. ~ I WellName: I 1-33/M-23 Well Plan Summary Type of Well (producer or injector): ] Producer Surface Location: 3217 FSL 2114 FEL S36 T12N R16E UM Target Location: 1921 FSL 1206 FEL S31 T12N R17E UM Bottom Hole Location: 1883 FSL 1031 FEL S31 T12N R 17E UM I AFE Number: ]717498 I I Estimated Start Date: I 8-10-95 I MD: ] 12224 I I Rig: I DOYON 15 [ Operating days to complete: I 24 IxvD: Ia°324 I II~E: Is6 I Well Design (conventional, sHmhole, etc.): I SLIMHOLE Formation Markers: Formation Tops MD TVD (BKB) UPPER SV SHALE 3650 3341 BASE UPPER SV 4043 3661 TOP SV MARINE 4589 4106 SHALE BASE SV 4761 4246 MARIINE SHALE SV-5 4761 4246 BASE SV-5 5081 4506 TOP UGNU 6525 5682 ~ ]Z ff [2 I \! l:; [ } TOP WEST SAK 7966 6856 ;~ ~ '''~ ~ ' ' "- TOP 9102 7781 SEABEE/AYLYAK JUL ~! 4 1995 TOP SHALE 10514 8931 WALL/TUFFS A!~ska 0il & Gas Cons. Commission HRZ 11159 9456 gnl-:hn;r , BASE HRZ 11484 9721 PUT RIVER Absent Absent LCU 11484 9721 KEKIKTUK 11548 9773 4704 psi Zone3A 4624psi Zone2B 4370 psi Zone 2A Well Plan Surnrnary Page 1 Casing/Tubing Program: Hole Size Hole size'- Csg/ " Wt/Ft~ Grade Corm Length Top Btm Tbg O.D. MD/TVD MD/TVD 13.5 10.75 45.5 L-80 BTC 4958 0 4958/4406 9.875 7.625 29.7 USS-95 Butt 12224 0 12224/10324 Logging Prol Open Hole Logs: Cased Hole Logs: ,ram. DIT JMSFL/LDT/CNL/GR FMT 10-15 points SBT (optional) P Ff'FIVFI} ,..xia.qka L}il & Gas Cong. Commission · . bnc,~oi'c. -,. ' Mud Program: I Special design considerations Surface Mud Properties: [SPUD Density Marsh Yield 10 sec 10 min pH Fluid (PPG) Viscosity Point gel gel Loss 8.7 300 40-60 30-60 60-80 9-10 15-25 to to to to to to to 9.2 100 20-40 ! 5-20 20-30 9-10 15-25 Production Mud Properties: [ Density Marsh Yield 10 sec 10 min pH Fluid (PPG) Viscosity Point gel gel Loss 9.8-10.2 50-6- 20-30 12-15 25-30 9.5-10.0 <6 to to to to to to to Well Control: Well control equipment consisting of 5000 psi W.P. pipe rams, blind rams, and annular preventer will be installed and is capable of handling maximum potential surface pressures. Diverter, BOPE and drilling fluid system schematics on file with AOGCC. Directional: IKOP: 11050 Maximum Hole Angle: Close Approach Well: 36.0 None The above listed wells will be secured during the close approach. Well Plan Summary Page 2 Deep well intersection guidelines met on 1-25/N-22. jul_ ~ 4 '~995 0il & Gas Cons. Commission Well Plan Summary Page 3 1-33/M-23 CEMENT PROGRAM- HALLIBURTON CASING SIZE: 10-3/4", 45.5ff CIRC. TEMP: 40°F 10-3/4" SURFACE CASING LEAD CEMENT TYPE: Type 'E' Permafrost ADDITIVES: retarder WEIGHT: 12.0 ppg YIELD: 2.17 ft/sx MIX WATER: 11.63 gps APPROX. SACKS: 795 THICKENING TIME: 5+ hrs TAIL CEMENT TYPE: Premium ADDITIVES: 2% Calcium Chloride WEIGHT: 15.8 ppg YIELD: 1.15 ft3/sx MIX WATER: 5.00 gps APPROX. SACKS: 412 THICKENING TIME: 4 hrs TOP JOB CEMENT TYPE: Type 'E' Permafrost ADDITIVES: retarder WEIGHT: 12.0 ppg YIELD: 2.17 ft3/sx APPROX. SACKS: 150 MIX WATER: 11.63 gps SPACER: 100 bbb fresh water ahead of lead slurry. The mixing temperature should be as cold as possible to prevent acceleration-approximately 40 - 45 F. CEMENT VOLUME The objective is to get cement back to surface 1. Lead slurry w/30% excess over gauge hole. 2. Tail slurry to 3650 w/30% excess over guage hole. 3650 'MD = top of SV shale 2. Top job volume 150 sx. 7 5/8" PRODUCTION CASING CASING SIZE: 7-5/8", 29.7# CIRC. TEMP 135°F RECEIVED J~JL 1 z~ !995 TAIL CEMENT TYPE: Premium ADDITIVES: 0.2% CFR-3 (Dispersant) + 0.45% Halad-344 (Fluid Loss) + HR-5 (Retarder) WEIGHT: 15.8 ppg YIELD: 1.15 ft3/sx MIX WATER: 5.0 gps SACKS: 488 PUMP TIME: 4 hrs Retarder (HR-5) concentration will be based on actual lab tests. SPACERS_.' Pump 20 bbb Fresh Water; 70 bbls NSCI (Halliburton) spacer @ 11 ppg. OTHER CONSIDERATIONS: Displace at 14 bpm with rig pumps. .CEMENT VOLUME: Tail Slurry to 1000' above the Kekektuk w/50% excess over gauge hole + 80 ft. shoe. The estimated MD of the Kekektuk is 11,548. 1-33/M-23 OPERATIONS SUMMARY: Dig out cellar, Weld on landing ring. Ensure landing ring is the proper height with Endicott Field personel. Insta!l diverter. MIRU Doyon 15. Hold pre spud meeting with crew. 1. Test diverter. Drill 13-1/2" surface hole. Use gyro for close approach until magnetic interference is past. Check with Anadrill & Gyrodata to insure they are following JORPS. Drill hole to 4406' TVD. 2. Run 10-3/4" 45.5 ppf surface casing 3. Cement surface casing. 4. Perform top job, if necessary with 150 sx Type "E" Permafrost cement. 5. ND diverter. NU Bop's & test. 6. Drill out shoe and perform-LOT. 7. Directionally drill production hole to 10,324 TVD. Well site geologist will help pick final TD (175' below lower most possible perforation in 2Al 10120' tvdss).. 8. Have sample catchers and well site geologist on site before drilling the Kekiktuk. 9. Use key seat wiper for Tuffs and HRZ. 10. RU E/Line & run open hole logs ("Triple Combo" ).+ FMT. 11. Run 7-5/8" production casing. Turbolators should be 2 per joint on the bottom 1000' of casing. 12. Run bond logs. (optional dependent on the mechanics of the cement job). 13. Run 4-1/2" 13CR-80 completion with hydraulic set permanent packer with WLEG 350' aboVe the top of Kekiktuk (estimated WLEG @ 11,200' MD). 14. ND Bop's. NU 4-1/16" 5M# tree. Set packer and test. 15. Freeze protect tbg. 16. RD MO Rig. i, , i , Illl Il Il Im III I I II __1 Anadr~ / ] Schlumberger , I ,Il · Ill Il ~ Il Il 1-33/M-23 (P3) PLAN VIEW · 6~07 feet at Azimuth 102.60 OECL~NAT ~01~.: 29.754 E SCALE · I [rich = ~000 feel ORA~ ...... ' 07/07/95 I, ORIL'EING, ........ ,,, , J ! ii i -i __ ...... SHARED 'SE-R'ViCES' i i i L-- i i Ill ii i i i ii i i i i i ~ ldentif]cat~an ~ HfS A) KB 0 0 0 B) NUOGE BL~LO i.5/t~ ~0 0 0 C] E~ 1.5/i~ ~ILD ~0 10 6 O] ST~T ~ l/JO0 " 600 iO 6 E) E~ 1/~00 ~ i~O 25 F) K~ BUZ~ 2.5/~00 ~ ~ Gl ~ 2.5/i00 ~ILO E469 ~t7 H) ~A~ ~SI~ ~INT 4~ 427 lB41 I) Tifl~l-lO0 FT ~S 1{9i4 i~3 · 5784 d] TO ]~2Z4 i3~ 5960 FEASIBILITY PLAN ...... . ........ ~OT ^PP~OVED FOR , X CUTiOU J __ '. ........ ,_ PLA_I~I ~ ~' z'~,._¢o , -- . _ .. J , _ , : .... : · g · · ' ,. ,,, . , l ~ ,, , ~._ IARf:'.~T I, N'I FI R&I']TIIq '.... ' , ! t, .::'. .......... J '_ ~ ., !-. .... ,.' :.-.'r 1 L , ·.. . :~ .,..>.... -[ .,, .:... ,.. G..~: :...~. ,.: .:-::'.-.' .y :.~:: . .c..~ ..... ...... . ,, ..... : ':'.-'-'?':'!:~ ~ ':' " '! I' " -: · ' '~i - -. -~ - :' -i -'.. t ' .. " "::"2' ' ' ~' '. · ;.-, :' 500 C; C ~N~DRILL ~NCHOR~GEE TEL:907-~9'8176 __ , -.~--..~,o-- ,~ ,.~._ ....... ,, ,-,, ,,-,, ,,--- .- .... .T.~- :[-33/M-2.3 ':(P.3)' , · VERTICAL sEC.T'.I:ON..:'VTEN .... o ........ .:- Sect'ion TVD'$~]e.' ~ ~nch = ~aO0 feet E j- ~ Oep'Sca]e,' ~ inch = ~00 feet ....................... ~m~-~z ~r-r~q ,Oraun ..... ' 07/07/95 · , ,- ..... ' '- Anaflri ]] Sch]umO. e~ger He~k~r Identt[lcaL~on ~ 8K~ ~CTN INCH '-' Al KB 0 0 0 O.OO B) ~ BUILD ~,5/fO0 300 3QO 0 o.oo C) ~ ~.5/~00 BUILD 600 ~0 ~ 4.50 .............. D) '~TART DROP ~/!00 600 600 8 4,50 ' E) E~ t/t00 DROP' J05O. lOd9 20 O,OO ~-~l r~-~ ................ F) KOP BUILD 2,5/t00 '1050 104g 20 0.00 G) END 2.5/i00 BU~LO 2469 .~37g 445 35..4B ~.; .......... ~ ..... H) ~ACEC~SINGPOINT '49. 440' 'B90 35,4B ~~~';)'~'''' ~ I) TARGET-lO0 Fl RADI~ i1914 1007i 5927 35,4B d) TO ....... : AS B ~'~ ................. N ,. p kL~ ,- .......... .......... ,,., ~ ~ ~ '~ ......................... - . .., . , .. . . _ _~_~_q ..... . :; ~ ~ ..... ~ ...... ~m~.~ n.~.~ ~"' ..... , ., ~~,?~ ~r .... , ~mmmmmmm~ ~ mm ...... . .......... ................. ~ ...... ........... ,.','.. ........,.. ~ ~ ....... . ~...,,....., .... - :: ..... =~ ........ - ..... ". .......... , . 0 BOO $~00 l~O 2400 ~000 ~BO0 d~O0 4BO0 ~400 ~00 e~O0 7~00 7BO0 Section 0~ ~anture ~m~"l:H ,lcJg) S33Na3e~ I~,S~ ~ )L~,,J). .......... ~"'~'"" ' ' ...... "' ' .....i :7~.: ',' "' ' ' ·" , '~ sly .... . .....~. ,~ .... '~:,,: . .... ~~ 4" ,,... ' ,. . WELL PERMIT CHECKLIST PROGRAM: exp [] dev~ redrll [] serv [] ADMINISTRATION Permit fee attached ................... y Lease number appropriate ............... N 3. Unique well name and number .............. N 4. Well located in a defined pool ............. N 5. Well located proper distance from drlg unit boundary.. N 6. Well located proper distance from other wells ..... N ' 7. Sufficient acreage available in drilling unit ..... N 8. If deviated, is wellbore plat included ........ N 9. Operator only affected party .............. N 10. Operator has appropriate bond in force ......... N 11. Permit can be issued without conservation order .... N 12. Permit can be issued without administrative approval.. N 13. Can permit be approved before 15-day wait ....... N ENGINEERING 14. Conductor string provided ............... ~ N 15. Surface casing protects all known USDWs ........ .~ N 16. CMT vol adequate to circulate on conductor & surf csg. N 17. CMT vol adequate to tie-in long string to surf csg . . . Y (N~ 18. CMT will cover all known productive horizons ...... ~ 19. Casing designs adequate for C, T, B & permafrost .... ~ N 20. Adequate tankage or reserve pit ............ .~ N 21. If a re-drill, has a 10-403 for abndnmnt been approved. ~-¥ ~ - 22. Adequate wellbore separation proposed .......... ~ N 23. If diverter required, is it adequate .......... ~ N 24. Drilling fluid program schematic & equip list adequate .~ N 25. BOPEs adequate ..................... ~y~ N 26. BOPE press rating adequate; test to _~-.~- psig.~)~ N 27. Choke manifold complies w/API RP-53 (May 84) ...... ,¥ ~ 28. Work will occur without operation shutdown ....... ~ N 29. Is presence of H2S gas probable ............ ~ N GEOLOGY 30. Permit can be issued w/o hydrogen sulfide measures .... Y 31' Seismic analysis 9f shallow gas zones ......... Data presented on potential overpressure zones ..... Y 32. / 33. Seabed condition survey (if off-shore) ........ / Y N ' ' - ' 34. Contact name/phone for weekly progress reports . . ./ . Y N [exploratory only] GEOLOGY: ENGINEERING: COMMYSSION: Comments/Instructions: Z W/~o - A:~ORMS~cheklist rev 03/94 WELL PERMIT CHECKLIST co~Y /--~//~-~ PROGRAM: exp [] dev~ redrll [] serv [] UNI~# ,/~ ~Cc3 ON/OFF S~O~ ~J ADMINISTRATION 1. Permit fee attached .................. 2. Lease number appropriate ............... 3. Unique well name and number .............. 4. Well located in a defined pool ............. 5. Well located proper distance from drlg unit boundary.. 6. Well located proper distance from other wells ..... '7. Sufficient acreage available in drilling unit ..... 8. If deviated, is wellbore plat included ........ 9. Operator only affected party .............. 10. Operator has appropriate bond in force ......... 11. Permit can be issued without conservation order .... 12. Permit can be issued without administrative approval.. 13. Can permit be approved before 15-day wait ....... REMARKS ENGINEERING , APPR DATE 14. Conductor string provided ............... ~ N 15. Surface casing protects all known USDWs ........ ~ N 16. CMT vol adequate to circulate on conduc%or & surf csg..~ N 17. CMT vol adequate to tie-in long string to surf csg . . . Y 18. CMT will cover all known productive horizons ...... ~ N 19. Casing designs adequate for C, T, B & permafrost .... ~ N 20. Adequate tankage or reserve pit ............. ~ N 21. If a re-drill, has a 10-403 for abndnmnt been approved. 22. Adequate wellbore separation proposed .......... ~ N 23. If diverter required, is it adequate .......... ~ N 24. Drilling fluid program schematic & equip llst adequate .~ N 25. BOPEs adequate ..................... ~ N 26. BOPE press rating adequate; test to ~~ psig.~ N 27. Choke manifold complies w/API RP-53 (May ~..' . . ~j N 28. Work will occur without operation shutdown ....... ~ N 29. Is presence of N2S gas probable ............ /.Y~ N GEOLOGY / 30. Permit can be issued w/o hydrogen sulfide measures .... Y N/ . 31. Data presented on potential overpressure zones. .... Y 32. Seismic analysis qf shallow gas zones .......... Y// N . 33. Seabed condlt~on survey (~f off-shore) ........ /Y N ' 34. Contact name/phone for weekly progress reports . . . ;/. Y N [ex~ploratory only] GEOLOGY: ENGINEERING: COMMISSION: Comments/Instructions: HOW/jo - A:',FORMS~cheklist rev 03/94 Well History File APPENDIX Information of detailed nature that is not particularly germane to the Well Permitting Process but is part of the history file. To improve the readability of the Well History file and to simplify finding information, information of this nature is accumulated at the end of the file under APPENDIX. No special effort has been made to chronologically organize this category of information. Tape Subfile 2 .is type: TAPE HEADER ENDICOTT UNIT OPEN HOLE WIRELINE LOGS WELL NAME: API NUMBER: OPERATOR: LOGGING COMPANY: TAPE CREATION DATE: JOB DATA JOB NUMBER: LOGGING ENGINEER: OPERATOR WITNESS: SURFACE LOCATION SECTION: TOWNSHIP: RANGE: FNL: FSL: FEL: FWL: ELEVATION(FT FROM MSL 0) KELLY BUSHING: DERRICK FLOOR: GROUND LEVEL: WELL CASING RECORD 1ST STRING 2ND STRING 3RD STRING PRODUCTION STRING RUN 1 6483.00 K. RICHARDS P. BARKER REMARKS: 1- 33/M- 23 500292257700 BP EXPLORATION (ALASKA) INC. WESTERN ATLAS LOGGING SERVICES 26-SEP-95 OPEN HOLE RUN 2 RUN 3 36 12N 16E 3217 2114 56.00 54.00 15.00 CASING DRILLERS BIT SIZE (IN) SIZE (IN) DEPTH (FT) 10.750 5013.0 9.875 12425.0 DIFL/ZDL/CN/GR. CIRCULATION STOPPED AT 0200 ON 20-SEP-95. DENSITY DATA QUESTIONABLE FROM TD TO 10320'. CORRECTION IS HIGH AND CALIPER IS SMALL. DENSITY PAD IS PROBABLY ON THE HIGH SIDE OF HOLE AND NOT MAKING CONTACT WITH THE FORMATION. PER CLIENT'S REQUEST, BOREHOLE & TORNADO CHART CORREC- TIONS WERE APPLIED TO THE DIL DATA. THE DIL DATA WAS CORRECTED FOR BOREHOLE SIZE (9.875"). THE CORRECTED DATA WAS THEN USED IN THE ATLAS TORNADO CHART TO GET "RT" & "DI" CURVES. RT = TRUE FORMATION RESISTIVITY. DI = DEPTH OF INVASION. NEUTRON LOG PARAMETERS: SANDSTONE MATRIX, CALIPER CORRECTED, CHISM FILTERING IS ACTIVE, CASING CORRECTIONS OFF, SALINITY = 0.00 PPM. FILE HEADER FILE NUMBER: 1 EDITED OPEN HOLE MAIN PASS All tool strings; depth shifted and clipped curves; hole data. DEPTH INCREMENT: .5000 FILE SUMMARY PBU TOOL CODE START DEPTH STOP DEPTH GR 5012.0 12354.0 DIL 5012.0 12413.0 SDN 5012.0 12379.0 2435 5012.0 12358.0 $ BASELINE CURVE FOR SHIFTS: GR CURVE SHIFT DATA (MEASURED DEPTH) EQUIVALENT UNSHIFTED DEPTH BASELINE DEPTH LL8 ILD RHOB NPHI 5034.0 5104.0 5138.0 5138.0 5138.0 5178.0 5178.0 5178.0 5179.0 5187.0 5186.5 5186.5 5197.0 5197.0 5208.5 5208.5 5208.5 5224.5 5224.5 5228.5 5228.0 5228.0 11590.5 11589.5 11591.0 11589.0 11644.5 11644.0 11673.0 11672.0 11672.0 11676.5 11676.0 11676.0 11677.0 11677.0 11679.5 11679.0 11680.0 11680.0 11680.5 11680.0 11686.5 11685.0 11692.5 11692.5 11692.5 11696.0 11696.5 11696.5 11700.5 11700.0 11700.0 11701.0 11706.0 11705.0 11713.5 11712.5 11717.0 11717.0 11717.0 11716.5 11725.0 11726.0 11725.0 11728.5 11729.0 11729.0 11727.5 11733.5 11733.5 11733.5 11732.5 11744.0 11742.5 11747.0 11746.5 11749.5 11750.0 11749.0 11749.5 11750.5 11752.5 11762.0 11760.5 11762.5 11761.5 11761.5 11773.0 11773.0 11773.0 11773.5 11772.0 all runs merged; 5034.5 5034.5 5103.5 5103.5 5138.0 5138.0 5179.5 5186.5 5197.0 5224.5 11644.0 11677.0 11680.5 11692.5 11696.5 11701.0 11705.0 11712.5 11717.5 11725.0 11727.5 11732.5 11746.5 11749.0 11753.0 11762.0 11773.5 no case 11776.0 11776.5 11814.5 11817.0 11817.5 11836.5 11837.0 11846.0 11847.0 11887.5 11888.0 11902.5 11907.5 11926.5 11927.0 11927.5 11930.0 11934.0 11940.0 11940.5 11952.0 11960.0 11960.5 11962.5 11966.5 11967.0 11980.5 11985.5 11990.5 11998.5 12000.5 12006.0 12032.5 12040.5 12041.0 12044.5 12048.0 12056.0 12058.5 12064.5 12071.5 12082.5 12107.5 12108.0 12135.0 12148.0 12150.5 12151.5 12167.5 12171.0 12186.0 12199.5 12249.0 12249.5 12254.5 12256.0 12259.5 12274.0 12274.5 12275.0 11776.0 11815.0 11835.5 11845.5 11886.5 11931.5 11941.5 11961.0 11963.0 11980.0 11985.5 11998.0 12006.0 12032.5 12040.5 12044.5 12064.0 12108.0 12151.5 12171.0 12249.0 11776.0 11815.0 11835.5 11845.5 11886.5 11928.0 11934.5 11941.5 11961.0 11963.0 11980.0 11985.5 11999.5 12006.0 12033.0 12040.5 12044.5 12064.0 12107.0 12151.5 12171.0 12249.0 12274.5 11775.0 11814.0 11816.5 11835.5 11845.5 11887.0 11902.0 11907.5 11924.5 11933.0 11951.5 11966.5 12031.5 12040.0 12048.0 12056.0 12058.5 12071.0 12082.5 12107.0 12135.0 12147.0 12150.5 12167.5 12186.5 12198.5 12254.5 12259.0 12274.5 11814.0 11817.5 11836.5 11845.5 11888.0 11902.0 11907.5 11927.5 11930.5 11933.5 11938.5 11951.5 11960.0 11967.5 11990.5 11999.0 12006.5 12032.5 12056.0 12058.5 12071.0 12082.5 12107.0 12135.0 12147.0 12151.0 12167.5 12186.5 12198.5 12248.5 12255.0 12259.0 12273.5 12283.0 12286.5 12289.0 12289.5 12297.5 12300.0 12305.5 12310.0 12312.5 12315.0 12319.0 12321.0 12325.0 12342.0 12343.5 12344.0 12376.0 12393.0 $ MERGED DATA SOURCE PBU TOOL CODE GR GR DIL DIL SDN SDN 2435 2435 $ REMARKS: 122~3.5 12283.5 12287.5 12287.5 12291.0 12291.0 12298.5 12298.5 12311.0 12311.0 12322.0 12322.0 12325.5 12325.5 12342.0 12376.5 12394.5 12288.5 12288.5 12299.0 12299.0 12305.5 12305.5 12309.5 12313.5 12316.0 12319.0 12319.0 12343.0 12345.0 RUN NO. PASS NO. MERGE TOP MERGE BASE 1 5 5012.0 5236.0 1 2 11512.0 12354.0 1 5 5012.0 5296.0 1 2 11572.0 12413.0 1 5 5012.0 5260.0 1 2 11538.0 12379.0 1 5 5012.0 5238.0 1 2 11578.0 12358.0 OPEN HOLE MAIN PASS. THE OPEN HOLE PORTION OF THE CASING PASS WAS SPLICED ONTO THE MAIN PASS. NOTE THERE IS A LARGE DATA GAP BETWEEN THESE 2 INTERVALS. MTEM, SP, TEND, & TENS WERE SHIFTED WITH LL8. ILM, RT, & DI WERE SHIFTED WITH ILD. DRHO, PEF, & CALl WERE SHIFTED WITH RHOB. FUCT & NUCT WERE SHIFTED WITH NPHI. / ? ?MATCH1. OUT /??MATCH2.OUT / ? ?MATCH3. OUT /??MATCH4.OUT $ CN : BP EXPLORATION WN : 1 - 33/M - 23 FN : ENDICOTT COUN : NORTH SLOPE STAT : ALASKA * FORMAT RECORD (TYPE# 64) ONE DEPTH PER FRAME (ALASKA) Tape depth ID: F 17 Curves: Name Tool Code Samples Units API API API API Log Crv Crv Size Length Typ Typ Cls Mod 1 GR DIL 68 1 GAPI 4 2 LL8 DIL 68 1 OHMM 4 3 ILM DIL 68 1 OHMM 4 4 ILD DIL 68 1 OHMM 4 5 RT DIL 68 1 OHMM 4 6 DI DIL 68 1 IN 4 7 SP DIL 68 1 MV 4 8 MTEM DIL 68 1 DEGF 4 9 TEND DIL 68 1 LB 4 10 TENS DIL 68 1 LB 4 11 RHOB SDN 68 1 G/C3 4 12 DRHO SDN 68 1 G/C3 4 13 PEF SDN 68 1 BN/E 4 14 CALl SDN 68 1 IN 4 15 NPHI 2435 68 1 PU-S 4 16 FUCT 2435 68 1 CPS 4 17 NUCT 2435 68 1 CPS 4 4 08 310 01 1 4 08 995 99 1 4 08 995 99 1 4 08 995 99 1 4 08 995 99 1 4 08 995 99 1 4 08 995 99 1 4 08 995 99 1 4 08 995 99 1 4 08 995 99 1 4 49 995 99 1 4 49 995 99 1 4 49 995 99 1 4 49 995 99 1 4 43 995 99 1 4 43 995 99 1 4 43 995 99 1 68 * DATA RECORD (TYPE# 0) 1014 BYTES * Total Data Records: 1060 Tape File Start Depth = 12427.000000 Tape File End Depth = 5012.000000 Tape File Level Spacing = 0.500000 Tape File Depth Units = Feet **** FILE TRAILER **** LIS representation code decoding summary: Rep Code: 68 266959 datums Tape Subfile: 2 1292 records... Minimum record length: Maximum record length: 62 bytes 1014 bytes Tape Subfile 3 is type: LIS FILE HEADER FILE NUMBER: 2 EDITED CASED HOLE MAIN PASS Depth shifted and clipped curves for open hole logs run into casing. PASS NUMBER: 5 DEPTH INCREMENT: .5000 FILE S~RY PBU TOOL CODE START DEPTH STOP DEPTH GRCH 4827.0 5012.0 2435 4892.0 5012.0 $ BASELINE CURVE FOR SHIFTS: CURVE SHIFT DATA (MEASURED DEPTH) EQUIVALENT UNSHIFTED DEPTH BASELINE DEPTH $ REMARKS: CASED HOLE PORTION OF CASING PASS. DUE TO THE SHORT INTERVAL NO DEPTH SHIFTING WAS DONE. CN WN FN COUN STAT : BP EXPLORATION (ALASKA) : 1 - 33/M- 23 : ENDICOTT : NORTH SLOPE : ALASKA * FORMAT RECORD (TYPE# 64) ONE DEPTH PER FRAME Tape depth ID: F 6 Curves: Name Tool Code Samples Units API API API API Log Crv Crv Size Length Typ Typ Cls Mod 1 GRCH 2435 68 1 GAPI 4 2 NPHI 2435 68 1 PU-S 4 3 FUCT 2435 68 1 CPS 4 4 NUCT 2435 68 1 CPS 4 5 TEND 2435 68 1 LB 4 6 TENS 2435 68 1 LB 4 4 43 310 01 1 4 43 890 01 1 4 43 334 31 1 4 43 334 30 1 4 43 635 99 1 4 43 635 99 1 24 * DATA RECORD (TYPE# 0) 1014 BYTES * Total Data Records: 11 Tape File'Start DepnR = 5012.000000 Tape File End Depth = 4819.000000 Tape File Level Spacing = 0.500000 Tape File Depth Units = Feet **** FILE TRAILER **** LIS representation code decoding summary: Rep Code: 68 2710 datums Tape Subfile: 3 40 records... Minimum record length: 62 bytes Maximum record length: 1014 bytes Tape Subfile 4 is type: LIS FILE HEADER FILE NUMBER: 3 RAW OPEN HOLE MAIN PASS Curves and log header data for each run and tool string in separate files; Tool String #1 for Sadlerochit run presented first (primary depth control string used to depth shift the Sadlerochit interval) followed by files for other main pass tool strings per run. RUN NUMBER: 1 TOOL STRING NUMBER: 1 PASS NUMBER: 2 DEPTH INCREMENT: .2500 FILE SUMMARY VENDOR TOOL CODE START DEPTH GR 11512.0 DIFL 11567.0 ZDL 11537.5 2435 11518.0 $ LOG HEADER DATA DATE LOGGED: SOFTWARE VERSION: TIME CIRCULATION ENDED: TIME LOGGER ON BOTTOM: TD DRILLER (FT): TD LOGGER (FT): TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT) : LOGGING SPEED (FPHR): TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE CHT CABLEHEAD TENSION MODL MODAL SUB GR GAMMA RAY CN COMPENSATED NEUTRON ZDL Z-DENSITY KNJT KNUCKLE JOINT KNJT KNUCKLE JOINT TEMP TEMPERATURE PCM PULSE CODE MODULATOR DIFL DUAL INDUCTION $ BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE(IN): DRILLER'S CASING DEPTH (FT): LOGGER'S CASING DEPTH (FT): BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S) : MUD PH: FLUID LOSS (C3): MAXIMUM RECORDED TEMPERATURE (DEGF): STOP DEPTH 12356.5 12417.0 12380.5 12363.0 20-SEP-95 FSYS REV. J001 VER. 1.1 200 20-SEP-95 921 20-SEP-95 12425.0 12420.0 11550.0 12417.0 1500.0 TOOL NUMBER 3974XA 3517XA 1309XA 2435XA 2222EA/2222MB 3921XA 3921XA 2806XA 3506XA 1503XA 9.875 5013.0 5012.0 LSND 10.70 53.O 9.6 3.9 178.0 RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT BOTTOM HOLE TEMPERATURE (BHT): MUD FILTRATE AT MT: MUD FILTRATE AT BHT: MUD CAKE AT MT: MUD CAKE AT BHT: NEUTRON TOOL TOOL TYPE (EPITHERMAL OR THERMAL): MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN) : REMARKS: MAIN PASS. $ CN WN FN COUN STAT : BP EXPLORATION (ALASKA) : 1- 33/M- 23 : ENDICOTT : NORTH SLOPE : ALASKA .280 .104 .820 .000 1.200 .000 THERMAL SANDSTONE .00 .000 1.5 62.0 178.0 62.0 .0 62.0 .0 * FORMAT RECORD (TYPE# 64) ONE DEPTH PER FRAME Tape depth ID: F 21 Curves: Name Tool Code Samples Units API API API API Log Crv Crv Size Length Typ Typ Cls Mod 1 2 3 4 5 6 7 8 9 10 11 12 13 14 15 16 17 18 19 2O 21 GR DIFL 68 1 GAPI RFOC DIFL 68 1 OHMM RILM DIFL 68 1 OHMM RILD DIFL 68 1 OHMM VILD DIFL 68 1 MV RT DIFL 68 1 OHMM DI DIFL 68 1 IN SP DIFL 68 1 MV TEMP DIFL 68 1 DEGF CHT DIFL 68 1 LB TTEN DIFL 68 1 LB SPD DIFL 68 1 F/MN ZDEN ZDL 68 1 G/C3 ZCOR ZDL 68 1 G/C3 PE ZDL 68 1 BN/E CAL ZDL 68 1 IN CNC 2435 68 1 PU-S CNCF 2435 68 1 PU-S CN 2435 68 1 PU-L LSN 2435 68 1 CPS SSN 2435 68 1 CPS 4 07 310 01 1 4 07 220 06 1 4 07 120 44 1 4 07 120 46 1 4 07 995 46 1 4 07 120 46 1 4 07 120 44 1 4 07 010 01 1 4 07 660 99 1 4 07 635 99 1 4 07 635 99 1 4 07 636 99 1 4 46 350 01 1 4 46 356 99 1 4 46 358 01 1 4 46 280 99 1 4 43 995 99 1 4 43 995 99 1 4 43 890 01 1 4 43 334 31 1 4 43 334 30 1 84 * DATA RECORD (TYPE# 0) Total Data Records: 335 974 BYTES * Tape File Start Depth = 12427.000000 Tape File End Depth = 11507.000000 Tape File Level Spacing = 0.250000 Tape File Depth Units = Feet **** FILE TRAILER **** LIS representation code decoding summary: Rep Code: 68 347942 datums Tape Subfile: 4 416 records... Minimum record length: Maximum record length: 62 bytes 974 bytes Tape Subfile 5 is type: LIS FILE HEADER FILE NUMBER: 4 RAW OPEN HOLE REPEAT PASSES Curves and log header data for each pass, tool string, and run in separate files. RUN NUMBER: 1 TOOL STRING NUMBER: 1 PASS NUMBER: 3 DEPTH INCREMENT: .2500 FILE SUMMARY VENDOR TOOL CODE START DEPTH GR 11856.0 DIFL 11911.0 ZDL 11881.0 2435 11922.0 $ LOG HEADER DATA DATE LOGGED: SOFTWARE VERSION: TIME CIRCULATION ENDED: TIME LOGGER ON BOTTOM: TD DRILLER (FT): TD LOGGER (FT): TOP LOG INTERVAL (FT) : BOTTOM LOG INTERVAL (FT) : LOGGING SPEED (FPHR): TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE CHT CABLEHEAD TENSION MODL MODAL SUB GR GAMMA RAY CN COMPENSATED NEUTRON ZDL Z-DENSITY KNJT KNUCKLE JOINT KNJT KNUCKLE JOINT TEMP TEMPERATURE PCM PULSE CODE MODULATOR DIFL DUAL INDUCTION $ BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE(IN): DRILLER'S CASING DEPTH (FT): LOGGER'S CASING DEPTH (FT): BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: FLUID LOSS (C3) : MAXIMUM RECORDED TEMPERATURE (DEGF): RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): STOP DEPTH 12252.0 12312.0 12276.0 12254.0 20-SEP-95 FSYS REV. J001 VER. 1.1 200 20-SEP-95 1024 20-SEP-95 12425.0 12420.0 11550.0 12417.0 1500.0 TOOL NUMBER 3974XA 3517XA 1309XA 2435XA 2222EA/2222MB 3921XA 3921XA 2806XA 3506XA 1503XA 9.875 5013.0 5012.0 LSND 10.70 53.0 9.6 3.9 178.0 .280 62.0 MUD AT BOTTOM huLE TEMPERATURE (BHT): MUD FILTRATE AT MT: MUD FILTRATE AT BHT: MUD CAKE AT MT: MUD CAKE AT BHT: NEUTRON TOOL TOOL TYPE (EPITHERMAL OR THERMAL): MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): REMARKS: REPEAT PASS. $ CN WN FN COUN STAT : BP EXPLORATION (ALASKA) : 1 - 33/M- 23 : ENDICOTT : NORTH SLOPE : ALASKA .