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197-085
AoGcC Geological Materials Inventory TD ~ ~ PERMIT 9 7-085 Log Data 8252 ,~'/' BH ZIPPED DPR 8313 q~SCHLUM MWD-DSI/BHC/LDT/CNTH 8314 '3>/' SCHLUM MDT 8315 ~ BH DPR ~'"~B~IC S L 3970-9552 / d..C't~i"DT L 227-10254~'~' /JCP'~./GR-M D ~/~' 989-10229 ~R/GR-TVD L 989-8559 ~ ~SI L 3484-1024~" ./ ,, ',g~W L ~60-8712 [~UD LOG L ~(C) 1020-10286 ,,, '~UD LOG L t~020-, 0286 SRVY CALC. D ...... BH 280.-10286. SRVY CALC. ~Btt 280.-10286. SW CORE DESCRIPT ~ .... 4432-10270 VSP ~/"'5000-8500 ~0-407 Completion Date ..])',/(~/ ~*'~ 'Daily well ops Are dry ditch samples required? Was the well cored? ARCO Sent Received 2/26/1998 2/24/1998 2/26/1998 2/24/1998 2/26/1998 2/24/1998 2/26/1998 2/24/1998 2/27/1998 2/24/I 998 2/27/1998 2/24/1998 2/27/1998 2/24/1998 2/26/1998 2/24/1998 2/27/I 998 2/24/1998 2/27/1998 2/24/1998 2/27/1998 2/24/1998 D 2/27/1998 2/24/1998 2/27/1998 2/24/1998 2/27/1998 2/24/1998 2/27/1998 2/24/1998 D 2/27/1998 2/24/1998 2/27/1998 2/24/1998 Are tests required? Well is in compliance Comments Box I-'~.-yes I'.'i.. I no And received? i~yes i1 no I:-".:1 yes r: ':':1 no ~,,.,,~ (.: 0~, nalysis escription received? [ ...... ~ yes [.~no Received? [.:.[ yes t: -I no ~,fl Initial / 4'~'"~}L~'? ' Wednesday, October 13, 1999 Page I of l ARCO Alaska, Inc. Post Office Bt,. 00360 Anchorage Alaska 99510-0360 Telephone 907 265 6136 Mark A. Major Permits Director May 11, 1999 Ms. Jana Harcharek North Slope Borough (NSB) Inupiat History, Language, and Culture Commission (IHLC) P. O. Box 69 Barrow, AK 99723 Subject: Discovery of Sea Floor Anomaly Warthog #1 Exploration Well Area Dear Ms. Harcharek: In accordance with the terms and conditions of the NSB development permit for the Warthog #1 exploration well (NSB 97-091 and amendments), ARCO Alaska, Inc. (AAI) is providing formal notification to the NSB IHLC of a recent discovery of an anomaly on the sea floor about two miles southwest of the Warthog #1 exploration well site. Attached for your information and use is a May 6, 1999 document prepared by the Minerals Management Service (MMS) that provides detailed information regarding this discovery. As you will note in your review of this material, the anomaly is unidentified at this time. However, the favored interpretation of this object at this time is an aircraft fuselage. If you have any questions about this matter, please feel free to contact the State Historic Preservation Office (Mr. Robert Shaw), the Minerals Management Service (Mr. Dennis Thurston), the Alaska Department of Natural Resources (Ms. Carol Lee), and/or the Alaska Oil and Gas Conservation Commission (Mr. Robert Crandall). Additionaiiy, you are also welcome to contact me by e-mail at mmajor@mail.arco.com or by phone at 265-6136 if I can be of further assistance. Sincerely, Mark Major Exploration Permits Director Attachment ARCO Alaska. Inc. is a Subsidiary of Atlantic Richfield Company May 11, 1999 N,_,.~ IHLC Correspondence Discovbry of Sea Floor Anomaly - Warthog #1 Exploration Well Page 2 of 2 Exploration Permits Director Attachment C: · //Robert Crandall, AK Oil & Gas Conservation Commission - Anchorage Jon Dunham, NSB Planning - Barrow Carol Lee, AK Department of Natural Resources - Anchorage Robert Shaw, State Historic Preservation Office - Anchorage Dennis Thurston, Minerals Management Service - Anchorage (all without attachment) AOGCC Individual Well Page: 1 Geological Materials Inventory Date: 11/25/98 / PERMIT DATA T DATA PLUS RUN RECVD D ......... .......................................... .............. 97-085 VSP ~'/5000-8500 02/24/98 97-085 SW CORE DESCRIPT~"~432-10270 02/24/98 97-085 SRVY CALC. ~/~H 280.-10286. 02/24/98 D 97-085 SRV~ CaLC. ~H 28O.-1O286. 02/24/98 97-085 MUD nOG ~)/~CII FORMAT 1020-10287 02/24/98 97-085 MUD LOG c-~'~020-10286 02/24/98 97-085 MUD nOG ~L(C) 1020-10286 02/24/98 D 97-085 MDT ~160-8712 FINAL 02/24/98 97-085 BHCS ~/~ 970- 9552 FINAL 02/24/98 97-085 PSI ~/3484-10244 FINAL 02/24/98 97-085 CN/LDT ~a/227-10254 FINAL 02/24/98 97-085 DPR/GR-MD ~89-10229 FINAL 02/24/98 97-085 DPR/GR-TVD ~'~9-8559 FINAL 02/24/98 97-085 8313 ~C'~SCHLUM MWD-DSI/BHC/LDT/CNTH 1 02/24/98 97-085 8314 ~' SCHLUM MDT 1 02/24/98 97-085 8315 ~/~ DPR 2,4-7 02/24/98 97-085 8252 ~"~BH ZIPPED DPR 2,4-7 02/24/98 10-407 ~Lf/COMPLETION DATE ,/~ 4 /f'~/ /~/'l~,!/ ~/ DAILY WELL OPS ~R~'/ // /fT/ TO /J~/~/~/ ~,,~/~/ Are dry ditch samples required? yes no And received? yes no Was the well cored? ~ no~~ &[fde~-ption~)eceivedv.y~s) Are well tests required? yes Well is in compliance COMMENTS Initial no ARCO Alaska, Inc. '_ ~' i~ ,~-,.~.~ ,~ ,ii !' _,-. ~ !'. May 12, 1998 Mr. David 3.3ohnston Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Re' Transmittal of Confidential Well Information, Warthog #1 Dear Mr. 3ohnston: ARCO Alaska, Inc., as Operator of the Warthog #1 exploration well in Camden Bay is submitting well information as required in the Alaska Oil And Gas Conservation Commission (AOGCC), Alaska Administrative Code, Title 20, Chapter 25.070, Records and Reports. A phone conversation and follow up memo dated May 5th from Mr. Howard Okland brought to our attention that some required information was missing, while other information had been duplicated. The missing information enclosed within, memo includes the FIT's for the 13 3/8" and 9 5/8" casing shoes and the J~rl~Dual Propagation Resistivity Log, as 2 copies of the ~ ~ were mistakenl~'~submitted to the AOGCC initially. No electric line resisl~i~t~-y logs were run in the Warthog Well. No conventional core was cut and so an analysis will not be forthcoming. Work has been initiated on the geochemical and biostratigraphic reports and analyzes and they will be submitted when they become available. As Operator of the Warthog #1, ARCO Alaska, Inc. is requesting that the AOGCC keep this information extremely confidential. Thank you in advance for your continued efforts in keeping this well information confidential. Please call me at 263-4603 if you have any questions. Sincerely, Paul Mazzolini Exploration Team Leader MEMORANDOM STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION Date: 5 May, 1998 To: From: Bob Crandall Sr. Petroleum Geologist Howard Okland Petroleum Geology Assistant Subj: Phone conversation with Paul Mazzolini, ARCO (263-4603) At approximately 8:45 AM on May 5th I called Pa~ni atj~,~L~ ARCO inquiring about certain data from the ARCOk.~rthog ~ ~ .~ Exploration well (PTD 97-085). This data is require~y -~ regulation to be submitted to the Commission upon completion of a well and as of this date have not been received. The following data are missing: Wireline Resistivity Log (B.L. and Sepia) Wireline FIT Log (B.L. and Sepia) DPR/GR-TVD (Sepia) Core Analysis Report I asked Paul to look into getting the missing data sent over to us and he said that he contact the people responsible for the data. He also said he would get back to me in the next day or so and inform me when the Commission could expect delivery of the data. I'll be informing you of the progress made on obtaining these data. cc: Paul Mazzolini ARCO ?~ !~,)7%, h,~ ~,· PERMIT DATA 97-085 97-085 97-085 97-085 97-085 97-085 97-085 AOGCC Individual Well Geological Materials Inventory T DATA PLUS VSP ~ 5000-8500 SW CORE DESCRIPT ~432-10270 MUD LOG MUD LOG MUD LOG Page: 1 Date: 04/21/98 RUN RECVD /-y;,,.~- .~. ,. o2/24/98 ~/BH 280.-10286. Z.D" BH 2 8 0 . - 10 2 8 6 . ~, ~., 'i'.: ~..: ,,',~ 02/24/98 02/24/98 D 02/24/98 ~.~:'AS C I I FORMAT 1020-10287 --; ~,_,.?,t~..~,.~... %? o,':,'.c .~,.., "" 1020-10286 02/24/98 ~E/BL (C) 1020-10286 02/24/98 D 97-085 97-085 97-085 97-085 97-085 97-085 97-085 MDT BHCS DSI CN/LDT DPR/GR-MD DPR/GR-TVD 8313 FINAL 02/24/98 FINAL 02/24/98 FINAL 02/24/98 FINAL 02/24/98 L 989-10229 [~ ~~"" FINAL 02/24/98 L 989-8559 ~ ~- ~'\"I FINAL ~/SCHLUM MWD-DSI/BHC/LDT/CNTH 1 02/24/98 97-085 8314 1 02/24/98 97-085 8315 ~BH DPR 2,4-7 02/24/98 97-085 8252 &~ BH ZIPPED DPR 2,4-7 02/24/98 10-407 DAILY WELL OPS ~COMPLETION ,D%TE I~kl ~' I':f '?/ Fu,,'',',- ¥ ,~ ...... ,'!,~?i,.~,f/ R /// / /~7./ TO / / / ,,?/.,~ ?,,/ / / / Are dry ditch samples required? yes no And received? ~ th~ ~ cored? ,~ no An~±% ~ d~or±pt±o%~?~o~v~d? ~"~.~...,..,~ .... ~,~' ~u_~4~ ~ ~7'i; ~. ~-~..,~' ~'~,~./~ ?"'~' Are well te~ts requmred? yes no Received? ........ yes---no ....... Well f~ in compliance Initial COMMENTS yes no yes no ARCO Alaska, Inc, Post Office Box 100360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 February 26, 1998 Mr. David J. Johnston Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 RE: Transmittal of Confidential Well Information, Warthog #1 Dear Mr. Johnston: ARCO Alaska, Inc. as Operator of the Warthog #1 exploration well in Camden Bay is submitting well information as required in the Alaska Oil And Gas Conservation Commission (AOGCC), Alaska Administrative Code, Title 20, Chapter 25.070, Records and Reports. Enclosed with the transmittal letter are the final electric line logs, LWD/MWD logs, MDT formation pressure data, the sidewall cores with associated descriptions and final mud logs for the open hole section of the well to 10,296' MD, 8602' TVD. Please see attachment for detailed list of final well information being submitted. Work has been initiated on the geochemical and biostratigraphic reports and analyzes and they will be submitted when they become available. As Operator of the Warthog #1 ARCO Alaska, Inc. is requesting that the AOGCC keep this information extremely confidential. Thank you in advance for your continued efforts in keeping this well information confidential. Please call me at 263-4603 if you have any questions. ..~,~ .... . .... Sincerely, Paul Mazzolini Senior Staff Drilling Engineer Warthog Final Well Information Transmittal Mud Log Data ~,.e~:O ~,'~ - Final composite mudlog, ~ & color copy , Reproducible composite mudlog · Floppy disk, ASCII Format - ~,~ u,.o co ch I , Electric Line Logs · LIS tape with openhole MWD / DSI / BHC / LDT / CNTH -- T~(>~_ - LDT / CNTH log, final & reproducible · BHC log, final & reproducible DSI log, final & reproducible · LIS tape of MDT Pressure data ---- W'~_ qT~-~. ~'-~ MDT log, final & reproducible VSP Report, floppy disk (ASCII Format), velocity survey log & computer processed interpretation ~ t~\~-,~ ~,'~,~:~ ~. I ~rct- Sidewall core depth & description LWDfMWD Logs ~ Floppy disk LASASCII Format of logs '~-..- d .. ° Dual Propagation Resistivity, Gamma Ray RWD fina! & reproducible (2 copies of ea.) Final directional survey data r¢~- ~vq o, uc_ · Floppy disk, ASCII Format of directional surveys * LIS tape & 4 mm data tape _.. TI',D~_ -"&PO-.~ ~4 t'~,~. ,ff c_.~t ~ ,,:.~,,~ ) ,! ARCO Oil and Gas Company,. ORIGINAl Jidewali Sample Description Operator and Well Name '- -._¢ j % J ~ 'J J '~ ~ ~_ _ ' ARCO Warthog #1 ~ I ¢ ~ ~. .-r~ t ~j~ ~liage j7°f Location 'VI ~ ~ t~. ~ L ~ t~ ~~= ~)ate Beaufort Sea, Alaska Dec. 4, 1997 Shot '. Re~°~t~red1 - .... _ Depth Rec. Description % Oil Odor Oil Fluor · Cut Cut fluor Show Stain % Intensity Color color color sum 4432 1.5 Mudstone, medium brownish grey, None No None slightly silty, soft, plastic, slightly ne calcareous 4542 1.5 Mudstone, medium brownish grey, None No None slightly silty, soft, plastic, highly ne calcareous 4693 1.5 Thin interbeds of muddy, sandy None No None None None None siltstone, and very fine grain ne sandstone, light grey brown, non to slightly calcareous, trace organics 4814 1.5 Mudstone, medium brownish grey, None No None '~':" . slightly silty, soft, plastic, slightly ne calcareous "'"",;. ' ~" "~ .. ,; , ,¢.. , , 4927 1.5 Mudstone, medium brownish grey, None No None .,:~.,,.:. :.;,;.!..;!;: :~, .... "~,.,~ ,. ..' . slightly silty, soft, plastic, blebs of white, very fine sandstone, massive appearance, highly calcareous .... 4995 1,5 Thin interbeds of muddy, sandy None No None None None None siltstorne, and very fine grain ne sandstone, medium grey brown, very calcareous 5015 1.5 Mudstone, medium brownish grey,' None No .None soft, massive, highly calcareous ne 5028 1.5 Mudst°ne, mediurn brown grey, soft, None No None slightly silty, massive, highly ne calcareous 5125 0.5 Sandstone, shattered, salt and pepper, None No None None None None fine grain, calcareous cement, poorly ne sorted, Iow P &P, quartz, black lithic and/or chert .,, 5131 1.5 Sandy Muddy Siltstone, medium brown None No None None None None grey, mostly very fine sand, ne discontinuOus thin subparallel laminations, highly clacareous ., 5173 1.5 Mudstone, medium brown grey, soft, None No None massive, highly calcareous ne 5295 1.5 Muddy Sandstone, fine with occasional None No None None None None medium sand, moderately sorted, ne friable, moderate to highly calcareous, quartz and black lithic/chert grains, trace pyrite iVN 5306 1.0 Sandstone, light grey, fine sand, None No None None None None friable, highly calcareous, moderately ne sorted, clear and translucent quartz, black lithic/chert, trace pyrite 5327 1.5 Sandstone, medium grey, very fine None No None None None None sand, poorly sorted, calcareous ne cement, quartz, black lithics/chert, possibly tuffaceous 5378 1.5 Mudstone, medium brown grey, highly None No None calcareous, soft, massive, silty zones ne 5453 1.25 Silty Mudstone, medium brown grey, None No None soft, moderate to highly calcareous ne 5463 1.25 Muddy Sandstone, medium grey, None no None None None None mostly very fine to fine, poorly sorted, ne highly calcareous, calcareous cement, possibly tuffaceous 5985 1.5 Mudstone, medium brown grey, None No None moderately to highly calcareous, soft, ne massive 6225 1.5 Mudstone, medium brown grey, slightly None No None calcareous, soft, massive ne 6280 1.5 Sandstone, light grey, very fine to fine None No None None None None sand, highly calcareous, friable, clear ne and translucent quartz, black lithics/chert. 6284 1.5 Sandstone, light grey, veryfineto fine None No None None None None sand, highly calcareous, friable, clear ne and translucent quartz, black lithics/chert. ,, 6364 1.5 Muddy Siltstone, medium grey brown, None No None firm, no apparent laminations, highly ne calcareous 6395 1.0 Sandstone, very disturbed, mostly fine None No None None None None to very fine, very calcareous, with ne calcareous cement, possibly tuffaceous, trace pyrite 6402 1.5 TuffaceoUs Sandstone, light-medium None No None None None None grey, very fine grained, subparallel ne laminations, clear quartz and black lithics, very calcareous Many of the sandstone cores are deeply invaded by mud filtrate. ARSB-2S89-B Described by D. Bannan ORIGINAL ARCO Oil and Gas Company ,Sidewall Sample Description Operator and Well Name Page of Warthog #1 3 I 7 Location Date Beaufort Sea, Alaska Dec. 4,1997 Shot Recovered Depth Rec. Description % Oil Odor Oil Fluor Cut Cut fluor Show Stain % Intensity Color color color sum 6615 1.5 Silty Mudstone, medium brown grey, None No None soft, moderately calcareous ne 6638 1.5 Muddy Sandstone, medium grey, None No None None None None mostly very fine grain, friable, non to ne sloghtly calcareous, trace pyrite and organics 7025 1.5 Tuffaceous Siltstone, light grey, None No None None None None moderately calcareous, subparallel ne discontinous laminations 7093 1.25 Tuffaceous silty Sandstone, light grey, None No None None None None highly calcareous, abundant silt size ne pyrite through out sample 7350 1.5 Pebble Mudstone, light-medium grey None No None None None None brown, scattered sand grains ranging ne from coarse to 5 mm, no bedding, slightly calcareous 7495 1.5 Siltstone, medium brown grey, firm, None No None None None None highly calcareous ne 7578 1.5 Sandstone, light grey, very fine to None No None None None None medium, friable, non to slightly ne calcareous, clear and white quartz 60% with some black lithics 30% 7723 1.5 Sandy, silty, Mudstone, medium brown None No None None None None - grey, soft, non to slightly calcareous ne 7853 1.5 Sandstone, light- medium grey, very None No None None None None fine to medium sand, friable, poorly ne sorted, moderately calcerous, clear and white quartz, black lithics 7965 1.0 Tuffaceous Siltstone, light grey, non to None No None slightly calcareous, scattered silt size ne pyrite 8095 1.5 Sandstone, medium grey, fine grain, None No None None None None friable, quartz and lithics grains ne SOme moderately calcareous, 1/3 of sample bright ~s an orange brown highly calcareous yellow zone which may represent a fracture orange fill min,fluor 8395 1.0 Silty Sandstone, medium grey, very None No None None None None fine to fine sand, friable, non to slightly ne calcareous, clear and white quartz and black lithics 8456 1.25 Tuffaceous SandsTone, light grey, very None No None None None None fine to medium grain, friable, poorly ne sorted, white material mineral binds most of sand grains, non to slightly calcareous, clear and translucent quartz and black lithics, trace organics 8495 1.25 Sandstone, medium grey brown, None No None None None None mostly very fine to fine grain, firm, non ne to slightly calcareous, equal amounts quartz and black lithics, trace organics 8507 1.25 Tuffaceous Sandstone, medium grey, None No None None None None very fine to medium grain, friable, ne poorly sorted, non calcareous, quartz and lithic grains 8520 1.0 Sandstone, medium grey, very fine to None no None None None None medium grained, friable, abundant ne pryrite scattered through out, non to slightly calcareous, tuffaceous 8552 1.25 Tuffaceous Sandstone, light grey, very None no None None None None fine to medium grain, friable, poorly ne sorted, non to slightly calcareous, quartz and lithic grains, organics and pyrite scattered throughout 8585 1.5 Mudstone, medium grey brown, None No None None None None scattered pyrite, slightly to moderately ne calcareous, soft ..... 8587 1.5 Sandstone, medium to light grey, very None No 20 weak yello none instan Poor fine to coarse, friable, non calcareous, ne % w t pale scattered pyrite throughout, quartz and yellow black lithics ,, 8714 1.5 Sandstone, light grey, very fine to fine None No None None None None grained, well sorted, friable, mostly ne quartz with some black and brown lithics, moderately calcareous 8754 1.25 Sandstone, light grey, very fine-fine None No None None None None with some medium sand, friable, ne subparallel laminations, very calcareous, quarz and black lithics 8781 1.5 Tuffaceous Siltstone, light grey, None No None scattered pyrite, non to slightly ne calcareous, very firm 8797 1.25 Sandstone, light grey, very fine to fine, None No None None None None friable, well sorted, very calcareous, ne mostly clear and white quartz with black lithics 8803 1.25 Sandstone, light grey, very fine to fine, None no None None None None friable, mod. Sorting, moderately ne calcareous, mostly clear quartz with black lithics Remarks Many of the sandstones have been invaded by drilling mud. Described by D. Bannan ORIGINAL ARCO Oil and Gas Company ,.4idewall Sample Description Operator and Well Name Page of Warthog #1 5 I 7 Location Date Beaufort Sea, Alaska Dec. 4, 1997 Shot Recovered Depth Rec. Description % Oil Odor Oil Fluor Cut Cut fluor Show Stain % Intensity Colorcolor color sum 8807 1.5 Sandstone, medium grey, very fine to None No None None None None fine, muddy, poorly sorted, friable, ne moderately calcareous, organic fragments, quartz and lithic grains 8813 1.5 Sandstone, medium grey, very fine to None No None None None None fine grained, friable, heavily invaded ne with mud filtrate, moderately calcareous, poorly sorted, mostly quartz with some dark lithics 8823 1.25 Silty Sandstone, medium grey, very None no None None None None fine to fine, friable, poorly sorted, ne moderately calcareous, mostly quartz with black lithics 8834 1.25 Silty Sandstone, medium grey, very None No None None None None fine to fine, friable, moderately ne calcareous, pyrite scattered throughout, subparallel laminations ..... 8846 1.5 Clayey Sandstone, medium grey, very None No None None None None fine, friable, scattered tuffaceous ne material, moderately calcareous, subparallel laminations 8858 1.5 Sandstone, medium grey, very fine to None No None None None None medium grain, friable, moderately ne sorted, non - slightly calcareous, quartz with black and brown lithics. 8904 1.5 ~/2 Mudstone, dark grey, silty, firm, None no None None None None moderately calcareous. 1/2 Sandstone, ne light grey, fine to medium, friable, moderately sorted, moderately calcareous 8917 1.25 Sandstone, medium grey, very fine to None No None None None None fine, friable, slity, poorly sorted, slightly ne calcareous, 9096 1.5 Thinly interbedded Mudstones and None No None None None None Sandstones. Mudstone, dark grey, ne firm, slightly calcareous. Sandstone, light grey, very fine to fine, moderately sorted, moderately calcareous 9143 1.5 Thinly interbedded Mudstones and None No None None None None Sandstones. Mudstone, dark grey, ne firm, slightly calcareous. Sandstone, light grey, very fine to fine, moderately sorted, moderately calcareous 9164 1.25 Sandstone, medium grey, very fine to None No None None None None medium, silty, moderately sorted, ne subparallel laminations, moderately calcareous. 9200 1.25 Silty Sandstone, medium grey, very None No None None None None fine to fine, silty, poorly sorted, very ne calcareous 9276 1.25 Silty Sandstone, medium grey, very None No None None None None fine, silty, poorly sorted, friable, slightly ne calcareous 9325 1.0 Sandstone, light grey, very fine to None No None None None None medium, moderately sorted, friable, ne moderately calcareous, subparallel stringers of mudstone with pyrite. 9420 1.0 Mudstone, medium grey, silty, firm, None No yelow- None None None very calcareous, with thin laminations ne orange of very calcareous, fine to medium, min. grey, sandstone fluor ,, 9550 1.5 Sandstone, light grey, very fine to fine, None No None None None None slightly silty, friable, moderately to well ne sorted, slightly calcareous 9645 1.25 Mudstone, medium grey, firm, None No None moderately calcareous, with thin ne laminations of light grey, fine sandstone 9654 1.25 Sandstone, light grey, very fine to None No None None None None medium, moderately sorted, friable, ne slightly calcareous, subparallel stringers of mudstone 9660 1.25 Mudstone, dark grey, sandy, firm, None No None pyrite scattered throughout ne 9693 1.25 Mudstone, dark grey, very firm, slightly None No None None None None calcareous, possibly tuffaceous ne 9696 1.5 Sandstone, medium grey, very fine to None no None None None None fine, friable, moderately sorted, ne moderately calcareous, clear and white quartz with black and brown lithics, faint subparallel laminations 9715 1.5 Tuff?, light brown, hard chalky None No None None None None appearance with some cemented clear ne quartz? Crystals 9724 1.5 ¼ Mudstone, dark grey, silty, firm, None No None None None None moderately calcareous. Y2 Sandstone, ne light grey, fine to medium, friable, moderately sorted, moderately calcareous. Abundant pyrite scattered throughout both units 9945 1.25 Sandy Mudstone, light grey brown, None No None None None None firm, very calcareous, with thin fine ne sand stringers D ~-~ ~ ~ ,~1.~ _ Many of the sandstone samples are deeply invaded by drilling mud. Described by D. Bannan ARCO Oil and Gas Company 5idewati Sample Description Operator and Well Name Page - of Warthog #1 7 ~ 7 Location Date ..L Beaufort Sea, Alaska Dec. 4, 1997 Shot Recovered Depth Rec. Description % Oil Odor Oil Fluor Cut Cut fluor Show Stain % Intensity Colorcolor color sum 9976 1.25 Interbedded Sandstone and Mudstone. None No None None None None Sandstone light grey, very fine to ne medium, friable, moderately calcareous. Mudstone, dark grey, firm, slightly calcareous 10024 1.25 Interbedded Mudstone and Sandstone. None No None None None None Mostly Mudstone, dark grey, firm, ne slightly calcareous w/sandstone; light grey, very fine to medium, friable, slightly calcareous. 10082 1.25 Interbedded Sandstone and Mudstone. None No None None None None Sandstone light grey, very fine to ne medium, friable, highly calcareous. Mudstone, dark grey, firm, highly calcareous 10092 1.5 Interbedded Mudstone and Sandstone. None No None None None None Mostly Mudstone, dark grey, firm, ne highly calcareous w/sandstone; light grey, very fine to fine, friable, highly calcareous. 10156 1.5 Interbedded Sandstone and Mudstone. None No None None None None Sandstone light grey, very fine to ne medium, friable, slightly calcareous. Mudstone, dark grey, firm, moderately calcareous, trace organics 10245 1.25 Interbedded Mudstone and Sandstone. None No None None None None Mostly Mudstone, dark grey, firm, ne moderately calcareous w/sandstone; light grey, very fine to fine, friable, moderately calcareous, 10270 1.25 Interbedded Mudstone and Sandstone. None No None None None None Mostly Mudstone, dark grey, firm, ne slightly calcareous w/sandstone; light grey, very fine to fine, friable, slightly calcareous, subparallel laminations. Remarks Sandstones are often deeply invaded by drilling mud. Described by D. Bannan ~arget TVD Target Description Target Direction Date ,,, -NOV-97 01-NOV-97 01-NOV-97 01-NOV-97 01 -NOV-97 01-NOV-97 01-NOV-97 02-NOV-97 05-NOV-97 05-NOV-97 95<NOV-97 NOV-97 SURVEY CALCULATION AND FIELD WORKSHEET Job No. 0450-90728 Company FAIRWEATHER E & P SERVICES, INC. Rig Contractor & No. Glomar Marine - CIDS _. Well Name & No. ARCO-WARTHOG #1 Survey Section Name MWD WELL DATA Target Coord. N/S Slot Coord. N/S 855.00 Grid Correction 0.000 'd' Sidetrack No. Page I of 5 Field BEAUFORT SEA BHI Rep. ~!!J_~F~_, 05-NOV-97 05-NOV-97 05-NOV-97 05-NOV-97 05-NOV-97 06-NOV-97 06-NOV-97 06-NOV-97 06-NOV-97 (DD) Target Coord. E/W Slot Coord. E/W Build\Walk\DL per: 100ft[~ 30m ~] 10m ~] Vert. Sec. Azim. SURVEY DATA 1724.00 217.09 Magn. Declination 30.330 Calculati(m Method MINIMUM CURVATURE Magn. to Map Corr. 30.330 Map North to: OTItER Survey Tool Type MWD MWD MWD MWD Survey Depth (FI) 0.00 280.00 373.00 465.00 557.00 649.00 742.00 834.00 927.00 970.00 1059.00 1123.00 1181.00 1250.00 1346.00 1410.00 1473.00 1568.00 1664.00 1762.00 1857.00 1952.00 2015.00 2079.00 Incl. Angle (DD) 0.00 1.40 1.50 1.30 0.90 0.90 1.10 1.10 0.60 Hole Direction (DD) Course Length (FT) 0.00 213.40 280.00 210.90 93.00 TVD (FI) 0.00 279.97 372.94 Vertical Section 0.00 223.20 92.00 464.92 215.50 92.00 556.90 9.75 204.20 92.00 648.89 11.18 199.70 187.70 194.00 93.00 741.87 833.86 926.84 92.00 93.00 197.90 43.00 969.84 183.80 89.00 1058.83 199.70 64.00 1122.82 58.00 1180.80 69.00 1249.73 208.40 215.10 217.60 219.00 96.00 1345.49 64.00 1409.16 218.60 63.00 214.10 95.00 211.60 96.00 1471.70 1565.70 1660.13 1755.81 1847.74 216.90 98.00 218.30 95.00 3.41 5.76 7.99 12.74 14.35 15.58 15.96 17.05 18.15 19.73 22.78 29.56 36.02 43.59 57.29 74.48 95.65 119.59 217.60 95.00 1938.3~. 219.00 63.00 1997.62 219.00 64.00 2057.21 148.07 169.41 192.74 Total Coordinate N(+) / S(-) E(+) / W(-) (FT) (FI) 0.00 0.00 -2.86 -1.88 -4.85 -6.64 -7.99 -3.13 -4.47 -5.60 -9.24 -6.32 -10.75 -6.92 -12.45 -7.33 -13.81 -7.57 -14.21 -7.68 -15.43 -7.86 -16.62 -8.11 -18.08 -8.80 -20.67 -10.44 -26.10 -14.49 -31.17 -37.07 -18.50 -23.24 -48.15 -31.31 -62.65 -40.63 -80.12 -52.63 -99.08 -67.25 -121.55 -84.76 -138.29 -97.99 -156.44 -112.68 Build Rate Build (+) Drop (-) 0.50 0.11 -0.22 0.22 0.~ -0.54 -0.23 0.67 0.00 1.72 1.30 Walk Rate Right (+) Comment Left (-) .... TIE IN POI 17 1/2" ttOI.E W/9.5" M1C @ 1.2 _ _ ~ ~ "i~ ~ 12 1/4" HOLE W/9.5" MIC @ 1.2 2.19 2.60 2.19 2.19 1.27 -0.63 2.11 -4.74 2.19 -2.60 2.24 5.41 2.11 1.47 3.89 -0.74 1.59 2.22 3.44 0.00 [ SURVEY CALCULATION AND FIELD WORKSHEET Job No. 0450-90728 Sidetrack No. Page 2 of _5.__ Company FAIRWEATHER E & P SERVICES, INC. Rig Contractor & No. Glomar Marine - CIDS Field BEAUFORT SEA li~~[~ Well Name & No. ARCO WARTHOG gl Survey Section Name MWD BHI Rep. MILLER, IIAMBURG, FOX WELL DATA ~arget TVD (FT) Target Coord. N/S Slot Coord. N/S 855.00 Grid Correction 0.000 Depths Measured From: RKB ~ MSL[~i SS ~ Target Description Target Coord. E/W Slot Coord. E/W 1724.00 Magn. Declination 30.330 Calculation Method MINIMUM CURVATURE Target Direction (or)) Build\Walk\DL per: 100ft[~ 30m [~ 10m 1~ Vert. Sec. Azim. 217.09 Magn. to Map Corr. 30.330 Map North to: OTItER SURVEY DATA Survey Survey Incl. Hole Course Total Coordinate Build Rate Walk Rate Date Tool Vertical Depth Angle Direction Length TVD Section N(+) / S(-) E(+i / W(-) DL Build (+) Right (+) Comment Type (VT) (DD) (DD) (FT) (VT) (FT) (I~T) (Per 100 Fr Drop (-) Left (-) O'~--N OV-97 MWD 2141.00 23.40 222.20 62.00 2114.30 216.86 -174.78 -128.42 2.48 1.45 5.16 . ,,v-NOV-97 MWD 2203.00 22.90 220.00 62.00 2171.31 241.17 -193.14 -144.44 1.61 -0.81 -3.55 __ 06-NOV-97 MWD 2267.00 25.30 218.60 64.00 2229.73 267.28 -213.37 -160.98 3.85 3.75 -2.19 06-NOV-97 MWD 2364.00 26.90 219.00 97.00 2316.83 309.94 -246.62 -187.72 1.66 1.65 0.41 _ _ 06-NOV-97 MWD 2460.00 28.20 220.00 96.00 2401.95 354.30 -280.88 -215.97 1.44 1.35 1.04 06-NOV-97 MWD 2556.00 31.60 222.90 96.00 2485.16 401.99 -316.69 -247.68 3.85 3.54 3.02 06-NOV-97 MWD 2652.00 33.40 225.00 96.00 2566.13 453.19 -353.80 -283.49 2.21 1.88 2.191 06-NOV-97 MWD 2748.00 36.70 224.30 96.00 2644.71 507.84 -393.03 -322.22 3.46 3.44 -0.73 ___ 06-NOV-97 MWD 2844.00 36.90 222.90 96.00 2721.58 564.97 -434.67 -361.88 0.90 0.21 -1.46 07-NOV-97 MWD 2935.00 36.10 223.90 91.00 2794.73 618.77 -474.00 -399.06 1.1(1 -0.88 1.10 07-NOV-97 MWD 3034.00 36.10 220.40 99.00 2874.73 676.85 -517.23 -438.19 2.08 0.00 -3.54 _ 07-NOV-97 MWD 3129.00 36.30 217.60 95.00 2951.39 732.91 -560.83 -473.49 1.75 0.21 -2.95 074NOV-97 MWD 3225.00 36.80 219.70 96.00 3028.52 790.06 -605.47 -509.20 1.40 0.52 2.19 _,IOV-97 MWD 3321.00 37.40 218.60 96.00 3105.09 847.92 -650.37 -545.75 0.93 0.62 -1.15 07-NOV-97 MWD 3416.00 37.40 218.60 95.00 3180.56 905.60 -695.47 -581.75 0.00 0.00 0.00 07-NOV-97 MWD 3512.00 36.80 218.60 96.00 3257.12 963.49 -740.73 -617.88 0.62 -0.62 0.00 07-NOV-97 MWD 3608.00 36.30 218.30 96.00 3334.24 1020.65 -785.50 -653.43 0.55 -0.52 -0.31 07-NOV-97 MWD 3704.00 36.70 217.60 96.00 3411.41 1077.74 -830.53 -688.54 0.60 0.42 -0.73 07-NOV-97 MWD 3800.00 35.90 214.80 96.00 3488.79 1134.55 -876.37 -722.11 1.92 -0.83 -2.92 07-NOV-97 MWD 3895.00 35.20 215.50 95.00 3566.08 1189.76 -921.53 -753.91 0.85 -0.74 0.74 08-NOV-97 II MWD 3959.00 36.00 214.40 64.00 3618.12 1226.98 -952.07 -775.25 1.60 1.25 -1.72 ~3-NOV-97 MWD 4096.00 35.30 214.80 137.00 3729.44 1306.76 -1017.80 -820.59 0.54 -0.51 0.29 8 1/2" tlOLE W/6.75" MIXL @ 1.0 _ 13-NOV-97 MWD 4190.00 35.00 215.10 94.00 3806.30 1360.84 -1062.15 -851.59 0.37 -0.32 0.32 13-NOV-97 MWD 4286.00 34.70 214.80 96.00 3885.09 1415.65 -1107.12 -883.01 0.36 -0.31 -0.31 SURVEY CALCULATION AND FIELD WORKSHEET Job No. 0450-90728 Sidetrack No. l'agc 3 ¢,f ._5 []-'[l~-'l:~ Company FAIRWEATHER E & P SERVICES, INC. Rig Contractor & No. Glomar Marine- CIDS .... Field _B_E_A__UFp_R_'!' SEA ....... l~ Well Name & No. ARCO WARTHOG gl Survey Section Name MWD BHI Rep. MILLER, !!~A~MB_U_I_{_G.~_F_O_X_ _ WELL DATA · Target TVD Wr) Target Coord. N/S ........... Slot Coord. N/S 855.00 Grid Correction __. _0.0(~)(? Depths Measured Target Description Target Coord. E/W Slot Coord. E/W 1724.00 Magn. Declination 30.330 Calculatim~ Method MINIMUM CIJRVATURE Target Direction (or)) Build\Walk\DL per: 100ft[~ 30m ~] 10m ~ Vert. Sec. Azim. 217.09 Magn. to Map Corr. 30.330 Map North to: OT}IER SURVEY DATA Survey Survey Incl. Hole Course Total Coordinate Build Rate Walk Rate Date Tool Vertical Depth Angle Direction Length TVD Section N(+) / S(-) [ E(+) / W(-) DL Build (+) Right (+) Comment Type (ET) (DD) (DD) (FT) (FT) (PT) (FT) (Per ~00 VT) Drop (-) Left (-) _ ' "'~ NOV-97 MWD 4380.00 35.50 214.80 94.00 3961.99 1469.66 -1151.50 -913.86 0.85 0.85 0.00 _ t_,-NOV-97 MWD 4476.00 35.50 213.00 96.00 4040.15 1525.32 -1197.77 -944.95 1.09 0.00 -1.87 -13-NOV-97 MWD 4572.00 34.70 214.40 96.00 4118.69 1580.42 -1243.69 -975.57 1.18 -0.83 1.46 13-NOV-97 MWD 4665.00 35.40 213.70 93.00 4194.83 1633.75 -1287.94 -1005.47 0.87 0.75 -0.75 13-NOV-97 MWD 4761.00 36.80 213.40 96.00 4272.39 1690.20 -1335.08 -1036.73 1.47 1.46 -0.31 13-NOV-97 MWD 4857.00 36.80 213.00 96.00 4349.26 1747.58 -1383.20 -1068.22 0.25 0.00 -0.42 14-NOV-97 MWD 4951.00 36.70 213.40 94.00 4424.58 1803.69 -1430.27 -1099.01 0.28 -0.11 0.43 14-NOV-97 MWD 5047.00 37.00 211.60 96.00 4501.40 1861.07 -1478.82 -1129.94 1.17 0.31 -1.88 14-NOV-97 MWD 5144.00 36.80 212.00 97.00 4578.97 1919.06 -1528.32 -1160.63 0.32 -0.21 0.41 14-NOV-97 MWD 5239.00 36.70 210.90 95.00 4655.09 1975.63 -1576.81 -1190.29 0.70 -0.11 -1.16 14-NOV-97 MWD 5336.00 37.10 212.30 97.00 4732.66 2033.60 -1626.41 -1220.81 0.96 0.41 1.44 14-NOV-97 MWD 5430.00 36.80 211.60 94.00 4807.78 2089.88 -1674.35 -1250.71 0.55 -0.32 -0.74 14,NOV-97 MWD ' 5525.00 36.50 210.20 95.00 4884.00 2146.25 -1723.01 -1279.83 0.93 -0.32 -1.47 .4OV-97 MWD 5653.00 35.90 210.20 128.00 4987.29 2221.30 -1788.34 -1317.86 0.47 -0.47 0.00 15-NOV-97 MWD 5750.00 35.80 211.60 97.00 5065.92 2277.78 -1837.09 -1347.03 0.85 -0.10 1.44 15-NOV-97 MWD 5846.00 36.10 211.30 96,00 5143.63 2333.86 -1885.17 -1376.44 0.36 0.31 -0.31 15-NOV-97 MWD 5942.00 36.20 209.80 96.00 5221.15 2390.12 -1933.93 -1405.22 0.93 0.10 -1.56 15-NOV-97 MWD 6039.00 36.40 210.90 97.00 5299.33 2447.15 -1983.49 -1434.23 0.70 0.21 1.13 15-NOV-97 MWD 6134.00 36.40 214.80 95.00 5375.80 2503.34 -2030.83 -1464.80 2.44 0.00 4.11 15-NOV-97 MWD 6229.00 36.40 213.00 95.00 5452.27 2559.62 -2077.61 -1496.24 1.12 0.00 -1.89 ......... 15-NOV-97 MWD 6324.00 36.60 213.40 95.00 5528.64 2616.00 -2124.90 -1527.18 0.33 0.21 0.42 15-N0¥-97 MWD 6420.00 36.40 214.40 96.00 5605.81 2673.01 -2172.29 -1559.03 0.65 -0.21 1.04 _ 16-NOV-97 MWD 6515.00 36.40 212.70 95.00 5682.27 2729.28 -2219.27 -1590.18 1.06 0.00 -1.79 16-NOV-97 MWD 6609.00 36.60 213.70 94.00 5757.84 2785.06 -2266.05 -1620.80 0.67 0.21 1.06 Target TVD SURVEY CALCULATION AND FIELD WORKSHEET Job No. 0450-90728 Company FAIRWEATHER E & P SERVICES, INC. Rig Contractor & No. Glomar Marine - CIDS Well Name & No. ARCO WARTHOG gl Survey Section Name MWD WELL DATA (t-'T) Target Coord. N/S Slot Coord. N/S 855.00 Grid Correction Target Description Target Direction (DD) Target Coord. E/W Slot Coord. E/W 1724.00 Build\Walk\DL per: 100ft[~ 30m[~ 10m [~ Vert. Sec. Azim. 217.09 0.000 Magn. Declination 30.330 Magn. to Map Corr. 30.330 Sidetrack No. Page 4 of 5 Field BEAUFORT SEA BIll Rep. MII,I,ER, ItAMBURG, FOX Calculation Method MINIMUM CURVATURE Map North to: OTIIER SURVEY DATA Date ) &~NOV-97 _ _ .NOV-97 16-NOV-97 16-NOV-97 16-NOV-97 17-NOV-97 17-NOV-97 17-NOV-97 17-NOV-97 17-NOV-97 17-NOV-97 17-NOV-97 17-NOV-97 _ ,~OV-97 18-N OV-97 18-NOV-97 18-NOV-97 18-NOV-97 18-NOV-97 18-NOV-97 18-NOV-97 1~-N0¥-97 19-NOV-97 19-NOV-97 Survey Tool Type MWD --__ MWD MWD MWD -- MWD Survey Depth (FT) 6704.00 6801.00 6894.00 6989.00 7083.00 7178.00 7275.00 7371.00 7468.00 7563.00 7656.00 7751.00 7845.00 7941.00 8036.00 8131.00 8227.00 8322.00 8418.00 8513.00 8609.00 8705.00 8801.00 8898.00 Hole Direction (DD) Course Length (FT) TVD (FT) Vertical Section 215.80 95.00 5833.86 2841.98 214.10 97.00 5911.23 2900.44 215.80 93.00 5985.31 2956.63 214.10 95.00 6060.78 3014.28 214.80 94.00 6135.30 3071.51 213.70 95.00 6210.67 3129.27 214.80 97.00 6287.73 3188.11 215.10 96.00 6364.04 3246.31 213.00 97.00 6441.26 3304.94 213.00 95.00 6516.98 3362.16 213.00 93.00 6590.91 i 3418.44 214.40 95.00 6665.93 3476.62 215.10 94.00 6739.64 3534.90 213.70 96.00 6814.36 3595.11 213.00 95.00 6887.87 3655.15 214.40 95.00 6961.07 3715.60 212.70 96.00 7034.61 3777.19 211.60 95.00 7107.23 3838.21 211.60 96.00 7180.61 213.00 95.00 7253.96 212.00 96.00 7328.83 3899.83 3959.97 4019.87 214.10 96.00 7404.07 4079.34 213.70 96.00 7479.72 4138.35 213.40 97.00 7555.90 4198.29 Total Coordinate N(+) / S(-) E(+) / W(-) (FT) (FT) -2312.86 -1653.27 -2360.81 - 1686.79 -2406.89 -1719.00 -2454.19 - 1752.05 -2501.43 -1784.46 -2549.23 -1817.00 -2597.93 - 1850.16 -2645.66 -1883.53 -2694.30 -1916.40 -2742.42 - 1947.64 -2789.74 -1978.37 -2838.23 -2010.72 -2886.15 -2043.96 -2935.89 -2078.01 -2986.15 -2111.09 -3036.53 -2144.69 -3087.95 -2178.79 -3139.81 -2211.39 -3192.53 -2243.82 -3243.56 -2276.06 -3294.24 -2308.35 -3344.22 -2340.86 -3393.27 -2373.82 -3443.32 -2407.01 ___ Build Rate Walk Rate Build (+) Right (+) Drop (-) Left (-) 0.53 2.21 0.00 -1.75 0.22 {).21 -I .79 O. 11 0.74 -0.21 -1.16 0.00 1.13 _ -0.10 0.31 -0.10 -2.16 0.54 O.0O 0.53 1.47! 