±04 .820 .000 1.200 .000 THERMAL SANDSTONE .00 .000 1.5 178.0 62.0 .0 62.0 .0 * FORMAT RECORD (TYPE# 64) ONE DEPTH PER FRAME Tape depth ID: F 21 Curves: Name Tool Code Samples Units API API API API Log Crv Crv Size Length Typ Typ Cls Mod 1 GR DIFL 68 1 GAPI 4 2 RFOC DIFL 68 1 OHMM 4 3 RILM DIFL 68 1 OHMM 4 4 RILD DIFL 68 1 OHMM 4 5 VILD DIFL 68 1 MV 4 6 RT DIFL 68 1 OHMM 4 7 DI DIFL 68 1 IN 4 8 SP DIFL 68 1 MV 4 9 TEMP DIFL 68 1 DEGF 4 10 CHT DIFL 68 1 LB 4 11 TTEN DIFL 68 1 LB 4 12 SPD DIFL 68 1 F/MN 4 13 ZDEN ZDL 68 1 G/C3 4 14 ZCOR ZDL 68 1 G/C3 4 15 PE ZDL 68 1 BN/E 4 16 CAL ZDL 68 1 IN 4 17 CNC 2435 68 1 PU-S 4 18 CNCF 2435 68 1 PU-S 4 19 CN 2435 68 1 PU-L 4 20 LSN 2435 68 1 CPS 4 21 SSN 2435 68 1 CPS 4 4 07 310 01 1 4 07 220 06 1 4 07 120 44 1 4 07 120 46 1 4 07 995 46 1 4 07 120 46 1 4 07 120 44 1 4 07 010 01 1 4 07 660 99 1 4 07 635 99 1 4 07 635 99 1 4 07 636 99 1 4 46 350 01 1 4 46 356 99 1 4 46 358 01 1 4 46 280 99 1 4 43 995 99 1 4 43 995 99 1 4 43 890 01 1 4 43 334 31 1 4 43 334 30 1 84 * DATA RECORD (TYPE# 0) 974 BYTES * Total Data Records: 172 Tape File Start Depth = 12322.000000 Tape File End Depth = 11850.000000 Tape File Level Spacing = 0.250000 Tape File Depth Units = Feet **** FILE TRAILER **** LIS representation code decoding summary: Rep Code: 68 44269 datums Tape Subfile: 5 251 records... Minimum record length: Maximum record length: 62 bytes 974 bytes Tape Subfile 6 is type: LIS FILE HEADER FILE NUMBER: 5 RAW CASED HOLE MAIN PASS Curves and log header data for open hole logs run into casing. PASS NUMBER: 5 DEPTH INCREMENT: .2500 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH GR 4827.0 5236.5 DIL 4885.0 5297.0 ZDL 4852.0 5260.5 2435 4892.0 5238.5 $ LOG HEADER DATA DATE LOGGED: SOFTWARE VERSION: TIME CIRCULATION ENDED: TIME LOGGER ON BOTTOM: TD DRILLER (FT): TD LOGGER (FT): TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): LOGGING SPEED (FPHR) : 20-SEP-95 FSYS REV. J001 VER. 1.1 200 20-SEP-95 1129 20-SEP-95 12425.0 12420.0 4850.0 12417.0 1500.0 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE CHT MODL GR CN ZDL KNJT KNJT TEMP PCM DIFL $ CABLEHEAD TENSION MODAL SUB GAMMA RAY COMPENSATED NEUTRON Z-DENSITY KNUCKLE JOINT KNUCKLE JOINT TEMPERATURE PULSE CODE MODULATOR DUAL INDUCTION TOOL NUMBER 3974XA 3517XA 1309XA 2435XA 2222EA/2222MB 3921XA 3921XA 2806XA 3506XA 1503XA BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE(IN): DRILLER'S CASING DEPTH (FT): LOGGER'S CASING DEPTH (FT): 9.875 5013.0 5012.0 BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: FLUID LOSS (C3): MAXIMUM RECORDED TEMPERATURE (DEGF): RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT BOTTOM HOLE TEMPERATURE (BHT): MUD FILTRATE AT MT: MUD FILTRATE AT BHT: LSND 10.70 53.0 9.6 3.9 178.0 .280 · 104 .820 .000 62.0 178.0 62.0 .0 MUD CAKE AT MT: MUD CAKE AT BHT: NEUTRON TOOL TOOL TYPE (EPITHERMAL OR THERMAL): MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN) : REMARKS: CASING PASS. $ CN WN FN COUN STAT : BP EXPLORATION (ALASKA) : 1 - 33/M - 23 : ENDICOTT : NORTH SLOPE : ALASKA 1.~00 .000 THERMAL SANDSTONE .00 .000 1.5 62.0 .0 * FORMAT RECORD (TYPE# 64) ONE DEPTH PER FRAME Tape depth ID: F 21 Curves: Name Tool Code Samples Units API API API API Log Crv Crv Size Length Typ Typ Cls Mod 1 GR DIFL 68 1 GAPI 4 2 RFOC DIFL 68 1 OHMM 4 3 RILM DIFL 68 1 OHMM 4 4 RILD DIFL 68 1 OHMM 4 5 VILD DIFL 68 1 MV 4 6 RT DIFL 68 1 OHMM 4 7 DI DIFL 68 1 IN 4 8 SP DIFL 68 1 MV 4 9 TEMP DIFL 68 1 DEGF 4 10 CHT DIFL 68 1 LB 4 11 TTEN DIFL 68 1 LB 4 12 SPD DIFL 68 1 F/MN 4 13 ZDEN ZDL 68 1 G/C3 4 14 ZCOR ZDL 68 1 G/C3 4 15 PE ZDL 68 1 BN/E 4 16 CAL ZDL 68 1 IN 4 17 CNC 2435 68 1 PU-S 4 18 CNCF 2435 68 1 PU-S 4 19 CN 2435 68 1 PU-L 4 20 LSN 2435 68 1 CPS 4 21 SSN 2435 68 1 CPS 4 4 07 310 01 1 4 07 220 06 1 4 07 120 44 1 4 07 120 46 1 4 07 995 46 1 4 07 120 46 1 4 07 120 44 1 4 07 010 01 1 4 07 660 99 1 4 07 635 99 1 4 07 635 99 1 4 07 636 99 1 4 46 350 01 1 4 46 356 99 1 4 46 358 01 1 4 46 280 99 1 4 43 995 99 1 4 43 995 99 1 4 43 890 01 1 4 43 334 31 1 4 43 334 30 1 84 * DATA RECORD (TYPE~ 0) 974 BYTES * Total Data Records: 178 Tape File Start Depth = 5307.000000 Tape File End Depth = 4819.000000 Tape File Level Spacing = 0.250000 Tape File Depth Units = Feet **** FILE TRAILER **** LIS representation code decoding summary: Rep Code: 68 390909 datums Tape Subfile: 6 254 records... Minimum record length: Maximum record length: 62 bytes 974 bytes Tape Subfile 7 is type: LIS 95/ 9/26 01 **** REEL TRAILER **** 95/ 9/27 01 Tape Subfile: 7 2 records... Minimum record length: 132 bytes Maximum record length: 132 bytes End of execution: Wed 27 SEP 95 2:01p Elapsed execution time = 6.16 seconds. SYSTEM RETURN CODE = 0 COMPANY NAME : BP EXPLORATION WELL NAME : 1-33/M-23 FIELD NAME : ENDICOTT BOROUGH : NORTH SLOPE STATE : ALASKA API NUMBER : 500292257700 REFERENCE NO : 97396 Date-~~~ LIS Tape Verification Listing Schlumberger Alaska Computing Center 5-SEP-1997 13:04 PAGE: **** REEL HEADER **** SERVICE NA~E : EDIT DATE : 97/09/ 5 ORIGIN ' FLIC REEL NAbfE : 97396 CONTINUATION # : PREVIOUS REEL : COf4~ENT . BP EXPLORATION, 1-33/M-23, ENDICOTT, 50-029-22577-00 **** TAPE HEADER **** SERVICE NAM~ : EDIT DATE : 97/09/ 5 ORIGIN : FLIC TAPE NAME : 97396 CONTINUATION # : 1 PREVIOUS TAPE : COf~Ff : BP EXPLORATION, 1-33/M-23, ENDICOTT, 50-029-22577-00 TAPE HEADER ENDICOTT CASED HOLE WIRELINE LOGS WELL NABiE : 1-33/M-23 API NU~4~ER: 500292257700 OPERATOR: BP EXPLORATION LOGGING COMPANY: SCHLUMBERGER WELL SERVICES TAPE CREATION DATE: 4-SEP-97 JOB ~ER: 97396 LOGGING ENGINEER: J. PAWLUK OPERATOR WITNESS: B. CLUMP SURFACE LOCATION SECTION: 3 6 TOWNSHIP: 12N RANGE: 16E FNL: FSL: 3217 FEL: 2114 FWL: ELEVATION (FT FROM MSL O) KELLY BUSHING: 56. O0 DERRICK FLOOR: 54. O0 GROUND LEVEL: 15. O0 WELL CASING RECORD OPEN HOLE CASING DRILLERS CASING BIT SIZE (IN) SIZE (IN) DEPTH (FT) WEIGHT (LB/FT) 1ST STRING 10. 750 5013.0 45.50 2ND STRING 7. 625 12404.0 29.70 3RD STRING 4. 500 11188.0 12.60 PRODUCTION STRING CURVE SHIFT DATA - ALL PASSES TO STANDARD(MEASURED DEPTH) LIS Tape Verification Listing Schlumberger Alaska Computing Center 5-SEP-1997 13:04 BASELINE CURVE FOR SHIFTS LDWG TOOL CODE: DIL LDWG CURVE CODE: GR RUN NUMBER: PASS NUMBER: DATE LOGGED: 20 -SEP- 95 LOGGING COMPANY: WESTERN ATLAS BASELINE DEPTH 88888.O 12283.5 12276.0 12266.0 12263.0 12259.0 12255.0 12250.5 12245.0 12238.0 12233.5 12219.5 12219.0 12207.5 12207.0 12199.0 12198.5 12186.0 12185.0 12172.0 12170.5 12170.0 12167.5 12167.0 12163.5 12156.0 12150.5 12148.5 12148.0 12147.0 12146.5 12143.0 12133.5 12131.0 12125.5 12115.0 12108.5 12107.0 12088.5 12087.5 12081.0 12073.0 12071.0 12070.5 12063.0 .......... EQUIVALENT UNSHIFTED DEPTH .......... GRCH SIGM 88887.0 88886.0 12254.0 12249.5 12244.5 12233.0 12219.5 12208.0 12199.0 12185.5 12173.0 12171.0 12167.5 12164.5 12155.0 12151.0 12149.0 12147.5 12143.0 12135.0 12132.5 12125.5 12115.0 12107.5 12090.5 12089.0 12082.5 12074.0 12071.5 12281.5 12273.5 12264.0 12262.5 12257.5 12249.5 12236.0 12219.0 12208.0 12199.0 12185.5 12171.0 12167.5 12151.0 12149.0 12147.5 12107.5 12071.5 12064.5 PAGE: LIS Tape Verification Listing Schlumberger Alaska Computing Center 12062.0 12063.0 12057.0 12058.5 12055.0 12056.0 12054.5 12056.0 12047.5 12048.5 12047.0 12048.5 12042.5 12043.5 12039.0 12040.5 12040.5 12031.5 12033.0 12033.0 12018.5 12020.5 12005.0 12006.0 12004.5 12006.0 11997.5 11998.0 11997.0 11998.0 11995.5 11996.5 11990.0 11990.5 11989.0 11990.5 11979.5 11980.0 11975.0 11975.5 11973.5 11973.5 11971.5 11973.5 11966.0 11966.0 11965.5 11966.0 11962.5 11962.0 11962.5 11960.5 11960.5 11960.0 11960.0 11956.5 11957.0 11955.0 11954.5 11952.0 11951.5 11938.5 11939.0 11937.0 11938.0 11934.0 11934.0 11933.5 11934.5 11930.5 11930.0 11930.0 11929.5 11927.5 11927.5 11927.0 11927.5 11915.5 11916.5 11912.0 11913.5 11909.0 11910.5 11907.5 11908.0 11887.0 11888.0 11887.5 11874.0 11875.0 11865.0 11866.0 11845.0 11846.5 11846.5 11836.0 11837.0 11835.5 11837.0 11826.0 11827.0 11825.5 11827.0 11817.0 11817.5 11816.5 11817.5 11814.0 11814.5 11808.5 11809.0 11808.0 11809.0 11793.5 11794.5 11794.5 11776.5 11776.0 5-SEP-1997 13:04 PAGE: LIS Tape Verification Listing Schlumberger Alaska Computing Center 5-SEP-1997 13:04 11774.0 11773.5 11770.5 11769.0 11767.0 11766.0 11762.0 11762.0 11762.0 11758.5 11757.0 11757.5 11757.0 11754.0 11752.0 11752.5 11752.0 11751.0 11750.0 11750.5 11750.0 11745.5 11744.0 11736.0 11735.0 11735.0 11733.0 11734.5 11733.0 11732.0 11730.0 11730.5 11728.5 11727.0 11725.5 11721.5 11719.5 11719.0 11717.0 11718.5 11716.5 11714.0 11713.5 11713.5 11707.0 11704.0 11706.5 11704.0 11703.0 11701.0 11697.5 11695.5 11695.5 11694.0 11692.0 11693.5 11692.0 11688.5 11687.0 11688.0 11687.0 11681.5 11680.0 11681.0 11679.5 11677.5 11676.5 11676.5 11675.0 11673 . 5 11674.5 11673.5 11672.0 11669.5 11669.0 11668.0 11667.5 100.0 99.0 98.5 $ CONTAINED HEREIN IS THE TDTP DATA ACQUIRED ON BP EXPLORATION WELL 1-33/M-23. THE DEPTH SHIFTS SHOWN ABOVE REFLECT BASELINE PASS #1 GRCH TO GR.DIL; AND BASELINE PASS #1 SIGM TO GR.DIL. ALL OTHER TDTP CURVES WERE CARRIED WITH THE SIGM SHIFT. $ $ PAGE: **** FILE HEADER **** FILE NA~iE : EDIT .001 SERVICE : FLIC VERSION ' O01CO1 DATE : 97/09/ 5 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : LIS Tape Verification Listing Schlumberger Alaska Computing Center 5-SEP-1997 13: 04 PAGE: FILE HEADER FILE NUPiBER : 1 EDITED CURVES Depth shifted and clipped curves for each pass in separate files. PASS NUMBER: 1 DEPTH INCREb!ENT : O . 5000 FILE SUFEqARY LDWG TOOL CODE START DEPTH STOP DEPTH GRCH 12261 . 0 11660.0 TDTP 12286.0 11660.0 $ CURVE SHIFT DATA - PASS TO PASS (MEASURED DEPTH) BASELINE CURVE FOR SHIFTS LDWG CURVE CODE: PASS NUMBER: BASELINE DEPTH .......... EQUIVALENT UNSHIFTEDDEPTH .......... GRCH TDTP REMARKS: THIS FILE CONTAINS TDTP BASELINE PASS #1. NO PASS TO PASS SHIFTS WERE APPLIED TO THIS DATA. $ LIS FORMAT DATA ** DATA FORMAT SPECIFICATION RECORD ** ** SET TYPE- 64EB ** TYPE REPR CODE VALUE 1 66 0 2 66 0 3 73 88 4 66 1 5 66 6 73 7 65 8 68 0.5 9 65 FT 11 66 11 12 68 13 66 0 14 65 FT 15 66 68 16 66 1 0 66 0 LIS Tape Verification Listing Schlumberger Alaska Computing Center 5-SEP-1997 13: 04 PAGE: ** SET TYPE - CHAN ** NAME SERV UNIT SERVICE API API API API FILE NUMB NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUMB SAMP ELEM CODE (HEX) DEPT FT 1088189 O0 000 O0 0 1 1 1 4 68 SIGMTDTP CU 1088189 O0 000 O0 0 1 1 1 4 68 TPHI TDTP PU-S 1088189 O0 000 O0 0 1 1 1 4 68 SBHF TDTP CU 1088189 O0 000 O0 0 1 1 1 4 68 SBHN TDTP CU 1088189 O0 000 O0 0 1 1 1 4 68 SIGC TDTP CU 1088189 O0 000 00 0 1 1 1 4 68 SIBH TDTP CU 1088189 O0 000 O0 0 1 1 1 4 68 TRAT TDTP 1088189 O0 000 O0 0 1 1 1 4 68 SDSI TDTP CU 1088189 O0 000 O0 0 1 1 1 4 68 BACK TDTP CPS 1088189 O0 000 O0 0 1 1 1 4 68 FBAC TDTP CPS 1088189 O0 000 O0 0 1 1 1 4 68 TCAN TDTP CPS 1088189 O0 000 O0 0 1 1 1 4 68 TCAF TDTP CPS 1088189 O0 000 O0 0 1 1 1 4 68 TCND TDTP CPS 1088189 O0 000 O0 0 1 1 1 4 68 TCFD TDTP CPS 1088189 O0 000 O0 0 1 1 1 4 68 TSCNTDTP CPS 1088189 O0 000 O0 0 1 1 1 4 68 TSCF TDTP CPS 1088189 O0 000 O0 0 1 1 1 4 68 INND TDTP CPS 1088189 O0 000 O0 0 1 1 1 4 68 INFD TDTP CPS 1088189 O0 000 O0 0 1 1 1 4 68 GRCH TDTP GAPI 1088189 O0 000 O0 0 1 1 1 4 68 TENS TDTP LB 1088189 O0 000 O0 0 1 1 1 4 68 CCL TDTP V 1088189 O0 000 O0 0 1 1 1 4 68 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 ** DATA ** DEPT. 12284. 000 SIGM. TDTP 19.133 TPHI. TDTP 40. 988 SBHF. TDTP SBI~N. TDTP 85.516 SIGC. TDTP 0 . 380 SIBH. TDTP 140. 185 TRAT. TDTP SDSI. TDTP 0.359 BACK. TDTP 104.515 FBAC. TDTP 25.135 TCAN. TDTP TCAF. TDTP 12583 . 152 TCND. TDTP 17219. 852 TCFD. TDTP 5162. 728 TSCN. TDTP TSCF. TDTP 1402. 476 INND. TDTP 2153. 340 INFD. TDTP 327. 879 GRCH. TDTP TENS. TDTP 1680. 000 CCL. TDTP O. 000 DEPT. 11658. 500 SIGM. TDTP 36. 714 TPHI. TDTP 53. 894 SBHF. TDTP SBPiN. TDTP 54. 226 SIGC. TDTP 2. 341 SIBH. TDTP 69. 203 TRAT. TDTP SDSI. TDTP O. 995 BACK. TDTP 153. 449 FBAC. TDTP 31. 605 TCAN. TDTP TCAF. TDTP 9295. 332 TCND. TDTP 16477.910 TCFD. TDTP 4281. 802 TSCN. TDTP TSCF. TDTP 553.605 INND. TDTP 1739.497 INFD. TDTP 304.802 GRCH. TDTP TENS. TDTP 1640. 000 CCL. TDTP O . 000 78.311 1.859 32774.539 3652.941 -999.250 46.601 1.664 31471.230 1754.113 -999.250 ** END OF DATA ** LIS Tape Verification Listing Schlumberger Alaska Computing Center 5-SEP-1997 13:04 PAGE: **** FILE TRAILER **** FILE NAM~ : EDIT .001 SERVICE : FLIC VERSION : O01CO1 DATE : 97/09/ 5 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : **** FILE HEADER **** FILE NA~E : EDIT .002 SERVICE : FLIC VERSION : O01CO1 DATE : 97/09/ 5 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE FILE HEADER FILENUFi~ER: 2 EDITED CURVES Depth shifted and clipped curves for each pass in separate files. PASSNUMBER: 2 DEPTH INCREMENT: 0.5000 FILE SUMMARY LDWG TOOL CODE START DEPTH STOP DEPTH GRCH 12261.0 11660.0 TDTP 12286.0 11660.0 $ CURVE SHIFT DATA - PASS TO PASS (f~EASURED DEPTH) BASELINE CURVE FOR SHIFTS LDWG CURVE CODE: GRCH PASS NUM~ER: 1 .......... EQUIVALENT UNSHIFTEDDEPTH .......... BASELINE DEPTH GRCH TDTP 88888.0 88887.5 88885.5 12276.5 12274.0 12273.5 12271.5 12265.5 12264.0 12263.5 12262.5 12255.0 12254.5 12251.5 12249.5 12250.0 12249.0 12238.5 12236.0 12234.0 12234.0 12233.0 12227.0 12227.5 LIS Tape Verification Listing Schlumberger Alaska Computing Center 5-SEP-1997 13:04 PAGE: 12220.0 12219.5 12213.0 12213.5 12198.5 12198.5 12198.0 12198.5 12186.0 12185.5 12172.0 12173.0 12170.0 12171.0 12169.0 12171.0 12163.5 12164.5 12156.0 12155.0 12150.5 12151.0 12151.0 12148.0 12149.0 12147.0 12147.5 12142.5 12143.0 12133.5 12134.5 12116.5 12117.0 12115.0 12115.5 12112.0 12112.0 12108.5 12108.0 12106.0 12105.5 12107.0 12100.0 12100.5 12095.0 12095.5 12074.0 12074.0 12071.0 12071.5 12070.5 12071.5 12066.5 12068.0 12063.0 12064 . 5 12056.5 12058.5 12055.0 12056.0 12051.0 12053.0 12047.0 12048.5 12046.5 12048.0 12044.0 12045.0 12039.5 12040.5 12038.5 12040.0 12031.5 12033.0 12033.0 12019.0 12020.5 12012.0 12013.5 12005.0 12006.0 12006.0 11997.5 11998.5 11997.0 11998.0 11989.5 11990.0 11989.0 11990.5 11979.5 11979.5 11975.0 11975.5 11972.5 11973.5 11972.0 11973.5 11967.5 11967.5 11965.5 11966.0 11965.0 11965.5 11962.5 11962.0 11962.0 11962.5 11960.5 11960.5 11960.0 11959.5 11957.5 11957.0 LIS Tape Verification Listing Schlumberger Alaska Computing Center 5-SEP-1997 13:04 PAGE: 11954.5 11955.5 11952.0 11951.5 11947.0 11946.5 11933.5 11934.5 11930.5 11930.0 11930.0 11930.0 11927.0 11927.5 11926.5 11927.5 11915.5 11916.5 11909.5 11911.0 11904.5 11905.0 11887.0 11887.5 11886.5 11888.0 11877.0 11877.0 11863.5 11866.0 11845.0 11846.5 11846.5 11836.0 11837.0 11835.0 11837.0 11817.0 11817.5 11816.5 11818.0 11814.0 11815.5 11808.0 11809.5 11809.0 11798.5 11800.5 11793.5 11794.5 11787.5 11789.0 11776.0 11776.0 11774.0 11773.5 11769.0 11768.0 11762.0 11761.5 11762.0 11757.5 11757.0 11754.0 11752.0 11753.0 11752.5 11751.0 11750.0 11750.5 11750.0 11737.0 11735.5 11734.5 11733.5 11731.5 11730.0 11726.5 11725.5 11721.5 11719.5 11718.5 11716.5 11714.5 11713.5 11713.5 11710.5 11709.0 11707.0 11704.0 11706.5 11704.0 11701.5 11700.0 11693.5 11692.0 11689.0 11687.0 11688.0 11687.0 11681.5 11680.0 11680.0 11678.0 11677.0 11677.5 11676.5 11674.5 11673.5 11673.5 11670.5 11669.5 11668.5 11668.0 11667.0 11666.5 LIS Tape Verification Listing Schlumberger Alaska Computing Center 5-SEP-1997 13: 04 PAGE: 10 100.0 $ 99.5 99.0 REMARKS: THIS FILE CONTAINS TDTP BASELINE PASS #2. THE DEPTH SHIFTS SHOWN ABOVE REFLECT BASELINE PASS #2 GRCH TO BASELINE PASS Hi GRCH; AND BASELINE PASS #2 SIGM TO BASELINE PASS Hi SIGM. ALL OTHER TDTP CURVES WERE CARRIED WITH THE SIGM SHIFT. $ LIS FORMAT DATA ** DATA FORMAT SPECIFICATION RECORD ** ** SET TYPE- 64EB ** .............................. TYPE REPR CODE VALUE 1 66 0 2 66 0 3 73 88 4 66 1 5 66 6 73 7 65 8 68 0.5 9 65 FT 11 66 11 12 68 13 66 0 14 65 FT 15 66 68 16 66 1 0 66 1 ** SET TYPE- CHAN ** NA~E SERV UNIT SERVICE API API API API FILE NUMB NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUM~ SAMP ELEM CODE (HEX) DEPT FT 1088189 O0 000 O0 0 2 1 1 4 68 0000000000 SIGMTDTP CU 1088189 O0 000 O0 0 2 1 1 4 68 0000000000 TPHI TDTP PU-S 1088189 O0 000 O0 0 2 1 1 4 68 0000000000 SBHFTDTP CU 1088189 O0 000 O0 0 2 1 1 4 68 0000000000 SBHNTDTP CU 1088189 O0 000 O0 0 2 1 1 4 68 0000000000 SIGC TDTP CU 1088189 O0 000 O0 0 2 1 1 4 68 0000000000 SIBHTDTP CU 1088189 O0 000 O0 0 2 1 1 4 68 0000000000 TRATTDTP 1088189 O0 000 O0 0 2 1 1 4 68 0000000000 SDSI TDTP CU 1088189 O0 000 O0 0 2 1 1 4 68 0000000000 BACK TDTP CPS 1088189 O0 000 O0 0 2 1 1 4 68 0000000000 FBAC TDTP CPS 1088189 O0 000 O0 0 2 1 1 4 68 0000000000 LIS Tape Verification Listing Schlumberger Alaska Computing Center 5-SEP-1997 13:04 PAGE: 11 NA~ SERV UNIT SERVICE API API API API FILE NUMB NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUMB SAMP ELE~ CODE (HEX) TCAN TDTP CPS 1088189 O0 000 O0 0 2 1 1 4 68 0000000000 TCAF TDTP CPS 1088189 O0 000 O0 0 2 1 1 4 68 0000000000 TCND TDTP CPS 1088189 O0 000 O0 0 2 1 1 4 68 0000000000 TCFD TDTP CPS 1088189 O0 000 O0 0 2 1 1 4 68 0000000000 TSCN TDTP CPS 1088189 O0 000 O0 0 2 1 1 4 68 0000000000 TSCF TDTP CPS 1088189 O0 000 O0 0 2 1 1 4 68 0000000000 INND TDTP CPS 1088189 O0 000 O0 0 2 1 1 4 68 0000000000 INFD TDTP CPS 1088189 O0 000 O0 0 2 1 1 4 68 0000000000 GRCH TDTP GAPI 1088189 O0 000 O0 0 2 1 1 4 68 0000000000 TENS TDTP LB 1088189 O0 000 O0 0 2 1 1 4 68 0000000000 CCL TDTP V 1088189 O0 000 O0 0 2 1 1 4 68 0000000000 ** DATA ** DEPT. 12283.500 SIGM. TDTP 19.961 TPHI.TDTP 41.930 SBHF. TDTP SBHN. TDTP 86. 201 SIGC. TDTP O. 549 SIBH. TDTP 141. 738 TRAT. TDTP SDSI. TDTP O. 486 BACK. TDTP 206. 442 FBAC. TDTP 52.189 TCAN. TDTP TCAF. TDTP 12193. 928 TCND. TDTP 16260. 604 TCFD. TDTP 4816. 325 TSCN. TDTP TSCF. TDTP 1278. 674 INND. TDTP 1938. 313 INFD. TDTP 322. 656 GRCH. TDTP TENS. TDTP 1660. 000 CCL. TDTP O . 000 DEPT. 11659. 000 SIGM. TDTP 38. 966 TPHI. TDTP 58. 960 SBHF. TDTP SBHN. TDTP 53. 397 SIGC. TDTP 1. 298 SIBH. TDTP 67. 323 TRAT. TDTP SDSI. TDTP 1. 037 BACK. TDTP 180. 743 FBAC. TDTP 40. 698 TCAN. TDTP TCAF. TDTP 10128.186 TCND. TDTP 17194. 055 TCFD. TDTP 4390. 832 TSCN. TDTP TSCF. TDTP 550. 922 INND. TDTP 1912. 333 INFD. TDTP 310. 339 GRCH. TDTP TENS. TDTP 1640. 000 CCL. TDTP O. 000 75. 024 I. 848 31636. 305 3317. 430 -999. 250 44.107 1.729 35665.883 1866.598 -999.250 ** END OF DATA ** **** FILE TRAILER **** FILE NAME : EDIT .002 SERVICE : FLIC VERSION : O01CO1 DATE : 97/09/ 5 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : LIS Tape Verification Listing Schlumberger Alaska Computing Center 5~SEP-1997 13:04 PAGE: 12 **** FILE HEADER **** FILE NAME : EDIT .003 SERVICE - FLIC VERSION : O01CO1 DATE : 97/09/ 5 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : FILE HEADER FILE AFtTRIBER: 3 EDITED CURVES Depth shifted and clipped curves for each pass in separate files. PASS NUMBER: 3 DEPTH INCREblENT: 0.5000 FILE SU3~VARY LDWG TOOL CODE START DEPTH STOP DEPTH GRCH 12261.0 11660.0 TDTP 12286.0 11660.0 $ CURVE SHIFT DATA - PASS TO PASS (MEASURED DEPTH) BASELINE CURVE FOR SHIFTS LDWG CURVE CODE: GRCH PASS AKIM~ER : 1 BASELINE DEPTH 88888.0 12276.5 12266.5 12263.5 12257.5 12255.0 12251.0 12250.5 12239.0 12235.0 12227.5 12198.5 12189.5 12186.0 12170.5 12164.5 12156.0 12150.5 12148.5 12146.5 12140.5 .......... EQUIVALENT UNSHIFTEDDEPTH .......... GRCH TDTP 88886.0 88885.0 12255.5 12254.5 12249.5 12227.5 12198.5 12189.0 12185.5 12171.0 12164.5 12155.0 12151.0 12147.5 12140.0 12273.5 12264.0 12262.0 12249.5 12236.0 12233.5 12199.0 12171.0 12151.0 12149.0 LIS Tape Verification Listing Schlumberger Alaska Computing Center 5-SEP-1997 13:04 PAGE: 13 12138.5 12134.0 12129 5 12119 5 12117 5 12114 5 12113 0 12109 0 12106.5 12104.0 12094.5 12084.5 12073.0 12072.5 12070.5 12068.0 12061.5 12058.0 12057.0 12055.5 12054.5 12052.0 12047.0 12039.0 12031.5 12025.5 12020.0 12013.5 12005.0 12004.5 11998.0 11997.5 11995.0 11989.5 11989.0 11979.0 11975.5 11973.5 11970.5 11966.0 11965.5 11962.5 11960.5 11960.0 11956.5 11954.5 11952.5 11949.5 11934.0 11933.5 11931.0 11930.5 11928.0 11927.0 11923.0 12134.5 12132.5 12119.5 12117.0 12115.0 12112.0 12108.0 12103.5 12085.5 12074.0 12068.0 12058.5 12056.0 12053.5 12048.0 12040.5 12033.0 12027.0 12020.5 12015.0 12006.0 11998.0 11990.0 11975.5 11973.5 11966.0 11962.0 11960.5 11957.0 11954.5 11951.5 11934.0 11930.0 11927.5 11923.0 12139.5 12107.5 12095.5 12073.5 12071.5 12063.0 12057.5 12056.0 12054.0 12048.5 1204 O. 5 12033.0 12006.0 11998.5 11996.0 11990.0 11979.5 11972.0 11966.0 11962.5 11960.0 11950.0 11934.5 11930.0 11927.5 LIS Tape Verification Lisring Schlumberger Alaska Computing Center 5-SEP-1997 13:04 PAGE: 14 11905.5 11887.5 11886.5 11882.0 11880.0 11865.0 11845.0 11837.0 11836.0 11826.0 11817.5 11817.0 11809.0 11808.0 11800.5 11794.0 11774.0 11770.0 11767.5 11762.5 11762.0 11757.0 11754.0 11751.0 11750.5 11745.0 11737.0 11735.0 11731.0 11727.5 11727.0 11719.5 11719.0 11716.0 11715.0 11707.0 11706.5 11703.0 11698.5 11697.5 11688.5 11688.0 11681 5 11681 0 11678 0 11675 0 11674 5 11669 5 100 0 $ 11888.0 11883.5 11881.5 11866.0 11846.5 11837.0 11827.0 11818.5 11809.5 11801.5 11773.5 11767.0 11761.5 11750.0 11744.0 11735.5 11729.5 11725.0 11716.5 11713.5 11704.0 11701.0 11695.5 11687.0 11679.5 11677.0 11673.5 11906.5 11888.0 11846.5 11837.0 11817.5 11808.5 11795.0 11768.0 11762.0 11757.0 11752.5 11750.0 11733.5 11725.5 11717.0 11714.0 11704.0 11695.5 11687.0 11680.0 11676.5 11673.0 11668.0 11668.5 98.5 99.0 THIS FILE CONTAINS TDTP BASELINE PASS #3. THE DEPTH SHIFTS SHOWN ABOVEREFLECT BASELINE PASS #3 GRCH TO BASELINE PASS #1 GRCH; AND BASELINE PASS #3 SIGM TO BASELINE PASS #1 SIGM. ALL OTHER TDTP CURVES WERE LIS Tape Verification Listing Schlumberger Alaska Computing Center 5-SEP-1997 13:04 PAGE: 15 CARRIED WITH THE SIGM SHIFT. $ LIS FORMAT DATA ** DATA FORMAT SPECIFICATION RECORD ** ** SET TYPE - 64EB ** TYPE REPR CODE VALUE 1 66 0 2 66 0 3 73 88 4 66 1 5 66 6 73 7 65 8 68 0.5 9 65 FT 11 66 11 12 68 13 66 0 14 65 FT 15 66 68 16 66 1 0 66 1 ** SET TYPE - CHAN ** NA~4~ SERV UNIT SERVICE API API API API FILE NUMB NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD ~ SAMP ELE~ CODE (HEX) DEPT FT 1088189 O0 000 O0 0 3 1 1 4 68 0000000000 SIGMTDTP CU 1088189 O0 000 O0 0 3 1 1 4 68 0000000000 TPHI TDTP PU-S 1088189 O0 000 O0 0 3 1 1 4 68 0000000000 SBHF TDTP CU 1088189 O0 000 O0 0 3 1 1 4 68 0000000000 SBHN TDTP CU 1088189 O0 000 O0 0 3 1 1 4 68 0000000000 SIGC TDTP CU 1088189 O0 000 O0 0 3 1 1 4 68 0000000000 SIBHTDTP CU 1088189 O0 000 O0 0 3 1 1 4 68 0000000000 TRAT TDTP 1088189 O0 000 O0 0 3 1 1 4 68 0000000000 SDSI TDTP CU 1088189 O0 000 O0 0 3 1 1 4 68 0000000000 BACK TDTP CPS 1088189 O0 000 O0 0 3 1 1 4 68 0000000000 FBAC TDTP CPS 1088189 O0 000 O0 0 3 1 1 4 68 0000000000 TCAN TDTP CPS 1088189 O0 000 O0 0 3 1 1 4 68 0000000000 TCAF TDTP CPS 1088189 O0 000 O0 0 3 1 1 4 68 0000000000 TCND TDTP CPS 1088189 O0 000 O0 0 3 1 1 4 68 0000000000 TCFD TDTP CPS 1088189 O0 000 O0 0 3 1 1 4 68 0000000000 TSCNTDTP CPS 1088189 O0 000 O0 0 3 1 1 4 68 0000000000 TSCFTDTP CPS 1088189 O0 000 O0 0 3 1 1 4 68 0000000000 INND TDTP CPS 1088189 O0 000 O0 0 3 1 1 4 68 0000000000 LIS Tape Verification Listing Schlumberger Alaska Computing Center 5-SEP-1997 13:04 PAGE: 16 NAME SERV UNIT SERVICE API API API API FILE NUMB NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUMB SAMP ELE~ CODE (HEX) INFD TDTP CPS 1088189 O0 000 O0 0 3 1 1 4 68 0000000000 GRCH TDTP GAPI 1088189 O0 000 O0 0 3 1 1 4 68 0000000000 TENS TDTP LB 1088189 O0 000 O0 0 3 1 1 4 68 0000000000 CCL TDTP V 1088189 O0 000 O0 0 3 1 1 4 68 0000000000 ** DATA ** DEPT. 12283.000 SIGM. TDTP 19.060 TPHI.TDTP 39.389 SBHF. TDTP SBHN. TDTP 85.755 SIGC. TDTP 0.557 SIBH. TDTP 140.726 TRAT. TDTP SDSI.TDTP 0.493 BACK. TDTP 235.946 FBAC. TDTP 63.006 TCAN. TDTP TCAF. TDTP 11823.400 TCND. TDTP 16016.131 TCFD.TDTP 4705.732 TSCN. TDTP TSCF. TDTP 1253.415 INND. TDTP 2004.493 INFD.TDTP 298.595 'GRCH. TDTP TENS.TDTP 1645.000 CCL.TDTP 0.000 79.407 1.825 30339.988 3216.384 -999.250 DEPT. 11658. 