0.53 0.74 0.63 -1.46 0.21 -0.74 0.42 1.47 0.42 -1.77 -0.11 -1.16 ColnlllCilt 0.10 0.00 -1.58 1.47 0.10 -1.04 -0.83 2.19 0.00 -0.42 0.52 -0.31 Target TVD Target Description Target Direction Date '-~'-NOV-97 ~ ~-NOV-97 21 -NOV-97 21-NOV-97 21-NOV-97 21-NOV-97 22-NOV-97 22-NOV-97 23-NOV-97 23-NOV-97 23-NOV-97 24-NOV-97 ?&NOV~97 NOV-97 SURVEY CALCULATION AND FIELD WORKSHEET Job No. 0450-90728 Company FAIRWEATHER E & P SERVICES, INC. Rig Contractor & No. Glomar Marine - CIDS Survey Section Name WELL DATA MWD 24-NOV-97 Well Name & No. ARCO WARTHOG #1 (DD) Survey Tool Type MWD --__ MWD --_ MWD __ MWD MWD -- MWD -- MWD -- MWD -- MWD MWD MWD MWD MWD MWD Survey Depth (FT) (bT) 8992.00 9089.00 9184.00 9277.O0 9370.00 9465.00 9561.00 9656.00 9747.00 9841.00 9936.00 10032.00 Incl. Angle (DD) 38.90 -- 39.30 -- 39.60 40.50 41.00 -- 41.40 -- 42.40 -- 44.10 -- 43.80 -- 42.60 41.00 40.60 39.80 10125.00 10209.00 10286.00 39.80 Target Coord. N/S Slot Coord. N/S Target Coord. E/W Slot Coord. E/W Build\Walk\DL per: 100ft ,~t 30m~ 10m~ Vert. Sec. Azizn. Hole Direction (DD) 213.40 213.40 Course Length (FT) 94.00 97.00 TVD (IT) 7629.26 Sidetrack No. Page 5 of Field BEAUFORT SEA BHI Rep. MILLER, ItAMBURG. FOX 7704.53 Vertical Section 4256.94 4317.99 SURVEY DATA 212.70 95.00 7777.89 4378.20 212.30 93.00 7849.08 4437.85 213.00 93.00 7919.53 4498.37 212.70 210.60 95.00 7991.01 96.00 8062.47 4560.78 855.00 Grid Correction 0.000 1724.00 Magn. Declination 30.330 217.09 Magn. to Map Corr. 30.330 Total Coordinate N(+) / S(-) (Fl') -3492.39 -3543.46 E(+) / W(-) (FT) -2439.36 -2473.04 -3594.05 -2505.96 ~3644.52 -2538.11 -3695.64 -2570.86 -3748.21 -2604.80 4624.59 -3802.78 212.00 95.00 8131.66 4689.35 -3858.39 210.90 91.00 8197.18 4752.20 -3912.26 -3967.48 -4022.36 -4077.25 -4130.24 -4178.15 -4222.07 210.90 94.00 8265.70 4816.17 209.10 95.00 8336.47 4879.06 209.80 96.00 8408.86 4941.54 208.80 93.00 8479.26 5001.75 207.00 84.00 8543.42 5055.27 5103.79 -2638.43 -2672.25 -2705.21 -2738.25 DL {Per 100 Fr) ____ 0.43 __ 0.41 0.56 1.01 --__ 0.73 -- 0.47 -- 1.79 __ 2.05 ____ 0.90 -- 1.28 -2769.95 I 2.02 -2800.9510.49 -2830.6910.82 -2856-06I 1.68 -2878.44 207.00 77.00 8602.58 Build Rate Build (+) Drop (-) 0.43 0.41 _ _ 0.32 0.97 0.54 0.42 1.04 1.79 -0.33 -1.28 -1.58 -0. I0 -0.43 -0.95 0.00 Depths Measured Fr, m,: RKB~ MSL[ i SS~ Calculation Method MINIMUM CURVATI Map Northto: OTHER __ Walk Rate Right (+) Left (-) 0.00 0.00 __ . -tl.74 . . -0.43 0.75 -0.32 -2.19 1.47 -1.21 0.00 -1.89 0.73 -1.08 -9-la [ ~7 ~_ j ' _ 0.00 ~PROJECTION TO BIT C{) frlnlell[ SAMPLE TRANSMITTAL TO: STATE OF AK 3001 PORCUPINE ANCH.,AK. DATE: 1/15/98 AIR BILL: AL864029 AFT: 08-01-15-01 CHARGE CODE: 15768 OPERATOR: ARCO NAME: WARTHOG #1 ~ APl NO: N/A NUMBER~i~~OF BOXES:.~~ ~~ SAMPLE TYPE: D/A SAMPLE DEPTHS: ONE COMPLETE SET OF~DITCH CUTTINGS: - ~o5o'-io,28~- lo~'-o .., lO~(o~Oc SENT BY: D.L. Przywojski UPON RECEIPT OF THESE SAMPLES, PLEASE NOTE ANY DISCREPANCIES AND MAIL A SIGNED COPY OF THIS FORM TO: ARCO ALASKA, INC. P. O. BOX 100360 ANCHORAGE, AK. 99510 ATTN: BAYVIEW GEOLOGIC FACILITY DAN PRZYWOJSK~c~.V,¢ CC: iLarry Casarta ATO 1302 State of AK. Anch. '-) 0 O~ '3 '-/ 1~¥ CC 0 ,,,,t 70. O'-/'A,. -27772 , lifo/, c//7,,~,,~).._2.L_ 7(1 0 ~ ' ~- -~. (o " l ~( ~/ ' $'-~ 3 2, 'f / ~Zate of Alaska 0IL & GAS CONSERVATION COMMISSION Memcrandu_m To File: Abnd Date Completed Note casi=q size, wi, depth, ce= vol, & procedur~. Perf i~:e~za!s - tops: Review the well file, ~nd' c~ent on plugging, well head status, and location clearance - provide loc. clear, code. , . w~~ ~ ~8 ~ - ~ ~ 9~S"C~OO~~. ~TjSV~,,~ 1~5', cu~ ~".~ Well heaa cu= off: ' ~/~% .. / ~arker 9osu or ~late= ~ December 22, 1997 Mr. Jeff Walker Regional Supervisor, Field Operations U.S. Department of the Interior Minerals Management Service,. 3rd Floor Alaska OCS Region 949 E 36th Avenue Anchorage, Alaska 99508-4302 RE: Well Summary Report ARCO Warthog #1 Exploration Well Dear Sirs, Mr. David Johnston Chairman AK Oil & Gas Conservation Comm. 3001 Porcupine Drive Anchorage, Alaska 99501-0030 Attached :find the final Well Summary Report and supporting documents for the ARCO Warthog #1 exploration well. The CIDS has been cold-stacked and the last person departed it on December 21. Fairweather plans to offload remaining rental equipment from the CIDS via rolligon as soon as ice conditions allow offshore travel between Point Thompson and the Warthog location. Thank you for your help during the permitting and operational phases of this project. I will keep in touch with your offices during the remaining logistical operations. If you have any questions or require additional information, please do not hesitate to call me at any time. Sincerely, Bill Penrose Project Manager RECEIVED DEC 24 1997 Oil & Gas Cons. oommismo~ Anchora{~e c: Mr. Glerm Gray - ADGC Mr. Paul Mazzolini - ARCO 715 L Street Anchorage, Alaska 99501 (907) 258-3446 FAX (907) 258-5557 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION CO,,.MISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1. Status of Well Classification of Service Well OIL [] GAS [] SUSPENDED [] ABANDONED [~ SERVICE [] , 2. Name of Operator 7. Permit Number . ARCO AT.A.~3CA~ INC. 97-85 3. Address 8. APl Number P O BO~ 100360, AN~~, AIC 99510-0360 ~:XS5-171_-00019 4. Location of well at surface ~'~ ' ' ~'~-~'~'~'-:~"~ 9. Unit or Lease Name At Top Producing Interval '" . .~Y/~'~ ~ i 0. Well Number ..: . ~ No. 1 At Total Depth ~.~ 11. Field and Pool 5. Elevation in feet (indicate KB. DF, etc.) 6. Lease Designation and Serial No. 91.5~ ]l:K:S~ ~ AD1'. 27].O1/+ ,, 12' Date SPudded11/01,97 13. Date T.D. Reached11/2/+/97 · 14'DateC°mp'°Susp'°rAband'115'WaterDepth'if°ffsh°rel'6'N°'°lC°mpled°ns:].2/06/97 35.5 feet MSL 17. TotalOepth,MD+TVD} 18. Plug Back Depth (MD+'l'VD} 19. DirectionalSurve¥ I 20. Depth where SSSV set 121. Thickness of Perrnafrost 10s286't~/D;8,602"~q/D 226'MD/~D YES ~ NO [] NIA feet MD 0t , 22. Type Electric or Other Logs Run · a) ])]]tEc-rz~, ua) cat/R~szs't; m,: ceJsm/urt/aa.l~c, ~'t, vsm, ])]],o~.~ so--c, s~c: '* 2:3. CASING, LINER AND CEMENTING RECORD ., SETrlNG DEPTH MD CASING SIZE WT. PER FT. GRADE TOP BOTTOM ,HOLESIZE CEMENTING RECORD AMOUNT PULLED 20- o.8]3,,ta~ x-52 -t~" 2:~0, ~]t_TV~ alA ]3~ ' Z3-:~18" 68~ [,-80 ]0'- Z,013' i ].7-]_/2" 9/+:~rt~ CS'Z'rTlZ~a~rt'~CS[T 9-5/8" ~0¢ I.-80 28'.. 4,017' 12-1/4" L976~JCSIII/36SrI4:IG l'~R' 24. Perforations open to Production {MD+TVD of Top and Bottom and 25. TUBING RECORD interval, size and number) SIZE DEPTH SET (MO) PACKER SET {MD) " N/A NJA 26. ACI~.' FRACTURE, CEMENT SOU6EZE. ETC. DEPTH I.TERVAL IMm AMOUNT ~ [~ND OF MATEm^L USED N/A ,, ,, :27. PRODUCTION TEST , , Date First Production .' I Melhod of Operation {Flowing. gas liszt, etc. J N/AI - Date of Test Hours Tested PRODUCTION FoR~ OI~L-BBL GAS-MCF WATER-BBL CHOKE SIZE ] GAS-OIL RATIO " TEST PERIOD 'Flow Tubing Casing Pressure CALCULATED ~OI[.-RBL GAS-MCF WATER-eeL OIL GRAVITY-APl (corr~ Press. 24-HOUR RATE , , '~8. "' ' CORE DATA ,,~ Brief description of lithology, porosity, fractures, apparent dips and presence of oil~ gas.or water. Submit core chips, - ORIGINAL ,, Form 10-407 Rev. 7-1-80 CONTINUED ON REVERSE SIDE 29. 30. GEOLOGIC; ,KEF:IS FORMATION TESTS _ .. NAME . . Include interval tested, pressure data, all ftuid~ rtcovered and gravity, MEAS. DEPTH TRUE VERT. DEPTH GOR. and timeD! each phase. HIO(IENK/PLIOCENE 126 ~ 126 ~ I~ 0I~~ 2~89~ 2~766~ I~RL¥ 0I~~ ?~0~0~ 6~096~ , 31. LIST OF ATTACHMENTS: Well Sch~tic~ Daily ~lg. Stories, Csg. & ~tg. ~tails, ~ plots~ ~ir. Su~ey Listi~. 32. I hereby certify that tb~ foregoing is true and correc~ to the best of. my knowledge Signed . m _ Title ~ ~, I~. 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 wate{ 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 cement- in.g and the location of the cementing tool. , , : .. , li:~e'm' 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 ARCO Warthog #1 P&A Schematic All depths RKB, RKB = 127' Above Mud Line 20" cs,g, top ~ 147' 1 13-3/,8 csg top @ 148'1 ~ 9-5/8' csg top @ 150' _i 230' 20", 0.813" wall, X-52 surf csg (driven to 230') Surface cement plug in 9-5/8" csg from 226' to 38O' 1,013' -- 9.7 ppg mud 13-3/8", 68#, L-80, BTC csg cmtd to surf. 2,013' -- -- Cement stage tool 2,013' 3,844'--~ 4,017' " ' 4,120' 9-5/8" 40#, L-80, BTC csg cmtd to surf. Csg shoe cement plug from 3,844' to 4,120' 9.7 ppg mud Limestone stringers 5,150' and 6,400' 6,697' 7,230' 9.7 ppg mud Open hole cement plug · from 6,697' to 7,230' 10,2~6' 8-1/2" open hole. ARCO Warthog #1 Well Operations Summary 0000, 11/1/97 - 0600, 11/1/97 MW: 8.8 ppg Vis: 40 sec M/U 17-1/2" BHA. RIH. Tag bottom at 163' RKB. Spud well at 0230 hrs, 11/1/97. Drill 17-1/2" hole from 163' to 316'. 0600, 11/1/97 - 0600, 11/2/97 MW: 9.4 ppg Vis: 34 sec Drill 17-1/2" hole from 316' to 1,020'. Short trip to jars ~ 250' and RIH to bottom. C&C hole, spot viscous pill on bottom and POH to rrm casing. 0600, 11/2/97 - 0600, 11/3/97 MW: 9.4 ppg Vis: 34 sec Run 25 jts 13-3/8", 68#, L-80, BTC casing to 1,013'. Hang offon landing ring in 20" drive pipe. C&C hole for cementing. Work out problem with mud-contaminated water being delivered to cementing unit. Cement with 491 sacks Cold Set III followed by 502 sacks Cold Set II. Displace with mud using rig pumps. Bump plug on schedule. Check floats - OK. Flush cmt from annulus above mudline hgr with water via wash ports in 13-3/8" running tool. R/D cementers. N/D diverter system. 0600,11/3/97 - 0600, 11/4/97 MW: 9.0 ppg Vis: 48 sec Finish N/D diverter system. Measure and cut 20' and 13-3/8" casing and install 13-3/8" casing head. N/U BOP system. 0600, 11/4/97 - 0600, 11/5/97 MW: 9.0 ppg Vis: 47 sec Finish N/U BOP system. Test BOPE - witnessed by MMS rep. L/D 17-1/2" drlg assy. M/U 12-1/4" drlg assy. RIH. Tag FC ~ 933'. Test 13-3/8" casing to 2,500 psi for 30 minutes - OK. Drill FC. 0600, 11/5/97 - 0600, 11/6/97 MW: 9.0 ppg Vis: 40 sec Drill FC, cmt, FS and 10' of new hole to 1,030'. Displace spud mud from wellbore w/polymer system. Perform LOT to 18.0 ppg EMW. Drill 12-1/4" straight hole f/1,030' to 1,136' KOP. KO and build angle at 2.0°/100'. Drill directional hole f/1,136' to 2,024'. CBU. Make 11-stand wiper trip. 0600, 116/97 - 0600, 11/7/97 MW: 9.0 ppg Vis: 40 sec Finish wiper trip.' Directionally drill f/2,024' to 3,010'. CBU. Make 12- stand, wiper trip. 0600, 11/7/97 - 0600, 11/8/97 MW: 9.2 ppg Vis: 44 sec Directionally drill f/3,010' to 4,037'. Raise MW to 9.2 ppg ~ 3,600' due to swabbing and sticky hole. CBU. Make wiper trip to 13-3/8" shoe and back to btm. 0600, 11/8/97 - 0600, 11/9/97 MW: 9.3 ppg Vis: 45 sec Finish wiper trip. C&C hole and spot viscous pill. POH (SLM). Install and function test 9-5/8" ram blocks. Run 96 jts 9-5/8", 40#, L-80, BTC csg to 4,017'. Landed out in hgr profile @ 158'. C&C hole for cementing. 0600, 11/9/97 - 0600, 11/10/97 MW: 9.2 ppg Vis: 44 sec C&C hole - lost returns. Hole packing off around csg hgr. Pump 2 LCM pills while attempting to clear hgr. Regain returns. R/U cementers and pump 1 st stage: 367 sacks Cold Set III followed with 317 sacks class G cmt. Maintained 100% returns. Shear open stage tool and circulate hole clean above it (received green cement @ surf.). Pump 2nd stage: 660 sacks Cold Set III. Maintained 100% returns and received cement back ~ surface. Shear stage tool closed. Flush cmt from annulus above mudline csg hgr. RJD cementers. P/U BOPs and make cut on 9-5/8" csg. 0600, 11/10/97 - 0600, 11/11/97 MW: 9.0 ppg Vis: 41 sec Install 9-5/8" csg head. N/U BOP stack. Replace 9-5/8" ram w/5" ram. Test BOPs - witnessed by AOGCC rep. L/D 12-1/4" BHA, M/U 8-1/2'"BHA. 0600, 11/11/97 - 0600, 11/12/97 MW: 9.2 ppg Vis: 45 sec Finish M/U 8-1/2" BHA. RIH, drill out stage tool & cmt down to bypass baffle ~ 3,809'. Pressure test csg to 4,000 psi for 30 min. - OK. Drlg ops suspended by MMS pending approval of ability to adequately respond to ............... __m_a.j.0? sp!_I_I_:._.PO__H__w._/._ ~ _I2!~ tP_.~a__v_o_i~.i_n_-_h_ho_l_e_._c_h~g__e__s_ o__n___B_~_A__c?__m_p__o_9_.__en_t~. 0600,11/12/97 - 0600, 11/13/97 MW: 9.2 ppg Vis: 40 sec Ops suspended pending MMS approval to proceed. Received MMS approval. RIH, drill out cmt, float equip and 10' of new hole to 4,047'. Conduct LOT to 11.3 ppg EMW. POH, change to drlg BHA, RIH. 0600,11/13/97 - 0600, 11/14/97 MW: 9.3 ppg Vis: 42 sec Continue RIH. Directionally drill 8-1/2" hole f/4,045' to 5,054'. CBU. Make wiper trip to 9-5/8" csg shoe. MWD failed. POH to replace MWD. 0600, 11/14/97 - 0600, 11./15/97 MW: 9.5 ppg Vis: 46 sec Finish POH. Replace MWD. RIH. Directionally drill f/5,054' to 5,756. 0600, 11/15/97 - 0600, 11/16/97 MW: 9.4 ppg Vis: 47 sec Directionally drill f/5,756' to 6,077'. CBU. Make 11-stand wiper trip. Directionally drill f/6,077' to 6,229'. 0600, 11/16/97 - 0600, 11/17/97 MW: 9.4 ppg Vis: 44 sec Directionally drill f/6,229' to 7,093'. CBU. Make wiper trip to shoe. Slip & cut drlg line. RIH. Directionally drill f/7,093' to 7,446'. 0600, 11/17/97- 0600, 11/18/97 MW: 9.4 ppg Vis: 61 sec Directionally drill f/7,446' to 8,076'. CBU. Make 11-stand wiper trip. Directionally drill f/8,076' to 8,322'. 0600, 11/18/97 - 0600, 11/19/97 MW: 9.5 ppg Vis: 44 sec Directionally drill f/8,322' to 9,065'. 0600, 11/19/97 - 0600, 11/20/97 MW: 9.7 ppg Vis: 46 sec CBU. POH to 4,000'. Hole swabbing. RIH to btm. C&C hole. POH. 0600, 11/20/97 - 0600, 11/21/97 MW: 9.5 ppg Vis: 46sec Finish POH. Test BOPs. Change BHA. RIH. Diectionally drill f/9,065' to 9,110'. 0600, 11/21/97 - 0600, 11/22/97 MW: 9.5 ppg Vis: 45 sec Directionally drill f/9,110' to 9,675' 0600, 11/22/97 - 0600, 11/23/97 MW: 9.6 ppg Vis: 42 sec Directionally drill f/9,675' to 9,737'. CBU, POH, change bit, RIH. Directionally drill f/9,737' to 9,750'. 0600, 11/23/97 -0600, 11/24/97 MW: 9.6 ppg Vis: 43 sec DirectionallY drill f/9,750' to 10,167'. 0600, 11/24/97 - 0600, 11/25/97 MW: 9.6 ppg Vis: 43 sec Directionally drill f/10,167' to 10,286' TD. CBU, make 10-stand wiper trip. C&C hole for logs. POH (SLM). R/U Schlumberger, RIH w/ GR/SP/CNL/LDT/BHC. Logging tools stopped ~ 9,550'. Log f/9,550' to csg shoe. 0600, 11/25/97 - 0600, 11/26/97 MW: 9.6 ppg Vis: 58 sec Finish logging to 9-5/8" csg shoe. POH w/logging tools. M/U clean-out BHA and RIH. C&C hole. 0600, 11/26/97 - 0600, 11/27/97 MW: 9.6 ppg Vis: 58 sec C&C hole. POH for logs. R/U Schlumberger. RIH w/GR/SP/CNL/LDT /BHC. Log 8-1/2" hole f/10,286' to 9,550'. POH. M/U FIT logging tool and RIH. Stuck'FIT tool ~ 8,690' 0600, 11/27/97 - 0600, 11/28/97 MW: 9.5 ppg Vis: 52 sec Work stuck tool while waiting on fishing tools. Pull out of rope socket, retrieve line. M/U overshot on DP, RIH. C&C mud above fish. 0600, 11/28/97 - 0600, 11/29/97 MW: 9.5 ppg Vis: 52 sec Work overshot onto FIT tool. POH, recovered fish. RIH w/bit, clean out hole, POH to log. 0600, 11/29/97 - 0600, 11/30/97 MW: 9.5 ppg Vis: 52 sec RIH w/VSP tool. Log f/TD to surf. RIH w/Dipole Sonic tool. Log f/TD to 3,500'. POH. RIH w/percussion SWC tool. Shoot 45 SWCs. POH. Recovered 38 cores. 0600, 11/30/97 - 0600, 12/1/97 MW: 9.5 ppg Vis: 52 sec RIH w/SWC Run #2. Shoot 45 SWCs. POH. Recovered 41 cores. R/D Schlumberger. RIH w/bit. C&C hole. POH. 0600, 12/1/97 - 0600, 12/2/97 MW: 9.7 ppg Vis: 45 sec L/D DP & BHA. RIH w/OEDP to 7,230'. Lay balanced cmt plug (120 sacks Class G cmt w/additives) calculated to cover f/6,950' to 7,230'. POH 8 stds. CBU & WOC. 0600, 12/2/97 - 0600, 12/3/97 MW: 9.7 ppg Vis: 45 sec RIH to 7,150' - no cmt. POH to 6,680'. CBU and WOC. RIH to 7,230' - no cmt. CBU. Lay balanced cement plUg (180 sacks Class G cement w/ additives). WOC. Tag firm cmt @ 6,697', test w/15,000 lbs DP wt - OK. POH. 0600, 12/3/97 - 0600, 12/4/97 MW: 9.7 ppg Vis: 46 sec Continue POH to 4,385'. Spot hi-vis pill. POH to 4,120'. Lay balanced cmt plug (145 sacks Class G cmt w/additives) calculated to cover f/3,870' to 4,120'. POH to 3,465'. CBU & WOC. POH, laying dn extra DP. RIH w/ DP f/derrick. Tag cmt ~ 3,529', would only take 5,000# wt. Pull up, CBU & WOC. Tag cmt, would only take 10,000#. Pull up, CBU & WOC. 0600, 12/4/97 - 0600, 12/5/97 MW: 9.7 ppg Vis: 46 sec Tag cmt ~ 3,844', test w/15,000# DP wt - OK. Test csg to 1,000 psi - OK. POH, L/D DP. W/OEDP ~ 375', lay balanced cmt plug (80 sacks Cold Set II) calculated to cover f/200' to 375'. POH to 155', flush mudline hgr & BOP stack. Begin N/D of stack & clean mud pits while WOC. Tag hard cmt ~ 226'. Witnessed & approved by MMS rep. Continue N/D BOP stack and clean mud pits. 0600, 12/5/97 - 0600, 12/6/97 MW: N/A Vis: N/A N/D BOP stack. Back out 9-5/8'' csg ~ mudline hgr (@150' RKB) & L/D. Attempt to back out 13-3/8" csg ~ mudline hgr - would not rotate. Cut 13- 3/8" csg ~ 148' & L/D. Cut 20" csg ~ 147' & L/D. Well P&A'd ~ 0600 hrs, 12/6/97. CSG DETAIL 13 3/9" CSG WELL:Warthog #1 DATE: 1112197 FAIRWEATHER E&P SERVICES, INC. 1 OF 1 PAGES ' ,~ ITEMS COMPLETE DES~:RIPTION OF EQUIPMENT RUN LENGTH DEPTH TOPS __ 4 JOINTS 13-3/8", 68#, L-80, BTC CASING 163.05 -13.55 1 VETCO-GRAY MLS 13-3/8" CASING HANGER 4.00 149.50 1 VETCO-GRAY 13-3/8" PIN X PIN CROSSOVER 1.50 153.50 19 JOINTS 13-3/8", 68#, L-80, BTC CASING 775.10 155.00 1 WEATHERFORD 13-3/8" FLOAT COLLAR .75 930.10 2 JOINTS 13-3/8", 68#, L-80, BTC CASING 80.84 930.85 1 WEATHERFORD 13-3/8" FLOAT SHOE 1.25 1011.69 BOTTOM OF CASING 1012.94 ,,, ,,, , , Remarks: Welded first 3 its, inStalled centralizers on first 11 collars (excluding float collar), welded the 4 its above mudline casin~l han~ler. Used APl Modified thread dope on all connections. .Hookl°ad 54K lbs. ,, G/omar Beaufort Sea 1 Drillin~l Supervisor: Bill Penrose FAIR WEATHER E&P SER VICES, I2v C. Cementine Detail 13-3/8" Conductor Casing Well Data Well Name Hole Depth Csg Depth Hole Size Casing Mud Weight Est BHST Est BHCT Excess ARCO Warthog/41 1,020'MD, 1,020'TVD 1,013'MD, 1,013'TVD 17-1/2" 13-3/8" OD, 68#, L-80, BTC 9.4 ppg 30°F 35°F 100% in open hole Cement Pumped Preflush: 25 bbl flesh water Lead: 491 sx (168 bbls including excess) COLD SET III Tail: 502 sx (86 bbls including excess) COLD SET II Cement Properties Lead Tail Density - PPG 12.2 14.95 Yield - CF/Sk 1.92 0.961 Mix Water - Gal/Sk 10.53 3.89 Thickening Time - Hrs:Mins 6:30 3:30 Fluid Loss - CCs/30 Min .... Free Water -Mls 0 0 Compressive Strength - PSI 12 Hrs -- 850 24 Hrs 24' 1,750 Returns: Full returns maintained throughout job. Top of Cement: 11.2 ppg cement received at surface. Discussion: C&C hole for 2 hours after running casing. BJ pumped 5 bbls fresh water, then pressure tested lines to 3,000 psi. Dropped bottom plug and pumped 20 bbls fresh water spacer. Discovered mix water being delivered to BJ badly contaminated by mud. Circulated well with mud using rig pumps for 2 hours while working out water delivery problem. Pumped job as planned. Dropped top plug and chased with 10 bbls fresh water. Switched to rig pumps and displaced with mud. Maintained full returns throughout job and received cement back to surface near end of job. Bumped plug on schedule w/1,000 psi. Check floats - OK. Washed cement out of annulus above mudline casing hanger and rigged down BJ. o 0.5. A~aska Oil & G~s Cons." ~"" Comml~s~o~ CSG DETAIL Anchorage 9-5/8" CSG WELL:Warthog #1 DATE: 1118197 FAIRWEATHER E&P SERVICES, INC. 1 OF ~ PAGES # ITEMS COMPLETE DESCRIPTION OF EQUIPMENT RUN LENGTH DEPTH TOPS 4 JOINTS 9-5/8", 40#, L-80, BTC CASING (Jts 93 - 96) 170.64 -21.31 1 VETCO-GRAY MLS 9-5/8" CSG HGR W/7" CSG LANDING SUB 15.00 149.33 44 JOINTS 9-5/8", 40#, L-80, BTC CASING (Jts 49 - 92) 1846.74 164.33 1 WEATHERFORD 9-5/8" '751E' STAGE TOOL 2.78 2011.07 46 JOINTS 9-5/8", 40#, L-80, BTC CASING (Jts 3 ~ 48) 1914.76 2013.85 1 WEATHERFORD 9-5/8" FLOAT COLLAR 1.88 3928.61 2 JOINTS 9-5/8", 40#, L-80, BTC CASING (Jts 1 & 2) 85.43 3930.49 1 WEATHERFORD 9-5/8" FLOAT SHOE 1.67 4015.92 BOTTOM OF CASING 4017.59 Remarks: Baker-Locked float shoe, float collar and first 3 joints. Ran centralizers on first 10 cnxns and one each above and below stage tool. Baker-Locked stage tool and next 3 its above it. Tack-welded casin9 hanger and the 4 its above it. G/omar Beaufort Sea 1 Drillin~l SUpervisor: Bill Penrose FAIR WEATHER E&P SER VICES, Cementine Detail 9-5/8" Surface Casing Well Data Well Name Date Hole Depth Csg Depth Hole Size Casing Mud Weight Est BHST Est BHCT Excess ARCO Warthog # 1 November 10, 1997 4,037'MD, 3,695'TVD 4,017'MD, 3,673 'TVD 12-1/4" 9-5/8" OD, 40#, L-80, BTC 9.2 ppg 85°F 70°F 50% in open hole Cement Pumped 1 st Stage Preflush: 30 bbl fresh water Lead: 367 sx (126 bbls including excess) COLD SET III Tail: 317 sx (65 bbls including excess) G + 1% A-7 + 1 ghs FP-6L 2nd Stage Preflush: 20 bbl fresh water Lead: 660 sx (226 bbls including excess) COLD SET III Cement Properties Lead Tail Density - PPG 12.2 15.86 Yield - CF/Sk 1.92 1.15 Mix Water - Gal/Sk 10.53 4.96 Thickening Time - Hrs:Mins 6:00 5:00 Fluid Loss - CCs/30 Min .... Free Water -Mls 0 0 Compressive Strength - PSI 12 Hrs 26 1,600 24 Hrs 120 2,100 Returns: Complete returns maintained throughout both stages. Top of Cement: Stage 1: Stage tool at 2,011', Stage 2: Surface Discussion: Stage 1: Pumped 5 bbls fresh water and tested lines to 3,000 psi. Pumped 20 bbls fresh water spacer, dropped bypass plug and kicked it out of cementing head w/5 bbls fresh water. Loaded opening plug in head. Pumped lead and tail cement as described above. Released opening plug and kicked it out of head w/ 10 bbls fresh water. Switched to rig pumps and displaced w/mud at 4.75 bpm. (Note: Lost circulation experienced while conditioning hole prior to cementing prompted the low displacement rate.) Bumped plug on schedule w/500 psi. Checked floats - OK. Loaded closing plug in head. Attempted to shear open stage tool with rig pumps. Stage tool pinned to shear at 2,400 psi. Shut down rig pumps at 3,400 psi. Verified max allowable 9- 5/8" casing pressure (4,700 psi), switched to BJ pump and sheared open stage tool at 4,200 psi. C&C'd hole above stage tool for 1 hour at 4.75 bpm. Received 10.0 ppg cement back to surface. Stage 2: BJ pumped 20 bbls fresh water followed by 226 bbls cement as described above. Switched to rig pumps and displaced w/mud at 4.75 bpm. Bumped plug on schedule w/ 500 psi. Sheared stage tool closed w/ 1,000 psi. Tested casing to 2,000 psi for 5 minutes to verify tool closed - OK. Used GBR tongs to rotate landing string to right to expose washout ports. Circulated cement Out of 9-5/8" x 13-3/8" annulus w/sea water. BJ spotted 10 bbls water containing R-7 cement retarder (1 bbl in casing, 9 bbls in annulus). Rotated landing string to left to bury washout ports. Test seal w/1,000 psi on 9-5/8" casing - OK. R/D GBR and Bj. 8o0 VELOCITY SURVEY FOR WARTHOG # 1 conducted for ARCO ALASKA, INC. November 1997 Arco Alaska Inc Warthog #1 WELL SEISMIC REPORT Run 1 November 24, 1997 Company: Arco Alaska Inc. Well: Warthog #1 Fi el d- Wi 1dc at Region: North SloDe Run: One API number: 55-171-00012 Well Loc.: State: Alaska Acquired: November 24, 1997 x=579,322.4 y=7,772,007.9 Permanent Datum/Seismic Reference - Mean Sea Level (MSL) Elevation of Permanent Datum: 0.0 Ft. Elevation of Ground Level: -36.0 Ft. Elevation of Kelly Bushing: 91.0 Ft. Driller's Depth: 10286.0 Ft. Logs Measured From: KB Drilling MeasuredFrom: KB Bottom Logged Intv. : 10286.0 Ft. Top Logged Interval: 250.0 Ft. Survey Started: 0: 00 24-Nov. Survey Completed: 24-Nov Logging Unit: 227 Loca t i on: Wi 1dc at Recorded by: R. Walsh Witnessed by: Campaign Log Analyst: Sines Processing Job Number: 97551 Source Description: Single Air,un Source Locations: 158 ft. 135 d. North of Well Bore Sonic Log: Schlumberger DSI Directional Data: Client supDlied Processed at Schlumberger - GeoQuest Alaska Interpretation Center 500 W. International Airport Rd. Anchorage, Alaska 99516 (907)563-1592 Arco Alaska Inc Warthog #1 CONTENTS - Run 1 November 24, 1997 1. - ACQUISITION INFORMATION 2. - SEISMIC REPORT Describes source and Geophone locations, applies geometrical corrections and computes Average and Interval Velocities for the selected levels. 3. -PLOTS Plots of the check shots, and Time /Depth Curve ~. - DRIFT COMPUTATION REPORT Computes Drift by comparing Vertical Travel Times from the Seismic Report to the Integrated Travel Time from the open hole Sonic log. Computes suggested Block Shift Parameters for calibrating the open hole Sonic log to agree with the vertical Travel Times. 5. - SONIC ADJUSTMENT REPORT Lists the drift and Blockshift values actually used in computing the Calibrated Sonic Log. 6. - VELOCITY REPORT Computes Average Velocity, RMS Velocity and interval Velocity from Calibrated Sonic Log versus Two Way Travel Time. 7. - DEPTH REPORT Lists Two Way Travel Time From the Calibrated Sonic Log versus Two Way Travel Time. 8. - TIME REPORT Lists Depth from the Calibrated Sonic Log versus Two Way Travel Time. 9. - FIELD REPORTS 10. - TOOL SPECIFICATIONS, MISCELLANEOUS INFORMATION 11. - POUCHES Contain plots of the Calibrated Sonic log and Synthetic Seismogram, and Logs All interpretations are opinions based on inferences from electrical or other measurements and we cannot, and do not guarantee the accuracy or correctness of any interpretations, and we shall not, except in the case of gross or willful negligence on our part, be liable or responsible for any loss, costs, damages or expenses incurred or sustained by anyone resulting from any interpretations made by any of our officers, agents or employees. These interpretations are also subject to our general terms and conditions as set out in our current price schedule. Have a nice day! Arco Alaska Inc Warthog #1 Run 1 November 24, 1997 Processing Notes Schlumberger acquired a check shot survey for ARCO on November 24, 1997 on their Warthog #1 well. The data were acquired using the Schlumberger SAT 3 component tool to record the downhole signal. The source signature was generated by a single airgun with 2 shots per level due to limitations of the air supply. Overall quality of the data was good. The well logs were acquired by Schlumberger using the DSI in open hole. The check shots times were corrected for source and geophone offset and depths were corrected to true vertical depth. A difference was computed between check shot time and the integrated sonic times, resulting in a drift curve. The sonic log was corrected to the check shot time using the drift curve. The corrected sonic log is included in this report. This corrected log was then used to produce a reflection series and convolved with 20, and 30 hrz rickers to make synthetic seismograms which are included in this report. Ramona Sines GeoQuest Anchorage, Alaska ANALYST: R. SINES 29-DEC-97 15:01:08 PROGRAM: GSHOT 007.E09 * SCHLUMBERGER * VELOCITY SURVEY SUMMARY COMPANY WELL FIELD COUNTY STATE : ARCO ALASKA INC. : WARTHOG #1 : WILDCAT : NORTH SLOPE : ALASKA REFERENCE: 97551 ****************************** SURFACE ~EOMETR¥ TABLE ******************************* ELEVATION OF KELLY BUSHING (KB) ABOVE MEAN SEA LEVEL ELEVATION OF SEISMIC REFERENCE DATUM (SRD) ABOVE MSL ELEVATION OF GROUND LEVEL ABOVE SRD VELOCITY OF MEDIUM FROM SOURCE TO SURFACE SENSOR VELOCITY OF MEDIUM FROM SOURCE TO SRD 91.00 FT 0.00 FT -36.00 FT 6000.00 FT/SEC 6000.00 FT/SEC ******************************************************************************************* ******************************************************************************************* ****************************** SOURCE POSITION TABLE ******************************** ******************************************************************************************* SOURCE ELEVATION I SOURCE DISTANCE I SOURCE AZIMUTH I DEPTH RANGE I ABoVE sm~ I F~OM WE~m~O I P~O~ NORTH I FROM TO I -lO.O FT I ~ss.o FT I 13S.0 DES I 99999.0 o.o FT I ****************************** SURFACE SENSOR TABLE ********************************* ******************************************************************************************* ******************************************************************************************* SURFACE SENSOR ELEVATION ABOVE SRD -10.0 FT SURFACE SENSOR DISTANCE FROM WELLHEAD 158.0 FT SURFACE SENSOR AZIMUT~ FROM NORTH 135.0 DEG DEPTI4RANGE FROM TO 99999.0 0.0 FT ******************************************************************************************* ******************************************************************************************* ****************************** SOURCE ELEVATION TABLE ******************************* ******************************************************************************************* ******************************************************************************************* T~ FROM SURFACE I T~ FROM SENSOR TO SOURCE I SOURCE TO SRD 0.00 mS I 1.67 mS *************************** DEVIATED WELL RECEIVER GEOMETRY TABLE ****************************** LEVEL NO 1 2 3 4 5 6 7 8 9 10 11 12 13 14 15 16 17 18 19 20 21 22 23 24 25 26 27 28 29 30 31 32 33 34 35 36 37 38 39 40 41 MEASURED DEPTH FROM KB 250.3 FT 500.2 FT 750.1 FT 1000.3 FT 1250.3 FT 1500.1 FT 1750.0 FT 1999.7 FT 2250.5 FT 2500.3 FT 2750.5 FT 2999.7 FT 3250.4 FT 3500.8 FT 3750.8 FT 4000.5 FT 4250.3 FT 4500.7 FT 4750.4 FT 4999.6 FT 5250.2 FT 5500.0 FT 5750.0 FT 6000.5 FT 6250.3 FT 6500.6 FT 6750.5 FT 6999.9 FT 7250.3 FT 7500.3 FT 7750.6 FT 8000.4 FT 8250.4 FT 8500.7 FT 8750.2 FT 9000.1 FT 9250.5 FT 9500.3 FT 9750.1 FT 10000.6 FT 10250.5 FT VERTICAL DEP'i"H FROM KB 250.3 FT 500.1 FT 750.0 FT 1000 1 FT 1250 0 FT 1499 6 FT 1749 3 FT 1998 7 FT 2237 1 FT 2473 7 FT 2687 9 FT 2894 8 FT 3097 4 FT 3298 8 FT 3500 9 FT 3702 8 FT 3905 8 FT 4109 7 FT 4311 1 FT 4512.0 FT 4713.1 FT 4913.2 FT 5114.3 FT 5315.8 FT 5516.8 FT 5718.3 FT 5918.3 FT 6117.2 FT 6316.2 FT 6514.9 FT 6712.1 FT 6908.3 FT 7102.7 FT 7297.1 FT 7491.5 FT 7686.2 FT 7878.8 FT 8066.6 FT 8251.5 FT 8437.5 FT 8627.6 FT VERTICAL DEPT~4 FROM SRD 159.3 FT 409.1 FT 659.0 FT 909.1 FT 1159.0 FT 1408.6 FT 1658.3 FT 1907.7 FT 2146.1 FT 2382.7 FT 2596.9 FT 2803.8 FT 3006.4 FT 3207.8 FT 3409.9 FT 3611.8 FT 3814.8 FT 4018.7 FT 4220.1 FT 4421.0 FT 4622.1 FT 4822.2 FT 5023.3 FT 5224 8 FT 5425 8 FT 5627 3 FT 5827 3 FT 6026 2 FT 6225 2 FT 6423 9 FT 6621 1 FT 6817 3 FT 7011.7 FT 7206.1 FT 7400.5 FT 7595.2 FT 7787.8 FT 7975.6 FT 8160.5 FT 8346.5 FT 8536.6 FT EAST WEST COORDINATES -1.3 FT -2.6 FT -4.0 FT -5.3 FT -8.6 FT -14.8 FT -20.9 FT -27.1 FT -72.8 FT -120.8 FT -203.4 FT -295.5 FT -389.9 FT -484.5 FT -572.8 FT -660.6 FT -744.1 FT -824.8 FT -903.6 FT -982.4 FT -1059.8 FT -1136.5 FT -1212.1 FT -1287.8 FT -1365.5 FT -1443.7 FT -1527.7 FT -161'3.4 FT -1699.2 FT -1783.8 FT -1868.3 FT -1952.5 FT -2038 1 FT -2123 9 FT -2209 6 FT -2295 3 FT -2382 1 FT -2468 3 FT -2554 6 FT -2639.7 FT -2713.7 FT NORT74 SOUTI{ COORDINATES -3.6 FT -7.2 FT -10.9 FT -14.5 FT -21.3 FT -29.6 FT -37.9 FT -46.3 FT -95.9 FT -148.0 FT -240.6 FT -344.4 FT -457.9 FT -572.7 FT -690.4 FT -808.1 FT -927.3 FT -1048.2 FT -1173.0 FT -1297.6 FT -1425.6 FT -1553.8 FT -1681.8 FT -1809 9 FT -1936 2 FT -2062 4 FT -2186 3 FT -2310 0 FT -2435 5 FT -2561 3 FT -2690 3 FT -2820.0 FT -2951.8 FT -3084.0 FT -3214.9 FT -3346.0 FT -3480.4 FT -3620.7 FT -3764.8 FT -3909.3 FT -4045.5 FT GEOPHONE OFFSET 3.9 FT 7.7 FT 11.6 FT 15.4 FT 22.9 FT 33.1 FT 43.3 FT 53.6 FT 120.4 FT 191 1 FT 315 1 FT 453 8 FT 601 4 FT 750 2 FT 897 1 FT 1043 8 FT 1188 9 FT 1333 8 FT 1480 7 FT 1627 5 FT 1776 3 FT 1925 1 FT 2073.1 FT 2221.3 FT 2369.2 FT 2517.5 FT 2667.2 FT 2817.7 FT 2969.7 FT 3121.3 FT 3275.4 FT 3430.0 FT 3587.0 FT 3744.6 FT 3901.0 FT 4057.6 FT 4217.5 FT 4382.0 FT 4549.7 FT 4717.1 FT 4871.4 FT GEOPMONE AZIML~i74 -160.0 DEG -160.0 DEG -160.0 DEG -160.0 DEG -158.0 DEG -153.5 DEG -151.1 DEG -149.6 DEG -142.8 DEG -140.8 DEG -139.8 DEG -139.4 DEG -139.6 DEG -139.8 DEG -140.3 DEG -140.7 DEG - 141.3 DEG -141.8 DEG -142.4 DEG -142 9 DEG -143 4 DEG -143 8 DEG -144 2 DEG -144 6 DEG -144 8 DEG -145 0 DEG -145.1 DEG -145.1 DEG - 145.1 DEG -145.1 DEG -145.2 DEG -145.3 DEG -145.4 DEG -145.4 DEG -145.5 DEG -145.6 DEG -145.6 DEG -145.7 DEG -145.8 DEG - 146.0 DEG -146.1 DEG COMPANY : ARCO ALASKA INC. WELL : WARTHOG #1 LEVEL NO 10 11 14 15 16 18 19 20 21 22 23 MEASURED DEPTH FROM ~ 250.3 500.2 750.1 1000.3 1250.3 1500.1 1750.0 1999.7 2250.5 2500.3 2750.5 2999.7 3250.4 3500.8 3750.8 4000.5 4250.3 4500.7 4750.4 4999.6 5250.2 5500.0 5750.0 VERTICAL DEPTH FROM SRD FT 159.3 409.1 659.0 909.1 1159.0 1408.6 1658.3 1907.7 2146.1 2382.7 2596.9 2803.8 3006.4 3207.8 3409.9 3611.8 3814.8 4018.7 4220.1 4421.0 4622.1 4822.2 5023.3 MEAS~D TIME FROM SURFACE SENSOR TO GEO 34.9 66 8 104 6 144 0 183 4 222 7 260.5 296.1 332.2 367.3 400.4 432.7 464.7 496.7 527.5 558.9 588.1 618.6 647.8 676.8 705.5 732.9 761.2 VERTICAL TIME FROM SOURCE TO GEOPHONE mS 24.1 62.3 101.8 142.0 181.9 221.4 259.4 295.1 331.0 365.5 397.0 426.7 455.4 483.5 510.1 537.0 561.6 587.4 611.7 635.6 659.1 681.3 704.4 VERTICAL TIME FROM SRD/GEO. 25.8 63.9 103.5 143.6 183.5 223.1 261.1 296.8 332.6 367.2 398.6 428.4 457.0 485.1 511.7 538.6 563.3 589.0 613.3 637.3 660.8 683.0 706.0 AVERAGE VELOCITY SRD/GEO. FT/S 6182 6398 6369 6329 6316 6314 6352 6428 6452 6489 6514 6545 6578 6612 6663 6706 6772 6822 6881 6937 6995 7060 7115 DELTA DEPTH FT 249.9 249.9 250.2 249.9 249.6 249.7 249.5 238.3 236.6 214.3 206.9 202.6 201.4 202.1 201.9 203.0 203.9 201.4 201.0 201.0 200.2 201.0 DELTA TIME 38.2 39.5 40.2 39.9 39.6 38.0 35.7 35.8 34.5 31.5 29.8 28.6 28.1 26.6 26.9 24.6 25.8 24.3 24.0 23.5 22.2 23.0 IITi"ERVAL VELOCITY FT/S 6544 6323 6224 6268 6307 6573 6982 6653 6848 6808 6955 7071 7173 7593 7507 8236 7916 8296 8385 8551 9011 8721 201.5 22.1 9127 COMPANY : ARCO ;LLASKA INC. WELL : WARTHOG #1 LEVEL NO 24 25 26 27 28 29 30 31 32 33 34 35 36 37 38 39 40 41 MEASURED DEPT~ FROM KB FT 6000.5 6250.3 6500.6 6750.5 6999.9 7250.3 7500.3 7750.6 8000.4 8250.4 8500 7 8750 2 9000 1 9250 5 9500 3 9750 1 10000.6 10250.5 VERTICAL DEP~ FROM SRD 5224.8 5425.8 5627.3 5827.3 6026.2 6225.2 6423.9 6621.1 6817.3 7011.7 7206.1 7400.5 7595.2 7787.8 7975.6 8160.5 8346.5 8536.6 MF_J~SURED TIME FROM SURFACE SENSOR TO GEO 788.5 815.1 842.4 868 6 892 4 916 2 940 0 962 4 984 7 1006.9 1032.1 1053.3 1072.4 1095.6 1117.8 1142.0 1163.3 1182.3 VERTICAL TIME FROM SOURCE TO GEOPHONE 726.5 747.9 769.9 790.7 809.4 827.9 846.5 863.6 880.7 897.5 916.9 932.8 947.0 964.5 980.8 998.6 1013.9 1028.0 VERTICAL TIS~E FROM SRD/GEO. mS 728.1 749.5 771.5 792 4 811 0 829 6 848 1 865 3 882 3 899 1 918.5 934.5 948.6 966.1 982.4 1000.2 1015.5 1029.7 AVERAGE VELOCITY SRD/GEO. FT/S 7176 7239 7294 7354 7430 7504 7574 7652 7726 7798 7845 7919 8007 8061 8118 8159 8219 8290 DELTA DEPTH FT 201.0 201.5 200.1 198.9 199.0 198.7 197.2 196.2 194.5 194.4 194.4 194.7 192.7 187.8 184.9 186.0 190.1 DELTA TIME 21.4 22 0 20 9 18 6 18 5 18 6 17 2 17 0 16.8 19.4 16.0 14.1 17.5 16.3 17.8 15.3 14.1 INTERVAL VELOCITY FT/S 9394 9153 9587 10687 10730 10704 11492 11516 11584 10002 12184 13795 10989 11528 10386 12144 13442 ANALYST: R. SINES 13~JAN-98 17:39:02 PROGRAM: GTRFRM 001.E14 * . * . * . * SCHLUMBERGER * * . DEPTH REPORT COMPANY WELL FIELD COUNTY STATE : ARCO ~KA INC. : WARTHOG #1 : WILDCAT : NORTH SLOPE : kLASKA REFERENCE: 97551 COMPANY : ARCO /tLASKA INC. WELL : WARTHOG #1 PAGE 1 LONG DEFINITIONS GLOBAL STPDPT - SAMPLING OF DEPTH REPORT SAMPLED NTIM - NAM Depth Report Time NTIM - NAM Depth Report Time NTIM - NAM Depth Report Time NTIM - NAM Depth Report Time NTIM - NAM Depth Report Time NTIM - NAM Depth Report Time NTIM - NAM Depth Report Time NTIM - NAM Depth Report Time NTIM - NAM Depth Report Time NTIM - NAM Depth Report Time (GLOBAL P~TERS) STEP OF DEPTH LIST (WST) STPDPT ( VALUE ) : 100.000 FT COMPANY : ARCO ALASKA INC. WELL : WARTHOG #1 PAGE 2 VERTICAL TWO WAY TWO WAY TWO WAY TWO WAY DEPTH TIME AT TIME AT TIME AT TIME AT FROM + 0 * + 1 * + 2 * + 3 * SRD SMPL/10 SMPL/10 SMPL/10 SMPL/10 FT MS MS MS MS 0 100.0 200.0 300.0 400.0 500.0 600.0 700.0 800.0 900.0 1000.0 1100.0 1200.0 1300.0 1400.0 1500.0 1600.0 1700.0 1800.0 1900.0 2000.0 2100.0 2200.0 2300.0 2400.0 250O.0 2600.0 2700.0 2800.0 2900.0 3000.0 3100.0 3200.0 3300.0 3400.0 3500.0 3600.0 3700.0 3800.0 3900.0 4000.0 4100.0 4200.0 4300.0 4400.0 4500.0 4600.0 4700.0 4800.0 4900.0 5000.0 5100.0 5200.0 5300.0 5400.0 5500.0 5600.0 0 33.07 65.12 95.68 126.24 157.78 189.41 221.25 253.38 285.51 317.44 349 35 381 18 412 89 444 59 475 13 505 56 535.24 563.89 