500 SIGM. TDTP -999. 250 TPHI. TDTP -999. 250 SBHF. TDTP -999. 250 SB~N. TDTP -999. 250 SIGC. TDTP -999. 250 SIBH. TDTP -999. 250 TRAT. TDTP -999. 250 SDSI. TDTP -999.250 BACK. TDTP -999.250 FBAC. TDTP -999.250 TCAN. TDTP -999.250 TCAF. TDTP -999.250 TCND. TDTP -999.250 TCFD.TDTP -999.250 TSCN. TDTP -999.250 TSCF. TDTP -999.250 INND. TDTP -999.250 INFD. TDTP -999.250 GRCH. TDTP 98. 000 TENS. TDTP -999. 250 CCL. TDTP - 999. 250 ** END OF DATA ** **** FILE TRAILER **** FILE NA~E : EDIT .003 SERVICE : FLIC VERSION : O01CO1 DATE : 97/09/ 5 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : **** FILE HEADER **** FILE NAME : EDIT .004 SERVICE : FLIC VERSION : O01CO1 DATE : 97/09/ 5 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : FILE HEADER LIS Tape Verification Listing Schlumberger Alaska Computing Center 5-SEP-1997 13:04 PAGE: 17 FILE 1VO-~ER: 4 EDITED CURVES Depth shifted and clipped curves for each pass in separate files. PASS NU~ER : 4 DEPTH INCRElZiENT : 0.5000 FILE SU~ff4ARY LDWG TOOL CODE START DEPTH STOP DEPTH GRCH 12255.0 11900.0 TDTP 12280.0 11900.0 $ CURVE SHIFT DATA - PASS TO PASS (MEASURED DEPTH) BASELINE CURVE FOR SHIFTS LDWG CURVE CODE: GRCH PASS NUMBER: 1 .......... EQUIVALENT UNSHIFTEDDEPTH .......... BASELINE DEPTH GRCH TDTP 88888.0 88886.5 88885.5 12276.0 12273.5 12266.0 12264.0 12263.5 12262.5 12250.5 12249.0 12249.0 12241.5 12239.5 12239.0 12236.0 12238.5 12237.0 12234.5 12233.0 12230.5 12230.0 12227.5 12227.5 12220.5 12219.5 12213.0 12213.5 12208.0 12208.0 12199.0 12199.0 12190.5 12189.5 12186.0 12185.5 12183.0 12185.5 12173.5 12173.0 12172.0 12173.5 12170.5 12171.0 12171.0 12167.5 12167.5 12165.0 12164.5 12157.0 12155.0 12151.0 12151.0 12150.5 12151.0 12149.0 12149.0 12147.0 12147.0 12137.5 12138.5 12134.5 12135.0 12125.0 12124.0 12117.5 12116.5 12115.5 12115.0 12109.0 12108.0 LIS Tape Verification Listing Schlumberger Alaska Computing Center 5-SEP-1997 13:04 PAGE: 18 12108.0 12107.5 12107~0 12105.5 12104.0 12103.5 12100.5 12100.5 12099.5 12100.0 12095.5 12095.5 12085.5 12085.5 12079.5 12079.5 12071.5 12071.5 12071.0 12071.5 12062.0 12063.0 12057.0 12057.5 12056.0 12056.0 12055.5 12056.5 12048.0 12048.5 12048.5 12042.0 12043.5 12040°0 12040.5 12040.5 12032.0 12033.0 12033.0 12026.0 12027.0 12006.0 12006.0 12005.5 12006.0 12002.0 12002.0 11998.0 11998.0 11998.0 11996.5 11996.0 11990.5 11990.5 11990.0 11991.0 11982.5 11982.0 11978.0 11977.5 11976.5 11975.5 11973.5 11973.5 11966.0 11966.0 11963.5 11962.5 11962.5 11961.5 11960.5 11961.0 11960.0 11957.5 11957.0 11953.0 11952.0 11935.0 11934.0 11934.5 11934.5 11931.0 11930.0 11929.5 11928.0 11927.5 11916.5 11916.5 11914.5 11913.5 11910.0 11910.5 11906.0 11904.5 100.0 98.5 100.5 $ REFiARJfS: THIS FILE CONTAINS TDTP BORAX PASS #1. THE DEPTH SHIFTS SHOWN ABOVE REFLECT BORAX PASS #1 GRCH TO BASELINE PASS #1 GRCH; AND BORAX PASS #1 SIGM TO BASELINE PASS #1 SIGM. ALL OTHER TDTP CURVES WERE CARRIED WITH THE SIGM SHIFT. $ LIS FORMAT DATA LIS Tape Verification Listing Schlumberger Alaska Computing Center 5-SEP-1997 13:04 PAGE: 19 ** DATA FORMAT SPECIFICATION RECORD ** ** SET TYPE - 64EB * * TYPE REPR CODE VALUE 1 66 0 2 66 0 3 73 88 4 66 1 5 66 6 73 7 65 8 68 0.5 9 65 FT 11 66 11 12 68 13 66 0 14 65 FT 15 66 68 16 66 1 0 66 1 ** SET TYPE - CHAN ** NAME SERV UNIT SERVICE API API API API FILE NUMB NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CI. dtSS MOD Nr.~B S~IP ELI~ CODE (HEX) DEPT FT 1088189 O0 000 O0 0 4 1 1 4 68 0000000000 SIGMTDTP CU 1088189 O0 000 O0 0 4 1 1 4 68 0000000000 TPHI TDTP PU-S 1088189 O0 000 O0 0 4 1 1 4 68 0000000000 SBHFTDTP CU 1088189 O0 000 O0 0 4 1 1 4 68 0000000000 SBP~NTDTP CU 1088189 O0 000 O0 0 4 1 1 4 68 0000000000 SIGCTDTP CU 1088189 O0 000 O0 0 4 1 1 4 68 0000000000 SIBH TDTP CU 1088189 O0 000 O0 0 4 1 1 4 68 0000000000 TRATTDTP 1088189 O0 000 O0 0 4 1 1 4 68 0000000000 SDSI TDTP CU 1088189 O0 000 O0 0 4 1 1 4 68 0000000000 BACK TDTP CPS 1088189 O0 000 O0 0 4 1 1 4 68 0000000000 FBAC TDTP CPS 1088189 O0 000 O0 0 4 1 1 4 68 0000000000 TCAN TDTP CPS 1088189 O0 000 O0 0 4 1 1 4 68 0000000000 TCAFTDTP CPS 1088189 O0 000 O0 0 4 1 1 4 68 0000000000 TCND TDTP CPS 1088189 O0 000 O0 0 4 1 1 4 68 0000000000 TCFD TDTP CPS 1088189 O0 000 O0 0 4 1 1 4 68 0000000000 TSCNTDTP CPS 1088189 O0 000 O0 0 4 1 1 4 68 0000000000 TSCFTDTP CPS 1088189 O0 000 O0 0 4 1 1 4 68 0000000000 INND TDTP CPS 1088189 O0 000 O0 0 4 1 1 4 68 0000000000 INFD TDTP CPS 1088189 O0 000 O0 0 4 1 1 4 68 0000000000 GRCH TDTP GAPI 1088189 O0 000 O0 0 4 1 1 4 68 0000000000 TENS TDTP LB 1088189 OO 000 O0 0 4 1 1 4 68 0000000000 CCL TDTP V 1088189 O0 000 O0 0 4 1 1 4 68 0000000000 LIS Tape Verification Listing Schlumberger Alaska Computing Center 5-SEP-1997 13:04 PAGE: 2O ** DATA ** DEPT. 12277.500 SIGM. TDTP 13.833 TPHI.TDTP SBHN. TDTP 88.985 SIGC. TDTP 0.487 SIBH. TDTP SDSI. TDTP 0.451 BACK. TDTP 166.607 FBAC. TDTP TCAF. TDTP 7796.073 TCND. TDTP 14590.037 TCFD. TDTP TSCF. TDTP 1569.790 INND. TDTP 1609.412 INFD. TDTP TENS. TDTP 1655.000 CCL. TDTP 0.000 34 . 636 SBHF . TDTP 148. 055 TRAT. TDTP 35. 661 TCAN. TDTP 4525. 746 TSCN. TDTP 256. 639 GRCH. TDTP 81.019 1.917 19170.629 3860.130 -999.250 DEPT. 11898.500 SIGM. TDTP -999.250 TPHI. TDTP -999.250 SBHF. TDTP -999.250 SBHN. TDTP -999.250 SIGC. TDTP -999.250 SIBH. TDTP -999.250 TRAT. TDTP -999.250 SDSI. TDTP -999.250 BACK. TDTP -999.250 FBAC. TDTP -999.250 TCAN. TDTP -999.250 TCAF. TDTP -999.250 TCND. TDTP -999.250 TCFD. TDTP -999.250 TSCN. TDTP -999.250 TSCF. TDTP -999.250 INND. TDTP -999.250 INFD. TDTP -999.250 GRCH. TDTP 24.125 TENS. TDTP -999.250 CCL. TDTP -999.250 ** END OF DATA ** **** FILE TRAILER **** FILE NA~IE : EDIT .004 SERVICE . FLIC VERSION . O01CO1 DATE . 97/09/ 5 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : **** FILE HEADER **** FILE NAM~ : EDIT °005 SERVICE : FLIC VERSION . O01CO1 DATE : 97/09/ 5 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : FILE HEADER FILE NUPIBER: 5 EDITED CURVES Depth shifted and clipped curves for each pass in separate files. PASS NUMBER: 5 DEPTH INCREMENT: 0.5000 FILE SUI~ULRY LDWG TOOL CODE START DEPTH GRCH 12255.0 TDTP 12280.0 STOP DEPTH 11900.0 11900.0 LIS Tape Verification Listing Schlumberger Alaska Computing Center 5-SEP-1997 13:04 PAGE: 21 $ CURVE SHIFT DATA - PASS TO PASS (MEASURED DEPTH) BASELINE CURVE FOR SHIFTS LDWG CURVE CODE: GRCH PASS ~ER : 1 BASELINE DEPTH 88888.0 12276.0 12265.5 12263.0 12251.0 12250.5 12245.0 12238.5 12235.5 12233.0 12228.0 12226.0 12220.0 12214.0 12210.5 12199.0 12198.5 12185.5 12183.0 12173.5 12172.5 12171.0 12170.5 12167.0 12164.0 12156.0 12154.0 12150.5 12150.0 12148.5 12142.5 12137.5 12133.5 12130.5 12129.5 12117.0 12115.5 12108.5 12107.5 12106.0 12096.0 12092.0 12074.0 12073.5 12071.0 .......... EQUIVALENT UNSHIFTEDDEPTH .......... GRCH TDTP 88886.5 88885.5 12249.5 12235.0 12233.0 12227.5 12225.5 12219.5 12199.0 12185.5 12173.0 12171.0 12167.5 12164.5 12155.0 12153.0 12151.0 12149.0 12142.5 12135.0 12132.0 12116.5 12115.0 12108.0 12105.0 12093.5 12074.0 12072.0 12273.5 12264.0 12262.0 12249.5 12243.5 12236.0 12213.5 12211.0 12199.0 12185.5 12174.0 12171.0 12151.0 12139.0 12129.5 12107.5 12096.0 12073.5 LIS Tape Verification Listing Schlumberger Alaska Computing Center 5-SEP-1997 13:04 PAGE: 22 12062.0 12063.5 12063.0 12057.5 12058.5 12056.0 12056.0 12055.5 12056.0 12052.5 12054.0 12050.0 12050.5 12047.5 12048.5 12047.0 12048.0 12039.5 12040.5 12039.0 12040.0 12032.0 12033.0 12033.0 12026.0 12027.0 12014.0 12014.5 12012. $ 12013.5 12005.0 12005.5 12006.0 12002.0 12002.5 11998.0 11998.5 11998.0 11990.5 11990.0 11990.0 11990.5 11979.5 11979.5 11977.5 11977.0 11974.5 11973.5 11967.5 11967.0 11966.0 11966.0 11963.5 11962.5 11963.0 11962.5 11961.5 11960.5 11961.0 11960.0 11955.0 11954.5 11955.0 11953.0 11951.5 11934.5 11934.0 11934.0 11934.5 11930.5 11929.5 11929.5 11928.5 11927.5 11928.0 11927.5 11923.5 11923.0 11914.0 11914.5 11909.5 11911.0 11907.0 11904.5 11906.5 11907.0 100.0 97.5 100.5 $ RE~ARKS: THIS FILE CONTAINS TDTP BORAX PASS #2. THE DEPTH SHIFTS SHOWN ABOVEREFLECT BORAX PASS #2 GRCH TO BASELINE PASS #1 GRCH; AND BORAX PASS #2 SIGM TO BASELINE PASS #1 SIGM. ALL OTHER TDTP CURVES WERE CARRIED WITH THE SIGM SHIFT. $ LIS FORMAT DATA LIS Tape Verification Listing Schlumberger Alaska Computing Center 5-SEP-1997 13:04 PAGE: 23 ** DATA FORMAT SPECIFICATION RECORD ** ** SET TYPE - 64EB ** TYPE REPR CODE VALUE 1 66 0 2 66 0 3 73 88 4 66 1 5 66 6 73 7 65 8 68 0.5 9 65 FT 11 66 11 12 68 13 66 0 14 65 FT 15 66 68 16 66 1 0 66 1 ** SET TYPE - CHAN ** NAME SERV UNIT SERVICE API API API API FILE NUMB NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUMB SAMP ELEM CODE (HEX) DEPT FT 1088189 O0 000 O0 0 5 1 1 4 68 0000000000 SIGM TDTP CU 1088189 O0 000 O0 0 5 1 1 4 68 0000000000 TPHI TDTP PU-S 1088189 O0 000 O0 0 5 1 1 4 68 0000000000 SBHF TDTP CU 1088189 O0 000 O0 0 5 1 i 4 68 0000000000 SBtlNTDTP CU 1088189 O0 000 O0 0 5 1 1 4 68 0000000000 SIGC TDTP CU 1088189 O0 000 O0 0 5 1 1 4 68 0000000000 SIBHTDTP CU 1088189 O0 000 O0 0 5 1 1 4 68 0000000000 TRAT TDTP 1088189 O0 000 O0 0 5 1 1 4 68 0000000000 SDSI TDTP CU 1088189 O0 000 O0 0 5 1 1 4 68 0000000000 BACK TDTP CPS 1088189 O0 000 O0 0 5 1 1 4 68 0000000000 FBAC TDTP CPS 1088189 O0 000 O0 0 5 1 1 4 68 0000000000 TCAN TDTP CPS 1088189 O0 000 O0 0 5 1 1 4 68 0000000000 TCAF TDTP CPS 1088189 O0 000 O0 0 5 1 1 4 68 0000000000 TCND TDTP CPS 1088189 O0 000 O0 0 5 1 1 4 68 0000000000 TCFD TDTP CPS 1088189 O0 000 O0 0 5 1 1 4 68 0000000000 TSCNTDTP CPS 1088189 O0 000 O0 0 5 1 1 4 68 0000000000 TSCF TDTP CPS 1088189 O0 000 O0 0 5 1 1 4 68 0000000000 INND TDTP CPS 1088189 O0 000 O0 0 5 1 1 4 68 0000000000 INFD TDTP CPS 1088189 O0 000 O0 0 5 1 1 4 68 0000000000 GRCHTDTP GAPI 1088189 O0 000 O0 0 5 1 1 4 68 0000000000 TENS TDTP LB 1088189 O0 000 O0 0 5 1 1 4 68 0000000000 CCL TDTP V 1088189 O0 000 O0 0 5 1 1 4 68 0000000000 LIS Tape Verification Listing Schlumberger Alaska Computing Center 5-SEP-1997 13:04 PAGE: 24 ** DATA ** DEPT. 12277. 500 SIGM. TDTP SBt~N. TDTP 87.216 SIGC. TDTP SDSI. TDTP 0.397 BACK. TDTP TCAF. TDTP 9927. 635 TCND. TDTP TSCF. TDTP 1944. 213 INND. TDTP TENS. TDTP 161 O. 000 CCL. TDTP DEPT. 11897.500 SIGM. TDTP SBHN. TDTP -999.250 SIGC. TDTP SDSI. TDTP -999.250 BACK. TDTP TCAF. TDTP ~999.250 TCND. TDTP TSCF. TDTP -999.250 INND. TDTP TENS. TDTP -999.250 CCL.TDTP 13.654 TPHI.TDTP 33.655 SBHF. TDTP 75.699 0.545 SIBH. TDTP 144.042 TRAT. TDTP 1.898 210.680 FBAC. TDTP 51.523 TCAN. TDTP 24429.168 18010.680 TCFD. TDTP 5653.997 TSCN. TDTP 4784.171 1979.910 INFD. TDTP 321.948 GRCH. TDTP -999.250 0.000 -999.250 TPHI.TDTP -999.250 SIBH. TDTP -999.250 FBAC. TDTP -999.250 TCFD. TDTP -999.250 INFD. TDTP -999.250 -999. 250 SBHF. TDTP - 999. 250 TRAT. TDTP -999. 250 TCAN. TDTP -999. 250 TSCN. TDTP -999. 