592.53 622.49 652.55 682.14 711.35 740.58 769.96 799.31 828.07 856.36 884.67 912.93 939.98 966.91 993.43 1019.83 1045.84 1072.16 1098.32 1123.40 1147.59 1171.74 1195.53 1219.20 1242.54 1266.28 1289.82 1312.63 1335.46 1358.56 1381.01 1404.15 1426.76 1449.64 1472.18 1494.29 1514.91 1534.71 3.31 36.38 68.17 98.74 129.31 160.94 192.57 224.46 256.59 288.72 320.63 352.54 384.35 416.06 447.75 478.17 508.60 538.10 566.75 595.43 625.49 655 55 68! .06 714 27 743 52 772 90 802 19 830 95 859 19 887.50 915.70 942.67 969.61 996.06 1022.46 1048.51 1074.92 1100.90 1125.96 1149.95 1174.10 1197.94 1221.45 1244.93 1268.82 1292.28 1314.97 1337.76 1360.72 1383.33 1406.53 1429.08 1451.90 1474.44 1496.53 1516.95 1536.94 6.61 39.69 71.23 101.79 132.47 164 10 195 74 227 68 259 81 291 91 323 82 355 73 387.52 419.23 450.79 481.22 511.64 540.97 569.61 598.44 628.50 658.56 687.98 717.19 746.46 775.83 805.06 833.78 862.02 890 33 918 40 945 37 972 28 998 66 1025 04 1051 10 1077.64 1103.42 1128.53 1152.35 1176.46 1200.36 1223.78 1247.32 1271.24 1294.53 1317 36 1340 21 1362 99 1385 68 1408 86 1431 40 1454.13 1476.66 1498.68 1519.05 1539.03 TWO WAY TWO WAY TIME AT TIME AT + 4 * + 5 * SMPL/10 SMPL/10 9.92 43.00 74.29 104.85 135.63 167.27 198.90 230.89 263.02 295.11 327.01 358.92 390.69 422.40 453.83 484.26 514.69 543.83 572.48 601.44 631 50 661 56 690 91 720 11 749 39 778 77 80794 836,61 864,86 893.16 895 921.10 923 948.06 950 974.95 977 1001.33 1003 1027.61 1030 1053.71 1080.24 1105.92 1130.82 1154.73 1178.76 1202.69 1226.14 1249.68 1273.54 1296.60 1319.59 1342.63 1365.23 1388.00 1411.13 1433.70 1456.36 1478.77 1500.77 1521.22 1541.08 13.23 46.30 77.34 107.90 138.80 170.43 202.06 234.10 266.23 298.30 330.20 362.11 393.86 425.57 456 87 487 30 517 73 546 70 575 34 604 45 634 51 664 57 69383 723.03 752.33 781.71 810.82 839.43 867.69 .98 .80 .75 .63 .99 .24 1056.30 1082.84 1108.42 1133.20 1157.05 1181.22 1205.00 1228.48 1252.07 1275.91 1298.77 1321.96 1344.96 1367.43 1390.38 1413.43 1435.96 1458.58 1481.05 1502.84 1522.90 1543.12 16.54 49.61 80.40 110.96 141.96 173.59 205.23 237.32 269.45 301.49 333.40 365.30 397.03 428.74 459.92 490.35 520.77 549.56 578.21 607.46 637.52 667.54 696.75 725.95 755.27 784.65 813.69 842.25 870.52 898.81 926.50 953.45 980.26 1006.58 1032.86 1058.84 1085.48 1111.00 1135.52 1159.49 1183.54 1207.31 1230.83 1254.43 1278.31 1300.99 1324.32 1347.25 1369.66 1392.63 1415.77 1438.23 1460.81 1483.24 1504.89 1524.48 1545.19 TWO WAY TIME AT + 6 * SMPL/10 19.84 52.89 83.46 114.02 145.12 176.76 208.40 240.53 272.66 304.68 336.59 368.49 400.20 431.91 462.96 493.39 523 78 552 43 581 07 610 46 640 52 670 46 699 67 728.87 758.21 787.58 816.57 845.08 873.35 901.63 929.19 956.14 982.90 1009.24 1035.47 1061.39 1088.10 1113.49 1137.86 1162.00 1186.00 1209.65 1233.14 1256.83 1280.61 1303.42 1326.73 1349.50 1371.92 1394.93 1417.90 1440.47 1463.10 1485.42 1506.88 1526.49 1547.27 TWO WAY TWO WAY TWO WAY TIME AT TIME AT TIME AT +7* +8* +9* SMPL/10 SMPL/10 SMPL/10 MS ME MS 23 15 55 95 86 51 117 07 148 29 179 92 211 61 243 74 275 87 307 87 339.78 371.66 403.37 435.08 466.00 496.43 526.64 555.29 583.94 613.47 643.53 673.38 702.59 731.79 761.15 790.52 819.44 847.90 876.18 904.46 931.89 958.83 985.56 1011.88 1038.07 1063.94 1090.67 1116.01 1140.28 1164.50 1188.39 1212.03 1235.45 1259.21 1282.85 1305.83 1329.03 1351.67 1374.24 1397.23 1420.01 1442.80 1465.40 1487.66 1508.83 1528.54 1549.27 26.46 59.01 89.57 120.13 151.45 183.08 214.82 246.95 279.09 311.06 342.97 374.83 406.54 438.25 469.05 499.47 529.51 558.16 586.80 616.47 646.53 676.30 705.51 734.71 764 08 793 46 822 32 850 72 879 01 907 28 934.59 961.53 988.21 1014.55 1040.64 1066.67 1093.15 1118.59 1142.77 1166.87 1190.68 1214.53 1237 81 1261 57 1285 12 1308 15 133113 1354,00 1376,51 1399.52 1422.18 1445.13 1467.64 1489.79 1510.78 1530.53 1551.34 29.77 62.06 92.62 123.19 154.61 186.25 218.04 250.17 282.30 314.25 346.16 378.01 409.71 441.42 472.09 502.52 532.37 561.02 589.67 619.48 649.54 679.22 708.43 737.64 767.02 796.40 825.20 853.54 881.84 910.11 937.28 964.21 990.85 1017.22 1043.20 1069.31 1095.60 1120.98 1145.18 1169.30 1193.08 1216.86 1240.14 1263.87 1287.47 1310.45 1333.31 1356.34 1378.76 1401.85 1424.42 1447.40 1469.94 1492.04 1512.80 1532.65 1553.29 COMPANY : ARCO ALASKA INC. WELL : WARTHOG #1 PAGE 3 VERTICAL TWO WAY TWO WAY TWO WAY TWO WAY DEPTH TIME AT TIME AT TIME AT TIME AT FROM + 0 * + 1 * + 2 * + 3 * SRD SMPL/10 SMPL/10 SMPL/10 SMPL/10 FT MS MS MS MS 5700.0 5800.0 5900.0 6000.0 6100.0 6200.0 6300.0 6400.0 6500.0 6600.0 6700.0 6800.0 6900.0 7000.0 7100.0 7200.0 7300.0 7400 0 7500 0 7600 0 7700 0 7800 0 7900 0 8000.0 8100.0 8200.0 8300.0 8400.0 8500.0 1555.36 1575.49 1594.85 1613.87 1632.61 1651.67 1670.86 1688 75 1707 33 1725 40 1743 51 1761 50 1779 19 1796.96 1814.84 1832.78 1850.38 1868.17 1885.98 1903.18 1920.28 1937.49 1954.63 1971.19 1987.89 2004.57 2021.26 2037.81 2054.40 1557.42 1577.48 1596.73 1615.84 1634.44 1653.61 1672.75 1690.64 1709.10 1727.27 1745.36 1763.27 1781.00 1798.76 1816.60 1834.56 1852.15 1869.94 1887.67 1904.92 1921.97 1939.18 1956.30 1972.85 1989.53 2006.25 2022.91 2039.49 2056.07 1559.54 1579.42 1598.59 1617.68 1636.51 1655.49 1674.53 1692.56 1710 94 1729 04 1747 16 1765 02 1782 78 180056 1818.40 1836.29 1853.85 1871.63 1889.40 1906.66 1923.69 1940.87 1957.92 1974.53 1991.30 2007.94 2024.52 2041.17 2057.74 1561.63 1581.41 1600.50 1619.52 1638.42 1657.40 1676.30 1694.49 1712.77 1730.84 1748.95 1766.81 1784.56 1802.37 1820 21 1838 02 1855 61 1873 36 1891 11 1908 41 192555 1942,46 1959,61 1976.21 1992.95 2009.60 2026.24 2042.85 2059.42 TWO WAY TWO WAY TIME AT TIME AT + 4 * + 5 * SMPL/10 SMPL/10 MS MS 1563.55 1565.55 1583.33 1585.26 1602.48 1604.48 1621.35 1623.20 1640 26 1642.26 1659 32 1661.37 1678 10 1679.94 1696 37 1698.19 1714 59 1716.41 1732 64 1734.45 1750.76 1752.60 1768.48 1770.26 1786.34 1788.12 1804.16 1805.89 1822.01 1823.82 1839.77 1841.49 1857.33 1859.16 1875.23 1877.16 1892.77 1894.40 1910.12 1911.78 1927.34 1928.97 1944 23 1945.98 1961 28 1962.95 1977 86 1979.52 1994 57 1996.26 2011 29 2012.97 202784 2029.52 2044.53 2046.18 TWO WAY TIME AT + 6 * SMPL/10 1567.60 1587.19 1606.37 1625.09 1644.13 1663.13 1681.66 1699.95 1718.28 1736.29 1754.39 1772.04 1789.88 1807.68 1825.60 1843.25 1860.98 1878.96 1896.15 1913.51 1930.69 1947.72 1964.60 1981.23 1997.95 2014.65 2031.17 2047.82 TWO WAY TWO WAY TWO WAY TIME AT TIME AT TIME AT +7* +8* +9* SMPL/10 SMPL/10 SMPL/10 MS MS MS 1569.48 1589.04 1608.33 1626.90 1645.95 1665.09 1683.44 1701.78 1720 10 1738 12 1756 21 1773 81 1791 65 1809 54 1827 48 1845,09 1862.81 1880.71 1897.91 1915.20 1932.40 1949.46 1966.24 1982.92 1999.61 2016.30 2032.83 2049.49 1571.53 1573.56 1591.06 1592.91 1610 17 1612.05 1628 82 1630.70 1647 86 1649.74 1666 96 1668.91 1685 18 1687.01 1703 62 1705.53 1721.86 1723.63 1739.96 1741.72 1757.98 1759.74 1775.56 1777.39 1793.43 1795.20 1811.33 1813.09 1829.27 1831.01 1846.85 1848.62 1864.61 1866.39 1882.42 1884.25 1899.67 1901.43 1916.90 1918.59 1934.11 1935.79 1951.21 1952.94 1967.88 1969.54 1984.64 1986.31 2001.27 2002.91 2017.94 2019.59 2034.47 2036.13 2051.13 2052.76 ANALYST: R. SINES 13-JAN-98 17:38:56 PROGRAM: GTRFRM 001.El4 * SCHLUMBERGER * * . ******************** TIME REPORT COMPANY WELL FIELD COUNTY STATE : ARCO ALASKA INC. : WARTHOG #1 : WILDCAT : NORTH SLOPE : ALASKA REFERENCE: 97551 COMPANY : ARCO ALASKA INC. WELL : WARTHOG #1 PAGE 1 LONG DEFINITIONS GLOBAL STPTIM - SAMPLING OF TIME REPORT SAMPLED N-DPT - NAM Time Report Depth NDPT - NAM Time Report Depth NDPT - NAM Time Report Depth NDPT - NAM Time Report Depth NDPT - NAM Time Report Depth NDPT - NAM Time Report Depth NDPT - NAM Time Report Depth NDPT - NAM Time Report Depth NDPT NAM Time Report Depth N-DPT NAM Time Report Depth (GLOBAL PARAMETERS) STEP OF TIME LIST (WST) STPTIM (VALUE) : 10.0000 MS COMPANY : ARCO ~KA INC. WELL : WARTHOG #1 PAGE 2 TWO WAY DEPTH DEPTH DEP'I"H DEPTH DEPT~ DEPTH DEPTH DEPT~ DEPTH DEPTH SONIC /SRD AT /SRD AT /SRD AT /SRD AT /SRD AT /SRD AT /SRD AT /SRD AT /SRD AT /SRD AT TIME + 0 * + 1 * + 2 * + 3 * + 4 * + 5 * + 6 * + 7 * + 8 * + 9 * FROM SRD SMPL/10 SMPL/10 SMPL/10 SMPL/10 SMPL/10 SMPL/10 SMPL/10 SMPL/10 SMPL/10 SMPL/10 MS FT FT FT FT FT FT FT FT FT FT 0 0 3.0 6.0 10 00 30.2 33.3 36.3 39 20 00 60.5 63.5 66.5 69 30 00 90.7 93.7 96.8 99 40 00 120.9 124.0 127.0 130 50 00 151.2 154.2 157.2 160 60 00 183.3 186.5 189.8 193 70.00 216.0 219.2 222.5 225 80.00 248.7 252.0 255.2 258 3 42.3 45.4 48 5 72.6 75.6 78 8 102.8 105.8 108 0 133.0 136.1 139 3 163.6 166.9 170 1 196.3 199 6 202 8 229.1 232 3 235 5 261.8 265 90.00 281.4 284.7 288.0 291.2 294.5 297 100.00 314 1 317.4 320.7 324.0 327.2 330 110.00 346 120.00 379 130.00 412 140.00 443 150.00 475 160.00 507 170.00 538 180.00 570 190.00 601 200.00 633 210.00 665 0 668.1 671 220.00 696.1 699.2 702 9 350.1 353.4 356.7 359.9 363 6 382.8 386.1 389.4 392.7 395 2 415.3 418.5 421.7 424.8 428 8 447.0 450.1 453.3 456 4 459 4 478.6 481.7 484.9 488 0 510.2 513.3 516.5 519 6 541.8 545.0 548.1 551 3 573.4 576.6 579.7 582 9 605.0 608 2 611.3 614 5 636.6 639 8 643.0 646 2 674.3 677 3 705.4 708 9 1 12.1 15.1 18 1 21.2 24.2 27.2 4 51.4 54.4 57.4 6 81.6 84.7 87.7 8 111.9 114.9 117.9 1 142.1 145.1 148.2 2 173.4 176 7 180.0 9 206.2 209 4 212.7 6 238.9 242 1 245.4 1 268 3 271.6 274 9 278.1 8 301 0 304.3 307 6 310.9 5 333.8 337.0 340 3 343.6 2 366.5 369.8 373 0 376.3 9 399.2 402.5 405 8 409.0 0 431.2 434.3 437 5 440.6 6 462.8 465.9 469.1 472.3 1 491.2 494.4 497.5 500.7 503.9 7 522.8 526.0 529.2 532.3 535.5 3 554.4 557.6 560.8 563.9 567.1 9 586.1 589.2 592.4 595.5 598.7 5 617.7 620.8 624.0 627.2 630.3 1 649.3 652.4 655.6 658.8 661.9 4 680.6 683.7 686.8 689.9 693.0 6 711.7 714.8 717.9 721.0 724.1 230.00 727.2 730.3 733 5 736.6 739.7 742.8 745.9 749 0 752.1 755.2 240.00 758.4 761.5 764 6 767.7 770.8 773.9 777.0 780 i 783.3 786.4 250.00 789.5 792.6 795 7 798.8 801.9 805.0 808.2 811 3 814.4 817.5 260.00 820.6 823.7 826 8 829.9 833.0 836.2 839.3 842 4 845.5 848.6 270.00 851.7 854.8 857 9 861.1 864.2 867.3 870.4 873 5 876.6 879.7 280.00 882.8 886.0 889.1 892.2 895.3 898.4 901.5 904 6 907.7 910.9 290 00 914.0 917.1 920.3 923.4 926.5 929.7 932.8 935 9 939.1 942.2 300 00 945.3 948.5 951.6 954.7 957.9 961.0 964.1 967.3 970.4 973.5 310 00 976.7 979 8 982.9 986.1 989.2 992.3 995 5 998.6 1001.8 1004.9 320 00 1008.0 1011 2 1014.3 1017.4 1020.6 1023.7 1026 8 1030.0 1033.1 1036.2 330 00 1039.4 1042 5 1045.6 1048.8 1051.9 1055.0 1058 2 1061.3 1064.4 1067.6 340 00 1070.7 1073 8 1077.0 1080.1 1083.2 1086.4 1089 5 1092.6 1095.8 1098.9 350 00 1102.0 1105 2 1108.3 1111.4 1114.6 1117.7 1120 8 1124.0 1127.1 1130.2 36000 1133.4 1136 5 1139.6 1142.8 1145.9 1149 0 1152 2 1155.3 1158.4 1161.6 370.00 1164.8 1167 9 1171.1 1174.2 1177.4 1180 5 1183 7 1186.8 1190.0 1193.1 380.00 1196.3 1199.4 1202.6 1205.8 1208.9 1212 1 1215.2 1218.4 1221.5 1224.7 390.00 1227.8 1231.0 1234.1 1237.3 1240.4 1243 6 1246.7 1249.9 1253.1 1256.2 400.00 1259.4 1262.5 1265.7 1268.8 1272.0 1275 1 1278.3 1281.4 1284.6 1287.7 410.00 1290.9 1294.1 1297.2 1300.4 1303 5 1306 7 1309.8 1313.0 1316.1 1319.3 420.00 1322.4 1325.6 1328.7 1331.9 1335 1 1338.2 1341.4 1344.5 1347.7 1350.8 430.00 1354.0 1357.1 1360,3 1363.4 1366 6 1369.7 1372.9 1376.0 1379.2 1382.4 440.00 1385.5 1388.7 1391.8 1395.0 1398 1 1401.3 1404.4 1407.6 1410.8 1414.1 450.00 1417.4 1420.7 1424.0 1427.3 1430 6 1433.8 1437.1 1440.4 1443.7 1447.0 460.00 1450.3 1453.6 1456.8 1460.1 1463 4 1466.7 1470.0 1473.3 1476.6 1479.8 470.00 1483.1 1486.4 1489.7 1493.0 1496.3 1499.6 1502.9 1506.1 1509.4 1512.7 480.00 1516.0 1519.3 1522.6 1525.9 1529.1 1532.4 1535.7 1539.0 1542.3 1545.6 490.00 1548.9 1552.2 1555.4 1558.7 1562.0 1565.3 1568.6 1571.9 1575.2 1578.4 500.00 1581.7 1585.0 1588.3 1591.6 1594.9 1598.2 1601.4 1604.7 1608.0 1611.3 510.00 1614.6 1617 9 1621.2 1624.5 1627.7 1631.0 1634.3 1637.6 1640.9 1644.2 520.00 1647.5 1650 7 1654.0 1657.3 1660.8 1664.3 1667.8 1671.2 1674.7 1678.2 530.00 1681.7 1685 2 1688.7 1692.2 1695.7 1699.2 1702.7 1706.1 1709.6 1713.1 540.00 1716.6 1720 1 1723.6 1727.1 1730.6 1734.1 1737.6 1741.1 1744.5 1748.0 550.00 1751.5 1755 0 1758.5 1762.0 1765.5 1769.0 1772.5 1776.0 1779.5 1782.9 560.00 1786.4 1789 9 1793.4 1796.9 1800.4 1803.9 1807.4 1810.9 1814.4 1817.9 COMPANY : i~RCO ~LASKA INC. WELL : WARTHOG #1 PAGE 3 TWO WAY DEPT}{ DEPTH DE PTI-I DEPTH D E P'i/q DEPTI~ DEPT"H DEPTH DEPTH DEPT~ SONIC /SRD AT /SRD AT /SRD AT /SRD AT /SRD AT /SRD AT /SRD AT /SRD AT /SRD AT /SRD AT TIME + 0 * + 1 * + 2 * + 3 * + 4 * + 5 * + 6 * + 7 * + 8 * + 9 * FROM SRD SMPL/10 SMPL/10 SMPL/10 SMPL/10 SMPL/10 SMPL/10 SMPL/10 SMPL/10 SMPL/10 SMPL/10 MS FT FT FT FT FT FT FT FT FT FT 570.00 1821.3 1824.8 1828.3 1831.8 1835.3 1838.8 184~.3 1845.8 1849.3 1852.8 580.00 1856 3 1859.7 1863.2 1866.7 1870 2 1873.7 1877 590.00 1891 600.00 1925 610.00 1958 620.00 1991 630.00 2025 640.00 2058 650.00 2091 660.00 2124 8 2128 670.00 2158.4 2161 2 1894.7 1898.1 1901.6 1905 2 1928.5 1931.8 1935.2 1938 5 1961.8 1965.1 1968.4 1971 7 1995.1 1998.4 2001.7 2005 0 2028.3 2031.6 2035.0 2038 3 206].6 2064.9 2068.2 2071 5 2094 9 2098.2 2101.5 2104 1 2131.4 2134.8 2138 8 2165.3 2168.7 2172, 1 1908.6 1911 5 1941.8 1945 8 1975.1 1978 0 2008.4 2011 3 2041.6 2045 6 2074.9 2078 8 2108.2 2111 1 2141.4 2144 1 2175.5 2179 2 1880.7 1884.2 1887.7 9 1915.2 1918.5 1921.9 2 1948.5 1951.8 1955.1 4 1981.7 1985.1 1988.4 7 2015.0 2018.3 2021.7 0 2048.3 2051.6 2054.9 2 2081.5 2084.9 2088 2 5 2114.8 2118.1 2121 5 8 2148.1 2151.6 2155 0 0 2182.4 2185.8 2189 2 2 2216.6 2220.1 2223 5 4 2250.9 2254.3 2257 7 860.00 2812 9 2816.4 2819.9 2823.5 2827 870.00 2848 2 2851.7 2855.2 2858.8 2862 880.00 2883 5 2887.0 2890.6 2894.1 2897 890.00 2918 8 2922.4 2925.9 2929.4 2933 900.00 2954 2 2957.8 2961.3 2964.8 2968 910.00 2989 6 2993 2 2996.7 3000.2 3003, 920.00 3025.9 3029 6 3033.3 3037.0 3040, 930.00 3063.0 3066 7 3070.4 3074.1 3077, 0 2830.5 2834.0 2837.6 2841.1 2844.6 3 2865.8 2869.4 2872.9 2876.4 2880.0 6 2901.2 2904.7 2908.2 2911.8 2915.3 0 2936.5 2940.1 2943.6 2947.1 2950.7 4 2971.9 2975.5 2979.0 2982.5 2986.1 8 3007.4 3011.1 3014.8 3018.5 3022.2 7 3044.5 3048.2 3051.9 3055.6 3059.3 8 3081.5 3085.2 3089.0 3092.7 3096.4 940.00 3100.1 3103 8 3107.5 3111.2 3114.9 3118.6 3122.4 3126.1 3129.8 3133.5 950 00 3137.2 3140 9 3144.6 3148.3 3152.1 3155 8 3159.5 3163.2 3166.9 3170.6 960 00 3174.3 3178 0 3181.8 3185.5 3189.2 3192 9 3196.6 3200.3 3204.1 3207.8 970 00 3211.4 3215.1 3218 9 3222.7 3226.5 3230 2 3233.9 3237.6 3241.4 3245.2 980 00 3249.0 3252.8 3256 6 3260.4 3264.1 3267 9 3271.7 3275.5 3279.2 3283.1 990 00 3286.8 3290.6 3294 4 '3298.4 3302.2 3306 0 3309.8 3313.7 3317.5 3321.2 1000,00 3325.0 3328.8 3332 5 3336.3 3340.0 3343 9 3347.7 3351.6 3355.4 3359.1 1010.00 3362.9 3366.7 3370 4 3374.2 3377.9 3381.7 3385.4 3389.2 3393.0 3396.8 1020.00 3400.6 3404.4 3408 2 3412.1 3416.0 3419.8 3423.8 3427.7 3431.5 3435.3 1030.00 3439.1 3442.9 3446.7 3450.5 3454.3 3458.2 3462.0 3465.9 3469.7 3473.6 1040.00 3477 5 3481.4 3485.4 3489.3 3493.0 3496.8 3500.6 3504.4 3508.1 3511.9 1050.00 3515 8 3519.6 3523.4 3527.2 3531.1 3534.9 3538.8 3542.7 3546.7 3550.6 1060.00 3554 5 3558.5 3562.4 3566.5 3570.2 3573.9 3577.5 3581.2 3585.0 3588.8 1070.00 3592 5 3596.0 3599.4 3603.0 3606.7 3610.3 3614.0 3617.7 3621.4 3625.2 1080.00 3629 1 3632.9 3636.7 3640.6 3644.4 3648.2 3652.0 3655.8 3659.6 3663.6 1090.00 3667 4 3671.4 3675.5 3679.4 3683.4 3687.7 3691.5 3695.2 3698.8 3702.5 1100.00 3706.4 3710.4 3714.2 3718.4 3722.3 3726.3 3730.3 3734.3 3738.4 3742.2 1110.00 3746.1 3750.0 3753.9 3758.1 3762.0 3766.0 3770.0 3773.9 3777.8 3781.6 1120.00 3785.9 3790.1 3794.1 3798.2 3802.4 3806.4 3810.1 3814.0 3818.0 3821.9 1130.00 3826.4 3830.8 3835.0 3839.2 3843.4 3847.7 3852.1 3856.3 3860.6 3864.7 680.00 2192.7 2196 1 2199.5 2202.9 2206.4 2209.8 2213 690.00 2226.9 2230 3 2233.7 2237.2 2240.6 2244.0 2247 700.00 2261.1 2264 6 2268.0 2271.4 2274.8 2278.3 2281.7 2285.1 2288.5 2292 0 710.00 2295.4 2298 8 2302.2 2305.7 2309.1 2312.5 2315.9 2319.4 2322.8 2326.2 720.00 2329.6 2333 1 2336.5 2339 9 2343.3 2346.7 2350.2 2353.6 2357.0 2360.4 730 00 2363.9 2367 3 2370.7 2374 1 2377.6 2381 0 2384.4 2387.8 2391.2 2394.6 740 00 2398.0 2401 4 2404.8 2408 2 2411.6 2415 0 2418.4 2421.8 2425.3 2428.7 750 00 2432.1 2435.5 2438.9 2442 3 2445.7 2449 1 2452.5 2455.9 2459.3 2462.7 760 00 2466.1 2469.5 2472.9 2476 3 2479.7 2483 1 2486.5 2489.9 2493.3 2496.7 770 00 2500.1 2503.5 2507 0 2510 4 2513.8 2517 2 2520.6 2524.0 2527 4 2530.8 780 00 2534.2 2537.6 2541 0 2544.4 2547.8 2551 2 2554.6 2558.0 2561 4 2564.8 790 00 2568.2 2571.6 2575 0 2578.4 2581.8 2585.2 2588.6 2592.1 2595 5 2598.9 800.00 2602.4 2605.9 2609 3 2612.8 2616.3 2619.8 2623.3 2626.7 2630 2 2633.7 810.00 2637.2 2640.6 2644 1 2647.6 2651.1 2654.5 2658.0 2661.5 2665 0 2668.5 820.00 2671.9 2675.4 2678 9 2682.4 2685.8 2689.3 2692.8 2696.3 2699 8 2703.2 830.00 2706.7 2710.2 2713.7 2717.2 2720.8 2724.3 2727.8 2731.4 2734.9 2738.5 840.00 2742.0 2745.6 2749.1 2752.6 2756.2 2759.7 2763.3 2766.8 2770.4 2773.9 850.00 2777.5 2781.0 2784.5 2788.1 2791 6 2795.2 2798.7 2802.3 2805.8 2809.3 COMPANY : ARCO ALJ~SKA INC. WELL : WARTHOG #1 PAGE 4 TWO WAY DEPTH DE PTIq DE P'I/q DE P'I~ DEP~ DE P'IS{ DEPTH DEPTH DE P'I~4 DEP~ SONIC /SRD AT /SRD AT /SRD AT /SRD AT /SRD AT /SRD AT /SRD AT /SRD AT /SRD AT /SRD AT TIME + 0 * + 1 * + 2 * + 3 * + 4 * + 5 * + 6 * + 7 * + 8 * + 9 * FROM SRD SMPL/10 SMPL/10 SMPL/10 SMPL/10 SMPL/10 SMPL/10 SMPL/10 SMPL/10 SMPL/10 SMPL/10 MS FT FT FT FT FT FT FT FT FT FT 1140.00 3868.9 3872.9 3876.9 3880.9 3885.0 3889.2 3893 4 3897.5 3901.8 3906.0 1150.00 3910.2 3914.3 3918.5 3922.8 3927.0 3931.1 3935 4 3939.8 3943.8 3948.0 1160.00 3952.1 3956.0 3960.0 3964.2 3968.1 3972.0 3976 2 3980.6 3984.7 3988.8 1170.00 3992.9 3996.9 4001.2 4005.5 4009.6 4013.7 4018 0 4022.4 4026.8 4031 0 1180.00 4035.1 4039 1 4043.4 4047.8 4051.9 4055.9 4060 0 4064.0 4068.3 407~ .7 1190.00 4077.1 4081 3 4085.6 4089.7 4093.8 4097.8 4102,0 4106.2 4110.2 4114 5 1200.00 4118.6 4122 7 4127.0 4131.4 4135.7 4140.0 4144.3 4148.7 4153.0 4157 3 1210.00 4161.5 4165 8 4169.9 4173 9 4177.9 4181.9 4186.2 4190.6 4194.9 4199 1 1220.00 4203.6 4208 1 4212.3 4216 6 4221.0 4225.3 4229.4 4233.6 4237.9 4242 2 1230.00 4246.5 4250 8 4255.1 4259 4 4263.7 4268.1 4272.3 4276.5 4280.8 4285 1 1240.00 4289.4 4293 6 4297.8 4302 0 4306.1 4310.3 4314.5 4318.7 4322.8 43270 1250.00 4331.4 4335 6 4339.7 4344 0 4348.2 4352.4 4356.5 4360.7 4364.9 4369.1 1260.00 4373.3 4377 5 4382.0 4386 2 4390.6 4394.7 4398.9 4403.1 4406.9 4410.7 1270 00 4414.7 4418 9 4423.6 4427 8 4431.9 4436.2 4440.4 4444.4 4448.6 4453.0 1280 00 4457.3 44617 4466.2 4470 7 4475.1 4479 5 4483.9 4488.0 4492 3 4496.6 1290 00 4500.7 45047 4508.9 4512 9 4517.4 4522 3 4527.4 4531.8 4536 4 4541.1 1300 00 4545.9 4550.0 4554.1 4558.2 4562.4 4566 6 4570.7 4574.8 4579 3 4583.8 1310 00 4588.0 4592.5 4597 0 4601.7 4606.1 4610 1 4614.0 4618.4 4622 9 4627.5 1320 00 4631.8 4635.9 4640 2 4644.4 4648.7 4652 7 4657.0 4661.1 4665 5 4669.9 1330 00 4674.5 4679.4 4684 0 4688.6 4693.1 4697 8 4702.4 4706 8 4711 0 4715.0 1340 00 4719 2 4723.3 4727 4 4731.5 4735.7 4740 2 4744.5 4748 9 4753 2 4757.8 1350 00 4762 2 4767.0 4771 4 4775.8 4780.0 4784 1 4788.5 4792 9 4797 5 4802.0 1360 00 4806 7 4811.4 4815 8 4820.1 4824.5 4829 0 4833.5 4838 1 48425 4847.1 1370 00 4851 5 4856.0 4860 4 4864.6 4868.9 4873 3 4877.8 4882 2 4886.7 4891.1 1380.00 4895 6 4900.0 4904 3 4908.6 4912.8 4917.0 4921.4 4925 7 4930.0 4934.2 1390.00 4938 4 4942.7 4947 2 4951.6 4956.0 4960.3 4964.7 4969 0 4973.3 4977.6 1400.00 4982 0 4986.3 49907 4995.0 4999.4 5003.6 5007.8 5012.0 5016.3 5020.6 1410.00 5025 0 5029.4 5033.8 5038.1 5042.6 5046.8 5051.0 5055.7 5060.5 5065.1 1420.00 5069 9 5074.4 5079.2 5083.8 5088.1 5092.4 5096 7 5101.0 5105.4 5109.7 1430.00 5113.9 5118.3 5122.6 5127.0 5131 3 5135.7 5140 2 5144.5 5149.0 5153.4 1440.00 5157.9 5162.3 5166.6 5170.9 5175 1 5179.4 5183 9 5188.3 5192.6 5197.1 1450.00 5201.6 5206.0 5210.5 5214.9 5219 4 5223.9 5228 4 5232.9 5237.4 5241.9 1460.00 5246.4 5250.8 5255.3 5259.6 5263 9 5268.2 5272 7 5277.1 5281.6 5286.0 1470.00 5290.3 5294.7 5299.2 5303.6 5308 0 5312.7 53171 5321.5 5326.6 5331.0 1480.00 5335.4 5339.8 5344.3 5348.9 5353 5 5358.1 5362,6 5367.2 5371.5 5376.3 1490.00 5381.0 5385.4 5389.8 5394.2 5398.7 5403.1 5407,6 5412.1 5416.8 5421.5 1500.00 5426.2 5431.1 5436.0 5440.7 5445.7 5450.6 5455.5 5460.6 5465.8 5470.9 1510.00 5476.2 5481.1 5486.0 5491.0 5495.7 5500.4 5505.4 5510.3 5515.1 5519.8 1520.00 5524.4 5529.0 5533.7 5540.8 5547.6 5552.5 5557.7 5562.5 5567 3 5572.4 1530 00 5577.4 5582.1 5586.8 5591.7 5596.5 5601.4 5605.8 5610.3 5615 0 5619.9 1540 00 5624.8 5629.6 5634.6 5639.4 5644.3 5649 1 5653.8 5658 5 5663 7 5668.7 1550 00 5673.5 5678.3 5683.5 5688.5 5693.5 5698 3 5703.1 5708 0 5712 8 5717.5 1560 00 5722.2 5727.0 5731.7 5737.0 5742.3 5747 2 5752.2 5757 0 57622 5767.5 1570 00 5772.5 5777.2 5782.4 5787.3 5792.3 5797 5 5802.4 5807 5 5812,7 5817.9 1580 00 5823.1 5828.0 5833.0 5838.1 5843.5 5848 6 5853.8 5859 0 5864.5 5869.8 1590 00 5874.7 5879.7 5885.4 5890.5 5895.6 5900 8 5906.5 5911 4 5916.8 5922.3 1600.00 5927.6 5932.7 5937.6 5942.7 5947.6 5952.8 5958.0 5963.2 5968.2 5973.6 1610.00 5979.1 5984.5 5989.7 5995.2 6000.8 6005.9 6010.9 6016.2 6021.8 6027.3 1620.00 6032.7 6038.1 6043.5 6048.9 6054.4 6059.5 6065.3 6070.5 6075.5 6081.1 1630.00 6086.4 6091.5 6096.8 6102.1 6107.7 6112.7 6117.6 6122.5 6127.6 6133.3 1640.00 6138.6 6143.8 6148.8 6153.9 6159.3 6164.7 6170.2 6175.4 6180.8 6185.9 1650.00 6191.6 6196.7 6201.7 6206.9 6211.9 6217.6 6222.6 6227.8 6233.1 6238.4 1660.00 6243.3 6248.2 6253.5 6259.3 6264.5 6269.5 6275.1 6280.2 6285.2 6290.5 1670.00 6295.6 6300.7 6305.9 6311.4 6317.0 6322.5 6328.2 6333.9 6339.5 6344.9 1680.00 6350.3 6356.4 6361.8 6367.5 6372.9 6379.0 6384.4 6389.9 6395.6 6401.4 1690.00 6406.6 6411.8 6417.1 6422.3 6427.5 6432.8 6437.9 6443.5 6449.0 6454.5 1700.00 6460.3 6465.6 6471.2 6476.5 6482.0 6487.1 6492.6 6498.2 6503.8 6509.5 COMPANY : ARCO ALASKA INC. WELL : WARTHOG #1 PAGE 5 TWO WAY DE PTI-I DEPTH DEPTH DEPTH DE PTI-I DE PTIq DEPT}{ DEPTH DE P'IS{ DE PTIq SONIC /SRD AT /SRD AT /SRD AT /SRD AT /SRD AT /SRD AT /SRD AT /SRD AT /SRD AT /SRD AT TIME + 0 * + 1 * + 2 * + 3 * + 4 * + 5 * + 6 * + 7 * + 8 * + 9 * FROM SRD SMPL/10 SMPL/10 SMPL/10 SMPL/10 SMPL/10 SMPL/10 SMPL/10 SMPL/10 SMPL/10 SMPL/10 MS FT FT FT FT FT FT FT FT FT FT 1730.00 6625.2 6630 1740.00 6680.3 6685 1750.00 6735.8 6741 1760.00 6791.4 6797 1770.00 6848.5 6854 1780.00 6904.5 6910 1790.00 6960.7 6966 1800.00 7016.9 7022 5 7028 1810.00 7072.5 7078 0 7083 1820.00 7128.9 7134 5 7140 1830.00 7184.1 7189.9 7195 1840.00 7241.4 7247.4 7252 1850.00 7297.8 7303.5 7309 1710.00 6514.8 6520.3 6525.7 6531.3 6536.8 6542.3 6547 8 6553.2 6558 5 6564.0 1720.00 6569.5 6575 3 6580.8 6586.4 6592.1 6597.8 6603 4 6608.7 6614 9 6636.5 6642.0 6647.6 6652.9 6658 4 6663.8 6669 9 6691.6 6697.2 6702.7 6708.1 6713 4 6719.1 6724 4 6746.9 6752.1 6757.8 6763.4 6768 8 6774.4 6780 1 6802.9 6808.5 6814.1 6819.9 6825 5 6831.1 6836 2 6859.8 6865.5 6871.1 6876.8 6882.4 6887.9 6893 0 6915 5 6921.2 6926.9 6932.5 6938.1 6943.7 6949 4 6972 0 6977.6 6983.2 6988 9 6994.5 7000.2 7005 0 7033.5 7039.1 7044 8 7089.5 7095.2 7100 9 7106.6 7112 1 7117.7 7123.5 0 7145.5 7151 0 7156 4 7162.2 7167 4 7172.8 7178.5 6 7201.2 720~ .9 7212 7 7218.3 7224 2 7229.9 7235.6 9 7258.6 7264 1 7269 6 7274.8 7280 9 7286.5 7292.1 2 7315.1 7320 8 7326 4 7332.2 7338 1 7343.8 7349.1 1860.00 7354 6 7360.1 7365 7 7371.0 7376 6 7382 2 7387.8 7393 4 7399.0 7404.7 1870.00 7410 3 7416.2 7422.2 7427.9 7433 5 7438 8 7444.0 7449.1 7454.6 7460.2 1880.00 7465 9 7471.6 7477.5 7483.2 7488 6 74943 7500.1 7506.1 7511.8 7517.6 1890.00 7523 5 7529.4 7535.3 7541.5 7547 6 7553.4 7559.1 7564.8 7570.5 7576.2 1900.00 7581 9 7587.6 7593.2 7599 0 7604.7 7610.5 7616.2 7622.0 7627.7 7633.4 1910.00 7639 3 7645.3 7651.2 7657 1920.00 7698 3 7704.3 7710.2 7716 1930.00 7756.0 7761.8 7767.6 7773 1940 00 7814.9 7820.8 7826.7 7833 1950 00 7873.1 7878.8 7884.6 7890 1960 00 7932.3 7938.3 7944.3 7950 1970 00 7992.8 7998.9 8004.9 8010 1 6619.8 3 6674.8 7 6730.3 1 6785.8 7 6842.9 4 6899.0 3 6955.0 8 7011.3 8 7050.6 7056 2 7061.7 7067.1 1980 00 8052.8 8058.6 8064.6 8070.5 8076.3 8082.1 8088.1 8094.5 8100 7 8106.7 1990 00 8112.8 8118.4 8124.3 8130.3 8136.3 8142.7 8148.4 8154.5 8160 3 8166.3 2000.00 8172.4 8178.4 8184.5 8190.6 8196.5 8202.5 8208.5 8214.5 82204 8226.4 2010.00 8232.4 8238.3 8244.2 8250.2 8256.1 8262.1 8268.2 8274.3 8280.4 8286.4 2020.00 8292.4 8298.4 8304.3 8310.7 8316.9 8322.8 8328.5 8334.7 8341.0 8346.8 2030.00 8352.9 8358.9 8365.0 8371.1 8377.2 8383.2 8389.2 8395.2 8401.1 8407.1 2040.00 8413.0 8419.0 8424.9 8430.9 8436.9 8442.9 8448.9 8455.0 8461.1 8467.0 2050.00 8473.1 8479.2 8485.4 8491.5 8497.6 8503.6 8509.6 8515.6 8521.6 8527.5 2060.00 8533.4 0 7662.9 7668.8 7674.7 7680.6 7686.5 7692.4 0 7721.7 7727.0 7732.5 7738.1 7743.7 7750.2 5 7779.3 7785.3 7791.3 7797.2 7803.0 7808.9 1 7838.7 7844.4 7850.1 7855.8 7861 6 7867.3 3 7896.2 7902.2 7908.2 7914.2 7920 5 7926.4 3 7956.3 7962.4 7968.5 7974.6 7980 7 7986.8 9 8016.9 8022.8 8028.8 8034.7 8040 9 8047.0 ANALYST: R. SINES 13-JAN-98 17:39:08 PROGRAM: GTRFRM 001.E14 TIME CONVERTED VELOCITY REPORT COMPANY WELL FIELD COUNTY STATE : ARCO i~LASKA INC. : WARTHOG #1 : WILDCAT : NORTH SLOPE : ALASKA REFERENCE: 97551 COMPANY : ARCO ALASKA INC. WELL : WARTHOG #1 PAGE 1 TWO-WAY ~fEASLrRED %FERTICAL TRAVEL DEPTH DEPT}I TIME FROM FROM FROM SRD KB SRD MS FT FT AVERAGE RMS INTERVAL VELOCITY VELOCITY VELOCITY SRD/GEO FT/S FT/S FT/S 0 91.0 0 2.00 97.1 6.0 6047 6047 4.00 103.1 12.1 6047 6047 6.00 109.2 18.1 6047 6047 8.00 115.2 24.2 6047 6047 10.00 121.3 30.2 6047 6047 12.00 127.3 36.3 6047 6047 14.00 133.4 42.3 6047 6047 16.00 139.4 48.4 6047 6047 18.00 145.4 54.4 6047 6047 20.00 151.5 60.5 6047 6047 22.00 157.5 66.5 6047 6047 24.00 163.6 72.6 6047 6047 26.00 169.6 78.6 6047 6047 28.00 175.7 84.7 6047 6047 30.00 181.7 90.7 6047 6047 32.00 187.8 96.8 6047 6047 34.00 193.8 102.8 6047 6047 36.00 199.9 108.8 6047 6047 38.00 205.9 114.9 6047 6047 40.00 212.0 120.9 6047 6047 42.00 218.0 127.0 6047 6047 44.00 224.1 133.0 6047 6047 46.00 230.1 139.1 6047 6047 48.00 236.2 145.1 6047 6047 50.00 242.2 151.2 6047 6047 52.00 248.3 157.2 6047 6047 54.00 254.7 163.6 6060 6060 6047 6047 6047 6047 6047 6047 6047 6047 6047 6047 6047 6047 6047 6047 6047 6047 6047 6047 6047 6047 6047 6047 6047 6047 6047 6047 6398 6544 COMPANY : ARCO ALASKA INC. WELL : WARTHOG #1 PAGE 2 TWO-WAY MEASURED VERTICAL TRAVEL DEPT~ DEPT/q TIME FROM FROM FROM SRD KB SRD MS FT FT AVERAGE VELOCITY SRD/GEO FT/S 56.00 261.2 170.2 6077 RMS INTERVAL VELOCITY VELOCITY FT/S 6078 58.00 267.8 176.7 6093 6095 60.00 274.3 183.3 6108 6110 62.00 280.8 189.8 6122 6125 64.00 287.4 196.3 6136 6138 66.00 293.9 202.9 6148 6151 68.00 300.5 209.4 6160 6163 70.00 307.0 216.0 6171 6174 72.00 313.6 222.5 6181 6185 74.00 320.1 229.1 6191 6195 76.00 326.7 235.6 6200 6204 78.00 333.2 242.1 6209 6213 80.00 339.8 248.7 6217 6222 82.00 346.3 255.2 6225 6230 84.00 352.8 261.8 6233 6237 86.00 359.4 268.3 6240 6245 88.00 365.9 274.9 6247 6252 90.00 372.5 281.4 6254 6258 92.00 379.0 288.0 6260 6265 94.00 385.6 294.5 6266 6271 96.00 392.1 301.0 6272 6277 98.00 398.7 307.6 6277 6282 100.00 405.2 314.1 6283 6288 102.00 411.7 320.7 6288 6293 104.00 418.3 327.2 6293 6298 106.00 424.8 333.8 6298 6302 108.00 431.4 340.3 6302 6307 110.00 437.9 346.9 6306 6311 112.00 444.5 353.4 6311 6316 FT/S 6544 6544 6544 6544 6544 6544 6544 6544 6544 6544 6544 6544 6544 6544 6544 6544 6544 6544 6544 6544 6544 6544 6544 6544 6544 6544 6544 6544 COMPANY : ARCO A/_J~SKA INC. WELL : WARTIqOG #1 PAGE 3 TWO-WAY MEASI/RED VERTICAL TRAVEL DEPTH DEPT}{ TIME FROM FROM FROM SRD KB SRD ME FT FT AVERAGE VELOCITY SRD/GEO FT/S FT/S 114.00 451.0 359.9 6315 6320 116.00 457.6 366.5 6319 6324 118.00 464.1 373.0 6323 6327 120.00 470.7 379.6 6326 6331 122.00 477.2 386.1 6330 6335 124.00 483.7 392.7 6333 6338 126.00 490.3 399.2 6337 6341 128.00 496.8 405.8 6340 6345 130.00 503.3 412.2 6341 6346 132.00 509.6 418.5 6341 6346 134.00 515.9 424.8 6341 6345 136.00 522.2 431.2 6341 6345 138.00 528.6 437.5 6340 6345 140.00 534.9 443.8 6340 6344 142.00 541.2 450.1 6340 6344 144.00 547.5 456.4 6340 6344 146.00 553.9 462.8 6339 6343 148.00 560.2 469.1 6339 6343 150.00 566.5 475.4 6339 6343 152.00 572.8 481.7 6339 6343 154.00 579.2 488.1 6338 6342 156.00 585.5 494.4 6338 6342 158.00 591.8 500.7 6338 6342 160.00 598.1 507.0 6338 6342 162.00 604.5 513.3 6338 6341 164 . 00 610 . 8 519 . 7 6337 6341 166.00 617.1 526.0 6337 6341 168.00 623.4 532.3 6337 6341 INTERVAL VELOCITY FT/S 6544 6544 6544 6544 6544 6544 6544 6544 6432 6323 6323 6323 6323 6323 6323 6323 6323 6323 6323 6323 6323 6323 6323 6323 6323 6323 6323 6323 6323 COMPANY : ARCO ALASKA INC. WELL : WARTHOG #1 PAGE 4 TWO-WAY MEASURED VERTICAL TRAVEL DEPTH DEPTH TIME FROM FROM FROM SRD KB SRD MS FT FT AVERAGE RMS INTERVAL VELOCITY VELOCITY VELOCITY SRD/GEO FT/S FT/S FT/S 170.00 629.7 538.6 6337 6340 172.00 636.1 545.0 6337 6340 6323 6323 174.00 642.4 551.3 6337 6340 6323 176.00 648.7 557.6 6336 6340 6323 178.00 655.0 563.9 6336 6340 6323 180.00 661.4 570.3 6336 6339 6323 182.00 667.7 576.6 6336 6339 6323 184.00 674.0 582.9 6336 6339 6323 186.00 680.3 589.2 6336 6339 6323 188.00 686.7 595.5 6336 6339 6323 190.00 693.0 601.9 6335 6339 6323 192.00 699.3 608.2 6335 6338 6323 194.00 705.6 614.5 6335 6338 6323 196.00 712.0 620.8 6335 6338 6323 198.00 718.3 627.2 6335 6338 6323 200.00 724.6 633.5 6335 6338 6323 202.00 730.9 639.8 6335 6338 6323 204.00 737.2 646.1 6335 6337 206.00 743.6 652.4 6334 6337 208.00 749.9 658.8 6334 6337 210.00 756.1 665.0 6333 6336 212.00 762.3 671.2 6332 6335 214.00 768.6 677.4 6331 6334 216.00 774.8 683.7 6330 6333 218.00 781.0 689.9 6329 6332 220.00 787.2 696.1 6328 6331 222.00 793.5 702.3 6327 6330 224.00 799.7 708.6 6326 6329 226.00 805.9 714.8 6326 6328 6323 6318 6224 6224 6224 6224 6224 6224 6224 6224 6224 COMPANY : ARCO ALASKA INC. WELL : WARTHOG #1 PAGE 5 TWO-WAY MEASURED VERTICAL TRAVEL DEPTH DEPTH TIME FROM FROM FROM SRD KB SRD MS FT FT AVERAGE VELOCITY SRD/GEO FT/S RMS VELOCITY FT/S 228.00 812.1 721.0 6325 6327 230.00 818.4 727.2 6324 6326 232.00 824.6 733.5 6323 6326 234.00 830.8 739.7 6322 6325 236.00 837.0 745.9 6321 6324 238.00 843.3 752.1 6320 6323 240.00 849.5 758.4 6320 6322 242.00 855.7 764.6 6319 6321 244.00 861.9 770.8 6318 6321 246.00 868.2 777.0 6317 6320 248.00 874.4 783.3 6317 6319 250,00 880.6 789.5 6316 6318 252.00 886.9 795.7 6315 6318 254.00 893.1 801.9 6314 6317 256.00 899.3 808.2 6314 6316 258.00 905.5 814.4 6313 6315 260.00 911.8 820.6 6312 6315 262.00 918.0 826.8 6312 6314 264.00 924.2 833.0 6311 6313 266.00 930.4 839.3 6310 6313 268.00 936.7 845.5 6310 6312 270.00 942.9 851.7 6309 6311 272.00 949.1 857.9 6308 6311 274.00 955.3 864.2 6308 6310 276.00 961.6 870.4 6307 6310 278.00 967.8 876.6 6307 6309 280.00 974.0 882.8 6306 6308 282.00 980.2 889.1 6305 6308 INTERVAL VELOCITY FT/S 6224 6224 6224 6224 6224 6224 6224 6224 6224 6224 6224 6224 6224 6224 6224 6224 6224 6224 6224 6224 6224 6224 6224 6224 6224 6224 6224 6224 6224 COMPANY : ARCO ~KA INC. WELL : WART}{OG #1 PAGE 6 TWO-WAY MEASURED VERTICAL TRAVEL DEPTI-I DEPTH TIME FROM FROM FROM SRD KB SRD MS FT FT 284.00 986.5 895.3 AVERAGE VELOCITY SRD/GEO FT/S 6305 RMS VELOCITY FT/S 6307 286.00 992.7 901.5 6304 6307 288.00 998.9 907.7 6304 6306 290.00 1005.2 914.0 6303 6306 292.00 1011.4 920.3 6303 6305 294.00 1017.7 926.5 6303 6305 296.00 1024.0 932.8 6303 6305 298.00 1030.2 939.1 6302 6305 300.00 1036.5 945.3 6302 6304 302.00 1042.8 951.6 6302 304.00 1049.1 957.9 6302 306.00 1055.3 964.1 6302 6304 6304 6304 308.00 1061.6 970.4 6301 6304 310.00 1067.9 976.7 6301 6303 312.00 1074.1 982.9 6301 6303 314.00 1080.4 989.2 6301 6303 316.00 1086.7 995.5 6301 6303 6300 6300 318.00 1093.0 1001.8 320.00 1099.2 1008.0 6302 6302 322.00 1105.5 1014.3 6300 6302 324.00 1111.8 1020.6 6300 6302 326.00 1118.0 1026.8 6300 6302 328.00 1124.3 1033.1 6299 6301 330.00 1130.6 1039.4 6299 6301 332.00 1136.9 1045.6 6299 6301 334.00 1143.1 1051.9 6299 6301 336.00 1149.4 1058.2 6299 6301 338.00 1155.7 1064.4 6298 6300 340.00 1161.9 1070.7 6298 6300 INTERVAL VELOCITY FT/S 6224 6224 6259 6268 6268 6268 6268 6268 6268 6268 6268 6268 6268 6268 6268 6268 6268 6268 6268 6268 6268 6268 6268 6268 6268 6268 6268 6268 COMPANY : ARCO ALASKA INC. WELL : WARTIqOG #1 PAGE 7 TWO-WAY MEASURED VERTICAL TRAVEL DEPTH DEPTH TIME FROM FROM FROM SRD KB SRD MS FT FT AVERAGE VELOCITY SRD/GEO FT/S RMS VELOCITY FT/S 342.00 1168.2 1077.0 6298 6300 344.00 1174.5 1083.2 6298 6300 346.00 1180.8 1089.5 6298 6300 348.00 1187.0 1095.8 6298 6299 350.00 1193.3 1102.0 6297 6299 352.00 1199.6 1108.3 6297 6299 354.00 1205.8 1114.6 6297 6297 356.00 1212.1 1120.8 6299 6299 358.00 1218.4 1127.1 6297 6299 360.00 1224.7 1133.4 6297 6298 362.00 1230.9 1139.6 6296 6298 364.00 1237.2 1145.9 6296 6298 366.00 1243.5 1152.2 6296 6298 368.00 1249.8 1158.4 6296 6298 370.00 1256.1 1164.8 6296 6298 6296 6296 6296 372.00 1262.4 1171.1 374.00 1268.7 1177.4 376.00 1275.0 1183.7 6298 6298 6298 378.00 1281.3 1190.0 6296 6298 380.00 1287.6 1196.3 6296 6298 382.00 1293.9 1202.6 6296 6298 384.00 1300.3 1208.9 6296 6298 386.00 1306.6 1215.2 6296 6298 388.00 1312.9 1221.5 6296 6298 390.00 1319.2 1227.8 6297 6298 392.00 1325.5 1234.1 6297 6298 394.00 1331.8 1240.4 6297 6298 396.00 1338.1 1246.7 6297 6298 INTERVAL VELOCITY FT/S 6268 6268 6268 6268 6268 6268 6268 6268 6268 6268 6268 6268 6268 6268 6307 6307 6307 6307 6307 6307 6307 6307 6307 6307 6307 6307 6307 6307 6307 COMPANY : ARCO igJ. J{SKA INC. WELL : WART~IOG #1 PAGE 8 TWO-WAY MEASURED VERTICAL TRAVEL DEFTH DEPTI4 TIME FROM FROM FROM SRD KB SRD MS FT AVERAGE RMS INTERVAL VELOCITY VELOCITY VELOCITY SRD/GEO FT/S FT/S FT/S 398.00 1344.4 1253.1 6297 6298 400.00 1350.8 1259.4 6297 6298 402.00 1357.1 1265.7 6297 6299 404.00 1363.4 1272.0 6297 6299 406.00 1369.7 1278.3 6297 6299 6297 408.00 1376.0 1284.6 6299 410.00 1382.3 1290.9 6297 6299 412.00 1388.6 1297.2 6297 6299 414.00 1394.9 1303,5 6297 6299 416.00 1401.3 1309.8 6297 6299 418.00 1407.6 1316.1 6297 6299 420.00 1413.9 1322.4 6297 6299 422.00 1420.2 1328.7 6297 6299 424.00 1426.5 1335.1 6297 6299 426.00 1432.8 1341.4 6297 6299 428.00 1439.1 1347.7 6298 6299 430.00 1445.5 1354.0 6298 6299 6298 432.00 1451.8 1360.3 434.00 1458.1 1366.6 6298 6299 6299 436.00 1464.4 1372.9 6298 6299 438.00 1470.7 1379.2 6298 6299 440.00 1477.0 1385.5 6298 6299 442.00 1483.3 1391.8 6298 6299 444.00 1489.6 1398.1 6298 6298 446.00 1496.0 1404.4 6299 6299 448.00 1502.4 1410.8 6298 6300 6300 450.00 1508.9 1417.4 6301 452.00 1515.5 1424.0 6301 6302 454.00 1522.1 1430.6 6302 6304 6307 6307 6307 6307 6307 6307 6307 6307 6307 6307 6307 6307 6307 6307 6307 6307 6307 6307 6307 6307 6307 6307 6307 6307 6402 6573 6573 6573 COMPANY : ARCO ALASKA INC. WELL : WARTI{OG #1 PAGE 9 TWO-WAY MEASURED VERTICAL TRAVEL DEPTI-I DEPTH TIME FROM FROM FROM SRD KB SRD MS FT FT AVERAGE VELOCITY SRD/GEO FT/S RMS VELOCITY FT/S 456.00 1528.7 1437.1 6303 6305 458.00 460.00 462.00 464.00 1535 3 1541 8 1548 4 1555 0 1561 6 1568 1 1443.7 1450.3 1456.8 1463.4 1470.0 1476.6 466.00 6304 6306 6307 6308 6309 6310 468.00 6306 6307 6308 6309 6311 6312 470.00 1574.7 1483.1 6311 6313 472.00 1581.3 1489.7 6312 6314 6313 474.00 1587.9 1496.3 6315 476.00 1594.5 1502.9 6315 6316 478.00 1601.0 1509.4 6316 6317 6318 480.00 1607.6 1516.0 482.00 1614.2 1522.6 6317 6318 6320 484.00 1620.8 1529.1 6319 6321 486.00 1627.4 1535.7 6320 6322 488.00 1633.9 1542.3 6321 6323 490.00 1640.5 1548.9 6322 6324 492.00 1647.1 1555.4 6323 6325 494.00 1653.7 1562.0 6324 6326 496.00 1660.3 1568.6 6325 6327 498.00 1666.8 1575.2 6326 6328 500.00 1673.4 1581.7 6327 6329 6328 502.00 1680.0 1588.3 504.00 1686.6 1594.9 6329 6330 6331 506.00 1693.1 1601.4 6330 6332 508.00 1699.7 1608.0 6331 6333 510.00 1706.3 1614.6 6332 6334 INTERVAL VELOCITY FT/S 6573 6573 6573 6573 '6573 6573 6573 6573 6573 6573 6573 6573 6573 6573 6573 6573 6573 6573 6573 6573 6573 6573 6573 6573 6573 6573 6573 6573 6573 COMPANY : ARCO AL~KA INC. WELL : WARTHOG #1 PAGE 10 TWO-WAY N~,ASURED %rERTICAL TRAVEL DEPTH DEPTH TIME FROM FROM FROM SRD IfB SR.D MS FT FT AVERAGE RMS INTERVAL VELOCITY VELOCITY VELOCITY SRD/GEO FT/S FT/S FT/S 512.00 1712.9 1621.2 6333 6335 514.00 1719.5 1627.7 6334 6336 516.00 1726.0 1634.3 6335 6337 518.00 1732.6 1640,9 6335 6337 520.00 1739.2 1647.5 6336 6338 522.00 1745.8 1654.0 6337 6339 524.00 1752.5 1660.8 526.00 1759.5 1667.8 528.00 530.00 532.00 534 00 536 O0 538 00 1766.5 1674 7 1773.5 1681 7 1780.5 1688 7 1787.5 1695 7 1794.4 1702 7 1801.4 1709 6 1808.4 1716 6 1815.4 1723.6 1822.4 1730.6 540 00 542 00 544 00 6339 6341 6341 6343 6344 6346 6346 6348 6348 6351 6351 6353 6353 6356 6356 6358 6358 6361 6360 6363 6362 6366 546.00 1829.4 1737.6 6365 6368 ~548.00 1836.4 1744.5 6367 6370 550.00 1843.4 1751.5 6369 6373 552.00 1850.3 1758.5 6371 6375 554.00 1857.3 1765.5 6374 6377 556.00 1864.3 1772.5 558.00 1871,3 1779.5 560.00 1878.3 1786.4 562.00 1885.3 1793.4 564.00 1892.3 1800.4 566.00 1899.3 1807.4 6376 6379 6378 6382 6380 6384 6382 6386 6384 6388 6387 6391 568.00 1906.2 1814.4 6389 6393 6573 6573 6573 6573 6573 6735 6982 6981 6981 6982 6981 6982 6981 6982 6982 6982 6981 6982 6982 6981 6982 6981 6982 6982 6981 6982 6982 6982 COMPANY : ARCO AL~KA INC. WELL : WARTHOG #1 PAGE 11 TWO-WAY 5~-~ASURED VERTICAL TRAVEL DEPTH DEPTH TIME FROM FROM FROM SRD KB SRD MS FT FT 570.00 1913.2 1821.3 572.00 1920.2 1828.3 574.00 1927.2 1835.3 576.00 1934.2 1842.3 578.00 1941.2 1849.3 580.00 1948.2 1856.3 582.00 1955.2 1863.2 584.00 1962.1 1870.2 586.00 1969.1 1877.2 588~00 1976.1 1884.2 590.00 1983.1 1891.2 592.00 1990.1 1898.1 594.00 1997.1 1905.1 596.00 2003.9 1911.9 598.00 2010.5 1918.5 600.00 2017.3 1925.2 602.00 2024.3 1931.8 604.00 2031.3 1938.5 606.00 2038.4 1945.2 608.00 2045.4 1951.8 610.00 2052.4 1958.5 612.00 2059.4 1965.1 614.00 2066.5 1971.8 616.00 2073.5 1978.4 618.00 2080.5 1985.1 620.00 2087.5 1991.7 622.00 2094.6 1998.4 624.00 2101.6 2005.0 AVERAGE VELOCITY SRD/GEO FT/S 6391 6393 6395 6397 6399 6401 6403 6405 6407 6409 6411 6413 6415 6416 6417 6417 6418 6419 6420 6420 6421 6422 6423 6423 6424 6425 6426 6426 RMS VELOCITY FT/S 6395 6397 6399 6401 6403 6406 6408 6410 6412 6414 6416 6418 6420 6421 6422 6422 6423 6424 6425 6426 6426 6427 6428 6429 6429 6430 6431 6431 INTERVAL VELOCITY FT/S 6981 6982 6981 6982 6982 6981 6982 6982 6982 6981 6982 6982 6981 6765 6653 ~653 6653 6653 6653 6653 6653 6653 6653 6653 6653 6653 6653 6653 6653 COMPANY : ARCO ALASKA INC. WELL : WARTHOG #1 PAGE 12 TWO-WAY MEASLrI~E D VERTICAL TRAVEL DEPTH DEPTH TIME FROM FROM FROM SRD KB SRD MS FT FT 626.00 2108.6 2011.7 AVERAGE RMS INTERVAL VELOCITY VELOCITY VELOCITY SRD/GEO FT/S FT/S FT/S 6427 6432 628.00 2115.6 2018.3 6428 6433 630.00 2122.7 2025.0 632.00 2129.7 2031.6 6429 6429 6434 6434 634.00 2136.7 2038.3 6430 6435 636.00 2143.7 2045.0 6431 6436 638.00 2150.8 2051.6 6431 6436 640.00 2157.8 2058.3 6432 6437 642.00 2164.8 2064.9 6433 6438 644.00 2171.8 2071.6 646.00 2178.9 2078.2 648.00 2185.9 2084.9 650.00 2192.9 2091.5 6433 6434 6435 6435 6436 6437 652.00 2199.9 2098.2 654.00 2207.0 2104.8 6438 6439 6440 6440 6441 6442 656.00 2214.0 2111.5 6437 6442 658.00 2221.0 2118.1 6438 6443 660.00 2228.0 2124.8 662.00 2235.1 2131.4 6439 6439 6440 6441 664.00 2242.1 2138.1 666.00 2249.1 2144.8 6444 6444 6445 6446 668.00 2256.3 2151.6 6442 6447 670.00 2263.5 2158.4 6443 6448 672.00 2270.8 2165.3 6444 6449 674.00 2278.0 2172.1 6445 6451 6447 676.00 2285.2 2179.0 678.00 2292.5 2185.8 680.00 2299.7 2192.7 6448 6449 6452 6453 6454 682.00 2306.9 2199.5 6450 6455 6653 6653 6653 6653 6653 6653 6653 6654 6653 6654 6653 6653 6654 6653 6654 6653 6653 6653 6653 6654 6812 6849 6848 6849 6848 6848 6849 6848 COMPA/qY : ARCO AI~KA INC. WELL : W/~RT}{OG #1 PAGE 13 TWO-WAY 5~ASUR_ED VERTICAL TRAVEL DEPTI4 DE P'I74 TIME FROM FROM FROM SRD KB SRD MS FT FT 684 00 2314.1 2206.4 686 00 2321.4 2213.2 688 00 2328.6 2220.1 690 00 692 00 2335.8 2226.9 2343.1 2233.7 694 00 2350.3 2240.6 696 00 2357.5 2247.4 698 00 2364.8 2254.3 700 00 702 00 2372.0 2261.1 2379.2 2268.0 704.00 2386.5 2274.8 706.00 2393.7 2281.7 708.00 2400.9 2288.5 710.00 2408.1 2295.4 AVERAGE RMS IN~RVAL VELOCITY VELOCITY VELOCITY SRD/GEO FT/S FT/S FT/S 6451 6457 6452 6458 6454 6459 6455 6460 6456 6461 6457 6462 6458 6463 6459 6465 6460 6466 6462 6467 6463 6468 6464 6469 6465 6470 6466 6471 712.00 2415.4 2302.2 6467 6472 714.00 2422.6 2309.1 6468 6473 716.00 2429.8 2315.9 6469 6475 ,718.00 2437.1 2322.8 720.00 2444.3 2329.6 722.00 2451.5 2336.5 724.00 2458.8 2343.3 726.00 2466.0 2350.2 728.00 2473.2 2357.0 730.00 2480.5 2363.9 732.00 2487.7 2370.7 6470 6476 6471 6477 6472 6478 6473 6479 6474 6480 6475 6481 6476 6482 6477 6483 734.00 2494.9 2377.6 6478 6484 736.00 2502.1 2384.4 6479 6485 738.00 2509.3 2391.2 6480 6486 6849 6848 6849 6848 6848 6849 6848 6849 6848 6848 6848 6848 6849 6848 6849 6848 6849 6848 6849 6848 6848 6849 6848 6849 6848 6849 6837 6808 6808 COMPANY : ARCO ALASKA INC. WELL : WARTHOG #1 PAGE 14 TWO-WAY MEASURED VERTICAL TRAVEL DEPTI~ DEPTH TIME FROM FROM FROM SRD KB SRD MS FT FT 740.00 2516.5 2398.0 AVERJ%GE VELOCITY SRD/GEO FT/S 6481 RMS INTERVAL VELOCITY VELOCITY FT/S 6487 742.00 2523.7 2404.8 6482 6488 744.00 2530.9 2411.6 6483 6489 746.00 2538.1 2418.4 6484 6489 748.00 2545.3 2425.3 6485 6490 750.00 2552.5 2432.1 6485 6491 752.00 2560.1 2438.9 6486 6492 754.00 2568.3 2445.7 6487 6493 756.00 2576.5 2452.5 758.00 2584.7 2459.3 6488 6489 6490 6491 760.00 2592.9 2466.1 762.00 2601.1 2472.9 6494 6495 6495 6496 764.00 2609.3 2479.7 6491 6497 766.00 2617.5 2486.5 6492 6498 768.00 2625.7 2493.3 6493 6499 770.00 2633.9 2500.1 6494 6500 772.00 2642.1 2507.0 6495 6500 774.00 2650.3 2513.8 6496 6501 6496 6497 776.00 2658.5 2520.6 778.00 2666.7 2527.4 780.00 2674.9 2534.2 782.00 2683.1 2541.0 6498 6499 6502 6503 6504 6504 784.00 2691.3 2547.8 6499 6505 786.00 2699.5 2554.6 6500 6506 788.00 2707.7 2561.4 6501 6507 790.00 2715.9 2568.2 6502 6508 6503 6503 792.00 2724.1 2575.0 794.00 2732.3 2581.8 6508 6509 FT/S 6808 6808 6808 6808 6808 6808 6808 6808 6808 6808 6808 6808 6808 6808 6808 6808 6808 6808 6808 6808 6808 6808 6808 6808 6808 6808 6808 6808 796.00 2740.5 2588.6 6504 6510 COMPANY : ARCO kLASKA INC. WELL : WARTI40G #1 PAGE 15 TWO-WAY MEASUR.ED VERTICAL TRAVEL DEPTH DEPTH TIME FROM FROM FROM SRD KB SRD MS FT FT 798.00 2748.7 2595.5 800.00 2757.1 2602.4 802.00 2765.5 2609.3 804.00 2773.8 2616.3 806.00 2782.2 2623.3 808.00 2790.6 2630.2 810.00 2799.0 2637.2 AVERAGE RMS INTERVAL VELOCITY VELOCITY VELOCITY SRD/GEO FT/S FT/S FT/S 6505 6506 6507 6508 6509 6510 6512 6511 6512 6513 6514 6515 6516 6517 812.00 2807.3 2644.1 6513 6518 814.00 2815.7 2651.1 6514 6520 816.00 2824.1 2658.0 6515 6521 818.00 2832.5 2665.0 6516 6522 6517 6518 6519 820.00 2840.8 2671.9 822.00 2849.2 2678.9 824.00 2857.6 2685.8 826.00 2866.0 2692.8 828.00 2874.3 2699.8 6520 6521 6523 6524 6525 6526 6527 830.00 2882.7 2706.7 6522 6528 832.00 2891.1 2713.7 6523 6529 834.00 2899.6 2720.8 6525 6531 836.00 2908.2 2727.8 6526 6532 838.00 2916.7 2734.9 840.00 2925.2 2742.0 842.00 2933.8 2749.1 6527 6529 6530 6533 6535 6536 844.00 2942.3 2756.2 6531 6538 846.00 2950.8 2763.3 6533 6539 848.00 2959.4 2770.4 6534 6540 6535 850.00 2967.9 2777.5 852.00 2976.5 2784.5 6536 6542 6543 6808 6932 6955 6955 6954 6955 6955 6954 6955 6955 6955 6955 6955 6955 6954 6955 6955 6976 7081 7082 7083 7084 7085 7086 7088 7089 7090 7091 7092 COMPANY : ARCO A/.J~SKA INC. WELL : WARTI4OG #1 PAGE 16 TWO-WAY MEASURED VERTICAL TRAVEL DEPTT{ DEPTI~ TIME FROM FROM FROM SRD KB SRD MS FT FT 854.00 2985.0 2791.6 AVERAGE VELOCITY SRD/GEO FT/S 6538 RMS INTERVAL VELOCITY VELOCITY FT/S 6544 856.00 2993.5 2798.7 6539 6546 858.00 3002.1 2805.8 860.00 3010.6 2812.9 862.00 3019.1 2819.9 864.00 3027.6 2827.0 6540 6542 6543 6544 6545 6546 866.00 3036.1 2834.0 868.00 3044.9 2841.1 6547 6548 6549 6551 6552 6553 870.00 3053.7 2848.2 6547 6554 872.00 3062.5 2855.2 6549 6555 874.00 3071.3 2862.3 6550 6557 876.00 3080.0 2869.4 6551 6558 878.00 3088.8 2876.4 6552 6559 880.00 3097.6 2883.5 6553 6560 882.00 3106.4 2890.6 6555 6561 884.00 3115.2 2897.6 6556 6557 6558 886.00 3124.0 2904.7 888.00 3132.8 2911.8 6563 6564 6565 890.00 3141.6 2918.8 6559 6566 892.00 3150.3 2925.9 6560 6567 894.00 3159.1 2933.0 6561 6569 896.00 3167.9 2940.1 6563 6570 898.00 3176.7 2947.1 6564 6571 900.00 3185.5 2954.2 6565 6566 6567 6568 902.00 3194.3 2961.3 904.00 3203.1 2968.4 906.00 3211.9 2975.5 6572 6573 6574 6576 908.00 3220.7 2982.5 6569 6577 910.00 3229.6 2989.6 6571 6578 FT/S 7093 7083 7056 7057 7058 7059 7060 7062 7062 7064 7064 7066 7067 7068 7069 7070 7072 7072 7074 7075 7076 7077 7078 7079 7080 7082 7083 7084 COMPANY : ARCO ALASKA INC. WELL : WARTHOG #1 PAGE 17 TWO-WAY MEASURED VERTICAL TPJ%VEL DEP'i~{ DEPTH TIME FROM FROM FROM SRD KB SRD MS FT FT 912.00 3238.4 2996.7 914.00 3247.2 3003.8 916.00 3256.3 3011.1 918.00 3265.5 3018.5 920.00 3274.7 3025.9 922.00 3283.9 3033.3 924.00 3293.1 3040.7 AVERAGE ~ INTERVAL VELOCITY VELOCITY VELOCITY SRD/GEO FT/S FT/S FT/S 6572 6573 6574 6576 6578 6580 6582 926.00 3302.3 3048.2 6584 928.00 3311.5 3055.6 6585 930.00 3320.8 3063.0 6587 932.00 3330.0 3070.4 6589 934.00 3339.2 3077.8 6591 936.00 3348.4 3085.2 6592 6579 6580 6582 6584 6586 6588 6590 6591 7085 7086 7309 7411 7411 7412 7413 7414 7415 6593 7416 6595 7417 6597 7417 6599 7418 6601 938.00 3357.7 3092.7 6594 6603 940.00 3366.9 3100.1 6596 6605 942.00 3376.1 3107.5 6598 6606 944.00 3385.3 3114.9 6599 6608 946.00 3394.6 3122.4 6601 6610 948.00 3403.8 3129.8 6603 6605 6612 6614 6615 6617 6619 6621 6606 6608 6610 6611 950.00 3413.0 3137.2 952.00 3422.2 3144.6 954.00 3431.5 3152.1 956.00 3440.7 3159.5 958.00 3449.9 3166.9 960.00 3459.2 3174.3 6613 6623 962.00 3468.4 3181.8 6615 6624 964.00 3477.7 3189.2 6617 6626 966.00 3486.9 3196.6 6618 6628 7419 7420 7421 7422 7423 7424 7425 7425 7426 7427 7428 7429 7432 7445 7438 7434 COMPAAIY : ARCO ALASKA INC. WELL : WARTHOG #1 PAGE 18 TWO-WAY MEASURED VERTICAL AVERAGE RMS INTERVAL TRAVEL DEPTH DEPTH VELOCITY VELOCITY VELOCITY TIME FROM FROM SRD/GEO FROM SRD KB SRD MS FT FT FT/S FT/S FT/S 968.00 3496.2 3204.1 6620 6630 970.00 3505.3 3211.4 6622 6631 972.00 3514.6 3218.9 6623 6633 974.00 3523.9 3226.5 6625 6635 976.00 3533.1 978.00 3542.4 980.00 3551.8 982.00 3561.1 984.00 3570.5 986.00 3579.8 3233 9 3241 4 3249 0 3256 6 3264 1 3271 7 6627 6637 6629 6639 6631 6641 6632 6643 6634 6645 6636 6647 988.00 3589.2 3279.2 6638 6649 990.00 3598.6 3286.8 6640 6651 992 00 994 00 996 00 998 00 1000 00 1002 00 3608.0 3294.4 6642 6653 3617.5 3302.2 6644 6655 3627.0 3309.8 6646 6657 3636.5 3317.5 6648 6660 3645.8 3325.0 6650 6661 3655.1 3332.5 6652 6663 1004.00 3664.4 3340.0 6653 6665 1006.00 3673.9 3347.7 6655 6667 1008.00 3683.4 3355.4 6658 6670 1010.00 3692.7 3362.9 6659 6671 1012.00 3702.0 3370.4 6661 6673 1014.00 3711.3 3377.9 6663 6675 1016.00 3720.5 3385.4 6664 6676 1018.00 3729.9 3393.0 6666 6678 1020.00 3739.3 3400.6 6668 6680 1022.00 3748.7 3408.2 6670 6682 1024.00 3758.3 3416.0 6672 6685 7351 7476 7559 7395 7529 7617 7539 7575 7539 7548 7597 7610 7735 7613 7761 7478 7522 7517 7659 7717 7479 7538 7501 7504 7536 7649 7606 7752 COMPA1TY : ARCO ALASKA INC. WELL : WARTHOG #1 PAGE 19 TWO-WAY MEASURED VERTICAL TRAVEL DEPTH DEPTH TIME FROM FROM FROM SRD KB SRD MS FT FT 1026.00 3768.0 3423.8 1028.00 3777.5 3431.5 1030.00 3786.9 3439.1 AVERAGE ~ INTERVAL VELOCITY VELOCITY VELOCITY SRD/GEO FT/S FT/S FT/S 6674 6676 6678 6687 6689 6691 1032.00 3796.3 3446.7 6680 6693 1034.00 3805.7 3454.3 6681 6695 6683 1036.00 3815.3 3462.0 6697 1038.00 3824.8 3469.7 6685 6699 1040.00 3834.4 3477.5 6688 6701 1042.00 3844.1 3485.4 6690 6704 1044.00 3853.5 3493.0 6692 6705 6693 1046.00 3863.0 3500.6 6707 1048.00 3872.2 3508.1 6695 6709 1050.00 3881.7 3515.8 6697 6711 1052.00 3891.1 3523.4 6698 6713 1054.00 3900.7 3531.1 6700 6715 1056.00 3910.2 3538.8 3546.7 3554 5 3562 4 3570 2 3577 5 1058.00 1060.00 1062.00 1064.00 1066.00 3920 0 3929 6 3939 4 3949 1 3958 1 6702 6705 6707 6709 6711 6712 6714 6715 6715 6716 3967 4 1068.00 1070.00 3976.6 3585 0 3592 5 1072.00 3985.2 3599.4 1074.00 3994.1 3606.7 6717 6719 6721 6724 6726 6727 6729 6730 6731 6731 1076.00 4003.2 3614.0 6717 6733 1078.00 4012.3 3621.4 6719 6734 1080.00 4021.9 3629.1 6721 6736 7802 7679 7624 7602 7642 7701 7684 7781 7849 7622 7622 7477 7691 7629 7701 7722 7878 7797 7949 7794 7312 7466 7499 6934 7212 7349 7357 7740 7576 COMPANY : ARCO AJ~ASKA INC. WELL : WARTHOG #1 PAGE 20 TWO-WAY M~LrR~ED VERTICAL TRAVEL DEPT~ DEPTH TIME FROM FROM FROM SRD KB SRD MS FT FT 1082.00 4031.3 3636.7 1084.00 4040.8 3644.4 1086.00 4050.2 3652.0 1088.00 4059.6 3659.6 1090.00 1092.00 1094.00 1096.00 1098.00 1100.00 1102.00 1104.00 1106.00 1108.00 1110.00 1112.00 1114.00 4069.3 3667 4 4079.3 3675 5 4089.0 3683 4 4099.0 3691 5 4108.0 3698 8 4117.4 3706 4 4126.9 3714 2 4136.8 3722 3 4146.6 3730 3 4156.5 3738 4 4166.0 3746 1 4175.6 3753 9 4185.5 37620 AVERAGE VELOCITY SRD/GEO FT/S 6722 6724 6726 6727 6729 6732 6734 6736 6737 6739 6741 6743 6746 6748 6750 6752 6754 RMS VELOCITY FT/S 6738 6739 6741 6743 6745 6748 6750 6753 6754 6755 6757 6760 6763 6765 6767 6769 6772 1116.00 4195.3 3770.0 6756 6774 ~118.00 4204.9 3777.8 6758 6776 1120.00 4214.9 3785.9 6761 6779 1122.00 4224.9 3794.1 6763 6781 1124.00 4235.1 3802.4 6766 6784 1126.00 4244.6 3810.1 6768 6786 1128.00 4254.2 3818.0 6769 6788 1130.00 4264.5 3826.4 1132.00 4275.1 3835.0 6772 6776 6778 6782 1134.00 4285.4 3843.4 1136.00 4296.1 3852.1 6791 6795 6798 6802 1138.00 4306.4 3860.6 6785 6805 INTERVAL VELOCITY FT/S 7682 7615 7642 7829 8069 7879 8087 7360 7604 7800 8027 8032 8062 7743 7827 8064 7967 7812 8168 8166 8282 7749 7811 8398 8672 8382 8698 8464 COMPANY : ARCO A.L~KA INC. WELL : Wi~THOG #1 PAGE 21 TWO-WAY MF_~ASURED VERTICAL TRAVEL DEPTH DEPT~ T I ME FROM FROM FROM SRD KB SRD ME FT FT 1140.00 4316.6 3868.9 AVERAGE RMS ISFi~ERVAL VELOCITY VELOCITY VELOCITY SRD/GEO FT/S FT/S FT/S 6788 6808 1142.00 4326.4 3876.9 6790 6810 1144.00 4336.4 3885.0 6792 6813 1146.00 4346.7 3893.4 6795 6816 1148.00 4357.0 3901.8 6797 6819 1150 00 1152 O0 1154 00 1156 00 4367.3 3910.2 6800 6822 4377 5 3918.5 4387 9 3927.0 4398 2 3935.4 4408 5 3943.8 4418 7 3952.1 4428 4 3960.0 1158 00 1160 00 6803 6806 6809 6811 6814 6816 1162.00 6825 6828 6831 6834 6837 6839 1164.00 4438.3 3968.1 6818 6841 6820 1166.00 4448.3 3976.2 1168.00 4458.7 3984.7 1170.00 4468.8 3992.9 1172.00 4478.9 4001.2 6823 6825 6828 6844 6847 6850 6852 1174.00 4489.4 4009.6 6831 6855 1176.00 4499.9 4018.0 6833 6858 1178.00 4510.8 4026.8 6837 6862 1180.00 4521.0 4035.1 6839 6865 1182.00 4531.4 4043.4 6842 6867 1184.00 4541.8 4051.9 6844 6847 6849 6852 1186.00 4551.9 4060.0 1188.00 4562.2 4068.3 1190.00 4573.1 4077.1 6870 6873 6875 6879 1192.00 4583.6 4085.6 6855 6882 1194.00 4593.8 4093.8 6857 6884 8307 7994 8143 8337 8406 8427 8328 8487 8404 8367 8280 7948 8067 8155 8451 8223 8257 8422 8453 8802 8252 8349 8456 8113 8278 8781 8508 8242 8170 COM~PA_NY : ARCO ALASKA INC. WELL : WARTHOG #1 PAGE 22 TWO-WAY MEAS~D VERTICAL TRAVEL DEPTH DEPTH TIME FROM FROM FROM SRD KB SRD MS FT FT 1196.00 4604.0 4102.0 1198.00 4614.2 4110.2 1200.00 4624.5 4118.6 1202 00 1204 00 1206 00 1208 00 1210 00 1212 00 1214.00 1216.00 4635.0 4127.0 4645 8 4135.7 4656 4 4144.3 4667 2 4153.0 4677 8 4161.5 4688 2 4169.9 4698 2 4177.9 4708.3 4186.2 1218.00 4719.2 4194.9 1220.00 4729.9 4203.6 1222.00 4740.8 4212.3 1224.00 4751.6 4221.0 1226.00 4762.0 4229.4 1228 . 00 4772 . 5 4237 . 9 1230.00 4783.1 4246.5 232.00 4793.8 4255.1 1234.00 4804.5 4263.7 1236.00 4815.2 4272.3 1238.00 4825.7 4280.8 1240.00 4836.4 4289.4 1242.00 4846.8 4297.8 1244.00 4857.1 4306.1 1246.00 4867.5 4314.5 1248.00 4877.8 4322.8 1250.00 4888.4 4331.4 1252.00 4898.7 4339.7 AVERAGE VELOCITY SRD/GEO RMS INTERVAL VELOCITY VELOCITY FT/S FT/S FT/S 6859 6862 6864 6867 6870 6873 6876 6879 6881 6883 6885 6888 6891 6894 6897 6900 6902 6905 6908 6910 6913 6916 6918 6921 6923 6925 6928 6930 6932 6887 8264 6889 8314 6892 8482 6895 8643 6898 8622 6901 8688 6905 8550 6908 8352 6910 8055 6912 8203 6915 8745 6918 8657 6921 8796 6925 8662 6928 8399 6931 8526 6934 8516 6936 8651 6940 8601 6943 8601 6946 8528 6948 8559 6951 8393 6954 8332 6956 8417 6959 8263 6961 8568 6964 8335 6967 COMPANY : ARCO ALASKA INC. WELL : WARTHOG #1 PAGE 23 TWO-WAY MEJM~URED VERTICAL AVERAGE RMS INTERVAL TRAVEL DEPTH DEPTH VELOCITY VELOCITY VELOCITY TIME FROM FROM SRD/GEO FROM SRD KB SRD MS FT FT FT/S FT/S FT/S 1254 00 1256 00 1258 00 1260 00 1262 00 1264 00 1266 00 4909.3 4348.2 6935 6969 4919.6 4356.5 6937 6972 4930.0 4364.9 6939 6974 4940.4 4373.3 6942 6977 4951.2 4382.0 6944 6980 4961.8 4390.6 6947 6982 4972.1 4398.9 6949 6985 1268.00 4982.0 4406.9 6951 6986 1270.00 4991.7 4414.7 6952 6988 1272.00 5002.8 4423.6 6955 6991 1274.00 5013.1 1276.00 5023.6 1278.00 5033.8 1280.00 5044.6 1282.00 5055.6 1284.00 5066.7 4431 9 4440 4 4448 6 4457 3 4466 2 4475 1 6958 6994 6960 6996 6962 6998 6965 7001 6968 7004 6970 7008 1286.00 5077.7 4483.9 6973 7011 1288.00 5088.3 4492.3 6976 7013 1290.00 5098.7 4500.7 6978 7016 1292.00 5108.9 4508.9 6980 7018 1294.00 5119.5 4517.4 6982 7020 1296.00 5132.0 4527.4 6987 7026 1298.00 5143.3 4536.4 6990 7029 1300.00 5155.1 4545.9 6994 7034 1302.00 5165.4 4554.1 6996 7036 1304.00 5175.8 4562.4 6998 7038 1306.00 5186.1 4570.7 7000 7040 1308.00 5196.8 4579.3 7002 7043 8517 8307 8362 8444 8637 8589 8296 8019 7790 8923 8358 8442 8258 8671 8869 8875 8845 8420 8390 8138 8543 9998 9033 9463 8231 8317 8261 8604 8735 COMPANY : ARCO ALASKA INC. WELL : WARTHOG #1 PAGE 24 TWO-WAY MEASURED VERTICAL TRAVEL DEPTH DEPTH TIME FROM FROM FROM SRD KB SRD MS FT FT AVERAGE RMS INTERVAL VELOCITY VELOCITY VELOCITY SRD/GEO FT/S FT/S FT/S 1310.00 5207.7 4588.0 7005 7045 1312.00 5218.9 4597.0 7008 7049 1314.00 5230.3 4606.1 7011 7052 1316.00 5240.1 4614.0 7012 7054 1318.00 5251.2 4622.9 7015 7057 1320.00 5262.3 4631.8 7018 7060 1322.00 5272.8 4640.2 7020 7062 1324.00 5283.4 4648.7 7022 7065 1326.00 5293.8 4657.0 7024 7067 1328.00 5304.3 4665.5 7026 7069 1330.00 5315.6 4674.5 7029 7072 1332.00 5327.5 4684.0 7033 7077 1334.00 5338.9 4693.1 7036 7080 1336.00 5350.5 4702.4 7040 7084 1338.00 1340.00 1342.00 1344.00 5361 1 4711.0 5371 4 4719.2 5381 7 4727.4 5392 1 4735.7 5403 0 4744.5 5413 9 4753.2 5425 1 4762.2 1346.00 1348.00 1350.00 1352.00 5436.6 4771.4 1354.00 5447.3 4780.0 1356.00 5457.8 4788.5 1358.00 5469.1 4797.5 7042 7044 7045 7047 7050 7052 7055 7058 7061 7063 7066 7069 7072 1360.00 5480.6 4806.7 1362.00 5491.9 4815.8 7086 7088 7090 7092 7095 7098 7101 7104 7107 7109 7112 7116 7119 1364.00 5502.8 4824.5 7074 7121 1366.00 5514.0 4833.5 7077 7125 8973 9088 7918 8884 8870 8409 8514 8347 8426 9004 9572 9088 9301 8535 8195 8267 8320 8768 8719 9000 9203 8567 8458 9034 9160 9124 8691 9008 COMPANY : ARCO ALASKA INC. WELL : WARTHOG #1 PAGE 25 TWO-WAY MEASURED VERTICAL TRAVEL DEPTH DEPTH TIME FROM FROM FROM SRD KB SRD MS FT FT 1368.00 5525.3 4842.5 1370.00 5536.5 4851.5 AVERAGE RMS INTERVAL VELOCITY VELOCITY VELOCITY SRD/GEO FT/S FT/S FT/S 7080 7128 7083 7131 1372.00 5547.5 4860.4 7085 7134 1374.00 5558.2 4868.9 7087 7136 1376.00 5569.1 4877.8 7090 7139 1378.00 5580.3 4886.7 7092 7142 1380.00 5591.3 4895.6 7095 7144 1382.00 5602.1 4904.3 1384.00 5612.7 4912.8 1386.00 5623.3 4921.4 1388.00 5634.0 4930.0 1390.00 5644.5 4938.4 1392.00 5655.4 4947.2 1394.00 5666.4 4956.0 1396.00 5677.2 4964.7 9034 9020 8827 8581 8830 8953 8842 8743 7097 7147 8493 7099 7149 8567 7102 7151 8613 7104 7154 8424 7106 7156 8751 7108 7158 8852 7110 7161 8683 7113 7163 1398.00 5687.9 4973.3 7115 7166 1400.00 5698.7 4982.0 7117 7168 1402.00 5709.5 4990.7 7119 7170 1404.00 5720.3 4999.4 7122 7173 1406.00 5730.8 5007.8 7124 7175 1408.00 5741.3 5016.3 1410.00 5752.2 5025.0 1412.00 5763.2 5033.8 1414.00 5774.0 5042.6 7125 7177 7128 7179 7130 7182 7132 7184 1416.00 5784.5 5051.0 7134 7186 1418.00 5796.3 5060.5 7138 7190 1420.00 5808.0 5069.9 7141 7194 1422.00 5819.6 5079.2 7144 7197 8632 8684 8643 8708 8479 8413 8761 8827 8737 8466 9465 9420 9275 8938 COMPAI~'Y : ARCO ALASKA INC. WELL : WARTHOG #1 PAGE 26 TWO-WAY MEASURED VERTICAL TRAVEL DEPTH DEPTH TIME FROM FROM FROM SRD KB SRD MS FT FT 1424.00 5830.7 5088.1 AVERAGE RMS INTERVAL VELOCITY VELOCITY VELOCITY SRD/GEO FT/S FT/S FT/S 7146 7200 1426.00 5841.4 5096.7 7148 7202 7150 1428.00 5852.1 5105.4 7204 1430.00 5862.7 5113.9 7152 7206 1432.00 5873.5 5122.6 7154 7208 1434.00 5884.4 5131.3 7157 7211 1436.00 5895.3 5140.2 7159 7213 1438.00 1440.00 5906.3 5149.0 5917 4 5157.9 5928 2 5166.6 5938 8 5175.1 5949 7 5183.9 5960 6 5192.6 5971,7 5201.6 1442.00 1444.00 1446.00 1448.00 1450.00 1452.00 5982.7 5210.5 1454.00 5993.9 5219.4 1456.00 6005.0 5228.4 1458.00 6016.2 5237.4 i460.00 6027.4 5246.4 1462.00 6038.4 5255.3 1464.00 6049.2 5263.9 1466.00 6060.0 5272.7 7161 7164 7166 7168 7170 7172 7175 7177 7179 7182 7184 7187 7189 7191 7193 7196 7198 7200 1468.00 6071.2 5281.6 1470.00 6081.9 5290.3 1472.00 6093.0 5299.2 7216 7218 7221 7223 7225 7227 7230 7232 8599 8622 8582 8671 8719 8825 8798 8950 8712 8487 8752 8772 8960 8863 8956 7235 8946 7238 9064 7241 8945 7243 7246 7248 7250 7253 7255 7257 1474.00 6103.9 5308.0 7202 7260 1476.00 6115.3 5317.1 7205 7262 1478.00 6127.0 5326.6 7208 7266 1480.00 6138.0 5335.4 7210 7268 8902 8639 8753 8962 8642 8938 8788 9159 9435 8798 COMPAATY : ARCO ~d2~SKA INC. WELL : WARTI-{OG #1 PAGE 27 TWO-WAY MEASURED VERTICAL TRAVEL DEPTIq DEPTH TIME FROM FROM FROM SRD KB SRD MS FT FT 1482 00 1484 00 1486 00 1488 00 1490 00 1492 00 1494.00 1496.00 1498.00 1500.00 1502.00 AVERAGE RMS INTERVAL VELOCITY VELOCITY VELOCITY SRD/GEO FT/S FT/S FT/S 6149.1 5344.3 7212 7271 6160.5 5353.5 7215 7274 6171.8 5362.6 7218 7276 6182.8 5371.5 6194.6 5381.0 6205 6 5389.8 6216 6 5398.7 6227 7 5407.6 6239 2 5416.8 6250 8 5426.2 6263 0 5436.0 1504.00 6275.0 5445.7 1506.00 6287.2 5455.5 1508.00 6300.0 5465.8 1510.00 6312.9 5476.2 1512.00 6325.0 5486.0 1514.00 6337.2 5495.7 7220 7223 7225 7227 7229 7232 7235 7238 7242 7245 7249 7253 7257 7260 7279 7282 7284 7287 7289 7292 7295 7299 7303 7307 8965 9140 9134 8833 95O0 8861 8885 8923 9205 9371 9811 9668 9857 10243 7312 10415 7317 9760 7320 9797 7324 1516.00 6349.2 5505.4 7263 7328 1518.00 6361.2 5515.1 7266 7331 1520.00 6372.8 5524.4 7269 7334 1522.00 6384.4 5533.7 7272 7337 1524.00 6401.7 5547.6 7280 7350 7284 7287 7291 1526.00 6414.1 5557.7 1528.00 6426.1 5567.3 1530.00 6438.6 5577.4 7354 7357 7362 7365 1532.00 6450.4 5586.8 7294 1534.00 6462.4 5596.5 7297 7368 1536.00 6474.0 5605.8 7299 7371 9639 9686 9365 9266 13923 10022 9627 10100 9458 9683 9307 9201 COMPANY : ARCO ALASKA INC. WELL : WARTMOG #1 PAGE 28 TWO-WAY MEASURED VERTICAL TRAVEL DEPTH DE P~i"M TIME FROM FROM FROM SRD KB SRD MS FT FT AVERAGE RMS INTERVAL VELOCITY VELOCITY VELOCITY SRD/GEO FT/S FT/S FT/S 1538.00 6485.4 5615.0 7302 7374 1540 00 1542 00 1544 00 1546 00 1548 00 1550 00 1552 00 1554 00 1556,00 1558.00 1560.00 6497.5 5624.8 7305 7377 6509.7 5634.6 7308 7381 6521.7 5644.3 7311 7384 9733 1562.00 9813 9688 9583 6533.7 5653.8 7314 7388 9894 6546.1 5663.7 7317 7391 9785 6558.3 5673.5 7321 7395 9997 6570.8 5683.5 7324 7399 9969 6583.3 5693.5 7328 7403 9626 6595.3 5703.1 7330 7406 9638 6607.3 5712.8 7333 7409 9444 6619.1 5722.2 7336 7412 9538 6631.1 5731.7 7339 7416 1564.00 6644.3 5742.3 1566.00 6656.6 5752.2 1568.00 6669.1 5762.2 1570.00 6682.0 5772.5 1572.00 6694.4 5782.4 7343 7346 7350 7354 7357 7360 7363 7367 7371 7420 7424 7428 7432 7436 7440 7444 7448 7452 1574.00 6706.7 5792.3 1576.00 6719.4 5802.4 1578.00 6732.3 5812.7 1580.00 6745.2 5823.1 1582.00 6757.6 5833.0 7374 7456 1584.00 6770.7 5843.5 7378 7461 1586.00 6783.6 5853.8 7382 7465 1588.00 6796.9 5864.5 7386 7470 1590.00 6809.7 5874.7 7390 7474 1592.00 6823.1 5885.4 7394 7479 1594.00 6835.8 5895.6 7397 7483 10566 9877 10000 10355 9859 9897 10148 10294 10354 9887 10524 10289 10671 10279 10662 10210 COMPAi~Y : ARCO ALASKA INC. WELL : WARTHOG #1 PAGE 29 TWO -WAY MEASURED VERTICAL AVERAGE RMS INTERVAL TRAVEL DEP'IS{ DEPTH VELOCITY VELOCITY VELOCITY TIME FROM FROM SRD/GEO FROM SRD KB SRD MS FT FT FT/S FT/S FT/S 1596.00 6849.4 5906.5 7402 7488 1598.00 6862.3 5916.8 7405 7492 1600.00 6875.8 5927.6 7410 7497 1602.00 6888.3 5937.6 7413 7501 1604.00 6900.9 5947.6 7416 7505 1606.00 6914.0 5958.0 7420 7509 1608.00 6926.8 5968.2 7423 7513 1610.00 6940.5 5979.1 7427 7518 1612 00 1614 00 1616 00 1618 00 1620 00 1622 00 1624 00 1626 O0 6953.9 5989.7 7431 7523 6967.8 6000.8 7436 7528 6980.5 6010.9 7439 7532 6994.3 6021.8 7444 7537 7008.0 6032.7 7448 7542 7021.7 6043.5 7452 7547 7035.4 6054.4 7456 7552 7049.1 6065.3 7460 7557 1628.00 7061.9 6075.5 7464 7561 1630.00 7075.6 6086.4 7468 7566 1632.00 7088.7 6096.8 7472 7570 1634.00 7102.5 6107.7 7476 7575 1636.00 7115.0 6117.6 7479 7578 1638.00 7127.6 6127.6 7482 7582 1640.00 7141.4 6138.6 7486 7587 1642.00 7154.1 6148.8 7489 7590 1644.00 7167.4 6159.3 7493 7595 1646.00 7181.2 6170.2 7497 7600 1648.00 7194.4 6180.8 7501 7604 1650.00 7208.1 6191.6 7505 7609 10862 10293 10871 9938 10047 10413 10200 10821 10667 11042 10088 10956 10879 10822 10920 10888 10174 10880 10381 10931 9933 10015 11015 10120 10532 10949 10534 10853 10029 COMPANY : ARCO ALASKA INC. WELL : WARTHOG #1 PAGE 30 TWO-WAY MEASURED VERTICAL TRAVEL DEPTH DEPTH TIME FROM FROM FROM SRD KB SRD MS FT 1652.00 1654.00 1656.00 1658.00 1660.00 1662.00 7220 7 6201.7 7233 5 6211.9 7247 0 6222.6 7260 3 6233.1 7273 1 6243.3 7285 9 6253.5 AVERAGE VELOCITY SRD/GEO FT/S 7508 7511 7515 7519 7522 7525 R_MS INTERVAL VELOCITY VELOCITY FT/S 7612 7616 7620 7624 7628 7632 1664.00 7299.7 6264.5 7529 7637 1666.00 7313.1 6275.1 7533 7641 1668.00 7325.8 6285.2 7536 7644 7540 7543 7547 7552 7556 1670.00 7338.9 6295.6 1672.00 7351.8 6305.9 1674.00 7365.8 6317.0 1676.00 7379.9 6328.2 1678.00 7394.0 6339.5 1680.00 7407.7 6350.3 1682.00 7422.2 6361.8 1684.00 7436.1 6372.9 7560 7565 7569 7648 7652 7657 7662 7667 7672 7678 7683 1686.00 7450.5 6384.4 7573 7688 1688.00 7464.7 6395.6 7578 7693 1690.00 7478.4 6406.6 7582 7698 1692.00 7491.7 6417.1 7585 7702 1694.00 7504.7 6427.5 7588 7706 1696.00 7517.9 6437.9 7592 7710 1698.00 7531.8 6449.0 7596 7714 1700.00 7546.0 6460.3 7600 7720 1702.00 7559.7 6471.2 1704.00 7573.5 6482.0 7604 7608 7612 1706.00 7587.0 6492.6 7724 7728 7732 FT/S 10212 10699 10574 10194 10134 11035 10636 10073 10416 10221 11172 11196 11226 10881 11506 11078 11458 11241 10955 10527 10355 10481 11060 11295 10906 10811 10640 11136 1708.00 7601.2 6503.8 7616 7737 COMPANY : ARCO ALASKA INC. WELL : WARTHOG #1 PAGE 31 TWO-WAY MEASURED VERTICAL TRAVEL DEPTH DE i:~I'H TIME FROM FROM FROM SRD KB SRD MS FT FT 1710.00 7615.2 1712.00 7629.1 1714.00 7643.2 1716.00 7657.2 1718.00 7670.9 1720.00 1722.00 1724.00 1726.00 1728.00 1730.00 1732.00 1734.00 1736.00 1738.00 1740.00 7684 8 7699 3 7713 7 7728 0 7741 6 7755 9 7770 2 7784 3 7798 1 7812 0 7825 9 6514 8 6525 7 6536 8 6547 8 6558 5 6569 5 6580 8 6592 1 6603 4 6614 1 6625 2 6636 5 6647 6 6658 4 6669 3 66803 1742.00 7840.3 6691.6 1744.00 7854.5 6702.7 1746.00 7868.1 6713.4 1748.00 7882.5 6724.7 1750.00 7896.6 6735.8 1752.00 7910.8 6746.9 1754.00 7924.6 6757.8 AVERAGE RMS INTERVAL VELOCITY VELOCITY VELOCITY SRD/GEO FT/S FT/S FT/S 7620 7742 7624 7746 7628 7751 7631 7756 7635 7760 7639 7764 7643 7769 7647 7774 7652 7779 7655 7783 7659 7788 7663 7793 7667 7798 7671 7802 7675 7806 7678 7810 7683 7815 7687 7820 7690 7824 7694 7829 7698 7833 7702 7838 7706 7842 1756.00 7938.7 6768.8 7709 7846 1758.00 7953.1 6780.1 7713 7851 1760.00 7967.5 6791.4 7718 7856 1762.00 7982.1 6802.9 7722 7861 1764.00 7996.4 6814.1 7726 7866 11041 10904 11072 10957 10734 10983 11324 11311 11278 10685 11164 11233 11088 10872 10921 1'0907 11329 11105 10719 11311 11065 11100 10881 11075 11270 11335 11483 11190 11361 COMPANY : ARCO ALASKA INC. WELL : WARTHOG #1 PAGE 32 TWO-WAY MEASURED VERTICAL TRAVEL DEPTH DEPTH TIME FROM FROM FROM SRD KB SRD MS FT F? AVERAGE RMS INTERVAL VELOCITY VELOCITY VELOCITY SRD/GEO FT/S FT/S FT/S 1766.00 8010.9 6825.5 7730 7870 1768.00 8025.1 6836.7 1770.00 8040.3 6848.5 1772.00 8054.7 6859.8 1774.00 8069.3 6871.1 1776.00 8083.8 6882.4 1778.00 8098.1 6893.4 1780.00 8112.3 6904.5 1782.00 8126.6 6915.5 1784.00 8141.1 6926.9 7734 7738 7742 7746 7750 7754 7758 7762 7766 7875 7881 7885 7890 7895 7899 7903 7907 7912 1786.00 8155.6 6938.1 7769 7916 1788.00 8170.1 6949.3 7773 7921 1790.00 8184.6 6960.7 7777 7926 1792.00 8199.2 6972.0 7781 7930 1794.00 8213.7 6983.2 7785 7935 1796.00 8228.2 6994.5 7789 7939 1798.00 8242.8 7005.8 7793 7944 1800.00 8257.1 7016.9 7797 7948 7800 1802.00 8271.3 7028.0 1804.00 8285.6 7039.1 1806.00 8300.5 7050.6 1808.00 8314.7 7061.7 1810.00 8328.7 7072.5 7804 7808 7812 7815 7952 7956 7961 7965 7969 1812.00 8343.3 7083.8 7819 7973 1814.00 8357.9 7095.2 7823 7978 1816.00 8372.5 7106.6 7827 7982 1818.00 8386.9 7117.7 7830 7987 1820.00 8401.3 7128.9 7834 7991 11214 11849 11244 11298 11291 11042 11051 11085 11307 11230 11249 11321 11306 11253 11249 11320 11162 11017 11123 11563 11047 10808 11337 11338 11400 11171 11128 11095 1822.00 8415.5 7140.0 7838 7995 COMPANY : ARCO ALASKA INC. WELL : WARTI-IOG #1 PAGE 33 TWO-WAY MEASURED VERTICAL AVER_AGE RMS INTERVAL TRAVEL DEPTH DEPTH VELOCITY VELOCITY VELOCITY TIME FROM FROM SRD/GEO FROM SRD KB SRD MS FT FT FT/S FT/S FT/S 1824.00 8429.7 7151.0 7841 7999 1826.00 8444.2 7162.2 7845 8003 1828.00 8457.9 7172.8 7848 8006 1830.00 8472.4 7184.1 7851 8011 1832.00 8487.2 7195.6 7855 8015 1834.00 8501.7 1836.00 8516.4 1838.00 8531.3 1840.00 8546.1 1842.00 8560.8 1844.00 8575.1 1846 00 1848 00 1850 00 1852 00 1854 00 1856 00 7206 9 7218 3 7229 9 7241 4 7252 9 7264 1 7859 8020 7863 8024 7867 8029 7871 8033 7875 8038 7879 8042 8588.9 7274.8 7882 8045 8603.9 7286.5 7886 8050 8618.4 7297.8 7890 8055 8633.0 7309.2 7893 8059 8648.0 7320.8 7897 8064 8662.5 7332.2 7901 8068 1858.00 8677.4 7343.8 7905 8073 1860.00 8691.3 7354.6 7908 8076 1862.00 8705.5 7365.7 7912 8080 1864.00 8719.6 7376.6 7915 8083 1866.00 8733.9 7387.8 7918 8087 1868.00 8748.3 7399.0 7922 8091 1870.00 8762.8 7410.3 7925 8095 1872.00 8778.0 7422.2 7930 8100 1874.00 8792.6 7433.5 7933 8105 1876.00 8806.0 7444.0 7936 8107 1878.00 8819.6 7454.6 7939 8110 11022 11241 10614 11268 11504 11254 11464 11541 11562 11445 11188 10705 11697 11354 11320 11678 11368 11619 10780 11094 10955 11160 11234 11289 11854 11347 10453 10604 11321 COMPANY : ARCO ALASKA INC. WELL : WARTHOG #1 PAGE 34 TWO-WAY MEASURED VERTICAL TRAVEL DEPT~ DEPTH TIME FROM FROM FROM SRD KB SRD MS FT FT 1880.00 1882.00 1884.00 1886.00 1888.00 1890.00 1892.00 1894.00 1896.00 8834.1 7465 9 8848.9 7477 5 8863.2 7488 6 8878.0 7500 1 8893.1 7511 8 8908.0 7523 5 8923.2 7535 3 8939.0 7547 6 8953.7 7559 1 AVERAGE VELOCITY SRD/GEO FT/S 7942 7946 7950 7953 7957 7961 7965 7970 7974 RMS INTERVAL VELOCITY VELOCITY FT/S 8115 8119 8123 8127 8132 8136 8141 8147 8151 1898.00 8968.3 7570.5 7977 8155 7981 1900.00 8982.9 7581.9 8159 1902.00 8997.6 7593.2 7984 8163 1904.00 9012.5 7604.7 7988 8167 1906.00 9027.4 7616.2 7992 8171 1908.00 9042.3 7627.7 7995 8176 1910.00 9057.4 7639.3 7999 8180 1912.00 9072.9 7651.2 8003 8185 1914.00 9088.1 7662.9 8007 8189 1916.00 9103.4 7674.7 8011 8194 1918.00 9118.8 7686.5 8015 8198 1920.00 9134.2 7698.3 1922.00 9149.6 7710.2 1924.00 9164.5 7721.7 1926.00 9178.6 7732.5 8019 8023 8027 8030 8033 1928.00 9193.1 7743.7 8203 8208 8212 8215 8219 1930.00 9209.1 7756.0 8037 8224 1932.00 9224.2 7767.6 8041 8228 1934.00 9239.5 7779.3 8045 8232 1936.00 9255.0 7791.3 8049 8237 FT/S 11563 11104 11562 11712 11648 11846 12309 11479 11374 11351 11395 11476 11482 11473 11612 11916 11685 11813 11814 11830 11829 11474 10839 11210 12314 11608 11721 11940 COMPANY : ARCO ALASKA INC. WELL : WARTHOG #1 PAGE 35 TWO-WAY 5IEASURED VERTICAL TRAVEL DEPTH DEPT}{ TIME FROM FROM FROM SRD KB SRD MS FT FT 1938.00 9270.2 7803.0 1940.00 9285.9 7814.9 1942.00 9301.6 7826.7 1944.00 9317.7 7838.7 1946.00 1948 00 1950 00 1952 00 1954 00 1956 00 1958 00 1960 00 1962.00 1964.00 1966.00 9332.9 7850.1 9348.2 7861.6 9363.6 7873.1 9378.9 7884.6 9394.4 7896.2 9410.4 7908.2 9426.7 7920.5 9442.5 7932.3 9458.5 7944.3 9474.6 7956.3 9490.9 7968.5 1968.00 9507.1 7980.7 1970.00 9523.2 7992.8 1972.00 9539.4 8004.9 1974.00 9555.3 8016.9 1976.00 9571.4 8028.8 1978.00 9587.8 8040.9 1980.00 9603.9 8052.8 AVERAGE VELOCITY SRD/GEO FT/S 8053 8057 8060 8065 8068 8071 8075 8078 8082 8086 8090 8094 8098 8102 8106 8110 8115 8119 8122 8126 8130 8134 RMS VELOCITY FT/S 8242 8246 8251 8255 8259 8263 8267 8271 8275 8280 8285 8289 8294 8299 8303 8308 8313 8318 8322 8327 8331 8336 1982.00 9620.0 8064.6 8138 8340 1984.00 9635.8 8076.3 8141 8344 1986.00 9651.9 8088.1 8145 8348 8150 8154 1988.00 9668.9 8100.7 1990.00 9685.4 8112.8 1992.00 9701.0 8124.3 8157 8354 8358 8362 INTERVAL VELOCITY FT/S 11729 11864 11833 12015 11382 11482 11547 11458 11625 11992 12246 11845 11981 12058 12206 12162 12095 12120 11932 11901 12123 11881 11818 11705 11807 12570 12150 11473 11979 COMPANY : ARCO ALASKA INC. WELL : WARTHOG #1 PAGE 36 TWO-WAY MEASURED VERTICAL AVERAGE ~ INTERVAL TRAVEL DEPTH DEPTH VELOCITY VELOCITY VELOCITY TIME FROM FROM SRD/GEO FROM SRD KB SRD MS FT FT FT/S FT/S FT/S 1994.00 9717 2 8136.3 1996.00 9733 7 8148.4 1998.00 9749 8 8160.3 2000.00 9766 2 8172.4 2002.00 9782 6 8184.5 2004.00 9799 0 8196.5 2006.00 9815 1 8208.5 2008.00 9831 3 8220.4 2010.00 9847 5 8232.4 2012.00 9863 4 8244.2 2014.00 9879 3 8256.1 2016.00 9895 6 8268.2 2018.00 9911 9 8280.4 2020.00 9928 1 8292.4 2022.00 9944 0 8304.3 2024.00 9960 8 8316.9 2026.00 9976 5 8328.5 2028.00 9993 2 8341.0 2030.00 10009 1 8352.9 2032.00 10025 3 8365.0 2034.00 10041 5 8377.2 2036.00 10057 4 8389.2 2038.00 10073 0 8401.1 8161 8366 8165 8371 8168 8375 8172 8380 8176 8384 8180 8389 8184 8393 8188 8397 8191 8402 8195 8406 8199 8410 8203 8414 8207 8419 8210 8423 8214 8427 8218 8432 8222 8436 8226 8441 8229 8445 8233 8450 8237 8454 8241 8458 8244 8463 2040.00 10088.6 8413.0 8248 8467 2042.00 10104.2 8424.9 8252 8471 2044.00 10119.9 8436.9 8255 8475 2046.00 10135.7 8448.9 8259 8479 2048.00 10151.7 8461.1 8263 8483 2050.00 10167.4 8473.1 8266 8487 12141 11881 12103 12124 12030 11930 11906 12009 11836 11829 12155 12152 12080 11854 12569 11685 12437 11884 12087 12223 12065 11898 11867 11920 11924 12043 12184 11979 COMPANY : ARCO ALASKA INC. WELL : WART}{OG #1 PAGE 37 TWO-WAY MEASURED VERTICAL AVERAGE RMS INTERVAL TRAVEL DEPTH DEPTH VELOCITY VELOCITY VELOCITY TIME FROM FROM SRD/GEO FROM SRD KB SRD MS FT FT FT/S FT/S FT/S 12301 2052.00 10183.6 8485.4 8270 8492 12207 2054.00 10199.6 8497.6 8274 8496 12021 2056.00 10215.3 8509.6 8278 8501 11976 2058.00 10230.9 8521.6 8281 8505 11809 2060.00 10246.3 8533.4 8285 8508 See enclosed field print for observer notes. ANALYST: R. SINES 16-DEC-97 11:32:56 * SCHLUMBERGER * TRUE VERTICAL DEPTH COMPANY : ARCO ALASKA INC. WELL : WARTHOG #1 FIELD : PRUDHOE BAY COUNTY : NORTH SLOPE STATE : ALASKA COUNTRY : USA REFERENCE: 97551 COMPA1N-Y : ARCO ALASKA INC. WELL : WARTHOG #1 PAGE 1 BOTTOM HOLE LOCATION DATA: (GLOBAL PAPJIMETERS ) BH COURSE LENGTH BOTTOM HOLE AZIMUTH BH MEASURED DEPTH BH TRUE VERTICAL DEPTH BH DISTANCE NORTH BH DISTANCE SOUTH BH DISTANCE EAST BH DISTANCE WEST TVD ALGORITHM BHCL BHAZI BHMD BHTVD BHDN BHDS BHDE BHDW TVDALG (VALUE) : 5315.54 FT : 207.000 DEG : 11209.0 FT : 9364.00 FT : -4443.88 FT : 4443.88 FT ' -2916.66 FT : 2916.66 FT : EXACT RADIUS OF CURVATURE METHOD. COMPANY : ARCO ALASKA INC. WELL : WARTHOG #1 PAGE 2 * DEPTH * DEVIATION * AZIMUTH * TRUE * + NORTH * + EAST * COURSE * * * * * VERTICAL * - SOUTH * - WEST * LENGTH * * * * * DEPTH * DRIFT * DRIFT * * * FT * DEG * DEG * FT * FT * FT * FT * ************************************************************************** 0 * 250* 500* 750* 100 0 * 125 0 * 150 0 * 175 0 * 200 0 * 225 0 * 250 0 * 275 0 * 300 0 * 325 0 * 350 0 * 375 0 * 400 0 * 425 0 * 450 0 * 475 0 * 500 0 * 525 0 * 550.0 * 575 0 * 600 0 * 625 0 * 650 0 * 675 0 * 700 0 * 725.0 * 750.0 * 775.0 * 800.0 * 825.0 * 850 0 * 875 0 * 900 0 * 925 0 * 950 0 * 975 0 * 1000 0 * 1025 0 * 1050 0 * 1075 0 * 1100 0 * 0 * 0 * .1 * .1 * .1 * .1 * .2 * .2 * .2 * .2 * .3 * .3 * .3 * .3 * .4 * .4 * .4 * .4 * .5 * .5 * .5 * .5 * .6 * .6 * .6 * .6 * .7 * .7 * .7 * .8 * .8 * .8 * .8 * .9 * .9 * .9 * .9 * 1.0 * 1.0 * 1 0 * 1 0 * 1 1 * 1 1 * 13' 15' 183 8 * 183 8 * 183 8 * 183 8 * 183 8 * 183 8 * 183 8 * 183 8 * 183 8 * 183 8 * 183.8 * 183.8 * 183.8 * 183 8 * 183 8 * 183 8 * 183 8 * 183 8 * 183 8 * 183.8 * 183.8 * 183.8 * 183 8 * 183 8 * 183 8 * 183 8 * 183 8 * 183 8 * 183 8 * 183 8 * 183 8 * 183 8 * 183 8 * 183 8 * 183 8 * 183 8 * 183 8 * 183 8 * 183 8 * 183 8 * 183 8 * 183 8 * 183 8 * 186 4 * 190.5 * 0 * 25.0 * 50.0 * 75.0 * 100.0 * 125.0 * 150 0 * 175 0 * 200 0 * 225 0 * 250 0 * 275 0 * 299 9 * 324 9 * 349 9 * 374.9 * 399 9 * 424 9 * 449 9 * 474 9 * 499 9 * 524 9 * 549 9 * 574 9 * 599 9 * 624 9 * 649.9 * 674.9 * 699.9 * 724.9 * 749.9 * 774.9 * 799.9 * 824.9 * 849.9 * 874.9 * 899.8 * 924.8 * 949.8 * 974.8 * 999.8 * 1024.8 * 1049.8 * 1074.8 * 1099.8 * -1.1 * -1.4 * -1.8 * -2.2 * -2.5 * -2.9 * -3.3 * -3.6 * -4.0 * -43* -47* -51' -54* -58* -62* -65* -69* -7.2 * -7.6 * -8.0 * -8.3 * -8.7 * -9.1 * -9.4 * -9.8 * -10.1 * -10.5 * -10.9 * -11.2 * -11.6 * -12.0 * -12.3 * -12.7 * -13.0 * -13.4 * -13.8 * -14.1 * -14.5 * -14.8 * -15.2 * -15.8 * -16.6 * 0 * 0 * -.1 * .4 * -.3 * .8 * -.4 * 1.2 * -.5 * 1.5 * -.7 * 1.9 * -.8 * 2.3 * -.9 * 2.7 * -1.1 * 3.1 * -1.2 * 3.5 * -1.3 * 3.9 * -1.4 * 4.2 * -1.6 * 4.6 * -1.7 * 5.0 * -1.8 * 5.4 * -2.0 * 5.8 * -2.1 * 6.2 * -2.2 * 6.6 * -2.4 * 6.9 * -2.5 * 7.3 * -2.6 * 7.7 * -2.8 * 8.1 * -2.9 * 8.5 * -3.0 * 8.9 * -3.2 * 9.2 * -3.3 * 9.6 * -3.4 * 10.0 * -3.6 * 10.4 * -3.7 * 10.8 * -3.8 * 11.2 * -4.0 * 11.6 * -4.1 * 11.9 * -4.2 * 12.3 * -4.3 * 12.7 * -4.5 * 13.1 * -4.6 * 13.5 * -4.7 * 13.9 * -4.9 * 14.3 * -5.0 * 14.6 * -5.1 * 15.0 * -5.3 * 15.4 * -5.4 * 15.8 * -5.5 * 16.2 * -5.8 * 16.9 * -6.2 * 17.7 * COMPANY : ARCO ALASKA INC. WELL : WARTHOG #1 PAGE 3 * DEPTH * DEVIATION * AZIMUTH * TRUE * + NORTH * + EAST * COURSE * * * * * VERTICAL * - SOUTH * - WEST * LENGTH * * * * * DEPTH * DRIFT * DRIFT * * * FT * DEG * DEG * FT * FT * FT * FT * *************************************************************************** 1125.0 * 1150.0 * 1175 0 * 1200 0 * 1225 0 * 1250 0 * 1275 0 * 1300 0 * 1325 0 * 1350 0 * 1375 0 * 1400.0 * 1425.0 * 1450.0 * 1475.0 * 1500.0 * 1525.0 * 1550.0 * 1575.0 * 1600 0 * 1625 0 * 1650 0 * 1675 0 * 1700 0 * 1725 0 * 1750 0 * 1775.0 * 1800.0 * 1825.0 * 1850.0 * 1875.0 * 1900.0 * 1925 0 * 1950 0 * 1975 0 * 2000 0 * 2025 0 * 2050 0 * 2075 0 * 2100 0 * 2125 0 * 2150 0 * 2175 0 * 2200 0 * 2225 0 * 1.8' 2.0* 2.3* 2.5* 2.8* 3.0* 3.0* 2.9* 2.9* 2.8* 2.8* 2.8* 2.7* 2.7* 2.6* 2.6* 2.6* 2.5* 2.5* 2.4* 2.4 * 2.4 * 2.3* 2.3* 2.2 * 22* 21' 21' 21' 20* 20* 1.9' 1.9' 1.9' 1.8' 1.8' 2.3* 37* 51' 64* 78* 92* 106' 120' 133' 194.6 * 198.7 * 202.8 * 206.9 * 211.0 * 215.1 * 215.2 * 215.4 * 215.5 * 215.6 * 215.7 * 215.9 * 216.0 * 216.1 * 216.2 * 216 . 