250 GRCH. TDTP -999.250 -999.250 -999.250 -999.250 30.078 ** END OF DATA ** **** FILE TRAILER **** FILE NAME : EDIT .005 SERVICE : FLIC VERSION : O01CO1 DATE : 97/09/ 5 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : **** FILE HEADER **** FILE NAME : EDIT .006 SERVICE : FLIC VERSION : O01CO1 DATE : 97/09/ 5 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : FILE HEADER FILE NU~BER: 6 EDITED CURVES Depth shifted and clipped curves for each pass in separate files. PASS NUMBER: 6 DEPTH INCREMENT: 0.5000 FILE SUI~VARY LDWG TOOL CODE START DEPTH GRCH 12255.0 TDTP 12280.0 STOP DEPTH 11900.0 11900.0 LIS Tape Verification Listing Schlumberger Alaska Computing Center 5-SEP-1997 13:04 PAGE: 25 $ CURVE SHIFT DATA - PASS TO PASS (~IEASURED DEPTH) BASELINE CURVE FOR SHIFTS LDWG CURVE CODE: GRCH PASS NUMBER: 1 BASELINE DEPTH 88888.0 12266.5 12263.5 12251.0 12245.0 12236.0 12235.0 12233.5 12228.0 12221.0 12213.0 12210.5 12209.5 12208.0 12199.0 12186.5 12183.0 12172.5 12171.5 12167.5 12165.0 12156.5 12151.0 12150.0 12149.0 12147.5 12138.0 12135.0 12125.5 12117.5 12109.0 12108.5 12106.5 12105.0 12094.5 12092.0 12085.0 12080.0 12074.0 12071.5 12071.0 12069.5 12065.0 12063.5 12062.5 .......... EQUIVALENT UNSHIFTED DEPTH .......... GRCH TDTP 88886.5 88885.5 12249.5 12235.0 12233.0 12228.0 12221.0 12208.0 12198.5 12185.5 12182.0 12173.0 12164.5 12155.0 12151.0 12149.0 12147.5 12135.0 12124.0 12117.0 12107.5 12105.5 12103.5 12093.5 12086.0 12074.0 12072.0 12068.5 12063.0 12264.0 12262.5 12249.0 12243.0 12232.5 12212.5 12210.5 12208.5 12199.0 12185.5 12171.5 12167.5 12151.0 12149.0 12139.0 12107.5 12095.5 12080.0 12073.5 12071.5 12065.0 12063.0 LIS Tape Verification Listing Schlumberger Alaska Computing Center 5-SEP-1997 13: 04 PAGE: 26 12056.5 12056.0 12056.0 12056.0 12053.0 12054.0 12048.5 12048.0 12048.0 12048.0 12042.0 12044.0 12040.5 12040.5 12040.0 12040.5 12032.5 12033.0 12033.0 12027.0 12027.0 12025.0 12025.0 12018.0 12018.0 12006.0 12006.0 12005.5 12006.0 11999.0 11998.5 11998.5 11998.0 11991.0 11990.5 11990.0 11990.5 11980.0 11979.5 11976.0 11975.5 11969.0 11968.0 11966.5 11966.0 11964.0 11962.5 11963.5 11962.5 11961.5 11960.5 11960.0 11955.5 11954.5 11953.5 11951.5 11942.0 11942.5 11935.5 11934.0 11935.0 11934.5 11931.5 11929.5 11931.0 11929.5 11929.0 11927.5 11910.5 11910.5 100.0 98.5 I00.0 $ REMARKS: THIS FILE CONTAINS TDTP BORAX PASS #3. THE DEPTH SHIFTS SHOWN ABOVEREFLECT BORAX PASS #3 GRCH TO BASELINE PASS #1 GRCH; AND BORAX PASS #3 SIGM TO BASELINE PASS #1 SIGM. ALL OTHER TDTP CURVES WERE CARRIED WITH THE SIGM SHIFT. $ LIS FORMAT DATA LIS Tape Vezxfication Listing Schlumberger Alaska Computing Center 5-SEP-1997 13:04 PAGE: 27 ** DATA FORMAT SPECIFICATION RECORD ** SET TYPE - 64EB * * TYPE REPR CODE VALUE 1 66 0 2 66 0 3 73 88 4 66 1 5 66 6 73 7 65 8 68 0.5 9 65 FT 11 66 11 12 68 13 66 0 14 65 FT 15 66 68 16 66 1 0 66 1 ** SET TYPE - CHAN ** NAlVlE SERV UNIT SERVICE API API API API FILE NUMB NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUMB SAMP ELE~ CODE (HEX) DEPT FT 1088189 O0 000 O0 0 6 1 1 4 68 0000000000 SIGMTDTP CU 1088189 00 000 O0 0 6 1 1 4 68 0000000000 TPHI TDTP PU-S 1088189 O0 000 O0 0 6 1 1 4 68 0000000000 SBHF TDTP CU 1088189 O0 000 O0 0 6 1 1 4 68 0000000000 SBHNTDTP CU 1088189 O0 000 O0 0 6 1 1 4 68 0000000000 SIGC TDTP CU 1088189 O0 000 O0 0 6 1 1 4 68 0000000000 SIBH TDTP CU 1088189 O0 000 O0 0 6 1 1 4 68 0000000000 TRAT TDTP 1088189 O0 000 O0 0 6 1 1 4 68 0000000000 SDSI TDTP CU 1088189 O0 000 O0 0 6 1 1 4 68 0000000000 BACK TDTP CPS 1088189 O0 000 O0 0 6 1 1 4 68 0000000000 FBAC TDTP CPS 1088189 O0 000 O0 0 6 1 1 4 68 0000000000 TCAN TDTP CPS 1088189 O0 000 O0 0 6 1 1 4 68 0000000000 TCAF TDTP CPS 1088189 O0 000 O0 0 6 1 1 4 68 0000000000 TCND TDTP CPS 1088189 O0 000 O0 0 6 1 1 4 68 0000000000 TCFD TDTP CPS 1088189 O0 000 O0 0 6 1 1 4 68 0000000000 TSCNTDTP CPS 1088189 O0 000 O0 0 6 1 1 4 68 0000000000 TSCFTDTP CPS 1088189 O0 000 O0 0 6 1 1 4 68 0000000000 INND TDTP CPS 1088189 O0 000 O0 0 6 1 1 4 68 0000000000 INFD TDTP CPS 1088189 O0 000 O0 0 6 1 1 4 68 0000000000 GRCHTDTP GAPI 1088189 O0 000 O0 0 6 1 1 4 68 0000000000 TENS TDTP LB 1088189 O0 000 O0 0 6 1 1 4 68 0000000000 CCL TDTP V 1088189 O0 000 O0 0 6 1 1 4 68 0000000000 LIS Tape Verification Listing Schlumberger Alaska Computing Center 5-SEP-1997 13:04 PAGE: 28 ** DATA ** DEPT. 12277.500 SIGM. TDTP 13.174 TPHI.TDTP SBHN. TDTP 89.376 SIGC. TDTP 0.888 SIBH. TDTP SDSI.TDTP 0.352 BACK. TDTP 246.356 FBAC. TDTP TCAF. TDTP 10091.166 TCND. TDTP 17991.711 TCFD. TDTP TSCF. TDTP 2090.519 INND. TDTP 2083.521 INFD. TDTP TENS. TDTP 1595.000 CCL.TDTP 0.000 DEPT. 11898.500 SIGM. TDTP -999.250 TPHI.TDTP SBHN. TDTP -999.250 SIGC. TDTP -999.250 SIBH. TDTP SDSI.TDTP -999.250 BACK. TDTP -999.250 FBAC. TDTP TCAF. TDTP -999.250 TCND. TDTP -999.250 TCFD. TDTP TSCF. TDTP -999.250 INND. TDTP -999.250 INFD. TDTP TENS. TDTP -999.250 CCL. TDTP -999.250 25.058 SBHF. TDTP 139. 034 TRAT. TDTP 48. 306 TCAN. TDTP 6023. 784 TSCN. TDTP 351. 714 GRCH. TDTP -999. 250 SBHF. TDTP -999. 250 TRAT. TDTP -999. 250 TCAN. TDTP -999. 250 TSCN. TDTP -999. 250 GRCH. TDTP 76.016 1.666 21944.223 4546.036 -999.250 -999.250 -999.250 -999.250 -999.250 33.156 ** END OF DATA ** **** FILE TRAILER **** FILE NAME : EDIT .006 SERVICE : FLIC VERSION : O01CO1 DATE : 97/09/ 5 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : **** FILE HEADER **** FILE NAME : EDIT .007 SERVICE : FLIC VERSION : O01CO1 DATE : 97/09/ 5 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : FILE HEADER FILE~ER: 7 AVERAGED CURVES Pulsed Neutron: Unaveraged edited Pass I Gamma Ray and backround counts; arithmetic average of edited static baseline passes for all other curves. DEPTH INCREMENT 0.5000 PASSES INCLUDED IN AVERAGE LDWG TOOL CODE PASS NUMBERS TDTP 1, 2, 3, $ LIS Tape Ve~_=ication Listing Schlumberger Alaska Computing Center 5-SEP-1997 13:04 PAGE: 29 REMARKS: THE ARITH~TIC AVERAGE OF THE BASELINE PASSES WAS CALCULATED AFTER CLIPPING ANDDEPTH CORRECTIONS WERE APPLIED. $ LIS FORMAT DATA ** DATA FORMAT SPECIFICATION RECORD ** ** SET TYPE- 64EB ** TYPE REPR CODE VALUE 1 66 0 2 66 0 3 73 80 4 66 1 5 66 6 73 7 65 8 68 0.5 9 65 FT 11 66 12 12 68 13 66 0 14 65 FT 15 66 68 16 66 1 0 66 1 ** SET TYPE - CHAN ** N~vJE SERV UNIT SERVICE API API API API FILE NUMB N-O~B SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUMB SAMP ELEM CODE (HEX) DEPT FT 1088189 O0 000 O0 0 7 1 1 4 68 0000000000 SIGM PNAV CU 1088189 O0 000 O0 0 7 1 1 4 68 0000000000 TPHI PNAV PU-S 1088189 O0 000 O0 0 7 1 1 4 68 0000000000 SBHF PNAV CU 1088189 O0 000 O0 0 7 1 1 4 68 0000000000 SBP~VPNAV CU 1088189 O0 000 O0 0 7 1 1 4 68 0000000000 SIGC PNAV CU 1088189 O0 000 O0 0 7 1 1 4 68 0000000000 SIBH PNAV CU 1088189 O0 000 O0 0 7 1 1 4 68 0000000000 TRAT PNAV 1088189 O0 000 O0 0 7 1 1 4 68 0000000000 SDSI PNAV CU 1088189 O0 000 O0 0 7 1 1 4 68 0000000000 BACK TDTP CPS 1088189 O0 000 O0 0 7 1 1 4 68 0000000000 FBAC TDTP CPS 1088189 O0 000 O0 0 7 1 1 4 68 0000000000 TCANPNAV CPS 1088189 O0 000 O0 0 7 1 1 4 68 0000000000 TCAFPNAV CPS 1088189 O0 000 O0 0 7 1 1 4 68 0000000000 TCNDPNAV CPS 1088189 O0 000 O0 0 7 1 1 4 68 0000000000 TCFDPNAV CPS 1088189 O0 000 O0 0 7 1 1 4 68 0000000000 TSCN PNAV CPS 1088189 O0 000 O0 0 7 1 1 4 68 0000000000 LIS Tape Verification Listing Schlumberger Alaska Computing Center 5-SEP-1997 13:04 PAGE: 3O NAlVlE SERV UNIT SERVICE API API API API FILE NUMB NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUM~ SAMP ELE~ CODE (HEX) TSCF PNAV CPS 1088189 O0 000 O0 0 7 1 1 4 68 0000000000 INND PNAV CPS 1088189 O0 000 O0 0 7 1 1 4 68 0000000000 INFD PNAV CPS 1088189 O0 000 O0 0 7 1 1 4 68 0000000000 GRCH TDTP GAPI 1088189 O0 000 O0 0 7 1 1 4 68 0000000000 ** DATA ** DEPT. 12284.000 SIGM. PNAV -999.250 TPHI.PNAV -999.250 SBHF. PNAV -999.250 SBHN. PNAV -999.250 SIGC. PNAV -999.250 SIBH. PNAV -999.250 TRAT. PNAV -999.250 SDSI.PNAV -999.250 BACK. TDTP 104.515 FBAC. TDTP 25.135 TCAN. PNAV -999.250 TCAF. PNAV -999.250 TCND.PNAV -999.250 TCFD.PNAV -999.250 TSCN. PNAV -999.250 TSCF. PNAV -999.250 INND. PNAV -999.250 INFD. PNAV -999.250 GRCH. TDTP -999.250 DEPT. 11658.500 SIGM. PNAV -999.250 TPHI.PNAV -999.250 SBHF. PNAV -999.250 SBPiN. PNAV -999.250 SIGC. PNAV -999.250 SIBH. PNAV -999.250 TRAT. PNAV -999.250 SDSI.PNAV -999.250 BACK. TDTP 153.449 FBAC. TDTP 31.605 TCAN. PNAV -999.250 TCAF. PNAV -999.250 TCND. PNAV -999.250 TCFD.PNAV -999.250 TSCN. PNAV -999.250 TSCF. PNAV -999.250 I19~ID. PNAV -999.250 INFD.PNAV -999.250 GRCH. TDTP -999.250 ** END OF DATA ** **** FILE TRAILER **** FILE NAME : EDIT .007 SERVICE : FLIC VERSION : O01CO1 DATE : 97/09/ 5 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : **** FILE HEADER **** FILE NAME : EDIT .008 SERVICE : FLIC VERSION : O01CO1 DATE : 97/09/ 5 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : FILE HEADER FILE NU~ER RAW CURVES LIS Tape Verification Listing Schlumberger Alaska Computing Center 5-SEP-1997 13:04 PAGE: 31 Curves and log header data for each pass in separate files; raw background pass in last file PASS NUMBER: 1 DEPTH INCRENIENT: 0.5000 FILE SUN~A~Y VENDOR TOOL CODE START DEPTH STOP DEPTH 12319.0 11649.0 TDTP LOG HEADER DATA DATE LOGGED: SOFTWARE VERSION: TIME LOGGER ON BOTTOM: TD DRILLER (FT) : TD LOGGER (FT) : TOP LOG INTERVAL (FT) : BOTTOM LOG INTERVAL (FT) : LOGGING SPEED (FPHR) : DEPTH CONTROL USED (YES/NO): TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE GR GA~g~A RAY TDTP THERMAL DECAY $ BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLERS CASING DEPTH (FT) : LOGGERS CASING DEPTH (FT) : BOREHOLE CONDITIONS FLUID TYPE: FLUID DENSITY (LB/G): SURFACE TEMPERATURE (DEGF) : BOTTOM HOLE TEMPERATURE (DEGF) : FLUID SALINITY (PPM) : FLUID LEVEL (FT) : FLUID RATE AT WELLHEAD (BPM) : WATER CUTS (PCT) : GAS/OIL RATIO: CHOKE (DEG) : NEUTRON TOOL TOOL TYPE (EPITHERMAL OR THERMAL) MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): 18-AUG-97 CP 39.116 1135 17-AUG-97 12276.0 12289.0 11670.0 12286.0 900.0 NO TOOL NUMBER ........... CGRS-A 805 TDIC-A 754 12404.0 PRODUCE FLUIDS THERMAL SANDSTONE 2.65 BLUELI1VE COUNT RATE NORMALIZATION IN OIL ZONE TOP NORMALIZING WINDOW (FT) : BASE NORMALIZING WINDOW (FT): LIS Tape Verification Listing Schlumberger Alaska Computing Center 5-SEP-1997 13:04 PA GE: 32 BLUELINE COUNT RATE SCALES SET BY FIELD ENGINEER FAR COUNT RATE LOW SCALE (CPS): 0 FAR COUNT RATE HIGH SCALE (CPS): 12000 NEAR COUNT RATE LOW SCALE (CPS): 0 NEAR COUNT RATE HIGH SCALE (CPS): 30000 TOOL STANDOFF (IN): REMARKS: TIED INTO AWS DIFL DATED 9-20-95. PUMPED 80 BBLS OF BORAX AND 306 BBLS OF SW. CHANNEL FOUND DOWN TO 12200' FROM PERF INTERVAL AT 12100' TO 12120'. THIS FILE CONTAINS THE RAW TDTP DATA FOR BASELINE PASS #1. $ LIS FORMAT DATA ** DATA FORMAT SPECIFICATION RECORD ** ** SET TYPE - 64EB ** TYPE REPR CODE VALUE 1 66 0 2 66 0 3 73 88 4 66 1 5 66 6 73 7 65 8 68 0.5 9 65 FT 11 66 11 12 68 13 66 0 14 65 FT 15 66 68 16 66 1 0 66 1 ** SET TYPE - CHAN ** NA~E SERV UNIT SERVICE API API API API FILE NUM~ NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUFiB SAMP ELEM CODE (HEX) DEPT FT 1088189 O0 000 O0 0 8 1 1 4 68 0000000000 SIG~PS1 CU 1088189 O0 000 O0 0 8 1 1 4 68 0000000000 TPHI PS1 PU 10~8189 O0 000 O0 0 8 1 1 4 68 0000000000 SBHF PS1 CU 1088189 O0 000 O0 0 8 1 1 4 68 0000000000 SBPfNPS1 CU 1088189 O0 000 O0 0 8 1 1 4 68 0000000000 SIGC PS1 CU 1088189 O0 000 O0 0 8 1 1 4 68 0000000000 LIS Tape Verification Listing Schlumberger Alaska Computing Center 5-SEP-1997 13: 04 PAGE: 33 NAME SERV UNIT SERVICE API API API API FILE NUMB NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUMB SAMP ELEM CODE (HEX) SIBH PS1 CU 1088189 O0 000 O0 0 8 1 1 4 68 TROT PS1 1088189 O0 000 O0 0 8 1 1 4 68 SDSI PS1 CU 1088189 O0 000 O0 0 8 1 1 4 68 BACK PS1 CPS 1088189 O0 000 O0 0 8 1 1 4 68 FBAC PS1 CPS 1088189 O0 000 O0 0 8 1 1 4 68 TCANPS1 CPS 1088189 O0 000 O0 0 8 1 1 4 68 TCAFPS1 CPS 1088189 O0 000 O0 0 8 1 1 4 68 TCND PSi CPS 1088189 O0 000 O0 0 8 1 1 4 68 TCFD PS1 CPS 1088189 O0 000 O0 0 8 1 1 4 68 TSCNPS1 CPS 1088189 O0 000 O0 0 8 1 1 4 68 TSCF PS1 CPS 1088189 O0 000 O0 0 8 1 1 4 68 INND PS1 CPS 1088189 O0 000 O0 0 8 1 1 4 68 INFD PS1 CPS 1088189 O0 000 O0 0 8 1 1 4 68 TENS PS1 LB 1088189 O0 000 O0 0 8 1 1 4 68 GR PS1 GAPI 1088189 O0 000 O0 0 8 1 1 4 68 CCL PS1 V 1088189 O0 000 O0 0 8 1 1 4 68 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 ** DATA ** DEPT. 12319.000 SIGM. PS1 26.648 TPHI.PS1 0.000 SBHF. PS1 SBPiN. PS1 142.307 SIGC.PS1 0.000 SIBH. PS1 180.762 TRAT. PS1 SDSI.PS1 1521.859 BACK. PSi 17.260 FBAC. PS1 7.574 TCAN. PS1 TCAF. PS1 0.000 TCND.PS1 -214.517 TCFD.PS1 -92.697 TSCN. PS1 TSCF. PS1 0.000 INND.PS1 -0.587 INFD. PS1 -0.257 TENS.PSi