4 * 216.5 * 216.6 * 216 . 8 * 216 . 9 * 217.0 * 217.1 * 217.3 * 217 4 * 217 5 * 217 6 * 217 8 * 217 9 * 218 0 * 218.2 * 218.3 * 218.4 * 218.5 * 218.7 * 218.8 * 218.9 * 219.1 * 219.3 * 219 4 * 219 6 * 219 8 * 220 0 * 220 2 * 220 3 * 220 5 * 1124.8 * 1149.8 * 1174.7 * 1199 7 * 1224 7 * 1249 7 * 1274 7 * 1299 7 * 1324 6 * 1349 6 * 1374 6 * 1399 6 * 1424 5 * 1449 5 * 1474 5 * 1499 5 * 1524 5 * 1549 4 * 1574.4 * 1599.4 * 1624.4 * 1649.3 * 1674.3 * 1699.3 * 1724.3 * 1749.3 * 1774 2 * 1799 2 * 1824 2 * 1849 2 * 1874 1 * 1899 1 * 1924 1 * 1949 1 * 1974 1 * 1999 0 * 2023 5 * 2047 2 * 2070.8 * 2094.5 * 2118.2 * 2141.9 * 2165.6 * 2189.2 * 2212.9 * -17.4 * -18.2 * -18.9 * -19.7 * -20.5 * -21.3 * -22.1 * -22.9 * -23.8 * -24.6 * -25.4 * -26.3 * -27 1 * -27 9 * -28 8 * -29 6 * -30 4 * -31 3 * -32 1 * -32.9 * -33.8 * -34.6 * -35.4 * -36.3 * -37.1 * -37.9 * -38.8 * -39.6 * -40.4 * -41.3 * -42.1 * -42 9 * -43 8 * -44 6 * -45 4 * -46 3 * -48 9 * -54 1 * -59 3 * -64 5 * -69 7 * -74.9 * -80.1 * -85.4 * -90.6 * -6.6 * -7.0 * -7.4 * -7.8 * -8.2 * -8.6 * -9.2 * -9.8 * -10.4 * -11.0 * -11.7 * -12.3 * -12.9 * -13.5 * -14.1 * -14.8 * -15.4 * -16.0 * -16.6 * -17.2 * -17.8 * -18.5 * -19.1 * -19.7 * -20.3 * -20.9 * -21.5 * -22.2 * -22.8 * -23.4 * -24.0 * -24.6 * -25.3 * -25.9 * -26.5 * -27.1 * -29.4 * -34.2 * -39.0 * -43.8 * -48.6 * -53.4 * -58.3 * 18.6 * 19.5 * 20.3 * 21.2 * 22.1 * 22.9 * 23.9 * 24.9 * 259* 270* 280* 290* 300* 310' 320* 331' 34.1 * 35.1 * 36.1 * 37.2 * 38.2 * 39.2 * 402* 413' 423* 433* 444* 454* 464* 474* 485* 495* 50.5 * 51.6 * 52.6 * 53.6 * 57.0 * 64.0 * 71.0 * 78.0 * 85.0 * 92.0 * 99.1 * -63.1 * 106.1 * -67.9 * 113.2 * COMPANY : ARCO ALASKA INC. WELL : WARTHOG #1 PAGE * DEPTH * DEVIATION * AZIMUTH * TRUE * + NORTH * + EAST * COURSE * * * * * VERTICAL * - SOUTH * - WEST * LENGTH * * * * * DEPTH * DRIFT * DRIFT * * * FT * DEG * DEG * FT * FT * FT * FT * 14.7 * 220.7 * 2236 6 * -95.8 * -72.7 * 120.2 * * 2250.0 * * 2275.0 * * 2300.0 * * 2325 0 * * 2350 0 * * 2375 0 * * 2400 0 * * 2425 0 * * 2450 0 * * 2475 0 * * 2500 0 * * 2525.0 * * 2550.0 * * 2575.0 * * 2600.0 * * 2625.0 * * 2650.0 * * 2675.0 * * 2700.0 * * 2725.0 * * 2750.0 * * 2775.0 * * 2800.0 * * 2825.0 * * 2850.0 * * 2875.0 * * 2900.0 * * 2925.0 * * 2950.0 * * 2975.0 * * 3000.0 * * 3025.0 * * 3050.0 * * 3075.0 * * 3100.0 * * 3125.0 * * 3150.0 * * 3175.0 * * 3200.0 * * 3225.0 * * 3250.0 * * 3275.0 * * 3300.0 * * 3325.0 * * 3350.0 * 16.1 * 220.9 * 2260 17.5 * 221.1 * 2284 18.9 * 221 2 * 2307 20.2 * 221 4 * 2331 21.6 * 221 6 * 2355 23 0 * 221 8 * 2378 24 4 * 222 0 * 2402 25 8 * 222 1 * 2426 27 1 * 222.3 * 2449 28 5 * 222.5 * 2473 29 9 * 222.7 * 2497 31 3 * 222.9 * 2520 31 8 * 222.8 * 2542 32 0 * 222.7 * 2563 32.2 * 222.5 * 2583 32.5 * 222.4 * 2604 32 7 * 222.3 * 2625 33 0 * 222.1 * 2646 33 2 * 222 0 * 2666 33 4 * 221 9 * 2687 3 * -101.0 * -77.5 * 127.3 * 0 * -106.2 * -82.3 * 134.4 * 6 * -111.4 * -87.1 * 141.4 * 3 * -116.6 * -91.9 * 148.5 * 0 * -121.9 * -96.7 * 155.6 * 7 * -127.1 * -101.5 * 162.7 * 3 * -132.3 * -106.4 * 169 7 * 0 * -137.5 * -111.2 * 176 7 * -142.7 * -116.0 * 183 4 * -147.9 * -120.8 * 191 1 * -153.2 * -125.6 * 198 7 * -158.4 * -130.4 * 205 2 * -167.5 * -138.6 * 217 0 * -177.9 * -147.8 * 231 7 * -188.4 * -157.0 * 245 5 * -198.8 * -166.3 * 259 2 * -209.2 * -175.5 * 273 0 * -219.6 * -184.8 * 287 7 * -230.0 * -194.0 * 300 5 * -240.4 * -203.2 * 314 8 ~ 9 * 0 * 1 * 1 * 4 * 3 * 2 * 2 * 1 * 0 * 9 * 8 * 33 7 * 221 33 9 * 221 34 1 * 221 34 4 * 221 34 6 * 221 34 8 * 221 35 1 * 221 35 3 * 220 8 * 2708.3 * -250.8 * -212.5 * 328 7 * 6 * 2729.0 * -261.2 * -221.7 * 342 6 * 5 * 2749.8 * -271.7 * -230.9 * 356 6 * 4 * 2770.5 * -282.1 * -240.2 * 370 5 * 2 * 2791.3 * -292.5 * -249.4 * 384 4 * 1 * 2812.1 * -302.9 * -258.7 * 398.3 * 0 * 2832.8 * -313.3 * -267.9 * 412.2 * 8 * 2853.6 * -323.7 * -277.1 * 426.1 * 35 5 * 220.7 * 2874.3 * -334.1 * -286.4 * 440.1 * 35 8 * 220.6 * 2895.1 * -344.5 * -295.6 * 454.0 * 36.0 * 220.4 * 2915 8 * -355.0 * -304.8 * 467.9 * 36.1 * 220.3 * 2936 36.2 * 220.2 * 2956 36.2 * 220.2 * 2976 36.2 * 220.1 * 2996 36.3 * 220.0 * 3016 36.3 * 219.9 * 3036 36.3 * 219.8 * 3056 36 4 * 219.7 * 3077 2 * -366.0 * -314.2 * 482.4 * 3 * -377.5 * -323.7 * 497 3 * 4 * -389.0 * -333.1 * 512 1 * 5 * -400.4 * -342.6 * 527 0 * 6 * -411.9 * -352.0 * 541 8 * 7 * -423.3 * -361.4 * 556 7 * 8 * -434.8 * -370.9 * 571 5 * 0 * -446.3 * -380.3 * 586 4 * 36 4 * 219.6 * 3097.1 * -457.7 * -389.8 * 601.2 * 36 5 * 219.5 * 3117.2 * -469.2 * -399.2 * 616.1 * 36 5 * 219.4 * 3137.3 * -480.7 * -408.7 * 630.9 * 36 5 * 219.3 * 3157.4 * -492.1 * -418.1 * 645.8 * 36 6 * 219.2 * 3177.5 * -503.6 * -427.6 * 660.6 * ************************************************************************** COMPANY : ARCO ALASKA INC. WELL : WARTHOG #1 PAGE 5 * DEPTH * DEVIATION * AZIMUTH * TRUE * + NORTH * + EAST * COURSE * * * * * VERTICAL * - SOUTH * - WEST * LENGTH * * * * * DEPTH * DRIFT * DRIFT * * * FT * DEG * DEG * FT * FT * FT * FT * 36 6 * 219.1 * 3197 6 * -515 0 * -437.0 * 675.5 * * 3375.0 * * 3400.0 * * 3425.0 * * 3450.0 * * 3475.0 * * 3500.0 * * 3525.0 * * 3550.0 * * 3575.0 * * 3600.0 * * 3625.0 * * 3650.0 * * 3675.0 * * 3700.0 * * 3725.0 * * 3750.0 * * 3775.0 * * 3800.0 * * 3825.0 * * 3850.0 * * 3875.0 * * 3900.0 * * 3925.0 * * 3950.0 * * 3975.0 * * 4000.0 * * 4025.0 * * 4050.0 * * 4075.0 * * 4100.0 * * 4125.0 * * 4150.0 * * 4175.0 * * 4200.0 * * 4225.0 * * 4250 0 * 0 * 0 * 0 * 0 * 0 * 0 * 0 * 0 * 0 * 36 36 36 36 36 36 36 36 36 36 36 * 4275 * 4300 * 4325 * 4350 * 4375 * 4400 * 4425 * 4450 * 4475 6 * 219.0 * 3217 7 * 218.9 * 3237 7 * 218.8 * 3257 7 * 218.7 * 3278 8 * 218.6 * 3298 8 * 218.5 * 3318 7 * -526 8 * -538 9 * -549 1 * -560 2 * -572 3 * -584 5 * -446.4 * 690.3 * 0 * -455.9 * 705.2 * 4 * -465.3 * 720.0 * 9 * -474.8 * 734.9 * 3 * -484.2 * 749.7 * 0 * -493.3 * 764.5 * 8 * -502.1 * 779.1 * 7 * 218.4 * 3338.5 * -595 6 * 218.2 * 3358.8 * -607.5 * -510.9 * 793.8 * 6 * 218.0 * 3379.0 * -619.3 * -519.7 * 808.5 * 5 * 217.9 * 3399.2 * -631.1 * -528.5 * 823.2 * 4 * 217.7 * 3419.4 * -642.9 * -537.3 * 837.9 * 36.4 * 217.5 * 3439.6 * -654.7 * -546.1 * 852.6 * 36.3 * 217.4 * 3459.8 * -666.5 * -554.9 * 867.2 * 36.3 * 217.2 * 3480.0 * -678.3 * -563.7 * 881.9 * 36.2 * 217.1 * 3500.3 * -690.0 * -572.5 * 896.6 * 36.1 * 216.9 * 3520.5 * -701.8 * -581.3 * 911.3 * 36.1 * 216.7 * 3540.7 * -713.6 * -590.1 * 926.0 * 36.0 * 216.6 * 3560.9 * -725.4 * -598.9 * 940 7 * 35.9 * 216.4 * 3581.1 * -737.2 * -607.7 * 955 4 * 35 9 * 216.2 * 3601.3 * -749.0 * -616.5 * 970 0 * 35 8 * 216.1 * 3621.5 * -760.8 * -625.3 * 984 7 * 35 7 * 215.9 * 3641.8 * -772.5 * -634.1 * 999 4 * 35 7 * 215.8 * 3662.0 * -784.3 * -642.9 * 1014 1 * 35 6 * 215.6 * 3682.2 * -796.1 * -651.7 * 1028.8 * 35 5 * 215.4 * 3702.4 * -807 9 * -660.5 * 1043.5 * 35.5 * 215.3 * 3722.6 * -819 35.4 * 215 1 * 3742.8 * -831 35.4 * 214 9 * 3763.1 * -843 35 3 * 214 8 * 3783.3 * -855 3 * 214 7 * 3803.7 * -867 3 * 214 5 * 3824.1 * -879 7 * -669.2 * 1058.2 * 5 * -678.0 * 1072.9 * 2 * -686.8 * 1087.6 * 1 * -695.5 * 1102.2 * 1 * -703.6 * 1116.6 * 1 * -711.7 * 1131.1 * 3 * 214 4 * 3844.4 * -891.1 * -719.7 * 1145.5 * 4 * 214 3 * 3864.8 * -903.1 * -727.8 * 1159.9 * 4 * 214.2 * 3885.2 * -915.2 * -735.9 * 1174.3 * 4 * 214.1 * 3905.6 * -927.2 * -744.0 * 1188.8 * 4 * 214.0 * 3925.9 * -939.2 * -752.1 * 1203.2 * 4 * 213.8 * 3946.3 * -951 2 * -760.1 * 1217.6 * 4 * 213.7 * 3966 7 * -963 35 35 35 35 35 35 35 35 35 1 * -975 5 * -987 8 * -999 2 * -1011 6 * -1023 0 * -1035 35.4 * 213.6 * 3987 35.4 * 213.5 * 4007 35.5 * 213.4 * 4027 35.5 * 213.2 * 4048 35.5 * 213.1 * 4068 35.5 * 213.0 * 4089 2 * -768.2 * 1232.1 * 3 * -776.3 * 1246.5 * 3 * -784.4 * 1260.9 * 3 * -792.4 * 1275.4 * 3 * -800.5 * 1289.8 * 3 * -808.6 * 1304.2 * 4 * -816.7 * 1318.7 * COMPANY : 3LRCO A_LAS~ INC. WELL : WARTHOG #1 PAGE 6 * DEPTH * DEVIATION * AZIMUTH * TRUE * + NORTH * + EAST * COURSE * * * * * VERTICAL * - SOUTH * - WEST * LENGTH * * * * * DEPTH * DRIFT * DRIFT * * * FT * DEG * DEG * FT * FT * FT * FT * 4500 0 * 4525 0 * 4550 0 * 4575 0 * 4600 0 * 4625 0 * 4650 0 * 4675.0 * 4700.0 * 4725.0 * 4750.0 * 4775.0 * 4800.0 * 4825.0 * 4850.0 * 4875.0 * 4900.0 * 4925.0 * 4950.0 * 4975.0 * 5000.0 * 5025.0 * 5050.0 * 5075.0 * 5100.0 * 5125.0 * 5150.0 * 5175.0 * 5200.0 * 5225.0 * 5250.0 * 5275 0 * 5300 0 * 5325 0 * 5350 0 * 5375 0 * 5400 0 * 5425 0 * 5450.0 * 5475.0 * 5500.0 * 5525.0 * 5550.0 * 5575.0 * 5600.0 * 35.6 * 35.6 * 35.7 * 35.8 * 35.8 * 35.9 * 36.0 * 36 0 * 36 1 * 36 2 * 36 2 * 36 3 * 36 4 * 36.4 * 36.5 * 36.5 * 36.6 * 36.7 * 36.7 * 36.8 * 36.9 * 36.9 * 37.0 * 37.0 * 36.9 * 36.9 * 36.9 * 36.9 * 36.8 * 36.8 * 36.8 * 36.8 * 36.7 * 36.7 * 36 7 * 36 7 * 36 6 * 36 6 * 36 6 * 36 6 * 36 5 * 36 5 * 36 5 * 36 5 * 36 5 * 212.9 * 212 9 * 212 8 * 212 8 * 212 7 * 212 6 * 212 6 * 212 5 * 212 5 * 212.4 * 212.3 * 212.3 * 212.2 * 212.1 * 212.1 * 212.0 * 212.0 * 211.9 * 211.8 * 211.8 * 211.7 * 211.7 * 211.6 * 211.5 * 211.4 * 211.4 * 211.3 * 211.2 * 211.2 * 211.1 * 211.0 * 210.9 * 210.9 * 210.8 * 210.7 * 210.6 * 210.6 * 210.5 * 210.4 * 210.3 * 210.3 * 210.2 * 210.2 * 210.3 * 210.3 * 4109 1 * -1047.8 * -824 6 * 1333.4 * 4129 4149 4169 4189 4209 4230 4250 4270 4290 4310 4330 4351 4371 4391 4411 3 * -1060.3 * -832 5 * -1072.8 * -840 6 * -1085.3 * -848 8 * -1097.8 * -856 9 * -1110.3 * -864 1 * -1122.8 * -871 3 * -1135.3 * -879 5 * 1348.1 * 4 * 1362.8 * 2 * 1377.5 * 1 * 1392.2 * 0 * 1406.9 * 9 * 1421.6 * 8 * 1436.3 * 4 * -1147.8 * -887.7 * 1451.0 * 6 * -1160.3 * -895.6 * 1465.8 * 8 * -1172.8 * -903.5 * 1480.5 * 9 * -1185.3 * -911.4 * 1495.2 * 1 * -1197.8 * -919.3 * 1509.9 * 2 * -1210.3 * -927.2 * 1524.6 * 4 * -1222.8 * -935.1 * 1539.4 * 6 * -1235.3 * -943.0 * 1554.1 * 4431.7 * -1247.8 * -950.9 * 1568.8 * 4451 9 * -1260.3 * -958.8 * 1583.5 * 4472 4492 4512 4532 4552 4572 4592 4612 4632 4652 4672.9 * -1399.8 * -1044.3 * 1746 4692.9 * -1412.6 * -1052.0 * 1761 4712.9 * -1425.5 * -1059.7 * 1776 4733.0 * -1438.3 * -1067.4 * 1791 4753 0 * -1451.1 * -1075.1 * 1806 4773 4793 4813 4833 4853 4873 4893 4913 4933 4953 4973 4993 0 * -1272.8 * -966.7 * 1598.3 * 2 * -1285.3 * -974.6 * 1613.0 * 4 * -1297.8 * -982.5 * 1627.7 * 5 * -1310.3 * -990.4 * 1642.4 * 7 * -1322.8 * -998 2 * 1657.2 * 7 * -1335.6 * -1005 9 * 1672.1 * 7 * -1348.5 * -1013 6 * 1686.9 * 8 * -1361.3 * -1021 3 * 1701.8 * 8 * -1374.1 * -1029 0 * 1716.7 * 8 * -1387.0 * -1036 7 * 1731 6 * 0 * -1464.0 * -1082.7 * 1820 0 * -1476.8 * -1090.4 * 1835 1 * -1489.6 * -1098 1 * 1850 1 * -1502 5 * -1105 3 * -1113 1 * -1121 0 * -1128 8 * -1136 6 * -1144 4 * -1151 2 * -1159 0 * -1166 1 * -1515 2 * -1528 2 * -1541 2 * -1553 3 * -1566 4 * -1579 5 * -1592 6 * -1605 4 * 3 * 2 * 1 * 0 * 9 * 7 * 6 * 8 * 1865.5 * 5 * 1880.4 * 2 * 1895.3 * 8 * 1910.2 * 5 * 1925.1 * 2 * 1940.0 * 8 * 1954.8 * 3 * 1969.5 * 9 * 1984.3 * COMPANY : ARCO ALASKA INC. WELL : WARTHOG #1 PAGE 7 * DEPTH * DEVIATION * AZIMUTH * TRUE * + NORTH * + EAST * COURSE * * * * * VERTICAL * - SOUTH * - WEST * LENGTH * * * * * DEPTH * DRIFT * DRIFT * * * FT * DEG * DEG * FT * FT * FT * FT * ************************************************************************** 5625.0 * 5650 0 * 5675 0 * 5700 0 * 5725 0 * 5750 0 * 5775 0 * 5800.0 * 5825 0 * 5850 0 * 5875 0 * 5900 0 * 5925 0 * 5950 0 * 5975.0 * 6000.0 * 6025.0 * 6050.0 * 6075.0 * 6100 0 * 6125 0 * 6150 0 * 6175 0 * 6200 0 * 6225 0 * 6250.0 * 6275.0 * 6300.0 * 6325.0 * 6350.0 * 6375.0 * 6400.0 * 6425.0 * 6450.0 * 6475.0 * 6500.0 * 6525.0 * 6550 0 * 6575 0 * 6600 0 * 6625 0 * 6650 0 * 6675 0 * 6700 0 * 6725.0 * 36.5 * 36.5 * 36.5 * 36.5 * 36.5 * 36.5 * 36.5 * 36.4 * 36.4 * 36.4 * 36.4 * 36.4 * 36.4 * 36.4 * 36.4 * 36.4 * 36.4 * 36.4 * 36.4 * 36.4 * 36.4 * 36.4 * 36.4 * 36.4 * 36.4 * 36.4 * 36.4 * 36.4 * 36.4 * 36.4 * 36.4 * 36.4 * 36.4 * 36.4 * 36.4 * 36.4 * 36.4 * 36.5 * 365* 366* 367* 367* 368* 368* 369* 210 3 * 210 4 * 210 4 * 210 4 * 210 5 * 210 5 * 210.5 * 210.6 * 210.6 * 210.6 * 210.7 * 210.7 * 210.7 * 210.8 * 210.8 * 210.8 * 210.9 * 210.9 * 211.0 * 211.1 * 211.2 * 211.3 * 211.4 * 211.5 * 211.6 * 211.7 * 211 8 * 211 9 * 212 0 * 212 1 * 212 2 * 212 3 * 212.4 * 212.5 * 212 5 * 212 6 * 212 8 * 213 0 * 213 2 * 213 4 * 213 6 * 213 8 * 214.0 * 214.2 * 214.4 * 5013 7 * -1617.8 * -1174.4 * 1999.1 * 8 * -1630.6 * -1182.0 * 2013.9 * 9 * -1643.4 * -1189.5 * 2028.7 * 0 * -1656.2 * -1197.0 * 2043.5 * 1 * -1669.0 * -1204.6 * 2058.3 * 3 * -1681.8 * -1212.1 * 2073.1 * 4 * -1694.5 * -1219 7 * 2087.9 * 5033 5053 5074 5094 5114 5134 5154 5174 5194 5214 5234 5255 5275 5295 5315 5335 5355 5375 5395 5415 5436 5456 5476 5496 5 * -1707.3 * -1227 6 * -1720.1 * -1234 7 * -1732.9 * -1242 8 * -1745.7 * -1249 9 * -1758.5 * -1257 0 * -1771.3 * -1265 1 * -1784.1 * -1272 2 * 2102.6 * 8 * 2117.4 * 3 * 2132.2 * 9 * 2147.0 * 4 * 2161.8 * 0 * 2176.6 * 5 * 2191.4 * 2 * -1796.9 * -1280.1 * 2206.2 * 3 * -1809.7 * -1287.6 * 2221.0 * 5 * -1822.5 * -1295.2 * 2235.8 * 6 * -1835.2 * -1302.9 * 2250.6 * 7 * -1847.8 * -1310.7 * 2265.4 * 8 * -1860.4 * -1318.5 * 2280.2 * 9 * -1873.0 * -1326.3 * 2295.0 * 1 * -1885.6 * -1334.1 * 2309.8 * 2 * -1898.2 * -1341.9 * 2324.6 * 3 * -1910.8 * -1349.8 * 2339.5 * 4 * -1923.4 * -1357.6 * 2354.3 * 5516.6 * -1936.0 * -1365.4 * 2369.1 * 5536 7 * -1948.6 * -1373.2 * 2383.9 * 5556 5576 5597 5617 5637 5657 5677 5697 5717 5737 5757 5777 5797 5817 5837 5857 5877 5897 8 * -1961.2 * -1381.0 * 2398.7 * 9 * -1973.8 * -1388.8 * 2413.5 * 0 * -1986.5 * -1396.7 * 2428.3 * 2 * -1999.1 * -1404.5 * 2443.1 * 3 * -2011.7 * -1412.3 * 2457.9 * 4 * -2024.3 * -1420.1 * 2472.7 * 5 * -2036 9 * -1427.9 * 2487.5 * 7 * -2049 8 * -2062 9 * -2074 9 * -2087 9 * -2099 9 * -2111 9 * -2124 9 * -2136 9 * -2148 9 * -2161 9 * -2173 5 * -1435.7 * 2502.4 * 1 * -1443.6 * 2517.2 * 6 * -1451.6 * 2532.0 * 0 * -1460.1 * 2547.0 * 4 * -1468.5 * 2562.0 * 8 * -1476.9 * 2577.0 * 2 * -1485.4 * 2592.0 * 6 * -1493.8 * 2607.0 * 9 * -1502.3 * 2622.0 * 3 * -1510.7 * 2637.0 * 7 * -1519.1 * 2651.9 * COMPANY : ARCO ALASKA INC. WELL : WARTHOG #1 PAGE 8 * DEPTH * DEVIATION * AZIMUTH * TRUE * + NORTH * + EAST * COURSE * * * * * VERTICAL * - SOUTH * - WEST * LENGTH * * * * * DEPTH * DRIFT * DRIFT * * * FT * DEG * DEG * FT * FT * FT * FT * ************************************************************************** * 6750.0 * 37.0 * * 6775.0 * 37.0 * * 6800.0 * 37.1 * * 6825.0 * 37.1 * * 6850.0 * 37.2 * * 6875.0 * 37.3 * * 6900.0 * 37.3 * * 6925.0 * 37.3 * * 6950.0 * 37.4 * * 6975.0 * 37.4 * * 7000.0 * 37.5 * * 7025.0 * 37.5 * * 7050.0 * 37.5 * * 7075.0 * 37.6 * * 7100.0 * 37.6 * * 7125.0 * 37.6 * * 7150.0 * 37.5 * * 7175.0 * 37.5 * * 7200.0 * 37.5 * * 7225.0 * 37.5 * * 7250.0 * 37.4 * * 7275.0 * 37.4 * * 7300.0 * 37.4 * * 7325.0 * 37.3 * * 7350.0 * 37.3 * * 7375.0 * 37.3 * * 7400.0 * 37.3 * * 7425.0 * 37.2 * * 7450.0 * 37.2 * * 7475.0 * 37.2 * * 7500.0 * 37.2 * * 7525.0 * 37.1 * * 7550.0 * 37.1 * * 7575.0 * 37.2 * * 7600.0 * 37.3 * * 7625.0 * 37.4 * * 7650.0 * 37.5 * * 7675.0 * 37.6 * * 7700.0 * 37.8 * * 7725.0 * 37.9 * * 7750.0 * 38.0 * * 7775.0 * 38.1 * * 7800.0 * 38.3 * * 7825.0 * 38.4 * * 7850.0 * 38.5 * 214.6 * 214.8 * 215.0 * 215.2 * 215.4 * 215.6 * 215.8 * 215.6 * 215.5 * 215.4 * 215.2 * 215.1 * 215.0 * 214.8 * 214.7 * 214.6 * 214.5 * 214.5 * 214.4 * 214.3 * 214.2 * 214.1 * 214.0 * 213.9 * 213.8 * 213.7 * 213.6 * 213.5 * 213.4 * 213.3 * 213.2 * 213.1 * 213 0 * 213 0 * 213 0 * 213 0 * 213 0 * 213 0 * 213.0 * 213.0 * 213.0 * 213.0 * 213.0 * 213.0 * 213.0 * 5917.9 * -2186.1 * -1527.6 * 2666 9 * 5937.9 * -2198.5 * -1536.0 * 2681 5957.9 * -2210.9 * -1544.5 * 2696 5977.9 * -2223.3 * -1552.9 * 2711 5998.0 * -2235.6 * -1561.3 * 2726 6018.0 * -2248.0 * -1569.8 * 2741 6037.9 * -2260.4 * -1578.3 * 2756 6057 8 * -2272.8 * -1587.1 * 2772 6077 6097 6117 6137 6157 6176 6196 6216.6 * -2372.4 * -1656.8 * 2893 7 * 6236.5 * -2385.0 * -1665.3 * 2908 8 * 6256.3 * -2397.6 * -1673.7 * 2924.0 * 6276.2 * -2410.1 * -1682.2 * 2939.1 * 6296.1 * -2422.7 * -1690.6 * 2954.3 * 6316.0 * -2435.3 * -1699.1 * 2969.5 * 6335.8 * -2447.9 * -1707.6 * 2984.6 * 6355.7 * -2460 5 * -1716.0 * 2999.8 * 9 * 9 * 9 * 9 * 9 * 9 * 1 * 6 * -2285.2 * -1595.9 * 2787.3 * 5 * -2297.6 * -1604.7 * 2802 5 * 3 * -2310.1 * -1613.4 * 2817 7 * 2 * -2322.5 * -1622.2 * 2832 9 * 0 * -2334.9 * -1631.0 * 2848 1 * 9 * -2347.3 * -1639.8 * 2863 3 * 7 * -2359.8 * -1648.3 * 2878 5 * 1 * -1724.5 * 3015.0 * 7 * -1732.9 * 3030.1 * 3 * -1741.4 * 3045.3 * 8 * -1749.9 * 3060 5 * 4 * -1758.3 * 3075 6 * 0 * -1766.8 * 3090 8 * 9* 1 * 3 * 6375.6 * -2473 6395.5 * -2485 6415.3 * -2498 6435.2 * -2510 6455.1 * -2523 6475.0 * -2536 6494.8 * -2548.6 * -1775.2 * 3105 6514.7 * -2561.2 * -1783.7 * 3121 6534.6 * -2573 8 * -1792.2 * 3136 4 * -1800.6 * 3151.4 * 1 * -1809.1 * 3166.7 * 1 * -1817.5 * 3182.2 * 1 * -1825.9 * 3197.7 * 1 * -1834.4 * 3213.1 * 1 * -1842.8 * 3228.6 * 0 * -1851.2 * 3244.1 * 0 * -1859.6 * 3259.6 * 0 * -1868.1 * 3275.0 * 0 * -1876.5 * 3290.5 * 0 * -1884.9 * 3306.0 * 6554.5 * -2586 6574.2 * -2599 6593.8 * -2612 6613.5 * -2625 6633.1 * -2638 6652.7 * -2651 6672.4 * -2664 6692.0 * -2677 6711.6 * -2690 6731.3 * -2703 6750.9 * -2716 6770.5 * -2728.9 * -1893.4 * 3321.4 * 6790.2 * -2741.9 * -1901.8 * 3336.9 * COMPANY : ARCO ALASKA INC. WELL : WARTHOG #1 PAGE 9 * DEPTH * DEVIATION * AZIMUTH * TRUE * + NORTH * + EAST * COURSE * * * * * VERTICAL * - SOUTH * - WEST * LENGTH * * * * * DEPTH * DRIFT * DRIFT * * * FT * DEG * DEG * FT * FT * FT * FT * 7875.0 * 7900.0 * 7925.0 * 7950.0 * 7975.0 * 8000.0 * 8025.0 * 8050.0 * 8075.0 * 8100.0 * 8125.0 * 8150.0 * 8175.0 * 8200.0 * 8225.0 * 8250.0 * 8275.0 * 8300.0 * 8325.0 * 8350 0 * 8375 0 * 8400 0 * 8425 0 * 8450 0 * 8475 0 * 8500 0 * 8525 0 * 8550.0 * 8575.0 * 8600.0 * 8625.0 * 8650.0 * 8675.0 * 8700.0 * 8725.0 * 8750.0 * 8775.0 * 8800.0 * 8825.0 * 8850.0 * 8875.0 * 8900.0 * 8925.0 * 8950.0 * 8975.0 * 38.6 * 38.7 * 38.9 * 39.0 * 39.1 * 39.2 * 39.3 * 39.4 * 39.3 * 39.3 * 39.3 * 39.2 * 39.2 * 39.2 * 39.1 * 39.1 * 39.0 * 39.0 * 39.0 * 38.9 * 38.9 * 38.9 * 38.8 * 38.8 * 38.8 * 38.7 * 38.7 * 38.7 * 38.7 * 38.7 * 38.7 * 38.8 * 38.8 * 38.8 * 38.8 * 38.8 * 38.8 * 38.8 * 38.8 * 38.8 * 38.9 * 38.9 * 38.9 * 38.9 * 38.9 * 213.0 * 213.0 * 213.0 * 213.0 * 213.0 * 213.0 * 213.0 * 213.0 * 213.0 * 213 . 0 * 213 . 0 * 213 . 0 * 213 . 0 * 213.0 * 213.0 * 213.0 * 213.0 * 213.0 * 213.0 * 213.0 * 213.0 * 213.0 * 213.0 * 213.0 * 213.0 * 213 . 0 * 213 . 0 * 213.0 * 213.1 * 213.1 * 213.1 * 213.1 * 213.1 * 213.2 * 213.2 * 213.2 * 213.2 * 213.2 * 213 3 * 213 3 * 213 3 * 213 3 * 213 3 * 213 4 * 213 4 * 6829 6849 6868 6888 6908 6927 6947 6966 6985 6809 8 * -2754.9 * -1910.2 * 3352 4 * 4 * -2767.9 * -1918.6 * 3367 1 * -2780.9 * -1927.1 * 3383 7 * -2793.8 * -1935.5 * 3398 3 * -2806.8 * -1943.9 * 3414 0 * -2819 8 * -1952.4 * 3429 6 * -2832 1 * -2845 5 * -2859 9 * -2872 7005.3 * -2885 7024.8 * -2898 7044.2 * -2911 7063.6 * -2925 7083.0 * -2938 7102.4 * -2951 7121.8 * -2964 7141.2 * -2978 7160.7 * -2991 7180.1 * -3004 7199.5 * -3017 7218.9 * -3030 7238.3 * -3044 7257.7 * -3057 8 * -1960.8 * 3445 9 * -1969.3 * 3460 1 * -1977.9 * 3476 3 * -1986.5 * 3492 5 * -1995.0 * 3508 7 * -2003.6 * 3523 9 * -2012.2 * 3539 1 * -2020.8 * 3555 3 * -2029.3 * 3571 6 * -2037.9 * 3586 8 * -2046.5 * 3602 0 * -2055.1 * 3618.2 * 2 * -2063.7 * 3634 0 * 4 * -2072.2 * 3649 7 * 6 * -2080.8 * 3665 5 * 8 * -2089.4 * 3681 2 * 0 * -2098.0 * 3697 0 * 2 * -2106.6 * 3712 7 * 8 ~ 3 * 8 * 2 * 7 * 2 * 8 * 6 * 3 * 0 * 8 * 5 * 3 * 0 * 8 * 5 * 7277.1 * -3070.4 * -2115.1 * 3728.4 * 7296.6 * -3083 6 * -2123.7 * 3744.2 * 8 * -2132.3 * 3759 9 * 9 * -2140.9 * 3775 6 * 0 * -2149.4 * 3791 2 * 1 * -2158.0 * 3806 9 * 2 * -2166.6 * 3822 5 * 3 * -2175.2 * 3838 2 * 7316 0 * -3096 7335 5 * -3109 7355 0 * -3123 7374 5 * -3136 7393 9 * -3149 7413 4 * -3162 9 ~ 9 * -3201 4 * -3214 8 * -3227 3 * -3241 8 * -3254 3 * -3267 8 * -3280 3 * -3293 7 * -3306 2 * -3319 7 * -3332 7 * -2200.9 * 3885.2 * 8 * -2209.5 * 3900.8 * 9 * -2218.1 * 3916.5 * 0 * -2226.6 * 3932.2 * 1 * -2235.2 * 3947.8 * 2 * -2243.8 * 3963.5 * 3 * -2252.4 * 3979.2 * 4 * -2260.9 * 3994.8 * 5 * -2269.5 * 4010.5 * 6 * -2278.1 * 4026.1 * 7 * -2286.7 * 4041.8 * 7432.9 * -3175.5 * -2183.8 * 3853 7452 4 * -3188 6 * -2192.3 * 3869 7471 7491 7510 7530 7549 7569 7588 7608 7627 7647 7666 COMPANY : ARCO ALASKA INC. WELL : WARTHOG #1 PAGE 10 * DEPTH * DEVIATION * AZIMUTH * TRUE * + NORTH * + EAST * COURSE * * * * * VERTICAL * - SOUTH * - WEST * LENGTH * * * * * DEPTH * DRIFT * DRIFT * * * FT * DEG * DEG * FT * FT * FT * FT * ************************************************************************** * 9000.0 * * 9025.0 * * 9050.0 * * 9075.0 * * 9100.0 * * 9125.0 * * 9150.0 * * 9175.0 * * 9200.0 * * 9225 . 0 * * 9250.0 * * 9275.0 * * 9300.0 * * 9325.0 * * 9350.0 * * 9375.0 * * 9400.0 * * 9425.0 * * 9450.0 * * 9475.0 * * 9500.0 * * 9525.0 * * 9550.0 * * 9575.0 * * 9600.0 * * 9625.0 * * 9650.0 * * 9675.0 * * 9700.0 * * 9725.0 * * 9750.0 * * 9775.0 * * 9800.0 * * 9825.0 * * 9850.0 * * 9875.0 * * 9900.0 * * 9925.0 * * 9950.0 * * 9975.0 * * 10000.0 * * 10025.0 * * 10050.0 * * 10075.0 * * 10100.0 * 38.9 * 39.1 * 39.2 * 39.4 * 39.5 * 39.6 * 39.8 * 39.9 * 40.1 * 40.2 * 40.3 * 40.5 * 40.7 * 40.8 * 41.0 * 41.2 * 41.3 * 41.5 * 41.7 * 41.8 * 42.0 * 42.2 * 423* 424* 424* 424* 425* 425* 42.5 * 42.5 * 42.5 * 426* 426* 426* 425* 423* 421' 419' 417' 415' 413' 411' 409* 407* 405* 213.4 * 213.3 * 213.2 * 213.1 * 213.0 * 212.9 * 212.8 * 212.7 * 212.6 * 212.5 * 212.4 * 212.3 * 212.2 * 212.0 * 211.9 * 211.7 * 211.6 * 211.4 * 211.3 * 211.1 * 211.0 * 210.8 * 210.7 * 210.6 * 210.6 * 210.7 * 210.7 * 210.7 * 210.7 * 210.8 * 210.8 * 210.8 * 210.9 * 210.9 * 210.8 * 210.7 * 210.6 * 210.4 * 210.3 * 210.1 * 210.0 * 209.8 * 209.5 * 209.1 * 208.7 * 7686 1 * -3346.0 * -2295.3 * 4057.6 * 7705 3 * -3359.4 * -2303.9 * 4073.5 * 7724 6 * -3372.8 * -2312.6 * 4089.5 * 7743 8 * -3386.2 * -2321.3 * 4105.4 * 7763 1 * -3399.6 * -2329.9 * 4121.4 * 7782 3 * -3413.0 * -2338.6 * 4137.4 * 7801 5 * -3426.4 * -2347.2 * 4153.3 * 7820 8 * -3439.9 * -2355.9 * 4169.3 * 7840 0 * -3453 3 * -2364.6 * 4185.2 * 7859 2 * -3466 7 * -2373.2 * 4201.2 * 7878.5 * -3480 1 * -2381.9 * 4217.2 * 7897.7 * -3493 5 * -2390.5 * 4233.1 * 7916.5 * -3507 6 * -2399.2 * 4249.6 * 7935.2 * -3521 7 * -2407.8 * 4266.1 * 7954.0 * -3535.8 * -2416.4 * 4282.7 * 7972.7 * -3549.9 * -2425.1 * 4299.2 * 7991.4 * -3564.1 * -2433.7 * 4315.7 * 8010.2 * -3578.2 * -2442.3 * 4332.2 * 8028.9 * -3592.3 * -2451.0 * 4348.8 * 8047 6 * -3606.4 * -2459.6 * 4365.3 * 4 * -3620.5 * -2468.2 * 4381.8 * 1 * -3634.7 * -2476.8 * 4398.4 * 9 * -3648.8 * -2485.5 * 4414.9 * 4 * -3663.1 * -2494.1 * 4431.6 * 9 * -3677.6 * -2502.7 * 4448.4 * 3 * -3692.1 * -2511 4 * 4465.3 * 8066 8085 8103 8122 8140 8159 8177 8196 8214.6 * -3735 8233.0 * -3750 8251.4 * -3764 8269.9 * -3779 8288.3 * -3793 8306.7 * -3808 8325.2 * -3822 8343.9 * -3837 8362.5 * -3851 8381.2 * -3865 7 * -3706.7 * -2520 1 * -3721 2 * -2528 7 * -2537 2 * -2545 7 * -2554 2 * -2563 8 * -2571 3 * -2580 7 * -2589 1 * -2597 5 * -2605 9 * -2614 8399.8 * -3880.2 * -2622 8418.4 * -3894 6 * -2631 8437.1 * -3909 0 * -2639 8455.7 * -3923 4 * -2648 8474.6 * -3937 7 * -2655 8493.7 * -3951 9 * -2663 8512.7 * -3966 2 * -2671 0 * 4482.2 * 6 * 4499.0 * 3 * 4515.9 * 9 * 4532.7 * 6 * 4549.6 * 2 * 4566.5 * 8 * 4583.3 * 5 * 4600.2 * 0 * 4617.0 * 4 * 4633.6 * 9 * 4650.2 * 3 * 4666.8 * 7 * 4683.5 * 1 * 4700.1 * 5 * 4716.7 * 0 * 4733.4 * 9 * 4749.6 * 6 * 4765.7 * 3 * 4781.9 * COMPANY : ARCO ALASKA INC. WELL : WARTHOG #1 PAGE 11 * DEPTH * DEVIATION * AZIMUTH * TRUE * + NORTH * + EAST * COURSE * * * * * VERTICAL * - SOUTH * - WEST * LENGTH * * * * * DEPTH * DRIFT * DRIFT * * * FT * DEG * DEG * FT * FT * FT * FT * ************************************************************************** * 10125.0 * * 10150.0 * * 10175.0 * * 10200 0 * * 10225 0 * * 10250 0 * * 10275 0 * * 10300 0 * * 10325 0 * * 10350 0 * * 10375.0 * * 10400.0 * * 10425.0 * * 10450.0 * * 10475.0 * * 10500 0 * * 10525 0 * * 10550 0 * * 10575 0 * * 10600 0 * * 10625 0 * * 10650 0 * * 10675 0 * * 10700.0 * * 10725.0 * * 10750 0 * * 10775 0 * * 10800 0 * * 10825 0 * * 10850 0 * * 10875 0 * * 10900 0 * * 10925 0 * * 10950 0 * * 10975 0 * * 11000.0 * * 11025.0 * * 11050 0 * * 11075 0 * * 11100 0 * * 11125 0 * * 11150 0 * * 11175 0 * * 11200 0 * 404* 402* 400* 399* 398* 398* 398* 398* 398* 39.8 * 398* 398* 398* 398* 398* 398* 398* 398* 398* 39.8 * 39.8 * 39.8 * 39.8 * 39.8 * 39.8 * 39.8 * 39.8 * 39.8 * 39.8 * 39.8 * 39.8 * 39.8 * 39.8 * 398* 398* 398* 398* 398* 398* 398* 398* 39.8 * 39.8 * 39.8 * 208.3 * 207.9 * 207.5 * 207.1 * 207.0 * 207.0 * 207.0 * 207.0 * 207.0 * 207.0 * 207 . 0 * 207.0 * 207.0 * 207.0 * 207.0 * 207.0 * 207.0 * 207.0 * 207.0 * 207.0 * 207.0 * 207.0 * 207.0 * 207.0 * 207.0 * 207.0 * 207 0 * 207 0 * 207 0 * 207 0 * 207 0 * 207 0 * 207 0 * 207.0 * 207.0 * 207.0 * 207.0 * 207 0 * 207 0 * 207 0 * 207 0 * 207 0 * 207 0 * 207 0 * 8550 8569 8588 8608 8627 8646 8665 8684 8531 7 * -3980 4 * -2679.0 * 4798.0 * 8 * -3994 7 * -2686.7 * 4814.1 * 8 * -4008 9 * -2694.4 * 4830.2 * 9 * -4023 1 * -2702.1 * 4846.4 * 0 * -4034 9 * -2708.3 * 4859.6 * 2 * -4045 3 * -2713.6 * 4871.2 * 4 * -4055.7 * -2718.9 * 4882.7 * 6 * -4066 1 * -2724.2 * 4894.3 * 8 * -4076 8704.0 * -4086 8723.3 * -4097 8742.5 * -4107 8761.7 * -4118 8780.9 * -4128 8800.1 * -4138 8819.3 * -4149 5 * -2729.5 * 4905.9 * 9 * -2734.8 * 4917.5 * 3 * -2740.1 * 4929.0 * 7 * -2745.4 * 4940.6 * 0 * -2750.6 * 4952.2 * 4 * -2755.9 * 4963.8 * 8 * -2761.2 * 4975.4 * 2 * -2766.5 * 4986.9 * 8838.5 * -4159.6 * -2771.8 * 4998.5 * 8857.7 * -4170.0 * -2777.1 * 5010.1 * 8876.9 * -4180.4 * -2782.4 * 5021.7 * 8896.1 * -4190.8 * -2787 7 * 5033.3 * 8915.3 * -4201.2 * -2793 0 * 5044.9 * 8934.5 * -4211.6 * -2798 3 * 5056.4 * 8953.7 * -4221.9 * -2803 6 * 5068.0 * 8972.9 * -4232.3 * -2808 9 * 5079.6 * 8992.2 * -4242.7 * -2814 2 * 5091.2 * 9011.4 * -4253.1 * -2819.5 * 5102.8 * 9030.6 * -4263.5 * -2824.8 * 5114 4 * 9049.8 * -4273.9 * -2830.1 * 5126 9069.0 * -4284.3 * -2835 3 * 5137 9088.2 * -4294.7 * -2840 9107.4 * -4305.1 * -2845 9126.6 * -4315.5 * -2851 9145.8 * -4325.8 * -2856 9165.0 * -4336.2 * -2861 9184.2 * -4346.6 * -2867 9203.4 * -4357.0 * -2872 9222.6 * -4367.4 * -2877 6 * 5149 9 * 5160 2 * 5172 5 * 5183 8 * 5195 1 * 5207 4 * 5218 7 * 5230.2 * 0 * 5 * 1 * 7 * 3 * 9 * 5 * 1 * 6 * 9241.8 * -4377 8 * -2883.0 * 5241.8 * 9261.1 * -4388 2 * -2888.3 * 5253.4 * 9280.3 * -4398 6 * -2893.6 * 5265.0 * 9299.5 * -4409 0 * -2898.9 * 5276.6 * 9318.7 * -4419 4 * -2904.2 * 5288.2 * 9337.9 * -4429 7 * -2909.5 * 5299.8 * 9357.1 * -4440 1 * -2914.8 * 5311.4 * 5DO o ~ I · I ~ ! {~ r ' '"' /o ,~ 7oo 0..5. / /. :', 1997 OIL AN~I~c~.~?CONSERVATION COMMISSION DOPE Test Report OPERATION; Drlg:_ .X' WorKover;~ Brig Contractor: _._[~-Z.~¢~,4~ A~.~*--~ .~.. Operator: Welt Name: ~T Casing S~e: Test: Initial ~' Wee~y Rio No, ~&5 t DATE: /~0~,' "~ t~'~ Rep.: /~L~ Pt~&~ ~, Riff Rep,: ~~ ~~ '~ _Ldcafi°n: Sec, T. R. ~Meridian , , ., ....... E ................ '"' ........ :" .... .7:;,:];','.:7:"' ".'"". ' ':" diSC, INSPECTIONS; Location Gen.: V/G~ Well Sign Housekeeping: eh) Dd. Rig PTD On Loca6on k,/" Hazard Sec. Standing Order Posted ~ · BOP STACK: Quan. Annular Preventer ..... Pipe Rams Lower Pipe Rams Blind Rams Choke Ln. Valves HCR Valves Kill Line Valves Check VaLve Test Press. Test FLOOR SAFETY VALVES: Quart. Pressure P/F Upper Kelly I IBQP [ I .~ ~ · 3.."",~ o I.... f' Lower Kelly / IBOF' ~.'. I .,~, ,~ ~-o~. I'~~- Ball Type _f._ ~ ~ .~_~o Inside BOP I .. ~ ,- '5.~oQ . 3co P/F f MU D SYST EM' Visual, AJarm Trip Tank ,-,'/' ¢ Pit Level Indicators ~ ~ Flow Indicator ~ ¢ Moth Gas Detector ~" 1,/' ' H2S Gas Detector ~ ~'/" Test CHOKE MANIFOLD: Pressure PtF No. Flanges Hydraulic Chokes ~ Functioned ~ .. ACCUMULATOR SYSTEM: System Pre,ute ~co I /p Pressure After Closure /'~l~ 1 /"' 200 psi Attained After Closure ~ ['nii~utes System Pressure Attained Ali.5. minutes Blind Switch Covers: Master: ~ Remote: " /OO0.p~l f./t~...~,,~,x~i.v~ '~C.O(' Psig. Number of Failures: Equipment Will be made within the AOGCC Commission Office at: Fax No. If your call is not returned by the inspector within 12 hours ptea~e contact the P. I. Supervisor at 279-1433 · _.. i/ ,..J . . i _. iii · / .... ~ ,Te.~t Tim/6: HO~IrS." Number of valves tested ~ Repair or R.placement of Failed ,~,_,. days'. ' / Notify the Inspector and fo[tow with Written or Foxed verification to "~ 21~-7542 Inspector North Slope Pager No, 659-3607 or 3687 sec, Sec. Distribution: STATE WITNESS REQUIRED? orig~Welt File YES X NO c - Oper./Rig c - Database 24 HOUR NOTICE GIVEN c - Trip Rpt File YES ,X' NO c - Inspector Waived Witn~s$ d By: FI-021 L (R~v,12/94) Ila"d d9G:90 Z6-110-I I DOPE.XI~ ££9;Z:ZO6 : '0N XU=I NUN 03 90HZ~IUM 03~iU :HO~:l ARCO Alaska, Inc. Post Office Box ! 00360 Anchorage Alaska 995! 0-0360 Telephone 907 265 61S6 Mark A. Major ?er~nits Director October 31, 1997 Mr. David Johnston Chairman COMM 'cofi"u 'RES ENG , , , SR ENG NRO GEOL ASST ,,, STAT, E~.H STAT TECH ,, ._ , , - IFILE,, ORIGINAL AK Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 ' Subject: Mr. Jeffrey Walker Regional Supervisor-Field Operation; Minerals Management Service AK OCS Region 949 E. 36 Avenue, Room 308 Anchorage, AK 99508 Request for Approval - Well Testing Operations Warthog #1 Exploration Well Dear Mr. Jolmston and Mr. Walker: As you know, ARCO Alaska, Inc. (AAI) will be drilling the Warthog #1 exploration well in Camden Bay, AK beginning around November 1, 1997. As previously discussed with you or your staff, AAI desires to perform reservoir limit testing on this well if it encounters significant producible hydrocarbons. The purpose of this letter is to request your approval for performance of such testing on the Warthog #1 exploration well. Typically, reservoir fluids are pulled fi'om a reservoir to induce pressure transient data. A pressure transient can also be induced by i~Ljection of fluids into the reservoir. This proposed operation would be similar to what is currently done on i~Ljection wells to obtain pressure fall-olY data. AAI believes that the use of seawater for injection purposes will allow pressure transient well data to be obtained while minimizing the volumes of hydrocarbons brought to the surface. This operation would be conducted by flowing the well initially for limited periods while obtaining short term pressure buildup/falloff data. After obtaining and briefly analyzing such data, the produced fluids would be reinjected into the producing formation followed by injection of treated seawater at higher matrix rates. This activity will yield a pressure transient with a larger pressure change than would normally be obtained from production operations. Seawater would be injected at various rates for a number of days before the well testing activities are concluded. In view of this situation, AAI requests approval to inject up to 50,000 barrels of seawater for reservoir limits testing on the Warthog #1 exploration well. We believe that this operation will result in a minimization of waste from well testing activities while allowing the data necessary to evaluate this well to be obtained. Since this well is being drilled from a surface location in Federal waters to a bottom-hole location in State waters, approval from both of your agencies is being sought. ARCO Alaska ~nc. is a Subsidiary of Atlantic Richfield Company October 31, 1997 AAI Letter to AOGCC & MMS Warthog #1 Well Testing Page 2 AAI would be happy to meet with you to discuss this testing operation in greater detail if so desired by you. Please corltact me at 265-6136 if you would like to have such a meeting or desire additional information regarding this well testing proposal. Sincerely, Mark Major Exploration Permits Director FROM: ARCO EXPLORATION AI~CO Alaska, lac, Post Offic~ 100360 Anchorage .... ska 99510-0360 Telephone g07 2t55 6136 FAX NO.: 265 1608 11-03-97 01:00P P.O1 Mark A. Major October3,, 1997 ~ ~~';'-:0- ~ ~', ~ ...... , .... · .. . Mr. David Johnston Mr. Jcl'frcy Walker '. ,... Chairman Regional Supervisor-Field Operations AK Oil & Gas Conservation Commission Minerals Management Service 3001 Porcupine Drive AK OCS Region Anchorage, AK 99.5(~1 ' 949 E. 36 Avenue, Roo~ ~.~ = Anchorage, AK Subject: Request for Approval- Well Testing Operations ": , Warthog ~1 Exploratiun Well ,'.~i~ ...... .'., Dear Mr. Johnston and Mr. Walker: ~ 7- Og~ :{Fio.~:qr~g', .. As you know, ARCO Alaska, Inc. (AAI) will be drilling the Warthog /ti exploration well in Camden Bay, AK beginning around November 1, 1997. As previously di.scussed with you or your staff, AAI de.sims to pm'form reservoir Ii,nit testing on this well it' it encounters signit-icant producible hydrocarbons. The purpose of this letter is to request your approval for performance of such testing on thc Warthog #1 exploration well. Typically, rescrvoir fluids arc pullcd from a reservoir to induce pressure transient data. A pressure transient can al.so bc induced by injection of fluids into thc reservoir. This proposed operation would be similar lO what is currently done on injection wells to obtain prcs..,;ure fall-off data. AA[ believes that thc usc of seawater for in.jcction purposes will allow prcssurc transient well data to be obtained while minimizing the volumes of hydrocarbons brought to the surhce. This operation wmdd be ctmducted by llowing the well iuitially for limited periods while obtaining sl~ort tcrm pressure builduplfalloff data. After obtaining and briefly analyzing such data, thc produced fluids would be reinjected into thc producing formation fi, flowed by injection of treated seawater at higher matrix rates. This activity will yield a pressure transient with a larger pressure change than would normally be obtained from production operations. Seawater would be injected at various rates lk, r a number of days before the well testing activities arc concluded. In view of this situation, AAI requests approval to inject up to 50,0tX) barrels of seawater for rcsctwoir limits testing on the Warthog #1 exploration well. We believe that this operation will result in a minimization of waste :{'rom well testing activities while allowing the data necessary to evaluate this well to be obtained. Since this well is being drilled from a surface location in Federal waters to a bottom-hole location in State waters, approval from both of your agencies is being sought. Post-It'' brand fax transmittal memo 7871 I Post-It'~ brand fax transmittal memo 7671 ~'co. "Te"=~/t/.x4/x/~"::c"eS I~;' /%4 ~'~,,'qE c o Dept, t FROM: ARCO EXPLORATION FAX NO. : October 31. Ie' AAI Letter to ,GCC & MMS Wnrthog #1 Well Testing Page 2 265 1688 I 1-83-97 81:80P P .82 AAI would be happy to meet with you to discuss this testing operation in greater detail if so desired by you, Please contact me at 265-6136 if you would like to have such a meeting or desire additional information regarding this well testing proposal_ Sincerely, Mark Major Exploration Permits Director E & ? SE'/?V/C£~, /A/~. December 2, 1997 Mr. Jeff Walker Regional Supervisor, Field Operations U.S. Department of the Interior Minerals Management Service, 3rd Floor Alaska OCS Region 949 E 36th Avenue Anchorage, Alaska 99508-4302 Mr. David Johnston Chairman AK Oil & Gas Conservation Comm. 3001 Porcupine Drive Anchorage, Alaska 99501-0030 RE: Request for Sundry Approval - P&A ARCO Warthog #1 Exploration Well Dear Sirs, Attached find a Sundry Notice requesting approval of the also enclosed Plug and Abandonment Procedure for the ARCO Warthog #1 well. Verbal approval of this procedure was issued on December 1, 1997 by the MMS' Kyle Monkelien and the AOGCC's Blair Wondzell. If you have any questions or require additional information, please call me at any time at 258-3446. Sincerely, Bill Penrose Project Manager enclosures c: Mr. Glenn Gray - ADGC Mr. Paul Mazzolini - ARCO 715 L Street Anchorage, Alaska 99501 (907) 258-3446 FAX (907) 258-5557 STATE OF ALASKA ALASK ..)IL AND GAS CONSERVATION L ,VlMISSION APPLICATION FOR SUNDRY APPROVAL 1. 