GR.PS1 19.781 CCL.PSi -0.022 DEPT. 11649.000 SIGM. PS1 40.680 TPHI.PS1 58.812 SBHF. PS1 SBH~.PS1 52.127 SIGC.PSl 1.284 SIBH. PS1 64.442 TRAT. PS1 SDSI.PS1 0.854 BACK. PSi 153.333 FBAC. PS1 33.649 TCAN. PS1 TCAF. PS1 8951.922 TCND.PSl 15211.707 TCFD. PS1 3728.990 TSCN. PS1 TSCF. PS1 416.915 INND.PS1 1667.267 INFD. PS1 282.561 TENS. PSi GR.PS1 100.375 CCL.PS1 0.000 68.307 0.000 0.000 0.000 905.000 46.210 1.721 32976.969 1485.796 1625.000 ** END OF DATA ** **** FILE TRAILER **** FILE NAM~ : EDIT .008 SERVICE : FLIC VERSION : O01CO1 DATE : 97/09/ 5 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : LIS Tape Verification Listing Schlumberger Alaska Computing Center 5-SEP-1997 13:04 PAGE: 34 **** FILE HEADER **** FILE NA~E : EDIT .009 SERVICE : FLIC VERSION : O01CO1 DATE · 97/09/ 5 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : FILE HEADER FILE NU~iBER 9 RAW CURVES Curves and log header data for each pass in separate files; raw background pass in last file PASS NUMBER: 2 DEPTH INCREMENT: 0.5000 FILE SUM~Jh~Y VENDOR TOOL CODE START DEPTH STOP DEPTH 12312.0 11648.5 TDTP LOG HEADER DATA DATE LOGGED: 18-AUG-97 SOFTWARE VERSION: CP 39.116 TIME LOGGER ON BOTTOM: 1135 17-AUG-97 TD DRILLER (FT): 12276.0 TD LOGGER (FT) : 12289.0 TOP LOG INTERVAL (FT) : 11670.0 BOTTOM LOG INTERVAL (FT): 12286.0 LOGGING SPEED (FPHR) : 900.0 DEPTH CONTROL USED (YES/NO): NO TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE GR GAMMA RAY TDTP THERMAL DECAY $ BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN) : DRILLERS CASING DEPTH (FT) : LOGGERS CASING DEPTH (FT) : BOREHOLE CONDITIONS FLUID TYPE: FLUID DENSITY (LB/G): SURFACE TEMPERATURE (DEGF) : BOTTOM HOLE TEMPERATURE (DEGF) : FLUID SALINITY (PPM) : FLUID LEVEL (FT) : TOOL NUMBER CGRS-A 805 TDIC-A 754 12404.0 PRODUCE FLUIDS LIS Tape Ver~Eication Listing Schlumberger Alaska Computing Center 5-SEP-1997 13:04 PAGE: 35 FLUID RATE AT WELLHEAD (BPM) : WATER CUTS (PCT) : GAS/OIL RATIO: CHOKE (DEG) : NEUTRON TOOL TOOL TYPE (EPITHERMAL OR THERMAL): MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): THERMAL SANDSTONE 2.65 BLUELINE COUNT RATE NORMALIZATION IN OIL ZONE TOP NORMALIZING WINDOW (FT) : BASE NORMALIZING WINDOW (FT) : BLUELINE COUNT RATE SCALES SET BY FIELD ENGINEER FAR COUNT RATE LOW SCALE (CPS): 0 FAR COUNT RATE HIGH SCALE (CPS): 12000 NEAR COUNT RATE LOW SCALE (CPS): 0 NEAR COUNT RATE HIGH SCALE (CPS): 30000 TOOL STANDOFF (IN): REMARKS: TIED INTO AWS DIFL DATED 9-20-95. PUMPED 80 BBLS OF BORAX AND 306 BBLS OF SW. CHANNEL FOUND DOWN TO 12200' FROM PERF INTERVAL AT 12100' TO 12120'. THIS FILE CONTAINS THE RAW TDTP DATA FOR BASELINE PASS #2. $ LIS FORMAT DATA ** DATA FORMAT SPECIFICATION RECORD ** ** SET TYPE- 64EB ** TYPE REPR CODE VALUE 1 66 0 2 66 0 3 73 88 4 66 1 5 66 6 73 7 65 8 68 0.5 9 65 FT 11 66 11 12 68 13 66 0 14 65 FT 15 66 68 LIS Tape Vei=fication Listing Schlumberger Alaska Computing Center 5-SEP-1997 13:04 PAGE: 36 TYPE REPR CODE VALUE 16 66 1 0 66 1 ** SET TYPE - CHAN ** NA~iE SERVUNIT SERVICE API API API API FILE NUMB NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUMB SAMP ELEM CODE (HEX) DEPT FT 1088189 O0 000 O0 0 9 1 1 4 68 0000000000 SIGM PS2 CU 1088189 O0 000 O0 0 9 1 1 4 68 0000000000 TPHI PS2 PU 1088189 O0 000 O0 0 9 1 1 4 68 0000000000 SBHF PS2 CU 1088189 O0 000 O0 0 9 1 1 4 68 0000000000 SBPiNPS2 CU 1088189 O0 000 O0 0 9 1 1 4 68 0000000000 SIGC PS2 CU 1088189 O0 000 O0 0 9 1 1 4 68 0000000000 SIBH PS2 CU 1088189 O0 000 O0 0 9 1 1 4 68 0000000000 TRAT PS2 1088189 O0 000 O0 0 9 1 1 4 68 0000000000 SDSI PS2 CU 1088189 O0 000 O0 0 9 1 1 4 68 0000000000 BACK PS2 CPS 1088189 O0 000 O0 0 9 1 1 4 68 0000000000 FBAC PS2 CPS 1088189 O0 000 O0 0 9 1 1 4 68 0000000000 TCANPS2 CPS 1088189 O0 000 O0 0 9 1 1 4 68 0000000000 TCAFPS2 CPS 1088189 O0 000 O0 0 9 1 1 4 68 0000000000 TCNDPS2 CPS 1088189 O0 000 O0 0 9 1 1 4 68 0000000000 TCFD PS2 CPS 1088189 O0 000 O0 0 9 1 1 4 68 0000000000 TSCN PS2 CPS 1088189 O0 000 O0 0 9 1 1 4 68 0000000000 TSCF PS2 CPS 1088189 O0 000 O0 0 9 1 1 4 68 0000000000 INNDPS2 CPS 1088189 O0 000 O0 0 9 1 1 4 68 0000000000 INFD PS2 CPS 1088189 O0 000 O0 0 9 1 1 4 68 0000000000 TENS PS2 LB 1088189 O0 000 O0 0 9 1 1 4 68 0000000000 GR PS2 GAPI 1088189 O0 000 O0 0 9 1 1 4 68 0000000000 CCL PS2 V 1088189 O0 000 O0 0 9 1 1 4 68 0000000000 ** DATA ** DEPT. 12312.000 SIGM. PS2 40.680 TPHI.PS2 58.812 SBHF. PS2 SBHN. PS2 52.127 SIGC.PS2 1.284 SIBH. PS2 64.442 TRAT. PS2 SDSI.PS2 0.854 BACK. PS2 153.333 FBAC. PS2 33.649 TCAN. PS2 TCAF. PS2 8951.922 TCND.PS2 15211.707 TCFD. PS2 3728.990 TSCN. PS2 TSCF. PS2 416.915 INND.PS2 1667.267 INFD. PS2 282.561 TENS.PS2 GR.PS2 194.625 CCL.PS2 -0.026 DEPT. 11648.500 SIGM. PS2 41.890 TPHI.PS2 62.715 SBHF. PS2 SBttN. PS2 50.785 SIGC.PS2 0.714 SIBH. PS2 61.397 TRAT. PS2 SDSI.PS2 0.993 BACK. PS2 193.125 FBAC. PS2 42.317 TCAN. PS2 TCAF. PS2 10234.008 TCND.PS2 15591.063 TCFD.PS2 3763.226 TSCN. PS2 TSCF.PS2 399.348 INND.PS2 1786.476 INFD.PS2 282.696 TENS.PS2 GR.PS2 113.563 CCL.PS2 0.000 46.210 1.721 32976.969 1485.796 810.000 43.326 1.805 39797.625 1489.167 1630.000 LIS Tape ~=~lfication Listing Schlumberger Alaska Computing Center 5-SEP-1997 13:04 PAGE: 37 ** END OF DATA ** **** FILE TRAILER **** FILE NAME : EDIT .009 SERVICE . FLIC VERSION : O01CO1 DATE : 97/09/ 5 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : **** FILE HEADER **** FILE NAlViE : EDIT .010 SERVICE : FLIC VERSION : O01CO1 DATE : 97/09/ 5 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : FILE HEADER FILE NU~4~ER 10 RAW CURVES Curves and log header data for each pass in separate files; raw background pass in last file PASS NUFiBER: 3 DEPTH INCREMENT: 0.5000 FILE SO?4MARY VENDOR TOOL CODE START DEPTH STOP DEPTH 12310.5 11648.5 TDTP LOG HEADER DATA DATE LOGGED: SOFTWARE VERSION: TIME LOGGER ON BOTTOM: TD DRILLER (FT): TD LOGGER (FT) : TOP LOG INTERVAL (FT) : BOTTOM LOG INTERVAL (FT) : LOGGING SPEED (FPHR) : DEPTH CONTROL USED (YES/NO): TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE 18-AUG-97 CP 39. 116 1135 17-AUG-97 12276.0 12289.0 11670.0 12286.0 900.0 NO TOOL NUMBER LIS Tape Verification Listing Schlumberger Alaska Computing Center 5-SEP-1997 13:04 PAGE: 38 GR GAF~A RAY TDTP THERMAL DECAY $ BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLERS CASING DEPTH (FT) : LOGGERS CASING DEPTH (FT) : BOREHOLE CONDITIONS FLUID TYPE: FLUID DENSITY (LB/G): SURFACE TEMPERATURE (DEGF) : BOTTOM HOLE TEMPERATURE (DEGF) : FLUID SALINITY (PPM) : FLUID LEVEL (FT) : FLUID RATE AT WELLHEAD (BPM) : WATER CUTS (PCT) : GAS~OIL RATIO: CHOKE (DEG) : CGRS-A 805 TDIC-A 754 12404.0 PRODUCE FLUIDS NEUTRON TOOL TOOL TYPE (EPITHERMAL OR THERMAL): MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): THERMAL SANDSTONE 2.65 BLUELINE COUNT RATE NORMALIZATION IN OIL ZONE TOP NORMALIZING WINDOW (FT): BASE NORMALIZING WINDOW (FT) : BLUELINE COUNT RATE SCALES SET BY FIELD ENGINEER FAR COUNT RATE LOW SCALE (CPS): 0 FAR COUNT RATE HIGH SCALE (CPS): 12000 NEAR COUNT RATE LOW SCALE (CPS): 0 NEAR COUNT RATE HIGH SCALE (CPS): 30000 TOOL STANDOFF (IN): REMARKS: TIED INTO AWS DIFL DATED 9-20-95. PUMPED 80 BBLS OF BORAX AND 306 BBLS OF SW. CHANNEL FOUND DOWN TO 12200' FROM PERF INTERVAL AT 12100' TO 12120'. THIS FILE CONTAINS THE RAW TDTP DATA FOR BASELINE PASS #3. $ LIS FORMAT DATA LIS Tape Verification Listing Schlumberger Alaska Computing Center 5-SEP-1997 13:04 PAGE: 39 DATA FORMAT SPECIFICATION RECORD ** ** SET TYPE- 64EB ** TYPE REPR CODE VALUE 1 66 0 2 66 0 3 73 88 4 66 1 5 66 6 73 7 65 8 68 0.5 9 65 FT 11 66 11 12 68 13 66 0 14 65 FT 15 66 68 16 66 1 0 66 1 ** SET TYPE - CHAN ** NA~E SERV UNIT SERVICE API API API API FILE NUMB NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUMB SAMP ELEM CODE (HEX) FT 1088189 O0 000 O0 0 10 1 1 4 68 0000000000 DEPT SIGM PS3 CU 1088189 O0 000 O0 0 10 1 1 4 68 0000000000 TPHI PS3 PU 1088189 O0 000 O0 0 10 1 1 4 68 0000000000 SBHF PS3 CU 1088189 O0 000 O0 0 10 1 1 4 68 0000000000 SBPZNPS3 CU 1088189 O0 000 O0 0 10 1 1 4 68 0000000000 SIGC PS3 CU 1088189 O0 000 O0 0 10 1 1 4 68 0000000000 SIBH PS3 CU 1088189 O0 000 O0 0 10 1 1 4 68 0000000000 TRAT PS3 1088189 O0 000 O0 0 10 1 1 4 68 0000000000 SDSI PS3 CU 1088189 O0 000 O0 0 10 1 1 4 68 0000000000 BACK PS3 CPS 1088189 O0 000 O0 0 10 i 1 4 68 0000000000 FBAC PS3 CPS 1088189 O0 000 O0 0 10 1 1 4 68 0000000000 TCANPS3 CPS 1088189 O0 000 O0 0 10 1 1 4 68 0000000000 TCAFPS3 CPS 1088189 O0 000 O0 0 10 1 1 4 68 0000000000 TCND PS3 CPS 1088189 O0 000 O0 0 10 1 1 4 68 0000000000 TCFD PS3 CPS 1088189 O0 000 O0 0 10 1 1 4 68 0000000000 TSCNPS3 CPS 1088189 O0 000 O0 0 10 1 1 4 68 0000000000 TSCF PS3 CPS 1088189 O0 000 O0 0 10 1 1 4 68 0000000000 INNDPS3 CPS 1088189 O0 000 O0 0 10 1 1 4 68 0000000000 INFD PS3 CPS 1088189 O0 000 O0 0 10 1 1 4 68 0000000000 TENS PS3 LB 1088189 O0 000 O0 0 10 1 1 4 68 0000000000 GR PS3 GAPI 1088189 O0 000 O0 0 10 1 1 4 68 0000000000 CCL PS3 V 1088189 O0 000 O0 0 10 1 1 4 68 0000000000 LIS Tape Verification Listing Schlumberger Alaska Computing Center 5-SEP-1997 13:04 PAGE: 40 ** DATA ** DEPT. 12310.500 SIGM. PS3 SBHN. PS3 50.785 SIGC. PS3 SDSI.PS3 0.993 BACK. PS3 TCAF. PS3 10234.008 TCND.PS3 TSCF. PS3 399.348 INND.PS3 GR.PS3 98.563 CCL.PS3 41.890 TPHI.PS3 0.714 SIBH. PS3 193.125 FBAC. PS3 15591.063 TCFD.PS3 1786.476 INFD. PS3 -0.013 62. 715 61. 397 42.317 3763. 226 282. 696 SBHF. PS3 TRAT. PS3 TCAN. PS3 TSCN. PS3 TENS.PS3 43.326 1.805 39797.625 1489.167 805.000 ** END OF DATA ** **** FILE TRAILER **** FILE NAIViE : EDIT . O10 SERVICE : FLIC VERSION : O01CO1 DATE . 97/09/ 5 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : **** FILE HEADER **** FILE NAME : EDIT .011 SERVICE : FLIC VERSION : O01CO1 DATE . 97/09/ 5 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : FILE HEADER FILE~ER 11 RAW CURVES Curves and log header data for each pass in separate files; raw background pass in last file PASS NURiBER: 4 DEPTH INCRE~F2VT : O . 5000 FILE SUP~4ARY VF2FDOR TOOL CODE START DEPTH TDTP 12293.0 $ LOG HEADER DATA DATE LOGGED: SOFTWAi%E V~RSION: TIM~ LOGGER ON BOTTOM: TD DRILLER (FT) : TD LOGGER (FT) : STOP DEPTH 11896.0 18-AUG-97 CP 39. 116 1135 17-AUG-97 12276.0 12289.0 LIS Tape verification Listing Schlumberger Alaska Computing Center 5-SEP-1997 13 .. 04 PAGE: 41 TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT) : LOGGING SPEED (FPHR) : DEPTH CONTROL USED (YES/NO): TOOL STRING (TOP TO BOTTOM) VF2~-DOR TOOL CODE TOOL TYPE GR GAM~A RAY TDTP THERMAL DECAY $ BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLERS CASING DEPTH (FT) : LOGGERS CASING DEPTH (FT): 11670.0 12286.0 900.0 NO TOOL NUMBER CGRS-A 805 TDIC-A 754 12404.0 BOREHOLE CONDITIONS FLUID TYPE: FLUID DENSITY (LB/G): SURFACE TEMPERATURE (DEGF) : BOTTOM HOLE TEMPERATURE (DEGF) : FLUID SALINITY (PPM) : FLUID LEVEL (FT) : FLUID RATE AT WELLHEAD (BPM) : WATER CUTS (PCT) : GAS~OIL RATIO: CHOKE (DEG) : PRODUCE FLUIDS NEUTRON TOOL TOOL TYPE (EPITHERMAL OR THERMAL): MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): THERMAL SANDSTONE 2.65 BLUELINE COUNT RATE NORMALIZATION IN OIL ZONE TOP NORMALIZING WINDOW (FT) : BASE NORMALIZING WINDOW (FT) : BLUELINE COUNT RATE SCALES SET BY FIELD ENGINEER FAR COUNT RATE LOW SCALE (CPS): 0 FAR COUNT RATE HIGH SCALE (CPS): 12000 NEAR COUNT RATE LOW SCALE (CPS): 0 NEAR COUNT RATE HIGH SCALE (CPS): 30000 TOOL STANDOFF (IN): REMARKS: TIED INTO AWS DIFL DATED 9-20-95. PUMPED 80 BBLS OF BORAX AND 306 BBLS OF SW. CHANNEL FOUND DOWN TO 12200' FROM PERF INTERVAL AT 12100' TO 12120'. THIS FILE CONTAINS THE RAW TDTP DATA FOR BORAX PASS #1. $ LIS FORMAT DATA LIS Tape Verification Listing Schlumberger Alaska Computing Center 5-SEP-1997 13:04 PAGE: 42 ** DATA FORMAT SPECIFICATION RECORD ** ** SET TYPE - 64EB ** TYPE REPR CODE VALUE 66 66 73 66 66 73 65 0 0 88 1 0.5 FT 11 1 2 3 4 5 6 7 8 68 9 65 11 66 12 68 13 66 0 14 65 FT 15 66 68 16 66 1 0 66 1 ** SET TYPE - CHAN ** NA~E SERV UNIT SERVICE API API API API FILE NUMB NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUM~ SAMP ELE~I CODE (HEX) DEPT FT 1088189 O0 000 O0 0 11 1 1 4 68 0000000000 SIGM BX1 CU 1088189 O0 000 O0 0 11 1 1 4 68 0000000000 TPHI BX1 PU 1088189 O0 000 O0 0 11 1 1 4 68 0000000000 SBHF BX1 CU 1088189 O0 000 O0 0 11 1 1 4 68 0000000000 SBI~VBX1 CU 1088189 O0 000 O0 0 11 1 1 4 68 0000000000 SIGC BX1 CU 1088189 O0 000 O0 0 11 1 1 4 68 0000000000 SIBH BX1 CU 1088189 O0 000 O0 0 11 1 1 4 68 0000000000 TRAT BX1 1088189 O0 000 O0 0 11 1 1 4 68 0000000000 SDSI BX1 CU 1088189 O0 000 O0 0 11 1 1 4 68 0000000000 BACK BX1 CPS 1088189 O0 000 O0 0 11 1 1 4 68 0000000000 FBAC BX1 CPS 1088189 O0 000 O0 0 11 1 1 4 68 0000000000 TCANBX1 CPS 1088189 O0 000 O0 0 11 1 1 4 68 0000000000 TCAFBX1 CPS 1088189 O0 000 O0 0 11 1 1 4 68 0000000000 TCNDBX1 CPS 1088189 O0 000 O0 0 11 1 1 4 68 0000000000 TCFD BX1 CPS 1088189 O0 000 O0 0 11 1 1 4 68 0000000000 TSCN BX1 CPS 1088189 O0 000 O0 0 11 1 1 4 68 0000000000 TSCF BX1 CPS 1088189 O0 000 O0 0 11 1 1 4 68 0000000000 INNDBX1 CPS 1088189 O0 000 O0 0 11 1 1 4 68 0000000000 INFD BX1 CPS 1088189 O0 000 O0 0 11 1 1 4 68 0000000000 TENS BX1 LB 1088189 O0 000 O0 0 11 1 1 4 68 0000000000 GR BX1 GAPI 1088189 O0 000 O0 0 11 1 1 4 68 0000000000 CCL BX1 V 1088189 O0 000 O0 0 11 1 1 4 68 0000000000 LIS Tape Verification Listing Schlumberger Alaska Computing Center 5-SEP-1997 13:04 PAGE: 43 ** DATA ** DEPT. 12293.000 SIGM. BX1 13.714 TPHI.BX1 SBPiN. BX1 92.329 SIGC. BX1 0.508 SIBH. BX1 SDSI.BX1 0.514 BACK. BX1 236.411 FBAC.BX1 TCAF. BX1 9083.844 TCND.BX1 15880.885 TCFD.BX1 TSCFoBX1 1816.457 INND.BX1 1997.215 INFD.BX1 GR.BX1 38.750 CCL.BX1 -0.013 DEPT. 11896.000 SIGM. BX1 SBHN. BX1 82.844 SIGC.BX1 SDSI.BX1 0.194 BACK. BX1 TCAF. BX1 28778.695 TCND.BX1 TSCFoBX1 5907.500 INND.BX1 GR.BX1 26.703 CCL.BX1 7.044 TPHI.BX1 0.097 SIBH. BX1 198.047 FBAC.BX1 18946.328 TCFD.BX1 1939.932 INFD.BX1 0.000 25.205 142. 765 107. 973 5235. 494 328. 220 7.862 106.883 30.277 10515.512 367.538 SBHF. BX1 TRAT. BX1 TCAN. BX1 TSCN. BX1 TENS.BX1 SBHF. BX1 TRAT. BX1 TCAN. BX1 TSCN. BX1 TENS.BX1 83.397 1.651 19265.723 3852.483 1465.000 61. 002 1.187 39449. 688 8097. 970 1550. 000 ** END OF DATA ** **** FILE TRAILER **** FILE NAME : EDIT .011 SERVICE : FLIC VERSION : O01CO1 DATE : 97/09/ 5 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : **** FILE HEADER **** FILE NAFiE : EDIT .012 SERVICE · FLIC VERSION · OOiCO1 DATE : 97/09/ 5 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : FILE HEADER FILE NUM~ER 12 RAW CURVES Curves and log header data for each pass in separate files; raw background pass in last file PASS ~ER: 5 DEPTH INCRE~iENT: 0.5000 FILE SO?4~¢ARY VENDOR TOOL CODE START DEPTH STOP DEPTH TDTP 12293.0 11895.5 $ LIS Tape Verification Listing Schlumberger Alaska Computing Center 5-SEP-1997 13: 04 PAGE: 44 LOG HEADER DATA DATE LOGGED: SOFTWARE VERSION: TIME LOGGER ON BOTTOM: TD DRILLER (FT) : TD LOGGER (FT) : TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT) : LOGGING SPEED (FPHR) : DEPTH CONTROL USED (YES/NO): 18-AUG-97 CP 39. 116 1135 17-AUG-97 12276.0 12289.0 11670.0 12286.0 900.0 NO TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE GR GA~A RAY TDTP THERMAL DECAY $ TOOL NUMBER CGRS-A 805 TDIC-A 754 BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN).. DRILLERS CASING DEPTH (FT) : LOGGERS CASING DEPTH (FT) : 12404.0 BOREHOLE CONDITIONS FLUID TYPE: FLUID DENSITY (LB/G): SURFACE TEMPERATURE (DEGF) : BOTTOM HOLE TEMPERATURE (DEGF) : FLUID SALINITY (PPM) : FLUID LEVEL (FT) : FLUID RATE AT WELLHEAD (BPM) : WATER CUTS (PCT) : GAS/OIL RATIO: CHOKE (DEG) : PRODUCE FLUIDS NEUTRON TOOL TOOL TYPE (EPITHERMAL OR THERMAL): MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): THERMAL SANDSTONE 2.65 BLUELINE COUNT RATE NORMALIZATION IN OIL ZONE TOP NORMALIZING WINDOW (FT) : BASE NORMALIZING WINDOW (FT): BLUELINE COUNT RATE SCALES SET BY FIELD ENGINEER FAR COUNT RATE LOW SCALE (CPS): 0 FAR COUNT RATE HIGH SCALE (CPS): 12000 NEAR COUNT RATE LOW SCALE (CPS): 0 NEAR COUNT RATE HIGH SCALE (CPS): 30000 TOOL STANDOFF (IN): REMARKS: TIED INTO AWS DIFL DATED 9-20-95. PUMPED 80 BBLS OF BORAX AND 306 BBLS OF SW. LIS Tape Verification Listing Schlumberger Alaska Computing Center 5-SEP-1997 13:04 PAGE: 45 CHANNEL FOUND DOWN TO 12200' FROM PERF INTERVAL AT 12100' TO 12120'. THIS FILE CONTAINS THE RAW TDTP DATA FOR BORAX PASS #2. $ LIS FORMAT DATA ** DATA FORMAT SPECIFICATION RECORD ** ** SET TYPE - 64EB ** TYPE REPR CODE VALUE 1 2 3 4 5 6 73 7 65 8 68 9 65 11 66 12 68 13 66 14 65 15 66 16 66 0 66 66 0 66 0 73 88 66 1 66 0.5 FT 11 0 FT 68 1 1 ** SET TYPE - CHAN ** NAME SERV UNIT SERVICE API API API API FILE NUMB NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUMB SAMP ELEM CODE (HEX) DEPT FT 1088189 O0 000 O0 0 12 1 1 4 68 0000000000 SIGM BX2 CU 1088189 O0 000 O0 0 12 1 1 4 68 0000000000 TPHI BX2 PU 1088189 O0 000 O0 0 12 1 1 4 68 0000000000 SBHF BX2 CU 1088189 O0 000 O0 0 12 1 1 4 68 0000000000 SBHNBX2 CU 1088189 O0 000 O0 0 12 1 1 4 68 0000000000 SIGC BX2 CU 1088189 O0 000 O0 0 12 1 1 4 68 0000000000 SIBH BX2 CU 1088189 O0 000 O0 0 12 1 1 4 68 0000000000 TRAT BX2 1088189 O0 000 O0 0 12 1 1 4 68 0000000000 SDSI BX2 CU 1088189 O0 000 O0 0 12 1 1 4 68 0000000000 BACK BX2 CPS 1088189 O0 000 O0 0 12 1 1 4 68 0000000000 FBAC BX2 CPS 1088189 O0 000 O0 0 12 1 1 4 68 0000000000 TCANBX2 CPS 1088189 O0 000 O0 0 12 1 1 4 68 0000000000 TCAFBX2 CPS 1088189 O0 000 O0 0 12 1 1 4 68 0000000000 TCNDBX2 CPS 1088189 O0 000 O0 0 12 1 1 4 68 0000000000 TCFDBX2 CPS 1088189 O0 000 O0 0 12 1 1 4 68 0000000000 LIS Tape Verification Listing Schlumberger Alaska Computing Center 5-SEP-1997 13:04 PAGE: 46 NAFIE SERV UNIT SERVICE API API API API FILE NUMB NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUMB SAMP ELE~ CODE (HEX) TSCN BX2 CPS 1088189 O0 000 O0 0 12 1 1 4 68 0000000000 TSCF BX2 CPS 1088189 O0 000 O0 0 12 1 1 4 68 0000000000 INNDBX2 CPS 1088189 O0 000 O0 0 12 1 1 4 68 0000000000 INFD BX2 CPS 1088189 O0 000 O0 0 12 1 1 4 68 0000000000 TENS BX2 LB 1088189 O0 000 O0 0 12 1 1 4 68 0000000000 GR BX2 GAPI 1088189 O0 000 O0 0 12 1 1 4 68 0000000000 CCL BX2 V 1088189 O0 000 O0 0 12 1 1 4 68 0000000000 ** DATA ** DEPT. 12293.000 SIGM. BX2 7.044 TPHI.BX2 7.862 SBHF.BX2 61.002 SBP~N. BX2 82.844 SIGC.BX2 0.097 SIBH.BX2 106.883 TRAT. BX2 1.187 SDSI.BX2 0.194 BACK. BX2 198.047 FBAC.BX2 30.277 TCAN. BX2 39449.688 TCAF. BX2 28778.695 TCND.BX2 18946.328 TCFD.BX2 10515.512 TSCN. BX2 8097.970 TSCF. BX2 5907.500 INND.BX2 1939.932 INFD.BX2 367.538 TENS.BX2 1625.000 GR.BX2 50.125 CCL.BX2 -0.022 DEPT. 11895.500 SIGM. BX2 7.023 TPHI.BX2 8.422 SBHF. BX2 60.947 SBHN. BX2 81.977 SIGC.BX2 0.103 SIBH. BX2 105.717 TRAT. BX2 1.216 SDSI.BX2 0.179 BACK. BX2 187.007 FBAC.BX2 33.621 TCAN. BX2 41159.539 TCAF. BX2 29253.824 TCND.BX2 19363.805 TCFD.BX2 10583.797 TSCN. BX2 8311.555 TSCF. BX2 5907.374 INND.BX2 2151.052 INFD.BX2 358.108 TENS.BX2 1540.000 GR.BX2 33.094 CCL.BX2 0.000 ** END OF DATA ** **** FILE TRAILER **** FILE NA~IE : EDIT .012 SERVICE : FLIC VERSION : O01CO1 DATE : 97/09/ 5 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : **** FILE HEADER **** FILE NAFiE : EDIT .013 SERVICE : FLIC VERSION : O01CO1 DATE : 97/09/ 5 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : LIS Tape Verification Listing Schlumberger Alaska Computing Center 5-SEP-1997 13:04 PAGE: 47 FILE HEADER FILE NIIMBER 13 RAW CURVES Curves and log header data for each pass in separate files; raw background pass in last file PASS NUAIBER : 6 DEPTH INCREMENT: 0.5000 FILE SUFmL~Y VENDOR TOOL CODE START DEPTH TDTP 12293.0 $ LOG HEADER DATA DATE LOGGED: SOFTWARE VERSION: TIldE LOGGER ON BOTTOM: TD DRILLER (FT) : TD LOGGER (FT) : TOP LOG IAFTERVAL (FT) : BOTTOM LOG INTERVAL (FT) : LOGGING SPEED (FPHR) : DEPTH CONTROL USED (YES/NO): STOP DEPTH 11893.5 18-AUG-97 CP 39.116 1135 17-AUG-97 12276.0 12289.0 11670.0 12286.0 900.0 NO TOOL STRING (TOP TO BOTTOM) VEJfDOR TOOL CODE TOOL TYPE GR GA~4~A RAY TDTP THERMAL DECAY $ TOOL NUMBER CGRS-A 805 TDIC-A 754 BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLERS CASING DEPTH (FT) : LOGGERS CASING DEPTH (FT) : 12404.0 BOREHOLE CONDITIONS FLUID TYPE: FLUID DENSITY (LB/G): SURFACE TEMPERATYJRE (DEGF) : BOTTOM HOLE TEMPERATURE (DEGF): FLUID SALINITY (PPM) : FLUID LEVEL (FT) : FLUID RATE AT WELLHEAD (BPM) : WATER CUTS (PCT) : GAS~OIL RATIO: CHOKE (DEG) : PRODUCE FLUIDS NEUTRON TOOL TOOL TYPE (EPITHERMAL OR THERMAL): MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): THERMAL SANDSTONE 2.65 BLUELINE COUNT RATE NORMALIZATION IN OIL ZONE LIS Tape Verification Listing Schlumberger Alaska Computing Center 5-SEP-1997 13:04 PAGE: 48 TOP NORMALIZING WINDOW (FT): BASE NORMALIZING WINDOW (FT) : BLUELINE COUNT RATE SCALES SET BY FIELD ENGINEER FAR COUNT RATE LOW SCALE (CPS): 0 FAR COUNT RATE HIGH SCALE (CPS): 12000 NEAR COUNT RATE LOW SCALE (CPS): 0 NEAR COUNT RATE HIGH SCALE (CPS): 30000 TOOL STANDOFF (IN): REMARKS: TIED INTO AWS DIFL DATED 9-20-95. PUMPED 80 BBLS OF BORAX AND 306 BBLS OF SW. CHANNEL FOUArDDOWN TO 12200' FROM PERF INTERVAL AT 12100' TO 12120'. THIS FILE CONTAINS THE RAWTDTP DATA FOR BORAX PASS #3. $ LIS FORMAT DATA ** DATA FORMAT SPECIFICATION RECORD ** ** SET TYPE- 64EB ** TYPE REPR CODE VALUE 1 66 0 2 66 0 3 73 88 4 66 1 5 66 6 73 7 65 8 68 0.5 9 65 FT 11 66 11 12 68 13 66 0 14 65 FT 15 66 68 16 66 1 0 66 1 ** SET TYPE - CHAN ** NAME SERV UNIT SERVICE API API API API FILE NUMB NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUMB SAMP ELE~ CODE (HEX) DEPT FT 1088189 O0 000 O0 0 13 1 1 4 68 0000000000 SIGM BX3 CU 1088189 O0 000 O0 0 13 1 1 4 68 0000000000 TPHI BX3 PU 1088189 O0 000 O0 0 13 1 1 4 68 0000000000 LIS Tape Verification Listing Schlumberger Alaska Computing Center 5-SEP-1997 13:04 PAGE: 49 NAM~ SERV UNIT SERVICE API API API API FILE NUMB NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUMB SAMP ELEM CODE (HEX) SBHF BX3 CU 1088189 O0 SBHIVBX3 CU 1088189 O0 SIGC BX3 CU 1088189 O0 SIBH BX3 CU 1088189 O0 TRAT BX3 1088189 O0 SDSI BX3 CU 1088189 O0 BACK BX3 CPS 1088189 O0 FBAC BX3 CPS 1088189 O0 TCANBX3 CPS 1088189 O0 TCAFBX3 CPS 1088189 O0 TCNDBX3 CPS 1088189 O0 TCFD BX3 CPS 1088189 O0 TSCNBX3 CPS 1088189 O0 TSCF BX3 CPS 1088189 O0 INNDBX3 CPS 1088189 O0 INFD BX3 CPS 1088189 O0 TENS BX3 LB 1088189 O0 GR BX3 GAPI 1088189 O0 CCL BX3 V 1088189 O0 000 O0 0 13 1 1 4 68 0000000000 000 O0 0 13 1 1 4 68 0000000000 000 O0 0 13 1 1 4 68 0000000000 000 O0 0 13 1 1 4 68 0000000000 000 O0 0 13 1 1 4 68 0000000000 000 O0 0 13 1 1 4 68 0000000000 000 O0 0 13 1 1 4 68 0000000000 000 O0 0 13 1 1 4 68 0000000000 000 O0 0 13 1 1 4 68 0000000000 000 O0 0 13 1 1 4 68 0000000000 000 O0 0 13 1 1 4 68 0000000000 000 O0 0 13 1 1 4 68 0000000000 000 O0 0 13 1 1 4 68 0000000000 000 O0 0 13 1 1 4 68 0000000000 000 O0 0 13 1 1 4 68 0000000000 000 O0 0 13 1 1 4 68 0000000000 000 O0 0 13 1 1 4 68 0000000000 000 O0 0 13 1 1 4 68 0000000000 000 O0 0 13 1 1 4 68 0000000000 ** DATA ** DEPT. 12293.000 SIGM. BX3 7.023 TPHI.BX3 8.422 SBHF.BX3 SBHN. BX3 81.977 SIGC. BX3 0.103 SIBH. BX3 105.717 TRAT. BX3 SDSI.BX3 0.179 BACK. BX3 187.007 FBAC. BX3 33.621 TCAN. BX3 TCAF. BX3 29253.824 TCND.BX3 19363.805 TCFD.BX3 10583.797 TSCN. BX3 TSCF. BX3 5907.374 INND.BX3 2151.052 INFD.BX3 358.108 TENS.BX3 GR.BX3 48.531 CCL.BX3 -0.013 DEPT. 11893.500 SIGM. BX3 6.832 TPHI.BX3 8.750 SBHF.BX3 SBHN. BX3 71.308 SIGC.BX3 0.118 SIBH. BX3 88.703 TRAT.BX3 SDSI.BX3 0.181 BACK. BX3 186.539 FBAC.BX3 33.243 TCAN. BX3 TCAF.BX3 31344.980 TCND.BX3 22063.527 TCFD.BX3 11605.453 TSCN. BX3 TSCF.BX3 6423.495 INND.BX3 1962.018 INFD.BX3 387.534 TENS.BX3 GR.BX3 40.844 CCL.BX3 0.000 60.947 1.216 41159.539 8311.555 1595.000 55.180 1.243 44946.852 9210.914 1490.000 ** END OF DATA ** LIS Tape Verification Listing Schlumberger Alaska Computing Center 5-SEP-1997 13:04 PAGE: 50 **** FILE TRAILER **** FILE NAlV~ : EDIT .013 SERVICE : FLIC VERSION : O01CO1 DATE : 97/09/ 5 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE **** TAPE TRAILER **** SERVICE NA~I~ : EDIT DATE : 97/09/ $ ORIGIN : FLIC TAPE NA~E : 97396 CONTINUATION # : 1 PREVIOUS TAPE : COf~T : BP EXPLORATION, 1-33/M-23, ENDICOTT, 50-029-22577-00 **** REEL TRAILER **** SERVICE NA~E : EDIT DATE : 97/09/ 5 ORIGIN · FLIC REEL NA~E : 97396 CONTINUATION # PREVIOUS REEL CO~4ENT : BP EXPLORATION, 1-33/M-23, ENDICOTT, 50-029-22577-00