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 2. Name of Operator ARCO Alaska, Inc. 3. Address p 0 Box 100360 Anchorage, AK 99510-0360 5. Type of well: [] Development [] Exploratory [] Stratigraphic [] Service / 4. Location of well at surface ~ 02'3~" w, lz~° 55' 02' N ~ ,- At top of I~interval 2370' FNL, 719' [~"EL, Sec. 20, TSN, R29E, ~ At effective depth same as Total Depth At total depth 328~' FALL, 1407' FEL, Sec 20, T8N, R29E, UM 6. Datum Elevation (DF or KB) 91.5' RKB, ASL 7. Unit or Property Name Camden Bay Unit 8. Well Number Warthog ~l 9. Permit Number 97-85 10. APl Number · ~l~r.- 55-171-00012 11. Field and Pool Wildcat 12. Present well condition summary Total depth: measured true vertical Effective depth: measured true vertical 10,286 feet Plugs (measured) None 8,600 feet 10,286 feet Junk (measured) None 8,600 feet Casing Length St ruct u ral 232 ' Conductor 1,013' Surface z~,O17 ' Intermediate N/A Production N/A Liner N/A Perforation depth' measured true vertical N/A Tubing (size, grade, and measured depth) N/A Packers and SSSV (type and measured depth) Size Cemented 20" Driven 13-3/8" Surface 9-5/8" Surface ORIGINAL MD TVD 232' 232' 1,013' 1,013' ~,017' 3,665' 13. Attachments [] Description summary of proposal [] Detailed operations program [] BOP sketch 4. Estimated date for commencing operation December 1, 1997 16. If proposal was verbally approved Blair Wondzell Name of approver Contact Engineer Name/Number: Bill Penrose 258-3/+/+6 Prepared By Name/Number: 15. Status of well classifications as: [] Oil [] Gas [] Suspended ! 12/1/97 { Service Wildcat to be abandoned Date approvedI Bill Penrose 258-3446 17. I hereby certify that the foregoing is true and correct to the best of my knowledge Signe .¢-~ /3 ~ n , /"/¢~:,¢ I;8/2. ......................... __~_~///~ ...... _/~_~ ........ Z~___6__~Z' Tit!e__ ..... _Ku?az-uE Drilling Superintendent Date Commission Use Only ! Approval U o.~,, Conditions of Approval: Notify Commission so representative may witness Plug integrity ~ Mechanical Integrity Test__ Approved by order of the Comm,,i.s~j,.,98,~ed~ COPY Form 10-403 Rev. 06/15/88 · BOP Test Location clearance Subsequent form required lO- Commissioner ., Submit tin ~ripli~ ARCO Warthog #1 Plug and Abandonment Procedure DEC RIH w/OEDP and spot a 280' cement plug from 6,950' to 7,230' across the interval 7,093'/7,130' as follows: 10 bbls fresh water spacer 25 bbls (120 sx) Class G + 1% BA-10 + 0.65% FL-33 + 0.3% CD-32 + 0.3% A-2 + 0.32% R-1 + 1 ghs FP-6L + 0.3% CD-32 added to the mix water. (15.8 ppg, 1.16 cf/sk) 10 bbls fresh water spacer With the OEDP at 7,230', pump a balanced plug as specified above such that the cement in the drillpipe is approximately 100' higher than the cement level in the annulus. Slowly POH 5 stands, allowing the cement to fall out the end of the drillpipe. Perform one complete circulation to clean out drillpipe and open hole above plug. Ensure the mud weight in the hole is at least 9.7 ppg. WOC 8 hours, then RIH and tag cement plug. Set 15,000 lbs drillpipe weight on plug. If cement has not yet set or will not take 15,000 lbs weight, pull back up and circulate drillpipe and hole clean. WOC, checking plug's ability to take weight every 4 hours. 2. POH to 4,120' RKB. o Spot a 250' cement plug from.3,870' to 4,120' across the 9-5/8" casing shoe at 4,017' with the cement plug extending from 150' above to 100' below the shoe. Pump the cement as follows: 10 bbls fresh water spacer 24 bbls (116 sx) Class G + 1% A-7 + 1 ghs FP-6L. (15.8 ppg, 1.15 cf/sk) 10 bbls fresh water spacer With the OEDP at 4,120', pump a balanced plug as specified above such that the cement in the drillpipe is approximately 100' higher than the cement level in the annulus. Slowly POH 5 stands, allowing the cement to fall out the end of the drillpipe. Perform one complete circulation to clean out drillpipe and open hole above plug. WOC 8 hours, then RIH and tag cement plug. Set 15,000 lbs drillpipe weight on plug. If cement has not yet set or will not take 15,000 lbs weight, pull back up and circulate drillpipe and hole clean. WOC, checking plug's ability to take weight every 4 hours. ORIGINAL If plug top is located below 3,917', another plug must be set to bring the top at least that high. 4. POH to 350' RKB. 5. Spot a 175' cement surface plug from 175' to 350'. Pump the cement as follows: 10 bbls fresh water spacer 13.5 bbls (80 sx) Cold Set II + 1 ghs FP-6L. (14.95 ppg, 0.961 cf/sk) 10 bbls fresh water spacer With the OEDP at 350', pump a 175' balanced plug as specified above such that the cement in the drillpipe is approximately 100' higher than the cement level in the annulus. Slowly POH 2 stands, allowing the cement to fall out the end of the drillpipe. Perform one complete circulation to clean out drillpipe and 'open hole above plug. WOC 8 hours, then RIH and tag cement plug. Set 15,000 lbs weight on plug. If cement has not yet set or will not take 15,000 lbs weight, pull back up and circulate drillpipe and hole clean. WOC, checking plug's ability to take weight every 2 hours. If plug top is located below 300' RKB, another plug must be set to bring the top at least that high. 6. POH and L/D BHA and all but 6 joints of drillpipe. N/D BOP stack, spacer spools, double studded adapter and 9-5/8" casing head. 7. Pull 9-5/8" slips and packoff from 13-3/8" casing head. o RIH w/9-5/8" casing spear and set at 140' RKB. Back out 9-5/8" casing at mudline hanger by rotating 12 - 13 tums to the right. This should require 2,500 - 4,500 ft-lbs of torque. Remove and lay out stub. L/D 9-5/8" spear. 9. N/D 13-3/8" casing head. 10. RIH w/ 13-3/8" casing spear and set at 140' RKB. mudline hanger by rotating 12 - 13 tums to the right. 6,000 ft-lbs of torque. Remove and lay out stub. Back out 13-3/8" casing at This should require 4,000 - 11. RIH w/20" casing cutter on drill pipe and cut 20" casing at 150' RKB (23' BML). 12. Pull 20" casing stub and lay out. 13. Prepare rig for cold stack and shut down for remainder of winter. ORIGINAL 14. After rig has been removed from location, conduct a bottom survey over wellsite for final site clearance approval per MMS and AOGCC regs. Mobilize divers to clean up any identified foreign objects lying on the seafloor. Anchora]~ SENT BY: 12- 1-97 ' 10'04 ; 907 276 7542;# 1/ 4 Fairweather E&P Services, Inc, 715 L Street, Anchorage, Alaska 99501 Phone: (907} 258-3446 Fax: I907] 258-5557 E-mail: bill@fairweather.com To: December. 1,. 1997 From the Office of Bill Penrose .]tlaiLr Wondz¢ll Fax: 276-7542 (including Coy_er) RE: Blair, Here's the proposed Warthog P&A procedure. I'd appreciate a. verbal approval as soon. as you're com.'l%rtable with it. 1'11 follow up with a Sundry Notice within thc next 24 hrs. BY' 12- 1-07 ' 10'04 ' B07 276 7542;~ 2/ 4 .. RIH w/OE P 7,093'/7, i 3C 10 bbls fi'es[ 25 bbls (1.20 0.32% R-I q cf/sk) 1.0 bbls ires[ With thc O] cement in I2 annulus. S drillpipe. 1' above plug. WOC 8 hm plug. If cer circulate dr 4 hours. 2. POH to 4,1 3. Spot a 250' with the cer cement as f'c 10 bbls fresl 2.4 bbls (1.1 10 bbls fi'et With the O'. cement in t arima{us. S drillpipe. above plug. W OC 8 ho~ plug. If ten circulate 4 hours. ARCO Warthog #1 Plug and Abandonment Procedure and spot a 280' cement plug From 6,950' to 7,230,~a.cross the i.r~terval T ,' as follows: ~"---"Y~---~ water spacer sx) Class G + 1% BA-10 + 0.65% FL-33 + t).3% CD-32 + 0.3% A-2 '~" 1 ghs FP-6L + 0.3% CD-32 added to the mix water. (15.8 ppg, 1.16 water spacer ,DP at 7,230', 'pump a balanced plug as specified above such that the te drillpipe is approximately 100' higher than thc cement level i'n the .owly POll 5 stands, allowing the cement to tall out the end of the erfonn one complete cir. culafion to clean out drillpipe and open hole Ensure the mud weight in the hole is at least 9.7 ppg. .rs, then PdH and tag cement plug. Set 15,000 lbs drillpipe weight on ent has not yet set m' will not take 15,000 lbs weight, pull back up a:nd Ipipe and hole clean. WOC, checking plttg's ability to take weight every 0' RICB. :e'ment plug from 3,870' to 4,120~ across the 9-5/8" casing shoe at 4~017' lent plug extending fix~m 150' above to 100~ below the shoe. Pump the liows: water spacer sx) Class G '[. 1% A-7 + 1 ghs FP-6L. (15.8 ppg, 1.15 effsk) water spacer !DP at 4,120', putnp a balanced plug as specified above such that the ~e drillpipe is approximately 100' higher than the cement level in the lowly POH 5 stands, allowing the cement to fall out the end of the 'erfom~ one complete circulation to clean out drillpipc and open hole .rs, then Rill and tag cement plug. Set 15,000 lbs drillpi.pe weight on ~ent has not yet set or will not take 15,{)00 lbs weight, pull back up and .lpipe and hole clean. WOC, checking plug's ability to take weight every SENT BY: 12- 1-07 : 10:05 : ~07 276 7542;# 3/ 4 , , , . , If plug top lhat high. POH to 350' Spot a 175' 10 bbls Ii'esl 13.5 bbls .(8( 10 bbls fres~ With the OE located below 3,917', another plug must be set to bring the top at least RKB. :ement surface plug fi:om 175' to 350'. Pump the cement as follows: wator spacer sx) Cold Set II +1 ghs FP-6L. ('14.95 ppg, 0.961 cr/sk) water spacer DP at 350', pump a !75' balauced plug as specified above such that the cement in tltc drillpipc is approximatcly 100' highcr than the cement level in the annulus. S.owly POH 2 stands, allowing the cement to i311 out the end of the drillpipe, l~erfmm one cmnplete circulation to clcari out drillpipe and open hole above plug. WOC 8 hotlrs, then RIH and tag cement plug. Set 15,000 lbs weight on plug. If cement has ~ot yet set or will not take 15,000 lbs weight, pull back up and circulate drillpipe an( hole clean. WOC, checking 'plug's ability to take wcight every 2 hours, If plug top s located below 300' RKB, another plug must be set to bring the top at least that hi h. POH and L/) BHA and. all but 6 joints of drillpipe. NTD BOP stack, spacer spools, double studt[ed adapter m~d 9-5/8" casing head.. .lips and packoff from 13~3/8" casing head. ~.¢~ 8" casing spear mqd set at 140' ltKB. t3ack out 9-5/8" casing at mudline ,rating 12 - 13 tums to the fight, This should require 2,500 - 4,500 R-lbs Pull 9-5/8" ~ RIH w/9~5/ hanger by r( of torque, lt.cmovc and lay out stub. L/D 9-5/8" spear. 9. N/D 13-3/8" 10. RIH w/ 13- nmdline hm 6,000 fl-lbs casing head. 3/8" casing spear and set at 140' RKB. Back out 13-3/8" casing at gcr by rotating 12 ~ 13 roms to the right. This should require 4,000 :)f torque. Remove and lay out stub. 11, RIH w/20" :asing cutter on drill, pipe and cut 20" casing at 150' RKB (23' BML). 12, Pull 20" casing stub and lay out, 13. Prepare rig ~or cold stack and shut down for remainder of winter, SENT BY: 12- 1-97 ; 10:0~ ; 907 276 7542;# 4/ 4 14, After rig has been removed from location, conduct a bottom survey over wellsite for final site clear.ce approval per MMS and AOGCC regs. Mobilize divers to clean tip any identified foreign objects lying on the seafloor, E & P S£RVIOES. /NC November 21, 1997 Mr. Jeff Walker Regional Supervisor, Field Operations U.S. Department of the Interior Minerals Management Service, 3rd Floor Alaska OCS Region 949 E 36th Avenue Anchorage, Alaska 99508-4302 Sundry Notices - _Subsequent l~epbrts o'f Setting Casing_ ARCO Warthog #1 Exploration Well Dear Mr. Walker, Per Reporting and Data Submission Requirement/48 of the ARCO Warthog #1 Permit to Drill, please find enclosed Sundry Notices concerning the running, cementing and testing of the 13-3/8" conductor casing and 9-5/8" surface casing in the Warthog #1 exploration well. Also included is information on the formation leak-off test mn at each casing shoe. Each Sundry Notice consists of an original, three copies and an original Public Infon'nation copy. If you have any questions or require additional information, please contact me at 258- 3446. Since~ Bill Penrose Project Manager enclosures C: Mr. Glenn Gray- ADGC Mr. David Johnston- AOGCC v/'' Mr. Paul Mazzolini - ARCO 715 L Street Anchorage, Alaska 99501 (907) 258-3446 FAX (907) 258-5557 MINERALS MANAGEMENT SERVIC" SUNDRY NOTICES AND REPORTS'" sub.~ odg~ ~ ,~e copk= ~ OMB No. 1l)104)O4S ~ .. dELL one copy marked "Public Infmma~.-- Expiration Date: September 30, 1999 .. FI. 2. APl WELL NUMBER/PRODUCING INTERVAL CODE 3. WELL NO. 11. OPERATOR NAME AND AI~DRESS ORIGINAL X , 55-171-00012-O0 T.~uq:~{)G (Submitting Office) CORRECTION NO. i ARCO ATA.qKA, [NC. ~B - P 0 BOX 100360 · FIELD NAME 9. UNIT NUMBER 10. MM$ OPERATOR NUMBER ANCHORAGEs AK 99510-0360 }fILl)CAT CAMDEN BAY UNIT WELL AT TOTAL DEPTH ,~. LEASE NUMBER 5. AREA NAME 6. BLOCK NUMBER 7. OPD NUMBER S~A_TE OF AT-A.c~A CAMD]~ BAY N/A N/A ADT. 37101~ ]U~UI~OI~ S]~JL I 132. TYPE OF 33. PROPOSED OR COMPLETED WORK 34. WELL STATUS/ SUBMI~I'AL TYPE CODE ACIDIZ~ FRACTURE PLU~ ~ WORKOV~R REQUEST ALTER CASII~ INITIAL C4:~P~Ot4 PUU. CASINO OTHER APPROVAL ARTIFICI~ LIFT MUL.~TX~ REG4:~d~ SI~ ~'~J~G KXI~ORA_T/Olql · SUBSEGUENT DEEPEN PERM ABAHOOf~aT ~ REPORT X WELL AT SU.FACE 12- WELL LOCATION AT SURFACE ($urv~ed} 13. LEASE NUMBER 14. AREA NAME i5. BLOCK NO. 16. ~)PO NUMBER 79°'"02~ 3/+" N OCS-¥-1663 CAI~EN RAY 144° 55~ 02" Il BEAIII~I~ SFJL 7067 NR06-O/+ , 3~. SURVEY BASE 18. WATER DEPTH 19. ELEVATION AT KB 20. RIG NAME. 21. RIG TYPE (Sun~/eo3 NAD 27 NAD 83 X 35.5 ~ 91.5 ' AS~ ~ ]g~A~R~ SEA I SIIIiMERS~I.~ i I ii I i 36. DESCRIBE PROPOSED OR COMPLETED OPERATIONS (Attach prognosis or summary of completed work, as appropriate) 13-3~8", 68~ ].-80~ ~ CASCO T~AS SA'J~ A~ ~013~ ]Q~B (HI) AND ~/D) ON 1_~/2~97. T~ ~IAS ~ ~68 BB~.S (~91 SZ) OF COil) SA"E TTT ~ $~.lJR]~ lzO~ BY 86 BB~S (502 SZ) OF. COU) GOOD ]~'BJE~$ ti-ERE MA~¥Y~NKD 33]]~DUGi~OU~ ~ ~O OPE:RA:I~ON T~r_1~i GOOD ~ CTRC[E~q"AI~ B&CK ~O .qlJ'RFAGE. ~ CASSIO gAS Stl~Si~~¥ ?RE$$URE-331:STED ~O 2~500 ?ST :FOR 30 MIt~J~$ AflD~ ~ DR[iJ~TNO OIY~ Tm~ lq~O/L~ AN EqtlT_¥ALRI~ HUD I~ETGI~ OF 18.0. ''~: PPG. i 26. CONTACT NAME 27. TELEPHONE NUMBER k-FIJ.IAM ~. PI~IROSE (BT~L) (907)258~3M+6 , ~ , , 28. AUTHORIZING OFFICIAL (Type Name) 29: TITLE K-u~ARIJK Di~J,]:NG Sb'P]D~N331:lqD:gt~ $0. ~uTNoRo'INO $ . ~. BAlE ,'. ... .-'; -;...,t._ ,, i c--7..( .- i ii THIS SPACE FOR MM$~I:I~,OJqLY APPROVED BY TITLE DATE 'PAPERWORK FI~-OuCTION ACT STATEMENT:' The Paperwork Reduction Act of 1995 (44 U.S.O. 3501 et seq,) requires Us to inform you lha! this information is being ColleCted lo obtain knowledge of equipment and procedures to .be used during .well- completion, workover, and production operations. This information Will be Used by MMS District Supervisors to evaluate and approve or disapprove the adequacy of the equipment and procedures to safely perform the proposed operations. Response to this request is mandalo~/(43 U.S.O. ~334). Proprietary data are covered under 80 OFR 250A8. An agency may not conduct or sponsor, and a person ts not required to respond to, a collection of information unless it displays a currently valid OMB Control No. Public reporting burden for this form Is estimated to average 1 hour per response, includino the time for reviewing instructions, gathering and maintaining data, and completing and reviewing the form. Direct comments regarding the burden estimate or any other aspect ct this form to the Information Collection Clearance Officer, Mail Stop 2053, Minerals Management Sen/ice, 38~ Elden Street, Hemdon, VA 20170-4817; and to the Office gl Management and Budget, Office of Information and Regulatory Affairs, Desk _Officer for the Department of the Interior,(OMB No. 10~0-0045), Washin~jtont DO ,~.0,S03.' ,, . FORM MMS-124 (September 1996) (Replaces all previous editions of Form MMS-124 which may not be used.) J .o. '' ' f t i ' J J ; ! 1~0 'd DOHI~It~M XI~=! 14el C;-I~: ~0 ....... j MINERALS MANAGEMENT SERVIC. sub~ odgi~ ~ u~me cop~ wic OMB No. 1010-0045 SUNDRY NOTICES AND REPORTS '~,~ IYELL ~e cx~py marked 'Public InformalJon.' Explral~on Dal~: September 30, 1999 t." ' ' 2. APl WELL NUMBER/PRODUCING INTERVAL coI~E 3. WELL NO. 11. OPERATOR NAME AND ADDRF'SS ORIGINAL ~ (Submitting Office) CORRECTION 55-171-00012-00 ' ~ .M~.CO A/.ASI~, ~_NC. B. FIELD NAME 9. UNIT NUMBER 10. MMS OPERATOR NUMBER ? 0 BOX 100360 ~Tr;~CA~ CAHDEN ~Y UNIT AN(ZORAC~, ~ 99510-0360 i I WELL AT TOTAL DEPTH 4. LEASE NUMBER 5. AREA NAME B. ~LOCK NUMBER 7. OPD NUMBER STiTE OF AY~.~I~ CIHDE~ P~Y N/A' ADL 271014 BEAUFO~ SEA 3Z TYPE OF 33. PROPOSED OR COMPLETED WORK 34. WELL STATUS/ SUBMITTAL TYPE CODE REQUEST ALTER CAS~G ~ CO%~tE~ON PULL CAS~G OTHER APPROVAL ARTiFK::IAL UFT MUL~TION RECONI:~tON S]~ CAS/NC WELL AT SURFACE I il 12. WELl LOCATION AT SURFACE (Sulveyed) 13. LEASE NUMBER 14. AREA NAME 15. BLOCK NO. 16. ~PD NUMBER 700 021 ~"l'll [ 0CS-¥-1663 Ck_-H~[N ~A¥ 1¥~.° 55' 02" N ]g~~ S]~ 7067 NR.06'O/+ ~ , ~ , 3s. SURVEY BASE ~S. WATER DEPTH ~9. ELEVATION AT K~ 20. RIe NAME. 21. R~e TYPE (Su~ (Sun~yed) NAD ~ NAD 83..~ GLOI4AR BEAUPOR~ SEA I 35;15~ 91.S ASL I I I I 36. DESCRIBE PROPOSED OR COMPLETED OPERATIONS (Attach i~ognosis or summao/of completed wink. as ap~e) 9-S/8"~ ~0~ L-80~ B~C casing was set at ~+,0171 PJ~, t~) (3,665~ ~D) on 11/~/97. It was cemented In place in two stages. 3~he £~rst sta§e contained 126 bbls (367 sx) o£ Gold Set III lead slurz7 followed by 65 bbls (317 sx) of Class G ta~l sI~rjr. Good returns ~ere maintained throughout ~h~s sta[{e.. At the completion of p~mp~n~ ~he 1st sta§e~ the s~a§e ~oo! at 2~Oll~ ]~K~Bz t4l) was opened and the hole above that point circulated in p~eparat[on for the 2nd sta§e. Cement returns were seen at the surface [nd~cat[n§ the 1st s..tage cement had reached the sta§e tool The SeCond sta§e'was .pm~ped containing; 226 bbls (660 sx) of "Cold Set III. Good retttrns were maintained th~oughout~ th£s stage ~ri_th §ood cement c£rnclated back to s~r£ace ~ont[nued on attached sheet. I I I I 26. CONTACT NAME 27. TELEPHONE NUMBER I/ILLIN4 3. PRNROSE (BILL) 907-258-3M+6 28. AUTHORIZING OFFICIAL (Type Name) 29: TITLE KUPARUK DRILLING $~EI~ i / i. ~ i ,, I I APPROVED BY TITLE DATE ' "PAPERWORK REDUCTION ACT STAteMENT: The Paperwork Reduction Act of 1995 (44 U.S.C. 3501 et seq.) requires Us to inform you that this information .is being Collected to obtain knowledge of equipment and procedures to .be used during Well- completion, workover, and production operations. This information Will be used by MMS District Supervisors to evaluate and approve or disapprove the adequacy of the equipment and procedures to safely perform the proposed operations. Response to this request is mandatory (43 U.S.C. 1334). Proprietary data are covered under 30 CFR 250.18. An agency may not conduct or. sponsor, and a person is not required to respond to, a collection of information unless it displays a currently valid OMB Control No. Public reporting burden for this form is estimated to average 1 hour per response, including the time for reviewing instructions, gathering and maintaining data, add completing and reviewing the form. Direct comments regarding the burden estimate or any other aspect of this form to the Information Collection Clearance Officer, Mail Stop 2053, Minerals Management Service, 381 Elden Street, Herndon, VA 20170-4817; and to the Office of Management and Budget, Office of Information and Regulatory Affairs, Desk _Officer for the Department of the Interior (OMB No. 1010-00451, Washin~lton~, DC ,2.,0,503., . FORM MMS-124 (September 1996) (Rel~iaces all previOus editions of Form MMS-124 which may not be used.) PAGE TNO 36. DESCP, XBE PROPOSRD OR COMPLETHD OPERA_T'iONS (continued) The casing was subsequently pressure-tested to ~,000 psi for 30 minutes and, after drillin~ out the float equipment and 10' of new hole, a leak-off test was conducted. The formation at the shoe leake~ off at an equivalent mud weight of 1_l.3 ppg. i i · o .i ,3'0 TONY KNOWLE$, GOVEF~NOFt ALASI~& OIL AND GAS CONSERVATION COMMISSION 3001 PORCUPINE DRIVE ANCHORAGE, ALASKA 99501-3192 PHONE: (907) 279-1433 FAX: (907) 276-7542 November 25, 1997 Mr. Mark Major Exploration Permits Director ARCO Alaska, Inc. P.O. Box 100360 Anchorage, AK 99510-0360 Re: Request for Approval - Well Testing Operations Warthog # 1 well Dear Mr. Major: Thank you for your letter dated October 31, 1997 in which you describe potential well testing operations for the Warthog # 1 well. Arco Alaska, Inc. (AAI) staff also met with Commission members on November 14, 1997 to further explain your plans in the event that significant producible hydrocarbons are found. AAI requests approval to inject up to 50,000 bbls of seawater for reservoir limit testing on this well. The Commission views this activity as part of well testing operations and, therefore, not a regulated underground injection control activity. The Commission requests that AAI file an Application for Sundry Well Approvals (form 10-403) prior to injecting the seawater. Any additional questions regarding the injection activity may be directed to Mr. Blair Wondzell of our office. · Chairman E ~ P SERVICES,/NC November 24, 1997 Mr. Jeff Walker Regional Supervisor, Field Operations U.S. Department of the Interior Minerals Management Service, 3rd Floor Alaska OCS Region 949 E 36th Avenue Anchorage, Alaska 99508-4302 Well Control Drill Plan ARCO Warthog #1 Exploration Well ~OMM LRES ENG NRO GEOL. STAT _ FILE Dear Mr. Walker, Per Reporting and Data Submission Requirement #3 of the ARCO Warthog #1 Permit to Drill, this addresses the well control drill plan for the well. The procedures to be followed by the rig crews in the event of a kick are contained in the "Emergency Procedures - Kick" portion of the Critical Operations Manual for the Gomar Beaufort Sea I of which the MMS has a copy. The Procedures detail the actions to be taken and individual crew members' responsibilities should a kick occur 1) while drilling, 2) while tripping, and 3) when out of the hole. It is Fairweather's and Global Marine's policy to hold well control drills at least once per week. The drills are noted on the daily IADC operations report on the rig. To date during this project, well control drills have been conducted on November 8, 14, 16, 17, 18 and 19. Another is planned for today, November 24. The procedures to be followed in the event of a kick are posted on the drill floor and are reviewed with the crew members periodically. If you have questions or require additional information, please contact me at 258-3446. Project Manager C: Mr. Glenn Gray- ADGC Mr. David Johnston - AOGCC v/ Mr. Paul Mazzolini - ARCO NOV 25 Alaska 011 & Gas Cons, Commission Anchorage 715 L Street Anchorage, Alaska 99501 (907) 258-3446 FAX (907) 258-5557 RID B J, djvertar, divartar [in,as. ~ line. Cut 20" and 1.3-3/B" ca'~l~l~ and Inst.Aq hi/L/I~OP ~lac~ .~i._~x up n~ I~ymer mud Post-It'~ Fax Note 7671 ICr~./DepL Phone ~ .. FO~ ~ Phone FBx ~ BIT, t t I I 1 ....._. -'.".', [ I .,. :.::: ..' ~ ~:, ..... · , I L~c~ 1 ~,- 1~,',~1~ I .~ ...... i .... i I ,-[- ~,~'--,----~-: ..... ........ :Ti~::I'.::Z::T-T-::i:::,'. ~Z":':"[-I:::T"- .... · ........... ~ ~_ ~..-- 07'~0~ ~'3~RID m~d PID dlva~e[~ rou~ cut 13,~B" csaing ~ ~' s~d~g head. Make ~ ~l ~UI, make 1~8" finnl ~ut, ata~ '1~-8/8" csg h~ a~ DSA. L~k and le~t to 2.0~ psi ,.. m~d b~lt~ ~eubl~U tame, ~.. Irs~all m~ cr~s, lop deu~)~.U r~ ~nd H~HI. ....... _ ..-. 11,984 s8¢~8 of ha'ire on ~a~u, 6~::~P)~.o_.~::!_?:~_.. ~.j:xAkilliwt mud. ~PENDA~LE SUPPLIES ON BOAI{~ '~'~"~'~" 1''°~"''~ l~ ....... 1~:~ I""' / ~d / Bit Navld~ill M~ch 1C 3hort NM DO DPrt - MWD _. _...- __ St~tr~,S___T_~ ~. NM x0 W~'I~.iHI I~ ~ld P~¥,TOT,~g TORQU~ I~AI[~ LA6t UOP IbBI 1114/97 HE.I 'URTFD ~Y BI[I { FN~TH 1.4 277 59.8 17 Rag 3'~ 4 FAIRWEATHI!IR E&P MORNINQ DRILLING REPORT - OFFaHORE ..... ARCO WBHh~ l~C~den ~ Unit J Rigging ~ dl~e~ ~em _ _ J N~____ j t;~' MO o,~ TVD BIT, WEIGHT, SPEED, AND HYDRAULICS - ':"d '- J '-' ...... ~ ~ ................. ......... ................ MUD PROPERTIED.~I E~ AUHkg 6~U u~GTG ?_____s!~__d- mud.and CRm._an_t circulated up dl~,g cement job and displacement was d,,is_g, he, r~ed owa'ooard. L , .!-!M.--I:- ............................... QPP..hJA IIr. JN~ IN Sb'QUENUI::: (rJBU'l) I0 OBf,,~,,) ~OTI"O,M H~LI~ A~tEMBi,,Y - "--4"1"~'-'~ ~ ~ "~4~ ~e*'~"~-.~.':-~: ~--': --~ ' -':-- '_ .... ~ ..... ' ...... ' !06:O0j{)7:30Contlnu~ to AlU I'o run e~ini~. [ X ] ~oci. l^N,Dr' I c~ec~ ~hoe and no.t- OK. W~ld ~r~t 3~.~e__~.!__.~__...r..~.~t !I ~s. s~U.~ ~'.u..~n~ ~u,,~ior, ~cs~ .,.~.~, ,~oT .__~ ___ J~ufllll~e ha~g~f., _W~eld ,'remaining 4its above hanger. Ta[Lu~o ora htndiru:j rir~j wi l-m.n_~er ~ ............ TE~.m.~_L.._.D_~C.~IT'TIL'U',~LEN~I'H 156' RK~ W/10K [bA,..P/~ J.~_ a.nd hang off casing in slips .............. ~Bfl ..,,,_ 1 40 __ 1ZoO~ 14'f}O C&C, hole. E/U BJ for cementing.. ........... Navidrill Mach I _~. ................ . '14. O0 14.3DHold e- baafe! meetm. PreeJurate~lli,~ealo3~m?,.~_l_l_lu,~an~d.~mp NM~/~Ir~L~TIii ..____:.~.~ 26 tthl.~ h'H~h w~ler space[. Found mix w-diet being d~llver,,d ~ BJ Ul~,~. bU~y I.~Ull[~!¥~l]~ .... _ MVVD 42.1~ .---- _ ................. ~ with drilling ff~ult Sbing S I ti 4..4 ............. .~_..._._ ........ :.:.._..._.._ . .......... .~ :~: .... ~ ...... 14:~,U 1U:0U C.&C ~oJe._w(~_U.d U~I_~_g_;.~=UJ).~__S.~!~!,e ~01'~l~l OUt. Water sUj~pi'y probl[m to BJ unit, __. 2 NM DC 59.8 I~;:~ ~e:{]L~ Pump 4~ ~< (;:Sill folloW~d.~.y.,Sg2 ~( C011, lhetl ~0 bb!.S._w~...l.e!'~Displaced w~h mud ~_ric~ ............ ~[[l,.n.~. G~T_.0.,_,__. 4 g ... ~_ , _ pumps. Goad returns lhrough~t j,'~,R~eg{',,~,ild ~j~rff back to sudae~, rtUmpL,,d pk~g .o.~. _=,~,,.~ ........... schedule wJ 10~30_@..~!=_Ch.,,~¢,~k._[l~,: ,O_K.: ,Sac~ oLat__~d_llne ha:_.~ger thread~_ to e~o~e. Washz.. ............... _3_? L; .... 89.5 out porl.s.. U~ rj~l_P.u_mpi~ to welllh ~ cement from !.~._:~.." X 20" armutus .w/.?..ea',~ter, U~e Jars 3~ 4 Run ha~.~ler ¢l~.d~.~_b~k in .................. 1~:00 C.~:OO ElD ~lJ. N/D ctlvener flne~, Olvarter valce$ hydra~lic lines, Remove ever:/ather ~'~ ,~ _ .~ ..... : :: ~.~ ~ ............. ERPENDABLE SUPPLIES ON BOARD ~r~rv. TOTAL ~Qf~.j ~l~J wt IL}ULI~. ~(L~'Ifl u:~uairl~l L,'Yrd;f]OW, ~ CdM TOYAL ....1.,4. deg I 31]' k~& l'.~J E J N/A . .O'vc, 0 .'~M ._ _.~1__.~'I18_.[.r !PI~'~.._.9?- ....... BILl- lu/,.-NNO~l. 5LJI~L I HIU G, I X~Ct_.4 3clt,l BIT, WEIqDHT, SPEED,/hIND HYDRAULIC~ ~ud DIRFCTIONAL ~IURVEYS I I)liql-{.~ TIME OPERATIONS IN SEOU ENCF,, (0~0 tO BHA w/DOs and jars. Orill 17.1/?' h,,h~ I'mn! 31D to g4¢'. Max tri? ~r, 75 unils, ba_ck~lround Oas ! §- 25 un~. on swivel. Drill 17-1/2" hel~ btm - na fill. run t~ ..... =:._..~_O_...TTOM HOLe A~sI:MItL¥ [ I NF.W ~4..5 ROt'. ~tF,[S CIN,:I= IHDPE~C Bi[ Navid~ill Mlach 1 NM S_trin~ ST.B MWD 2 UM DP. ...... b-lring STB .... LENGTH '368 $.6 42:,9.._ . 4,4 , ,. 1,7 TOTAL I.cNgTI }, _ ........ ._. VVEI;DH/~l'l MUD APPRDVFF) AF~.. A~C)U~(" :.=.:_ :.. PI~Y IltAII ¥ li)ll~l CIJM Y(')TAI 31 4 glfl 11 BILL Pt- NHOS,~ ,.leu ~e:Sp~ m_eating. Vl~,de up driltin~ BHA ,an, d s,~o,uclded Well. Drilled 17412," hul~ ifil ~ .... .... ........... .... .... .... L ,.. , _,.,..i__. [ OPERATIOHS IN SEQUENCE [0~"~ to o~OJ, BOTTOM HOLE ASSEMBLY ~D ~ DP, M~e kdl-~ mud to m~e~e and ~d a~t~nal 1 [.11').." dllilin Tl'ouble-.~h~ot al~d r, ol~ ~blgmS w/gCR ~1. bosom at l~;f' ~ ~, HO~..~J~E~[I~.~g ~w~ to en~u~ ,~it ~n~.~/~t ~b ir~ ~avldr ill Math 1 ~.8 L~" NM Shin 5.6 SPUD WELL AT 02~ HRS, ~ I/I~T. Drift 1T-I~" Iiulu IFg~ 1~' [~ ~l~l~. I~DP ~D 42.0 i Insteed of last 3 DCs and ]ar~. Gas 2'1 u~lt~, I tW 12P lmm drill e[rlr~i and replace w/8" D Cs and ...... Jar~ .... t~ co _m~l_ _.cie BHA., 1UCJL DEI~CRIFTION I.~.'NG I' H 4.4 2 NM DO t 7 .11.4 Dlverier 10130/97 roi ~L,. LEINUTH F PRCV ~OTAL / ~.~' ~nk ........ -'t' .......... / ;UM ~TA~ 1 .. E & P SERV/$ES./NC. November 3, 1997 Mr. David Jobmston, Chairman Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 Attention: Mr. Blair Wondzell, Senior Petroleum Engineer ARCO Alaska, Inc., Warthog No. 1 (PTD 97-85, &PI No. 55-171-00012) BOP Stack Test Pressure Dear Mr. Wondzell: This letter will confirm our telephone conversation earlier today regarding the above-referenced matter. The Permit to Drill for the Warthog No. I well states that the 13-5/8", 10,000 psi WP BOP stack will initially be tested to 75% of the rated working pressure (7,500 psi). Tiffs is not an appropriate test pressure, since the 13-5/8" starting head on this well is only rated to 5,000 psi. The BOP test tool seats below the 5,000 psi rated ring gasket. In. our conversation this morning we agreed that the initial BOP test pressure would be lowered to 5,000 psi for the reason set forth above. Thank you for your help in this matter. (for ARCO Alaska, Inc.) cc: Mike Zanghi-AAl Paul Mazz,-.!i,ni.- AA.~ C:VXfl{CO\WARTT[:I(.)G \13 op sta ck. doc 11/03/97 715 L Street Anchorage, Alaska 99501 (907) 258-3446 FAX (907) 258-5557 TONY KNOWLES, GOVERNOR ALASKA OIL AND GAS CONSERVATION COMMISSION October 31. 1997 3001 PORCUPINE DRIVE ANCHORAGE, ALASKA 99501-3192 PHONE: (907) 279-1433 FAX: (907) 276-7542 Michael Zanghi Kuparuk Drlg. Superintendent ARCO Alaska, Inc. ? O Box 100360 Anchorage, AK 99510-0360 Re: Warthog No. 1 .ARCO Alaska Inc. Permit No: 97-85 Sur. Loc. LAT: 70° 02' 34"; LONG: 144° 55' 02" Btmhole Loc. 3287'FNL: 1407'FEL, Sec. 20, T8N, R29E, UM Dear Mr. Zanghi: 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. A weekly status report is required from the time the well is spudded until it is suspended or plugged and abandoned. The report should be a generalized synopsis of the week's activities and is exclusively for the Commission's internal use. 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 given by contacting the Commission petroleum field inspector on the North Slope pager at 659-3607. Sincerely, jr~ginal Signed 8y ,:'lavid W .... Johnston David W. Johnston Chairman BY ORDER OF THE COMMISSION dlf/Enclosures cc: Department of Fish & Game, Habitat Section w/o encl. Department of Environmental Conservation w/o encl. E ~ P SERI//CES, /NC.. October 29, 1997 Mr. Jeff Walker Regional Supervisor, Field Operations U.S. Department of the Interior Minerals Management Service, 3rd Floor Alaska OCS Region 949 E 36th Avenue Anchorage, Alaska 99508- RE: Application for Permit to Drill ARCO Warthog #1 Exploration Well :. v/Mr. David Johnston ~' '.. ..' Chairman ' '?" ' AK Oil & Gas Conservation 3001 Porcupine Drive ~L ........................ Anchorage, Alaska 99501-003(T Dear Mr. Walker, Attached per the request of Mr. Kyle Monkelein of the MMS please find the fol. lowing: - Modified Page 5 of the Welding and Burning Safe Practices Plan - Certificate of Inspection (COI) issued by the U.S. Coast Guard - 2 copies of the Application for Permit to Drill signed by ARCO's Drilling Superintendent Mike Zanghi The Welding and Burning Safe Practices Plan has been modified to indicate the Fire Watch will remain to monitor the work site for 30 minutes after the hot work is complete. The Coast Guard COl is an amended Temporary COl and is valid for one year. The Coast Guard is in the process of issuing the final COI which, will be forwarded to your agency as soon as we receive it. The APD contains all of the modifications made to date resulting from discussions and agreements with the MMS and AOGCC. If you have any questions or require additional information, please don't hesitate to call me at any time Sincerely, B i Project Manager enclosures 715 / Street Anchorage, Alaska 99501 (907) 258-3446 FAX (907) 258-5557 Mr. Walker/Mr. Johnston 10/29/97 Page 2 Mr. Glenn Gray - ADGC Mr. Mark Major- ARCO Mr. Paul Mazzolini - ARCO (all w/enclosures) E & P SE'FIV/CES,/A/C. October 28, 19'97 Mr. Jeff Walker Regional Supervisor, Field Operations U.S. Department of the Interior Minerals Management Service, 3rd Floor Alaska OCS Region 949 E 36th Avenue Anchorage, Alaska 99508-4302 r. David Johnston i-- Chairman i ....... AK Oil & Gas Conservation CoiS~m. 3001 Porcupine Drive } ......................... ~ Anchorage, Alaska 99501-003CL. .....................~: Application for Permit to Drill ARCO Warthog gl Exploration Well Dear Sirs, This is to address recent questions and comments received from the AOGCC and MMS during the ongoing review of the Application for Permit to Drill the Warthog gl well. Specifically, the AOGCC submitted a list of questions and comments on October 24, 1997 and the MMS had earlier verbally asked about plans to use the ice load monitoring panel.s originally installed on the CIDS and referenced in the Critical Operations Manual. Responses to the questions and comments are as follow: AOGCC Comment #1' Drilling fluids and cuttings will be discharged overboard to the sea ice in conformance with. the EPA Beaufort Sea General NPDES Permit. AOGCC Comment #2: Following meetings with AOGCC and MMS representatives, an APD revision was issued on October 23, 1997 in which the potential gas and faulting down to 4,000' were addressed. These were also addressed in a revision to the Shallow Hazards Report. AOGCC Comment #3.1' The diverter schematic originally submitted with the APD is incorrect. There are no manual valves on the diverter lines. A corrected schematic is submitted herewith. AOGCC Comment #3.2: The diverter hydraulic system is set up so that, when the diverter closes, both of the hydraulic valves automatically open. While, after diverter shut-in, the valves can be operated to direct the flow to one diverter line or the other, the di~f"a..1/~ ~.,,il~';.i:.are coupled so it is not possible to shut in the well. 715 L Street Anchorage, Alaska 99501 (907) 258-3446 FAX (907) 258-5557 Mr. Walker/Mr. Johnston 10/28/97 Page 2 AOGCC Comment #4: We agree that, to simplify BOP testing after the initial test, it will always be tested to 200/5000 psi. AOGCC Comment #5' We agree the diverter should not be pressure tested with the 20" casing shoe this shallow. It will be function tested with water. AOGCC Comment #6' Visually checking the position of the diverter line valves when the diverter is open is not intended as a complete check of the valve/diverter hydraulic coupling. It is intended simply to take advantage of the opportunity to visually verify one aspect of the operation when it is possible. AOGCC Comment #7: The statement in the BOP Test Procedure is in error. tested to the low pressure first, then the high pressure. The BOPE will always be .AOGCC Comment #8: A leak-off test will be performed below the 13-3/8" conductor after drilling no more than 10' of new hole below the conductor shoe. MMS ©uestion re Ice Monitoring Panels: When the CIDS was built, strain gauge panels were installed on the sides to measure lateral ice forces. While the CIDS' Critical Operations Procedures manual still contains reference to these ice panels, they have been judged insUfficiently accurate and unreliable to be useful as indicators of real global ice forces acting on the unit. They will therefore not be used for environmental monitoring during the Warthog well. The unit's response, if any, to ice loading will be monitored as discussed under Rig Environmental Response Monitoring in the Application for Permit to Drill. If you have any questions or require additional information, please call me at any time at 258-3446. Sincerely) William J. Penrose Project Manager enclosure Mr. Walker/Mr. Johnston 10/28/97 Page 3 c: Glenn Gray - ADGC Mark Major- ARCO Paul Mazzolini - ARCO E & P SE/CV/$ES, //VC. October 23, 1997 Mr. Jeff Walker Regional Supervisor, Field Operations U.S. Department of the Interior Minerals Management Service, 3rd Floor Alaska OCS Region 949 E 36th Avenue Anchorage, Alaska 99508-4302 Chairman ~ AK Oil & Gas Conservation Comm.;, ............. 3001 Porcupine Drive Anchorage, Alaska 99501-0030 Application for Permit to Drill ARCO Warthog #1 Exploration Well Dear Sirs, Attached find three copies of the modified Pore Pressures and Mud Weights section of the Application for Permit to Drill submitted to you earlier. This section has been modified to address potential shallow hazards identified during the shallow hazards analysis for this location. It also addresses precautions to be taken in the event shallow gas or lost circulation are encountered. The MMS and AOGCC are requested to keep confidential all information included here as it is drawn from research and data proprietary to ARCO Alaska, Inc. If you have any questions or require additional information, please call me at any time at 258-3446. Sincerel. y,~._._.~ William J. Penrose Project Manager enclosures c: Glenn Gray - ADGC Mark Major - ARCO Paul Mazzolini - ARCO 715 L Street Anchorage, Alaska 99501 (907) 258-3446 FAX (907) 258-5557 E & P SERI//$ES,//VC. October 22, 1997 Mr. Jeff Walker Regional Supervisor, Field Operations U.S. Department of the Interior Minerals Management Service, 3rd Floor Alaska OCS Region 949 E 36th Avenue Anchorage, Alaska 99508-4302 //Mr. David Jolmston Chairman AK Oil & Gas Conservation Comm. 3001 Porcupine Drive Anchorage, Alaska 99501-0030 Application for Permit to Drill ARCO Warthog #1 Exploration Well Dear Sirs, Attached find modifications to parts of the Applications for Permit to Drill (APDs) originally submitted to your offices on May 30, 1997 and modified on October 8, 1997. These modifications are in response to comments made by the MMS and AOGCC since October 8. Please replace the appropriate parts of the previously-submitted APD with the following modified portions: Summary Well Plan Anticipated Surface Pressure Calculations The Summary Well Plan has been modified to show the BOP stack installed on the 13- 3/8" conductor casing (instead of the diverter) and a leak-off test performed at the 13-3/8" casing shoe. The Anticipated Surface Pressure calculations have been corrected to show the use of true vertical depth (instead of measured depth) in calculating the pore pressure at the 9-5/8" shoe and the anticipated surface pressure at TD. The MMS and AOGCC are requested to keep confidential all information included in the Application for Permit to Drill (except the Public Information Copy) as information in these documents is drawn from research and data proprietary to ARCO Alaska, Inc. If you have any questions or require additional information, please call me at any time at 258-3446. Sincerely, .... ~ ,//"'~ Project Manager 715 / Street Anchorage, Alaska 99501 (907) 258-:3446 FAX (907) 258-5557 Mr. Walker/Mr. Johnston 10/22/97 Page 2 enclosures c: Glenn Gray - ADGC Mark Major- ARCO Paul Mazzolini - ARCO E & P SERVICES,/NC October 22, 1997 Mr. Jeff Walker Regional Supervisor, Field Operations U.S. Department of the Interior Minerals Management Service, 3rd Floor Alaska OCS Region 949 E 36th Avenue Anchorage, Alaska 99508-4302 Welding and Buming Safe Practices Plan ARCO Warthog # 1 Exploration Well Dear Mr. Walker, Attached find the Welding and Burning Safe Practices Plan required as a part of the Application for Permit to Drill the ARCO Warthog #1 exploration well. If you have any questions or require additional information, please don't hesitate to call me at any time Bill Penrose Project Manager enclosure C~ Mr. Glenn Gray- ADGC Mr. David Johnston - AOGCC Mr. Mark Major- ARCO Mr. Paul Mazzolini - ARCO (all w/enclosure) 715 L Street Anchorage, Alaska 99501 (907) 258-3446 FAX (907) 258-5557 ARCO WARTHOG #1 Io WELDING AND BURNING SAFE PRACTICES PROCEDURES PLAN Purpose The primary purpose of this welding plan is to establish the operational procedures and safe practices to be used by ARCO Alaska, Inc. (ARCO) during welding and burning operations performed on ARCO operated structures in the Beaufort Sea, in this case, the Glomar Beaufort Sea I. Prior to the initiation of hot tapping operations on this structure, this Welding Plan will be amended and submitted to the District Office, Minerals Management Service, Anchorage, Alaska, for review. The operational procedures presented in the Welding Plan are not meant to replace prudent judgment, but should be used in conjunction with well thought out decisions. However, as in all situations, the safety practices outlined in the Welding Plan should be the minimum standard care which will be performed with additional precautions taken where prudent judgment dictates. The operational guidelines contained in the Welding Plan are meant to establish: 1. safe welding and burning practices; 2. the quality of personnel performing work involving welding or buming operations; and 3. a line of authority representing ARCO at the work site involving welding or burning operations. II. PERSONNEL QUALIFICATION PROCEDURES A. Welders 1. Definition: A welder is defined as any person performing work which involves arc or acetylene cutting and arc or acetylene welding. 2. Qualifying Procedure: Every welding contractor will qualify each welder in the 6G (45° fixed pipe) position on both 6-inch nominal and 2-inch nominal Schedule 80 pipe for the Shielded Metal Arc Welding Process. The test will be done prior to that welder commencing welding or burning operations on ARCO operated sites. Test pipes will be of a material specified in the ASTM P- 1 material group. Qualifications of the welder will depend on the results of one guided face bend test and one guided root bend test as per the ASME Boiler an. ?ressure Vessel Code, Section IX, m.. one additional nickbreak test as per APl Specification 1104. Welding on exotic materials; i.e., materials classified in other than the ASTM P-1 material group, on pipe with wall thicknesses above 0.864 inch, or by any process other than the Shielded Metal Arc Welding Process will require additional qualifications of the welder on the specific material and wall thickness, or in the specific process that the welder will be required to use. In addition, the welder will be required to be thoroughly familiar with this Welding Plan. Results of all welder qualification tests will be recorded by the vendor and be retained in their files for future reference. 3. Requalifying Procedure: a. b. Requalification of each welder is required when a welder has not used a specific welding process for six (6) months or while in service or employment to ARCO. Requalification of each welder may also be required when there is a specific reason to question the welder's ability to make welds that meet the specifications. Requalification for a specific welding process may be accomplished in the following manner: Qualify under the original qualifying procedure. X-ray analysis of one new test joint with all of the essential variables used on any one of the welder's previous qualification test joints. When requalifying by using the X-ray analysis technique, the X-ray of a new test joint must be sent to the contractor with verification by ARCO's Welding Supervisor that the weld was made with all of the essential variables. 4. Qualification Records: Results of all qualification and requalification tests for each welder in service to ARCO will be kept on file by the vendor. The original copy of the form will be kept by the contractor. One copy will be retained on file in the general location of the actual welding site during the welder's employment at that general location. General location for offshore operations is defined as the main living quarters structure of the area in which the welder is performing welding or burning operations. 5. Retest Procedure: Each welder will be allowed one retest on any specific process during any six (6) month period. B. Person-in-Charge 1. Definition: The person-in-charge is defined as the ARCO employee, or designated representative, who is responsible for operations at the job site where the welding or burning operations will be performed. 2. Qualifications: The person-in-charge will be thoroughly familiar with the Welding Plan. C. Fire Watch Personnel 1. Definition: One or more persons designated by the person-in-charge to stand Fire Watch while actual burning or welding operations are being accomplished in undesignated welding and burning areas. 2. Qualifications: The Fire Watch person will be familiar with the operation of all fire fighting equipment at his possession while standing watch during actual burning or welding operations. The Fire Watch person will be familiar with his duties as outlined in the Welding Plan. 3. Duties: The principal duty of the Fire Watch person is to stand fire watch during actual burning or welding operations in undesignated welding areas. The Fire Watch person will have in his physical possession the fire fighting equipment assigned by the person-in-charge and will be capable of operating that equipment. The Fire Watch person will check the fire fighting equipment to insure that it is in operable condition prior to beginning the welding or burning operations. III. DESIGNATED SA~ ,-WELDING AREAS A. Definition: Safe-welding areas will be those locations described as unclassified by the APl RP 5GOB, Classification of Areas for Electrical Installation at Drilling Rigs and Production Facilities on Land and on Marine Fixed and Mobile Platforms, 1973, and which meet the requirements of the National Fire Protection Association Bulletin No.51 B, Cutting and Welding Processes, 1976, as a safe-welding or burning area. A drawing outlining the designated safe-welding area is provided. B.Welding Safety Standards in Designated Safe-Welding Areas 1. The welder and person-in-charge will inspect the safe-welding area and determine that the area does conform to the requirements as defined. 2. The Welder will inspect his welding and burning equipment as per the Equipment Safety Checklist. 3. A fire watch is not necessary in designated safe-welding areas. However, fire extinguishers will be present for personnel protection and emergencies. IV. UNDESIGNATED WELDING AREAS. A. Definition: An undesignated welding area is defined as any other than those defined as safe-welding areas. B. Welding Safety Standards in Undesignated.Welding Areas 1. There will be a person-in-charge present at all times on the structure. 2. Prior to commencement of any welding or burning operations, the person- in-charge will personally insure that the following tasks are accomplished. a, Check the qualifications of all personnel who will be performing welding or burning operations to insure that ARCO's qualification requirements are met. b, In conjunction with the welder or welders, check all work areas in which burning or cutting operations are to be performed for potential. fire and explosion hazards and insure that these hazards are minimized or eliminated so that safe operations can be performed. ge . o c. Check all welding fipment as per ARCO's Equipment ffety Checklist. d, Designate one or more persons as necessary as a Fire Watch. Inform the Fire Watch personnel of their duties and insure that the Fire Watch personnel are capable of operating the fire fighting equipment to which they are assigned. Check the fire fighting equipment that are assigned to the Fire Watch personnel for proper operation. If welding is to be performed in an area which is not equipped with a gas detector, the Fire Watch personnel will maintain a continuous surveillance with a portable gas detector during welding. eo Check all containers, tanks, or other vessels which have contained a flammable substance to insure that the contents of the vessels have been rendered inert and are determined to be safe for welding or burning operations. Insure that all drilling, workover or wireline operations have ceased unless the wells which are being serviced contain noncombustible fluids and that entry of formation hydrocarbons into the wellbore is precluded by a positive overbalance toward that formation. ge Complete the ARCO form Welding or Burning in Undesionated Areas Safety Checklist. The form must be signed by the person-in-charge. Once completed, this form constitutes written authorization for work to proceed. The person-in-charge will monitor welding and burning operations while work is being done to insure that safe conditions continue to exist as described in the ARCO form Welding and Burning in Undesignated Areas Safety Checklist. If circumstances or conditions change and unsafe conditions occur, the person- in-charge must correct those unsafe conditions and again complete ARCO's form Welding and Burning in Undesignated Areas Safety Checklist to provide written authorization for welding or burning operations to recommence. The Fire Watch will remain at the site of welding or burning for at least 30 minutes after the termination of the work to insure no latent sparks or smoldering materials exist and all materials have cooled sufficiently so'as not to provide a source of ignition. Any pause in welding or burning operations of more than twelve (12) hours shall negate the previous written authorization and require items IV. B.2. and B.3. to be completed prior to recommencing welding or burning operations. V. DISTRIBUTION OF- _tE WELDING PLAN A, General Location The Welding Plan will be maintained with all approved revisions in the general location of the actual designated safe-welding site as previously defined. B. Contractors Each contractor, prior to doing work involving welding or burning operations under ARCO supervision or on the company-.operated structures will be furnished a copy of the Welding Plan with all approved revisions. ri ARCO Alaska. Inc. ARCO Alaska, Inc. will maintain a copy of the Welding Plan, with all approved revisions, at ARCO Alaska, Inc. headquarters in Anchorage, Alaska. D. Minerals Management Service A copy of the Welding Plan, with all approved revisions, will be furnished to the district office of the Minerals Management Service, Anchorage, Alaska. VI. AMENDMENT PROCEDURE A. Approval Amendments to the Welding Plan must be approved by the ARCO Alaska, Inc. Drilling Superintendent and by the Minerals Management Service District Supervisor prior to becoming part of the Welding Plan. B. Distribution Any approved amendment to the Welding Plan will be distributed under Section V of this plan. WELDER OR WEL _NG OPERATOR QUALIFICATION TE~_ RECORD ARCO ALASKA, INC., EXPLORATION DRILLING WELDER NAME I.D. NO. STAMP NO. WELDING PROCESS TYPE IN ACCORDANCE WITh WELDING PROCEDURE SPECIFICATION WPS MATERIAL SPEC. TO OF P NO. TO P NO. THICKNESS TESTED DIA. TESTED OUALIFIED THICKNESS RANGE DIA. RANGE FILLER METAL SPEC. NO. CLASS NO. F NO. POSITION PROGRES SION BACKING GAS TYPE & % COMPOSITION ELECTRICAL CHARACTERISTICS: CURRENT POLARITY FILLER METAL DIA. & TRADE NAME SUBMERGED ARC FLUX & TRADE NAME GMAW SHIELD GAS & TRADE NAME GUIDED BEND TEST RESULTS DATE TYPE & FIG. NO. RESULTS DATE TYPE & FIG NO. RESULTS NICK-BREAK TEST DATE TYPE & FIG NO. RESULTS DATE TYPE & FIG NO. RESULTS TESTING ORGANIZATION BY DATE WE CERTIFY THE STATEMENTS 1N THIS RECORD ARE CORRECT AND THAT THE TEST WELDS WERE PREPARED WELDED, AND TESTED IN ACCORDANCE WITH THE REQUIREMENTS OF ORGANIZATION DATE BY POSITION EOUIPMENT SAFETY CHECKLIS,T The Equipment Safety Checklist should be used as a guideline for checking equipment safety prior to starting any welding or burning operations. 1. Torches and blowpipes should be examined closely for leaky or improper installation of valves, nozzles, tips, or check valves. 2. Check that hoses are equipped with proper fittings, gauges, and regulators. o 4. . Oxygen and acetylene hoses should be inspected and tested for leaks, damage, or wear. Oxygen and acetylene fittings should be checked for leaks, improper installation, or damage. Oxygen and acetylene cylinder valves are operational and do not hold oil. 6. The rod holder should be checked against cracks or excessive wear. , o Electrodes and ground cables should be checked against cracks in the insulation and that all splices are properly insulated. Electrodes and ground cables should be checked for proper spark arrestor installation. 9. The welding machine should be checked for proper spark arrestor installation. 10. The welding cable should be checked for proper size and composition. 11. 12. Rods should be checked to insure they are of proper size and Composition. Any damaged or improper rods should be removed from the general area of the welding. Welding machine drip pans should be clean and properly installed. 13. Oxygen and acetylene bottles should be checked to insure proper pressures in the bottles and that they are secured and in a safe location away from the immediate area where the welding or burning is to be accomplished. WELDINt_ DR B[JRNIN(3 1N UNDE$IGNATE_ AREAS SAFETY CHECKLIST 1. Check qualifications of all personnel who will be performing welding or burning operations. Print names of all such personnel: . . In conjunction with the welder or weldrs, check all areas in which burning or cutting operations are to be performed for potential fire or expiosion hazards. Check all welding equipment as per ARCO's form Equipment Safety_ Checklist. Designate one or more persons, as necessary, as a Fire Watch. Inform the Fire Watch personnel of their duties. Insure that the Fire Watch personnel are capable of operating the equipment to which they are assigned. Check all fire fighting equipment assigned to the fire watch for proper operation. Print names of all assigned fire watch personnel: . . If welding or burning operations are to be accomplished on containers, tanks, or other vessels which have contained a flammable sulsstance, insure that the contents of these vessels have been rendered safe and are determined to be safe for welding or burning operations. Insure that all drilling, workover, or wireline operations are ceased unless the wells that are being serviced contain noncombustible fluids and that entry of formation hydrocarbons into the wellbore is precluded by a positive overbalance toward the formation. 7. The person-in charge should sign and date the following statement on this form in the space indicated. To the best of my ability, I have checked all the above items to insure that safe conditions for welding and burning operations exist. Signature of Person-In-Charge Date Distribution: Job Site File ARCO Exploration Drilling, Anchorage Office 10 SAFE WELDING AREA I WELL PIT, PUMP & POWER MODULE PIPE HOUSE QUARTERS ADDITIONAL SAFE WELDING AREA IN WELDING SHOP ON MAIN DECK LEVEL OF QUARTERS STRUCTURE HELIDECK HAZARDOUS AREA (FUEL INLET) HAZARDOUS AREA (FUEL INLET) 7 SUMMARY WELL PLAN (All depths are measured from RKB unless otherwise noted) o Tow rig from stack site in Federal waters off Prudhoe Bay to well location and ballast down. o Transport drilling consumables and major tools and equipment to drilling location by barge and load rig. o Rig up drive hammer and drive 20", 169#, 0.812" wall structural casing to a minimum of 227' RKB (100' BML). o Install 21-1/4" diverter on 20" structural casing and function test. o Drill 17-1/2" hole to 1,000'. o 'Run 13-3/8", 68//, L-80, BTC conductor to 1,000' and hang off on landing ring in 20" structural casing. o Cement 13-3/8" conductor to surface. o Wash out cement above casing hanger, nipple down diverter, cut off 20" and 13-3/8" casing and install 13-5/8" starting head. o Nipple up and test 13-5/8", 10,000 psi WP BOP stack. o Pressure test 13-3/8" casing to 2,500 psi (maximum anticipated surface pressure at the next casing point). Drill out and perform a leak-off test o Drill 12-1/4" hole to 4,000' MD using sea-water polymer mud system and incorporating LWD and MWD tools in the bottomhole assembly. Run 9-5/8", 40#, L-80, BTC surface casing to 4,000' MD. Cement 9-5/8" casing from 4,000' to surface. Pressure test 9-5/8" casing to 4,000 psi (70% of rated internal yield). Drill out and perform a leak-off test. o Drill 8-1/2" hole to 10,640'MD TD, continuously recording with MWD/LWD. ° Run the following open-hole logs from TD to the 9-5/8" casing shoe: Basic Logs: GR/BHC/LDT/CNL SWC (two passes, 45 shots) Velocity Survey - Check Shot (minimum 250' intervals) Contingent Logs (depend on results of basic logs): Dipole/Shearwave Sonic MDT-RFT Rotary Sidewall Cores (~ased-Hole VSP: To be nm if 7" casing is nm. Will substitute for check shot survey. At minimum, recordings will be taken every 50' from TD to the base of the conductor. If the logs provide sufficient encouragement for testing the well at this depth, run 7", 26#, L-80, BTC casing from TD to surface. Cement the 7" casing to +3,765' MD (3,500' TVD). (Note: Hydrocarbons are not expected to occur shallower than 4,000' TVD. All hydocarbon intervals will be covered with cement, regardless of where located.) Run cased-hole logs (CET/GR and gyro multishot) from TD to surface. Pressure test 7" casing to 5,000 psi (70% of rated internal yield). Run 3-1/2" completion/testing assembly in hole with packer and appropriate downhole flow control devices. Nipple down the BOP stack and nipple up and test a 3-1/2", 10,000 psi WP test tree on the 3-1/2" tubing spool. Conduct testing operations as approved subsequent to drilling by the AOGCC and MMS. The well will be tested by perforating underbalanced and flowing up the tubing and through surface testing facilities. Test liquids will be stored in tanks aboard the drilling unit and pumped back into the reservoir after testing of that reservoir is complete. Gas is to be flared. Testing will involve alternating flow and shut-in periods. Individual intervals may be tested separately or in combination. After completion of testing, pull packer loose or open by-pass above packer and circulate well full of kill-weight fluid. ° After verifying the well is dead, nipple down test tree and nipple up and test 13-5/8", 10,000 psi BOP stack. POH with test string. o Using drill pipe as the work string, abandon the well per AOGCC and MMS regulations. o Cut off and recover all casing at or below 20' BML. ° When sea ice conditions allow, de-ballast drilling unit to towing draft and tow back to stack site at Pmdhoe Bay. ° Conduct final site clearance after rig demobilization. Anticipated Surface Pressures The following presents data used for calculation of anticipated surface pressures (ASP) during drilling for the Warthog well: Casing Pore Casing Setting Fracture Pressure Pore ASP Size Depth Gradient Gradient Pressure Drilling (in.) (fi RKB) (lbs/gal) (lbs/gal) (psi) (psi) 13-3/8" 1,000' 13.0 8.9 463 566 9-5/8" 3,630' 14.8 8.9 1,680 2,394 7" 9,000' 15.0 9.5 4,446 2,394 Procedure for Calculating Anticipated Surface Pressure (ASP) 1. Drilling Below Conductor and Surface Casing ASP is determined on the basis of breakdown of the formation at the casing shoe with a gas gradient to surface as follows: ASP = [(FG x 0.052)- 0.11 ]D where: ASP = Anticipated Surface Pressure in psi FG = Fracture gradient at the casing shoe in lb/gal 0.052 = Conversion from lb/gal to psi/ft 0.11 = Gas gradient in psi/ft D = Tree vertical depth of casing shoe in fi RKB ASP Calculations 1. Drilling Below Conductor Casing (13-3/8") ASP = [(FG x 0.052) - 0.11] D = [(13.0x 0.052)-0.11] 1,000 = 566 psi 2. Drilling Below Surface Casing (9-5/8") ASP = [(FG x 0.052) - 0.11] D = [(14.8 x 0.052)- 0.11] 3,630 = 2,394 psi RECEIVED Pore Pressures and Mud Weiehts This analysis and prediction of geopressures for the Warthog #1 is based upon evaluation of seismic data, well test data and the following offset wells: Stinson g 1 Kuvlum g 1 Kuvlum g2 Kuvlum g3 Wild Weasel gl The closest wells to the Warthog location are the Stinson gl and the Wild Weasel gl which are 19.2 miles to the west and 20.5 miles to the northwest, respectively. An initial geopressure analysis was performed using 2-D seismic data obtained across the area in 1993. After evaluating sonic log data from Stinson gl and Wild Weasel #1, it was decided to use the Wild Weasel well to calibrate the prediction model because its log quality in the shallow portion of the hole is superior to that of the Stinson well. Once a normal compaction trend and the constants used to convert changes in interval transit time to changes in pressure were calculated, they were used to calculate a mud weight profile for the Wild Weasel well. This mud weight profile was then compared to the actual mud weights used to drill the Wild Weasel and was found to be within the normal range of accuracy. In the shallower portions of Wild Weasel the predicted mud weights were lower than those actually used to drill the well. At depths greater than 8,000' the predicted mud weights are closer to the actual mud weights used. The difference between the actual and predicted mud weights at the shallow depths can be explained by drilling practices. The interval from the mudline to 1,000' was drilled with sea water and gelled sweeps and no problems were encountered. This section of the hole did not penetrate any significant shallow gas in any of the offset wells. From 1,000' to approximately 4,000' the mud weight used was 9.6 to 9.8 ppg in all of the wells. This reflects a calculated decision to keep the mud weight in that range even though all indications were that the pore pressure was in the 8.9 to 9.0 ppg range. It was predicted that the 9.6 to 9.8 ppg fluids would contain all unexpected small gas stringers between 1,000' and 4,000' and provide hole stability for that section of the hole. Below 4,000' the mud weights used are more reflective of the actual pore pressures encountered. This is why, below 8,000', the predicted and actual mud weights show better agreement. For the Warthog well, seismic line CBV93-14 was used for analysis because it passes through both the proposed bottomhole and surface locations. Since there are no existing wells on that line, the model was calibrated using Wild Weasel data. Using the model, a pressure was calculated for CDP 548 on Line CBV93-14 which is at the proposed bottomhole location. At the permitted depth of 9,000' TVD, the predicted mud weight is 9.6 ppg with an approximate accuracy of +1.24 ppg. This prediction is consistent with the mud weights used on all the offset wells at this depth. Fracture Gradient The following table lists the fracture gradients found in the offsetting wells: Well Depth Leak-Off Test in PPG Kuvlum #1 1000' 12.9 3479' 15.0 Kuvlum #2 1017' 12.9 3978' 14.9 Kuvlum #3 1022' 14.3 3681' 14.8 Wild Weasel #1 1000' 15.0 3829' 15.5 Stinson #1 986' 11.1 4020' 14.1 The data indicate the fracture gradient at 1,000' increases to the south and east while the fracture gradient at approximately 3,800' remains constant over the area. The leak-off gradient of 15.0 ppg at 1,000' obtained at the Wild Weasel is probably anomalous. However, gradients of 12.0 to 14.0 can be expeCted at that depth. Discussion of Pressures and Potential Drilling Problems by Depth 100'- 1,000' TVD The geology in this interval at the Warthog location is expected to be very similar to that at the Wild Weasel location. The interval is predominantly characterized by unconsolidated sand with numerous gravel and some coal stringers. Pore pressures are expected to be in the 8.9 to 9.0 ppg range. The mud weight used to drill the interval will be in the 9.5 to 9.8 ppg range. The additional weight will be used to keep the hole open until conductor casing is run. Fracture gradient at the conductor shoe at 1,000' is expected to be between 12.5 and 13.5 ppg. While the shallow hazards analysis performed for this location showed no firm indications of shallow gas or major faulting in this hole section, the data could also not disprove the presence of minor gas and it does show some indications of faulting near the bottom of the interval. In anticipation of potential problems with gas entrainment in the mud and lost circulation in faulted intervals, the following precautions will be taken: - Kill-weight mud will be pre-mixed and standing by for mixing into the active mud system. - Lost circulation material will be broken out and standing by for mixing into the mud system. - Any significant gas shows in the mud will result in drilling being stopped, the gas circulated out and the well checked for flow. - If gas entrainment persists, though at an acceptable level, the interval will be drilled at a reduced drilling rate ("control drilled") until the gas level decreases to the point it is no longer a concern. 1,000' - 4,000' TVD This interval is expected to consist primarily of multiple unconsolidated sand sections separated by clay and minor gravels. Some minor coal sections may be present, but not in sufficient quantities to present problems. Small amounts of gas are expected to be associated with these coal stringers, however the volumes are expected to be small and normally pressured. Some gas is expected in some of the sand sections, but, again, they are expected to be normally pressured. The directional wellbore's build section and maximum angle are contained in this interval and additional mud weight over the expected pore pressures may be used to keep the hole open and stable. Drilling mud weights are expected to be 9.8 to 10.0 ppg. Fracture gradient at the casing shoe is expected to be between 14.5 and 15.8 ppg. Since the shallow hazards investigation indicated the possibility of some minor faulting high in this interval, careful attention will be paid to mud weights in this section due to the potential for lost circulation in the faulted intervals. Also, because of the potential, mentioned above, for minor gas, the same precautions listed for the previous hole section will be excercised. 4,000' - 9,000' TVD At the lower end of this interval the various formations are expected to become more consolidated and penetration rates should slow. Multiple sands interspersed with clay and shale intervals are expected. Pressures are still in the normal range but beginning to increase in the deepest part of the interval. While the formation pressures are expected to be normal, drilling mud weights will be between 10.0 and 10.4 ppg for hole stability reasons. The offset wells suggest no reason to expect significant lost circulation problems in this interval. If the logging program becomes lengthy, mud weights may be increased in small increments on wiper trips to maintain hole stability. Attached are the following supporting documents: - Warthog Pore Pressure/Mud Weight/Frac Gradient vs Depth - Internal Memo: Geopressure Prediction on Line CBV93-14 - Internal Memo: Time depth relation for Geopressure Prediction on Line (~BV93-14 - Color-Coded Seismic Interpretation: CBV 14 Predicted Mud Weight WARTHOG PORE PRESSURE/MUD WEIGHT/FRAC GRADIENT vs, DEPTH DEPTH TVD 8 9 IOO0 2000 '-'i ......... ~' / REF~~ 3OOO 4OOO 5OOO EQUIVALENTMUDWEIGHT, PPG 10 11 12 13 14 15 16 17 18 19 2O Q ! 6OOO 7OOO 8000 9000 10000 ARCO Alaska, Inc. Pore Pressures and Mud Weights This analysis and prediction of geopressures for the Warthog #1 is based upon evaluation of seismic data, well test data and the following offset wells: Stinson #1 Kuvlum #1 Kuvlum #2 Kuvlum #3 Wild Weasel #1 The closest wells to the Warthog location are the Stinson #1 and the Wild Weasel #1 which are 19.2 miles to the west and 20.5 miles to the northwest, respectively. An initial geopressure analysis was performed using 2-D seismic data obtained across the area in 1993. After evaluating sonic log data from Stinson #1 and Wild Weasel #1, it was decided to use the Wild Weasel well to calibrate the prediction model because its log quality in the shallow portion of the hole is superior to that of the Stinson well. Once a normal compaction trend and the constants used to convert changes in interval transit time to changes in pressure were calculated, they were used to calculate a mud weight profile for the Wild Weasel well. This mud weight profile was then compared to the actual mud weights used to drill the Wild Weasel and was found to be within the normal range of accuracy. In the shallower portions of Wild Weasel the predicted mud weights were lower than those actually used to drill the well. At depths greater than 8,000' the predicted mud weights are closer to the actual mud weights used. The difference between the actual and predicted mud weights at the shallow depths can be explained by drilling practices. The interval from the mudline to 1,000' was drilled with sea water and gelled sweeps and no problems were encountered. This section of the hole did not penetrate any significant shallow gas in any of the offset wells. From 1,000' to approximately 4,000' the mud weight used was 9.6 to 9.8 ppg in all of the wells. This reflects a calculated decision to keep the mud weight in that range even though all indications were that the pore pressure was in the 8.9 to 9.0 ppg range. It was predicted that the 9.6 to 9.8 ppg fluids would contain all unexpected small gas stringers between 1,000' and 4,000' and provide hole stability for that section of the hole. Below 4,000' the mud weights used are more reflective of the actual pore pressures encountered. This is why, below 8,000', the predicted and actual mud weights show better agreement. For the Warthog well, seismic line CBV93-14 was used for analysis because it passes through both the proposed bottomhole and surface locations. Since there are no existing wells on that line, the model was calibrated using Wild Weasel data. Using the model, a pressure was calculated for CDP 548 on Line CBV93-14 which is at the proposed bottomhole location. At the permitted depth of 9,000' TVD, the predicted mud weight is 9.6 ppg with an approximate accuracy of +1.24 ppg. This prediction is consistent with the mud weights used on all the offset wells at this depth. Fracture Gradient The following table lists the fracture gradients found in the offsetting wells: Well Depth Leak-Off Test in PPG Kuvlum # 1 1000' 12.9 3479' 15.0 Kuvlum #2 1017' 12.9 3978' 14.9 Kuvlum #3 1022' 14.3 3681' 14.8 Wild Weasel #1 1000' 15.0 3829' 15.5 Stinson #1 986' 11.1 4020' 14.1 The data indicate the fracture gradient at 1,000' increases to the south and east while the fracture gradient at approximately 3,800' remains constant over the area. The leak-off gradient of 15.0 ppg at 1,000' obtained at the Wild Weasel is probably anomalous. However, gradients of 12.0 to 14.0 can be expected at that depth. Discussion of Pressures and Potential Drilling Problems by Depth 100' - 1,000' TVD The geology in this interval at the Warthog location is expected to be very similar to that at the Wild Weasel location. The interval is predominantly characterized by unconsolidated sand with numerous gravel and some coal stringers. Pore pressures are expected to be in the 8.9 to 9.0 ppg range. The mud weight used to drill the interval will be in the 9.5 to 9.8 ppg range. The additional weight will be used to keep the hole open until conductor casing is mn. Fracture gradient at the conductor shoe at 1,000' is expected to be between 12.5 and 13.5 ppg. While the shallow hazards analysis performed for this location showed no firm indications of shallow gas or major faulting in this hole section, the data could also not disprove the presence of minor gas and it does show some indications of faulting near the bottom of the interval. In anticipation of potential problems with gas entrainment in the mud and lost circulation in faulted intervals, the following precautions will be taken: - Kill-weight mud will be pre-mixed and standing by for mixing into the active mud system. - Lost circulation material will be broken out and standing by for mixing into the mud system. - Any significant gas shows in the mud will result in drilling being stopped, the gas circulated out and the well checked for flow. - If gas entrainment persists, though at an acceptable level, the interval will be drilled at a reduced drilling rate ("control drilled") until the gas level decreases to the point it is no longer a concern. 1,000' - 4,000' TVD This interval is expected to consist primarily of multiple unconsolidated sand sections separated by clay and minor gravels. Some minor coal sections may be present, but not in sufficient quantities to present problems. Small amounts of gas are expected to be associated with these coal stringers, however the volumes are expeCted to be small and normally pressured. Some gas is expected in some of the sand sections, but, again, they are expected to be normally pressured. The directional wellbore's build section and maximum angle are contained in this interval and additional mud weight over the expected pore pressures may be used to keep the hole open and stable. Drilling mud weights are expected to be 9.8 to 10.0 ppg. Fracture gradient at the casing shoe is expected to be between 14.5 and 15.8 ppg. Since the shallow hazards investigation indicated the possibility of some minor faulting high in this interval, careful attention will be paid to mud weights in this section due to the potential for lost circulation in the faulted intervals. Also, because of the potentiall mentioned above, for minor gas, the same precautions listed for the previous hole section will be excercised. 4,000' - 9,000' TVD At the lower end of this interval the various formations are expected to become more consolidated and penetration rates should slow. Multiple sands interspersed with clay and shale intervals are expected. Pressures are still in the normal range but beginning to increase in the deepest part of the interval. While the formation pressures are expected to be normal, drilling mud weights will be between 10.0 and 10.4 ppg for hole stability reasons. The offset wells suggest no reason to expect significant lost circulation problems in this interval. If the logging program becomes lengthy, mud weights may be increased in small increments on wiper trips to maintain hole stability. Attached are the following supporting documents: - Warthog Pore Pressure/Mud Weight/Frac Gradient vs Depth - Internal Memo: Geopressum Prediction on Line CBV93-14 - Internal Memo: Time depth relation for Geopressure Prediction on Line CBV93-14 - Color-Coded Seismic Interpretation: CBV 14 Predicted Mud Weight CONFIDENTIAL (-~ARCO Alaska, Inc. CAMI)FN 8AY, NORTH SLOPE ALASKA WARTHOG #1 LOCATION LATITUDE: LONGITUDE: UTM 6 ~(: UTM 6 Y: SL BH LOCATION SL BH 70.044 7,,, 0:_:,-~ ASP 3 X: 634205.9 633323.5 144.926 ]44 '~:-'.:; ASP 3 Y: 5866936.1 5863187.0 578974 0 ¢,7~: ;'::.':~ ,', SIESMIC LINE: CB93-14, SP 300 7771997 7 ';770,~:."!',! (i) WATER DEPTH : 34'-38' 29' 'TH TOPS LITHOLOGY TOPS LITHOLOGY ~: CASING -SS) AGE FT/TWT (PROGNOSIS) FT/TWT (ACTUAL) ~ O LOGGING (HOLE SIZE) Z.~, · ... :.:. -:.. :.-::..?.:.:' 13 3/8' 1~1 ,:L; c-.?. v:~ IENO (17 1/2") ~' '~- .............................. SHOW.~ Z ~'~.::'-: '; :;::~:::_-': :_':'.~:,:::,:-:;..i~ 1) MWD GPJRES LM :-.'.:-:','.: '.' :-.:'..'.-.'- :': .".:~, :". '.'- :-.' ::'o ~ ' -'.'"'&2:.'~:" ".:&::-.'. ::'~:.::2~':~:;: }0 O ,~:: ...... 2940' :;.'TT-.- ........ ---' 0.900 ~.,,~:~: .............. ,:", ". % :', .. .......................... 4% !',,. .. , LLI ": -: ................. ,',', )0 LLI 4nno, ,.....i:"¥~-'-.. . . _£.: O .~.,:.- -..--:: O ::-z:~.-. :-: :..'.':'. ~->.-:..'.'..~-.-:.:-,> .,,.v::-;.: ,.~..-.....,.:. :-: :.y..>.-. :...~: LLI .-I ;~2:.::::::.::;,:::'::::&:.:-:.:.:.':'.:'..:.::.; :.:.::.~ O DRY O .~. ~_ ............ 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ARCO Warthog #1 Warthog slot #1 Beaufort Sea North Slope, Alaska PROPOSAL LISTING by Baker Hughes INTEQ Your ref : ARCO Warthog #1 Vers.#11 Our ref : prop2394 License : Date printed : 1-Oct-97 Date created : 27-Aug-97 Last revised : 1-Oct-97 Field is centred on nT0 18 57.380,w145 25 10.970,-147 Structure is centred on nT0 2 25.887,w144 55 51.938,-147 Slot location is n70 2 34.290,w144 55 2.300 Slot Grid coordinates are N 7772007.885, E 579322.407 Slot local coordinates are 854.54 N 1723.91 E Projection type: mercator - UTM, Spheroid: NAD 83 Reference North is True North Fairweather E & P Services, Inc. ARCO Warthog #1,Warthog Beaufort Sea,North Slope, Alaska Measured Inclin. Azimuth True Vert R E C T A N G U L A R Depth Degrees Degrees Depth C O 0 R D I N A T E S 0.00 0.00 217.09 0.00 0.00 N 0.00 E 100.00 0.00 217.09 100.00 0.00 N 0.00 E 500.00 0.00 217.09 500.00 0.00 N 0.00 E 1000.00 0.00 217.09 1000.00 0.00 N 0.00 E 1100.00 0.00 217.09 1100.00 0.00 N 0.00 E 1200.00 2.50 217.09 1199.97 1.74 S 1.32 W 1300.00 5.00 217.09 1299.75 6.96 S 5.26 W 1400.00 7.50 217.09 1399.14 15.64 S 11.82 W 1500.00 10.00 217.09 1497.97 27.77 S 21.00 W 1600.00 12.50 217.09 1596.04 43.34 S 32.76 W PROPOSAL LISTING Page 1 Your ref : ARCO Warthog #1 Vets.#11 Last revised : 1-0ct-97 Dogleg Vert Deg/100ft Sect 0.00 0.00 0.00 0.00 0.00 0.00 0.00 20" Casing Pt 0.00 0.00 13 3/8" Casing Pt 0.00 KOP 2.50 2.18 2.50 8.72 2.50 19.61 2.50 34.82 2.50 54.33 1700.00 15.00 217.09 1693.17 62.30 S 47.09 W 2.50 78.09 1800.00 17.50 217.09 1789.17 84.62 S 63.97 W 2.50 106.07 1900.00 20.00 217.09 1883.85 110.26 S 83.35 W 2.50 138.21 2000.00 22.50 217.09 1977.05 139.16 S 105.20 W 2.50 174.46 2100.00 25.00 217.09 2068.57 171.29 S 129.49 W 2.50 214.73 2200.00 27.50 217.09 2158.25 206.57 S 156.16 W 2300.00 30.00 217.09 2245.92 244.94 S 185.16 W 2400.00 32.50 217.09 2331.40 286.31 S 216.44 W 2500.00 35.00 217.09 2414.54 330.63 S 249.94 W 2538.45 35.96 217.09 2445.85 348.43 S 263.40 W 3000.00 35.96 217.09 2819.44 564.64 S 426.85 W 3500.00 35.96 217.09 3224.14 798.87 S 603.91 W 4000.00 35.96 217.09 3628.85 1033.09 S 780.98 W 4500.00 35.96 217.09 4033.56 1267.31 S 958.04 W 5000.00 35.96 217.09 4438.26 1501.54 S 1135.10 W 2.50 258.95 2.50 307.05 2.50 358.92 2.50 414.47 2.50 436.79 EOC 0.00 707.83 0.00 1001.45 0.00 1295.07 9 5/8" Casing Pt 0.00 1588.69 0.00 1882.31 5500.00 35.96 217.09 4842.97 1735.76 S 1312.17 W 0.00 2175.93 6000.00 35.96 217.09 5247.68 1969.98 S 1489.23 W 0.00 2469.54 6500.00 35.96 217.09 5652.38 2204.21 S 1666.30 W 0.00 2763.16 7000.00 35.96 217.09 6057.09 2438.43 S 1843.36 W 0.00 3056.78 7500.00 35.96 217.09 6461.80 2672.65 S 2020.42 W 0.00 3350.40 8000.00 35.96 217.09 6866.51 2906.88 S 2197.49 W 0.00 3644.02 8500.00 35.96 217.09 7271.21 3141.10 S 2374.55 W 0.00 3937.64 8675.17 35.96 217.09 7413.00 3223.16 S 2436.59 W 0.00 4040.51 Target 9000.00 35.96 217.09 7675.92 3375.32 S 2551.62 W 0.00 4231.26 9500.00 35.96 217.09 8080.63 3609.55 S 2728.68 W 0.00 4524.88 10000.00 35.96 217.09 8485.33 3843.77 S 2905.74 W 0.00 4818.50 10500.00 35.96 217.09 8890.04 4077.99 S 3082.81 W 0.00 5112.12 10635.85 35.96 217.09 9000.00 4141.63 S 3130.92 W 0.00 5191.89 Est. TD / 7" Csg Pt Ail data is in feet unless otherwise stated. Coordinates from slot #1 and TVD from RKB (Beaufort Sea I) (93.00 Ft above mean sea level). Bottom hole distance is 5191.89 on azimuth 217.09 degrees from wellhead. Total Dogleg for wellpath is 35.96 degrees. Vertical section is from wellhead on azimuth 217.09 degrees. Calculation uses the minimum curvature method. Presented by Baker Hughes INTEQ Fairweather E & P Sez-vices, Inc. ARCO Warthog #1,Warthog Beaufort Sea,North Slope, Alaska PROPOSAL LISTING Page 2 Your ref : ARCO Warthog #1 Vers.#11 Last revised : 1-0ct-97 Comments in wellpath MD TVD Rectangular Coords. Comment 100 00 100.00 0.00 N 0.00 E 20" Casing Pt 1000 00 1000.00 0.00 N 0.00 E 13 3/8" Casing Pt 1100 00 1100.00 0.00 N 0.00 E KOP 2538 45 2445.85 348.43 S 263.40 W EOC 4000 00 3628.85 1033.09 S 780.98 W 9 5/8" Casing Pt 8675 17 7413.00 3223.16 S 2436.59 W Target 10635.85 9000.00 4141.63 S 3130.92 W Est. TI) / 7" Csg Pt Casing positions in string 'A' Top MD Top TVD Rectangular Coords. Bot MD Bot TVD Rectangular Coords. Casing 0.00 0.00 0.00N 0.00E 100.00 100.00 0.00N 0.00E 20" Casing 0.00 0.00 0.00N 0.00E 1000.00 1000.00 0.00N 0.00E 13 3/8" Casing 0.00 0.00 0.00N 0.00E 4000.00 3628.85 1033.09S 780.98W 9 5/8" Casing 0.00 0.00 0.00N 0.00E 10635.85 9000.00 4141.63S 3130.92W 7" Casing Targets associated with this wellpath Target name Geographic Location T.V.D. Rectangular Coordinates Revised Warthog %1 Rvsd 19-S nT0 2 2.590,w144 56 12.450,-1 7413.00 3223.16S 2436.59W 27-Aug-97 Fairweather E & P Services, Inc. A~RCO Warthog #1,Warthog Beaufort Sea,North Slope, Alaska Measured Inclin. Azimuth True Vert R E C T A N G U L A R Depth Degrees Degrees Depth C O O R D I N A T E S 0.00 0.00 217.09 0.00 854.54 N 1723.91 E 100.00 0.00 217.09 100.00 854.54 N 1723.91 E 500.00 0.00 217.09 500.00 854.54 N 1723.91 E 1000.00 0.00 217.09 1000.00 854.54 N 1723.91 E 1100.00 0.00 217.09 1100.00 854.54 N 1723.91 E PROPOSAL LISTING Page 1 Your ref : ARCO Warthog #1 Vers.#ll Last revised : 1-Oct-97 Dogleg Vert Deg/100ft Sect 0.00 0.00 0.00 0.00 0.00 0.00 0.00 20" Casing Pt 0.00 0.00 13 3/8" Casing Pt 0.00 KOP 1200.00 2.50 217.09 1199.97 852.80 N 1722.59 E 2.50 2.18 1300.00 5.00 217.09 1299.75 847.59 N 1718.65 E 2.50 8.72 1400.00 7.50 217.09 1399.14 838.90 N 1712.09 E 2.50 19.61 1500.00 10.00 217.09 1497.97 826.77 N 1702.91 E 2.50 34.82 1600.00 12.50 217.09 1596.04 811.21 N 1691.15 E 2.50 54.33 1700.00 15.00 217.09 1693.17 792.25 N 1676.82 E 1800.00 17.50 217.09 1789.17 769.93 N 1659.94 E 1900.00 20.00 217.09 1883.85 744.29 N 1640.56 E 2000.00 22.50 217.09 1977.05 715.38 N 1618.71 E 2100.00 25.00 217.09 2068.57 683.26 N 1594.42 E 2200.00 27.50 217.09 2158.25 647.98 N 1567.75 2300.00 30.00 217.09 2245.92 609.61 N 1538.75 2400.00 32.50 217.09 2331.40 568.23 N 1507.47 2500.00 35.00 217.09 2414.54 523.92 N 1473.97 2538.45 35.96 217.09 2445.85 506.11 N 1460.51 3000.00 35.96 217.09 2819.44 289.90 N 1297.06 E 3500.00 35.96 217.09 3224.14 55.68 N 1120.00 E 4000.00 35.96 217.09 3628.85 178.55 S 942.93 E 4500.00 35.96 217.09 4033.56 412.77 S 765.87 E 5000.00 35.96 217.09 4438.26 646.99 S 588.80 E 2.50 78.09 2.50 106.07 2.50 138.21 2.50 174.46 2.50 214.73 2.50 258.95 2.50 307.05 2.50 358.92 2.50 414.47 2.50 436.79 EOC 0.00 707.83 0.00 1001.45 0.00 1295.07 9 5/8" Casing Pt 0.00 1588.69 0.00 1882.31 5500.00 35.96 217.09 4842.97 881.22 S 411.74 E 0.00 2175.93 6000.00 35.96 217.09 5247.68 1115.44 S 234.68 E 0.00 2469.54 6500.00 35.96 217.09 5652.38 1349.66 S 57.61 E 0.00 2763.16 7000.00 35.96 217.09 6057.09 1583.89 S 119.45 W 0.00 3056.78 7500.00 35.96 217.09 6461.80 1818.11 S 296.52 W 0.00 3350.40 8000.00 35.96 217.09 6866.51 2052.33 S 473.58 W 0.00 3644.02 8500.00 35.96 217.09 7271.21 2286.56 S 650.64 W 0.00 3937.64 8675.17 35.96 217.09 7413.00 2368.61 S 712.68 W 0.00 4040.51 Target 9000.00 35.96 217.09 7675.92 2520.78 S 827.71 W 0.00 4231.26 9500.00 35.96 217.09 8080.63 2755.00 S 1004.77 W 0.00 4524.88 10000.00 35.96 217.09 8485.33 2989.23 S 1181.83 W 0.00 4818.50 10500.00 35.96 217.09 8890.04 3223.45 S 1358.90 W 0.00 5112.12 10635.85 35.96 217.09 9000.00 3287.09 S 1407.01 W 0.00 5191.89 Est. TD / 7" Csg Pt Ail data is in feet unless otherwise stated. Coordinates from NE Corner of Sec. 20, T8N, R29E, UM and TVD from RKB (Beaufort Sea I) (93.00 Ft above mean sea level). Bottom hole distance is 5191.89 on azimuth 217.09 degrees from wellhead. Total Dogleg for wellpath is 35.96 degrees. Vertical section is from wellhead on azimuth 23.7.09 degrees. Calculation uses the minimum curvature method. Presented by Baker' Hughes ~'NTEQ Fairweather E & P Services, Inc. ARCO Warthog #1,Warthog Beaufort Sea,North Slope, Alaska PROPOSAL LISTING Page 2 Your ref : ARCO Warthog #1 Vers.#11 Last revised : 1-0ct-97 Comments in wellpath ==================== MD TVD Rectangular Coords. Comment 100 00 100.00 854.54 N 1723.91 E 20" Casing Pt 1000 00 1000.00 854.54 N 1723.91 E 13 3/8" Casing Pt 1100 00 1100.00 854.54 N 1723.91 E KOP 2538 45 2445.85 506.11 N 1460.51 E E0C 4000 00 3628.85 178.55 S 942.93 E 9 5/8" Casing Pt 8675 17 7413.00 2368.61 S 712.68 W Target 10635 85 9000.00 3287.09 S 1407.01 W Est. TD / 7" Csg Pt Casing positions in string 'A' Top MD Top TVD Rectangular Coords. Bet MD Bet TVD Rectangular Coords. Casing 0.00 0.00 854.54N 1723.91E 100.00 100.00 854.54N 1723.91E 20" Casing 0.00 0.00 854.54N 1723.91E 1000.00 1000.00 854.54N 1723.91E 13 3/8" Casing 0.00 0.00 854.54N 1723.91E 4000.00 3628.85 178.55S 942.93E 9 5/8" Casing 0.00 0.00 854.54N 1723.91E 10635.85 9000.00 3287.09S 1407.01W 7,, Casing Targets associated with this wellpath ===================================== Target name Geographic Location T.V.D. Rectangular Coordinates Revised Warthog #1 Rvsd 19-S nT0 2 2.590,w1~ 56 12.450,-1 7413.00 2368.61S 712.68W 27-Aug-97 Fairweather E & P Services, Inc. ARCO Warthog #1,Warthog Beaufort Sea,North Slope, Alaska PROPOSAL LISTING Page 1 Your ref : ARCO Warthog #1 Vets.#11 Last revised : 1-Oct-97 Measured Inclin Azimuth True Vert R E C T A N G U L A R Dogleg Vert G E 0 G R A P H I C Depth Degrees Degrees Depth C O 0 R D I N A T E S Deg/100ft Sect C 00 R D I N A T E S 0.00 0.00 217.09 0.00 0.00N 0.00E 0.00 0.00 n70 2 34.29 w144 55 02.30 100.00 0.00 217.09 100.00 0.00N 0.00E 0.00 0.00 n70 2 34.29 w144 55 02.30 500.00 0.00 217.09 500.00 0.00N 0.00E 0.00 0.00 n70 2 34.29 w144 55 02.30 1000.00 0.00 217.09 1000.00 0.00N 0.00E 0.00 0.00 n70 2 34.29 w144 55 02.30 1100.00 0.00 217.09 1100.00 0.00N 0.00E 0.00 0.00 n70 2 34.29 w144 55 02.30 1200.00 2.50 217.09 1199.97 1.74S 1.32W 2.50 2.18 n70 2 34.27 w144 55 02.34 1300.00 5.00 217.09 1299.75 6.96S 5.26W 2.50 8.72 n70 2 34.22 w144 55 02.45 1400.00 7.50 217.09 1399.14 15.64S 11.82W 2.50 19.61 n70 2 34.14 w144 55 02.64 1500.00 10.00 217.09 1497.97 27.77S 21.00W 2.50 34.82 n70 2 34.02 w144 55 02.90 1600.00 12.50 217.09 1596.04 43.34S 32.76W 2.50 54.33 n70 2 33.86 w144 55 03.24 1700.00 15.00 217.09 1693.17 62.30S 47.09W 2.50 78.09 n70 2 33.68 w144 55 03.66 1800.00 17.50 217.09 1789.17 84.62S 63.97W 2.50 106.07 n70 2 33.46 w144 55 04.14 1900.00 20.00 217.09 1883.85 110.26S 83.35W 2.50 138.21 n70 2 33.21 w144 55 04.70 2000.00 22.50 217.09 1977.05 139.16S 105.20W 2.50 174.46 n70 2 32.92 w144 55 05.33 2100.00 25.00 217.09 2068.57 171.29S 129.49W 2.50 214.73 n70 2 32.61 w144 55 06.03 2200.00 27.50 217.09 2158.25 206.57S 156.16W 2.50 258.95 nT0 2 32.26 w144 55 06.80 2300.00 30.00 217.09 2245.92 244.94S 185.16W 2.50 307.05 nT0 2 31.88 w144 55 07.63 2400.00 32.50 217.09 2331.40 286.31S 216.44W 2.50 358.92 n70 2 31.47 w144 55 08.53 2500.00 35.00 217.09 2414.54 330.63S 249.94W 2.50 414.47 n70 2 31.04 w144 55 09.50 2538.45 35.96 217.09 2445.85 348.43S 263.40W 2.50 436.79 n70 2 30.86 w144 55 09.89 3000.00 35.96 217.09 2819.44 564.64S 426.85W 0.00 707.83 n70 2 28.74 w144 55 14.59 3500.00 35.96 217.09 3224.14 798.87S 603.91W 0.00 1001.45 n70 2 26.43 w144 55 19.69 4000.00 35.96 217.09 3628.85 1033.09S 780.98W 0.00 1295.07 nT0 2 24.13 w144 55 24.79 4500.00 35.96 217.09 4033.56 1267.31S 958.04W 0.00 1588.69 n70 2 21.83 w144 55 29.89 5000.00 35.96 217.09 4438.26 1501.54S 1135.10W 0.00 1882.31 n70 2 19.52 w144 55 34.99 5500.00 35.96 217.09 4842.97 1735.76S 1312.17W 0.00 2175.93 n70 2 17.22 w144 55 40.09 6000.00 35.96 217.09 5247.68 1969.98S 1489.23W 0.00 2469.54 n70 2 14.92 w144 55 45.18 6500.00 35.96 217.09 5652.38 2204.21S 1666.30W 0.00 2763.16 nT0 2 12.61 w144 55 50.28 7000.00 35.96 217.09 6057.09 2438.43S 1843.36W 0.00 3056.78 n70 2 10.31 w144 55 55.38 7500.00 35.96 217.09 6461.80 2672.65S 2020.42W 0.00 3350.40 nT0 2 08.00 w144 56 00.47 8000.00 35.96 217.09 6866.51 2906.88S 2197.49W 0.00 3644.02 n70 2 05.70 w144 56 05.57 8500.00 35.96 217.09 7271.21 3141.10S 2374.55W 0.00 3937.64 n70 2 03.40 w144 56 10.66 8675.17 35.96 217.09 7413.00 3223.16S 2436.59W 0.00 4040.51 n70 2 02.59 w144 56 12.45 9000.00 35.96 217.09 7675.92 3375.32S 2551.62W 0.00 4231.26 n70 2 01.09 w144 56 15.76 9500.00 35.96 217.09 8080.63 3609.55S 2728.68W 0.00 4524.88 n70 i 58.79 w144 56 20.86 10000.00 35.96 217.09 8485.33 3843.77S 2905.74W 0.00 4818.50 n70 i 56.49 w144 56 25.95 10500.00 35.96 217.09 8890.04 4077.99S 3082.81W 0.00 5112.12 nT0 i 54.18 w144 56 31.04 10635.85 35.96 217.09 9000.00 4141.63S 3130.92W 0.00 5191.89 n70 I 53.56 w144 56 32.43 Ail data in feet unless otherwise stated. Calculation uses minimum curvature method. Coordinates from slot #1 and TVD from RKB (Beaufort Sea I) (93.00 Ft above mean sea level). Bottom hole distance is 5191.89 on azimuth 217.09 degrees from wellhead. Total Dogleg for wellpath is 35.96 degrees. Vertical section is from wellhead on azimuth 217.09 degrees. Grid is mercator - Universal Transverse Mercator (LVI'M). Grid coordinates in METERS and computed using the NAD 83 spheroid Presented by Baker Hughes INTEQ Fail-weather E & P Services, Inc. ARCO Warthog #1,Warthog Beaufort Sea,North Slope, Alaska PROPOSAL LISTING Page 2 Your ref : /%RCO Warthog #1 Vets.#11 Last revised : 1-Oct-97 Comments in wellpath ==================== MD TVD Rectangular Coords. Comment 100.00 100 00 0.00N 0.00E 20" Casing Pt 1000.00 1000 00 0.00N 0.00E 13 3/8" Casing Pt 1100.00 1100 00 0.00N 0.00E KOP 2538.45 2445 85 348.43S 263.40W EOC 4000.00 3628 85 1033.09S 780.98W 9 5/8" Casing Pt 8675.17 7413 00 3223.16S 2436.59W Target 10635.85 9000 00 4141.63S 3130.92W Est. TD / 7" Csg Pt Casing positions in string 'A' Top MD Top TVD Rectangular Coords. BotM/) Bot TVD Rectangular Coords. Casing 0.00 0.00 0.00N 0.00E 100.00 100.00 0.00N 0.00E 20" Casing 0.00 0.00 0.00N 0.00E 1000.00 1000.00 0.00N 0.00E 13 3/8" Casing 0.00 0.00 0.00N 0.00E 4000.00 3628.85 1033.09S 780.98W 9 5/8" Casing 0.00 0.00 0.00N 0.00E 10635.85 9000.00 4141.63S 3130.92W 7" Casing Targets associated with this wellpath ===================================== Target name Geographic Location T.V.D. Rectar~tlar Coordinates Revised Warthog #1 Rvsd 19-S nT0 2 2.590,w144 56 12.450,-1 7413.00 3223.16S 2436.59W 27-Aug-97 Fairweather E & P Services, Inc. ARCO Warthog #1,Warthog Beaufort Sea,North Slope, Alaska PROPOSAL LISTING Page 1 Your ref : A~RCO Warthog #1 Vers.#11 Last revised : 1-Oct-97 Measured Inclin Azimuth True Vert R E C T A N G U L A R Dogleg Vert G R I D C O 0 R D S Depth Degrees Degrees Depth C O O R D I N A T E S Deg/100ft Sect Easting Northing 0.00 0.00 217.09 0.00 0.00N 0.00E 0.00 0.00 579322.41 7772007.89 100.00 0.00 217.09 100.00 0.00N 0.00E 0.00 0.00 579322.41 7772007.89 500.00 0.00 217.09 500.00 0.00N 0.00E 0.00 0.00 579322.41 7772007.89 1000.00 0.00 217.09 1000.00 0.00N 0.00E 0.00 0.00 579322.41 7772007.89 1100.00 0.00 217.09 1100.00 0.00N 0.00E 0.00 0.00 579322.41 7772007.89 1200.00 2.50 217.09 1199.97 1.74S 1.32W 2.50 2.18 579322.02 7772007.34 1300.00 5.00 217.09 1299.75 6-96S 5.26W 2.50 8.72 579320.88 7772005.71 1400.00 7.50 217.09 1399.14 15.64S 11.82W 2.50 19.61 579318.97 7772003.00 1500.00 10.00 217.09 1497.97 27.77S 21.00W 2.50 34.82 579316.30 7771999.21 1600.00 12.50 217.09 1596.04 43.34S 32.76W 2.50 54.33 579312.88 7771994.35 1700.00 15.00 217.09 1693.17 62.30S 47.09W 2.50 78.09 579308.71 7771988.43 1800.00 17.50 217.09 1789.17 84.62S 63.97W 2.50 106.07 579303.80 7771981.46 1900.00 20.00 217.09 1883.85 110.26S 83,35W 2.50 138.21 579298.17 7771973.45 2000.00 22.50 217.09 1977.05 139.16S 105.20W 2.50 174.46 579291.81 7771964.42 2100.00 25.00 217.09 2068.57 171.29S 129.49W 2.50 214.73 579284.75 7771954.38 2200.00 27.50 217.09 2158.25 206.57S 156.16W 2.50 258.95 579276.99 7771943.36 2300.00 30.00 217.09 2245.92 244.94S 185.16W 2.50 307.05 579268.55 7771931.38 2400.00 32.50 217.09 2331.40 286.31S 216.44W 2.50 358.92 579259.46 7771918.46 2500.00 35.00 217.09 2414.54 330.63S 249.94W 2.50 414.47 579249.71 7771904.62 2538.45 35.96 217.09 2445.85 348.43S 263.40W 2.50 436.79 579245.80 7771899.05 3000.00 35.96 217.09 2819.44 564.64S 426.85W 0.00 707.83 579198.26 7771831.52 3500.00 35.96 217.09 3224.14 798.87S 603.91W 0.00 1001.45 579146.76 7771758.36 4000.00 35.96 217.09 3628.85 1033.09S 780.98W 0.00 1295.07 579095.26 7771685.21 4500.00 35.96 217.09 4033.56 1267.31S 958.04W 0.00 1588.69 579043.76 7771612.05 5000.00 35.96 217.09 4438.26 1501.54S 1135.10W 0.00 1882.31 578992.26 7771538.89 5500.00 35.96 217.09 4842.97 1735.76S 1312.17W 0.00 2175.93 578940.77 7771465.73 6000.00 35.96 217.09 5247.68 1969.98S 1489.23W 0.00 2469.54 578889.27 7771392.58 6500.00 35.96 217.09 5652.38 2204.21S 1666.30W 0.00 2763.16 578837.77 7771319.42 7000.00 35.96 217.09 6057.09 2438.43S 1843.36W 0.00 3056.78 578786.27 7771246.26 7500.00 35.96 217.09 6461.80 2672.65S 2020.42W 0.00 3350.40 578734.77 7771173.10 8000.00 35.96 217.09 6866.51 2906.88S 2197.49W 0.00 3644.02 578683.27 7771099.94 8500.00 35.96 217.09 7271.21 3141.10S 2374.55W 0.00 3937.64 578631.77 7771026.79 8675.17 35.96 217.09 7413.00 3223.16S 2436.59W 0.00 4040.51 578613.73 7771001.16 9000.00 35.96 217.09 7675.92 3375.32S 2551.62W 0.00 4231.26 578580.28 7770953.63 9500.00 35.96 217.09 8080.63 3609.55S 2728.68W 0.00 4524.88 578528.78 7770880.47 10000.00 35.96 217.09 8485.33 3843.77S 2905.74W 0.00 4818.50 578477.28 7770807.31 10500.00 35.96 217.09 8890,04 4077.99S 3082.81W 0.00 5112.12 578425.78 7770734.15 10635.85 35.96 217.09 9000.00 4141.63S 3130.92W 0.00 5191.89 578411.79 7770714.28 Ail data in feet unless otherwise stated. Calculation uses minimum curvature method. Coordinates from slot #1 and TVD from RKB (Beaufort Sea I) (93.00 Ft above mean sea level). Bottom hole distance is 5191.89 on azimuth 217.09 degrees from wellhead. Total Dogleg for wellpath is 35.96 degrees. Vertical section is from wellhead on azimuth 2],7.09 degrees. Grid is mercator - Universal Transverse Mercator (UTM). Gr~d coordinates in METERS a~d computed usin9 the NAD 83 spheroid Presented by Baker Rughes INq'EQ Fairweather E & P Services, Inc. ARCO Warthog #1,Warthog Beaufort Sea,North Slope, Alaska PROPOSAL LISTING Page 2 Your ref : ARCO Warthog #1 Vers.#11 Last revised : 1-Oct-97 Comments in wellpath .................... MD TVD Rectangular Coords. Comment 100.00 100.00 0.00N 0.00E 20" Casing Pt 1000.00 1000.00 0.00N 0.00E 13 3/8" Casing Pt 1100.00 1100.00 0.00N 0.00E KOP 2538.45 2445.85 348.43S 263.40W EOC 4000.00 3628.85 1033.09S 780.98W 9 5/8" Casing Pt 8675.17 7413.00 3223.16S 2436.59W Target 10635.85 9000.00 4141.63S 3130.92W Est. TD / 7" Csg Pt Casing positions in string 'A' Top MD Top TVD Rectangular Coords. Bot MD Bot TVD Rectangular Coords. Casing 0.00 0.00 0.00N 0.00E 100.00 100.00 0.00N 0.00E 20" Casing 0.00 0.00 0.00N 0.00E 1000.00 1000.00 0.00N 0.00E 13 3/8" Casing 0.00 0.00 0.00N 0.00E 4000.00 3628.85 1033.09S 780.98W 9 5/8" Casing 0.00 0.00 0.00N 0.00E 10635.85 9000.00 4141.63S 3130.92W 7" Casing Targets associated with this wellpath Target name Geographic Location T.V.D. Rectangular Coordinates Revised Warthog #1 Rvsd 19-S n70 2 2.590,w144 56 12.450,-1 7413.00 3223.16S 2436.59W 27-Aug-97 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION 3001 Porcupine Drive Anchorage Alaska 99501-3192 Re: THE APPLICATION OF ARCO ) ALASKA, INC. for an order granting ) an exception to spacing requirements ) of Title 20 AAC 25.055 to provide ) for the drilling of the Warthog No. I ) exploration oil well in the Camden ) Bay vicinity of the Beaufort Sea. ) Conservation Order No. 407 ARCO Alaska, Inc. Warthog No. I October 23, 1997 IT APPEARING THAT: . ARCO Alaska, Inc. submitted an application dated September 26, 1997 requesting exception to the well spacing provisions of Title 20 AAC 25.055 (1) to allow drilling of the ARCO Warthog No. 1, exploration oil well to an undefined oil pool, to a bottom-hole location which is within 500 feet of a quarter section line within Camden Bay in the Beaufort Sea. Notice of opportunity for public hearing was published in the Anchorage Daily News on October 1, 1997 pursuant to 20 AAC 25.540. 3. No protests to the application were received. FINDINGS: The Warthog No. 1 exploration oil well will be drilled as a deviated hole from a surface location of 70° 02' 34.29" N Latitude, and 144° 55' 2.30" W Longitude in the Outer Continental Shelf to a bottomhole location of 2384 feet from the south line and 853 feet from the east line of Section 20, Township 8 North and Range 29 East Umiat Meridian. 2. ARCO is the sole working interest owner of the subject and all offsetting drilling units. . An exception to the well spacing provisions of Title 20 AAC 25.055 (1) is necessary to allow the drilling of this well. Conscn'ation Order No. 4(,)/ October 23, ] 997 Page 2 CONCL[!SION: Granting a spacing exception to allow drilling of the ARCO Warthog ,.No. 1 well will not result in waste nor jeopardize correlative rights. NOW, TItEREFORE, IT IS ORDERED: ARCO Alaska, Inc.'s application for exception to the well spacing provisions of Title 20 AAC 25.055 (1) for the purpose of drilling the ARCO Warthog No. I is approved. DONE at Anchorage, Alaska and dated October 23, 1997. Alaska O~servation Commission Robert N ~stenson, P E, Commissioner Alaska Oil and Gas Consemation Commission Commission AS 31.05.()8() providcs that within 2() days allcr receipt of xwittcn notice of the entre, oF an order, a person allkcted by it mav Iile with the Commission an application tbr rehearing. A request lbr ~chearing must be received by 4:30 PM on thc 23~d day lbllowing thc date of thc order, or next working day il' a holiday or weekend, to bc timel~ filed. The Commission shall grant or rcthsc thc application in whole or in i)art within ]() days. Thc Commissio~i can rcfitse an application by not acting on it within thc l()-day period. An atlkctcd person ires 30 days l?om thc date thc Conmfission rclhses thc application or mails (or otherwise distributes) an order upon rehearing, both being thc final order oF thc Commission, to appeal the decision to Superior Court. Where a request Ibr rehearing is denied bv nonaction of the Commission, the 3()-day period for appeal to Superior Ct)un runs fi'om thc date on which thc request is deemed denied (i.e., 1()"' day allot thc application R)r rchearin~ was filed). STATE OF ALASKA ALASKA. iL AND GAS CONSERVATION CC MISSION PERMIT TO DRILL 20 AAC 25.OO5 [] Drill [] Redrill 1 lb. Type of well [] Exploratory F1Stratigraphic Test [] Development Oil la. Type ofwork DRe-Entry [].DeePe.n..J. F-1Service FI Development Gas DSingle Zone FlMulti_ple Zone 2. Name ~f Operator ........... 5. Datum Elevaii'c;n (DFo'~"'KB) 10.'F~i~'ld and Pool ARCO ALASKA, INC. 92' RKB (ASL) WILDCAT 3. Address P 0 BOX 100360 6. Property Designation .AJ~CHORAGE, Al( 99510-0360 ADL 3710ZZ~ 4. Location of well at sudace 7. Unit or Property Name 11. Type Bond (See 20 AAC 25.025) LA_T: 70° 02' 34"; LONG: lt~4° 55' 02" WILDCA_T~CAMDEN BAY STATEWIDE At top of~ target interval 8. Well Nu'mber Number U-630610 2370; FNL, 719' FA'L, Sec. 20, T8N, R29E, tim Warthog No. 1 At total depth 9. Approximate spud date Amount $200,000.O0 3287' FNL; 1/,07' FEI., sec. 20, T8N, R29E, UM 11/1/97 ., 12. Distance to nearest property line113. Distance to nearest well 14. Number of acres in property 15. Proposed depth (MD and TVD) 3287'I 19.2 miles (Stinson) 2560 9000' TVD, 10~366' MI)SS 16. To be completed for deviated wells 17. Anticipated pressure Isee 2o AAG 25.035 (e} (2)} Kick Off Depth 1,1o0' RKB Maximum Hole Angle 36 o Maximum surfaco ~-,395 psig.. At total depth (TVD) z~,z~.6 ....... psig 18. Casing Program Setting Depth v" Size Specifications Top BottomI Quantity of Cement Hoie l Casing Weight Grade Coupling i Length MD TVD--!-. MD TVD I (include stage data) ....... _ i 20. 169# Drive Welded ! 197' 30' 30' 4 227' 227' ~ N/& cSII 17-1/2{13-3/8 68 L-80 BTC ! 800' 200' ~ 200' { 1000' 1000'~ad z~80 sx CSIII, Tail ~3z~s i2'1/4{ 9~5i8 { 40 L-80 BTC i 3970' 30' 30' 4000' 3630' ~ead 785 SX CS I]I_. Tail 19. To be completed for Redrill, Re-entry, and Deepen Operations. Present well condition summary Total depth: measured feet Plugs (measured) true vertical feet Effective depth' measured feet Junk (measured) true vertical feet Casing Length Size Cemented MD TVD Structural Conductor Surface Intermediate REEEiV~I) Production .. Liner ,,,... ,iii: . ORiGI, NAL Perforation depth: measured ,:L,.iaSI<.S. ,.,,, & ~a'$ ,_..., Anchorag~ true vertical 2'-0. Attachments- ~ Filing Fee {9 Property Plat [] BOP Sketch [] Diverter Sketch [] Ddlling Program [] Drilling Fluid Program [] Time vs Depth Plot [] Refraction Analysis [] Seabed Report [] 20 AAC 25.050 Requirements ............. Contact ~n~i'nee'r'Nam'e~/~/umb~'r]-"w..¢ J. Penrose, 258-3446 Prepared By Name/Number: W. J. Penrose, 258-3]-+z+6 21. ! hereby cedify tha~h~ foreg°~g is/true and correct to the beSt of my knowledge Signed l~j/[ /~_ . ? Title Kuparuk Drlg. Superintendent Date /"~'~ 7~ Commission Use Only Permit Number [ APl Number i Approval Date See cover letter ¢/~-~"~_~' 0'",-~'"2~/- ~<::~::~ /.2... , _/~'""'=~//""~1 . for other requirements Conditions' of Approval: samples Required [.i] Yes El No Mud Log Required [71 Yes []'1 No Hydrogen Sulfide Measures ~Yes l_Z} No Directional Survey Required [I Yes I' I No Required Working Pressure forBOPE []2M; [i;3M' ~ 5M; El 10M; []¢i5M Othe, r: , Approved By Urlglfla. l Signed By by order of r-,~. ;:.~ ,~,~ ,,., I.~ ,-,o+r~ n C~O r'n _m_~i ~ s2 o_r] e~r_ _~(¢~t hdc o m miss ion D at e~z- '";=~"'-- Form 10-401 Rev. 12_01_~¥~u ,~.. Submit ~n Triplicate ARCO Warthog/41 Application For Permit to Drill List of Attachments Well Prognosis Plat: Warthog Proposed Bottomhole Location Summary Well Plan Directional Program Discussion: Pore Pressures and Mud Weights Discussion: Fracture Gradient Discussion: Pressures and Potential Drilling Problems by Depth Plot: Warthog Pore Pressure/Mud Weight/Frac Gradient vs Depth Internal Memo: Geopressure Prediction on Line CBV93-14 Internal Memo: Time Depth Relation for Geopressure Prediction on Line CBV93-14 Diverter Schematic BOP Stack Diagram, Cornponent List and Component Pressure Ratings Anticipated Surface Pressures Casing Properties and Design Discussion: Permafrost Discussion: Lost Circulation Discussion: Production Pressures Discussion: Drilling Within Annular Blowout Preventer Limitations Discussion: BOP Closing System and BOPE Testing Discussion: Directional Well/Surveys Discussion: Rig Environmental Response Monitoring Discussion: Injection of Fluids BOPE Testing Procedure Leak-Off Test Procedure Mud Program Diagrams: Mud System on the Glomar Beaufort Sea I Cement Program ARCO Warthog #1 Well Prognosis Well Name: Surface Loc.: Target Loc.: Bottomhole Loc.: Water Depth: Objective Horizon: Planned TD: Fonnation Tops: Cores: Planned Logs: ARCO Warthog/41 (NAD-83) Lat. 70°02'34"N, Long. 144°55'02"W (NAD-83) Lat. 70°02'02.6"N, Long. 144°56'1.2.5"W 719' FEL, 2,370' FNL, Sec 20, T8N, R29E, UM (NAD-83) Lat. 70°01'53.6"N, Long. 144°56'32.4"W 1,407' FEL, 3,287' FNL, Sec 20, T8N, R29E, UM 29' at Bottomhole Location 36' at Surface Location Early Oligocene Sands 9,000' TVD, RKB TOPS Top Oligocene Top Prospective Oligocene Mid-Oligocene Marker Gas Sand "Bright Spot" Base Prospective Oligocene Base Topset Sands TD None plam~ed DEPTHS (TVD, SS) 2,800' 4,000' 6,270' 7,460' 8,100' 8,1.00' 8,900' 12-1/4" Intermediate Hole, 1,000' - 4,000'MD: LWD Only - GR/Resistivity* 8-1/2" Production Hole, 4,000' - 9,000'MD, TD: LWD - GR/Resistivity* Wireline Logs (Schlumberger): GR/BHC/LDT/CNL SWC (2 passes, 45 shots) VSP - Check Shot (min 250' inte~wals) *Teleco Dual Propagation Resistivity II Tool from Baker Hughes Inteq Mudlogging: Mudlogging will be in operation from the base of the 13- 3/8' conductor to TD. Service will include sample collection, ROP, lithology, show description, hot wire, gas analysis of cuttings, gas chromatography, and drilling parameters. Thirty foot (30') samples will be collected from the base of the structural casing, and 10 foot (10') samples will be collected in zones of interest. The wellsite geologist will adjust the interval or sample frequency as required. Planned Sampling 1 set unwashed each: ARCO, Partners (2) 3 sets washed and dried: ARCO 1 set washed and dried: Partners (2), State of AK, MMS 1 set canned ditch samples for geochemical analysis collected at 30' intervals from base of the structural casing to TD. Contingent Logging: If the initial logging suite provides sufficient encouragement, all or part of the following Schlumberger logs may be run: Dipole/Shearwave Sonic MDT/RFT Rotary Sidewall Cores FMI - Borehole Imaging/Structural Diplog VSP - If casing is run, a cased-hole VSP may be conducted after the final logging run. It will substitute for the check shot survey. At a minimum, recordings will be taken every 50' from TD to the conductor. !85°_ 180° I'15°170° .6t~' i60° i55° 150° 145° 140° 135° 150° 135° "Cx', ~" ' // r-~ . De!to..-r ~ ~ / ~ :' )~ Nome Fob b~-~k~e, ~ ~ ~ OO~ /~-~.~/_~_~o ~-'.,,,.,' Alaska~ /~ ~ ~- A~SKA VICINI~ MAP AI.}I 37't030 /d'4, ?'l.~t[. L ' B~AUFO~T Pr.z,~dizoe AL6SX~_ ~ 2002 CAMDEN BAY VIOINI~ MAP Proposed i Camden AAt UnitI Al t< 4 .; / ? !iI,~, t't~l'. [. ti;':; R /4?,4/7(; ;,t.3 t. 57~012 B" 3~- g7 Ai)[. 371()0g 8" 51- 5)'/ 12-31'06 y 1653 Camden Bay Y - 7 '7 / ~ 2 ()0 : I/:(? '% Kongonevik K4169 57 PAl Proposed BotNimhal, Lo,c 8-31-97 1 ALK4.469 + + 75 '-¥- 8-~T-97 AUK4172 ^N 6 8-31-97 8-31-97 + + 36 31 ADL 371015 8-31-97 1 6 ALK447( LE IN 'I~ILE% WARTHOG Bottomhole Location Camden Bay Unit NORTH SLOPE ALASKA APl)llcotlon by: At?CO Alaska, In(:. "::,i'~eo'l: I ol [ ()tile.: Mor-cI~ 9703 O01A()(! August 13, 1997 Mr. Jeff Walker U.S. Department of the Interior Minerals Management Service Alaska OCS Region 949 E 36th Ave, Room 110 Anchorage, Alaska 99508-4302 Re: Analysis of Seafloor Video ARCO Warthog #1 Exploratory Well Dear Mr. Walker, Per the MMS' request, the scafloor video recorded in the vicinity of the proposed rig set- down location for the Warthog #1 well has been analyzed for kelp density. A copy of the videotape, the tape analysis and a sonar mosaic showing where the video was recorded are included with this memo. To record the video, an underwater camera containing a light source was lowered to approximately 0.7m above the seafioor in 10-12m of water and the vessel from which it was suspended allowed to drift. While the current in this location runs east-to-west, surface winds caused the vessel (and camera) to drift west-to-east. Four drift lines of 100m, 300rn, 310m and 60m length were run over the area and a short 30m line was run over a location of particular interest. See the sonar mosaic for the locations of the video tracks. In analyzing the video, all occurrences of kelp which entered the camera's field of view were recorded during each 5-minute block of time on each track. A 'kelp occurrence', as recorded, is usually a single frond of kelp, though sometimes it was two or three fronds which appeared to either be part of the same plant or were rooted to the same cobble. Also recorded were 'heads', defined as groupings of kelp 0.3 - 0.7m in diameter anaong which could be seen a more diversified community of plant life. These heads seem to be attached to larger 'cobbles or to groupings of cobbles. Four widely-spaced heads were observed during the survey. See the tape analysis for locations. Overall, 169 kelp occun'ences, including heads, were observed in the 616 square meters covered. This yields an average density of one kelp occurrence per each 3.6 square meters of seafloor. This is a thinly-populated, fairly extensive kelp patch associated with dispersed cobbles on a hard seafloor. Tiao cxten! of lbo patch can be seen on thc sonar 715 L.. Street A~x;horagc, Alaska 99501 (!..~()/) ;:!Ixt 3.:146 FAX (9(')/);i!t')~ t>!~!:,/ Analysis of Seafloor Video Warthog Location Note: Camera field-of-view is 0.8m. Line 1 00:50 --> 01:07 (Line Length: 100m, Coverage: 80 sq meters) Time Kelp Occurences 00:50 4 00:55 2 (+1 head) 01:00 1 ' 01:05 1 Line 2 01:54 --> 02:28 (Line Length: 300m, Coverage: 240 sq meters) Time Kelp Occurences 01:54 7 (+ 1 head) 01:59 17 02:04 14 02:09 7 02:14 0 02:19 0 02:24 0 Line 3 02:44 --> 03:36 (Line Length: 310m, Coverage 248 sq meters) Time Kelp Occurences 02:44 11 02:49 16 02:54 10 02:59 5 03:04 5 03:09 7 (+ 1 head) 03:14 6 03:19 11 03:24 10 03'29 7 (+ 1 head) 03:34 2 Line 4 03:46 --> 04:01 (Line Length: 60m, Coverage 48 sq meters) Time Kelp Occurences 03:46 6 03:51 3 04:01 1 S i~;P I 0 1997 Line 5 04:13 --> 04:20 (Line Length: 30m, Coverage not used in anat'¥'sis)'.Oil.&,'n~'.~it (~as'Oons. ¢o.m[r~iss, Time Kelp Occurences .... 04'13 0 An0h0ra 04:18 0 mosaic. Except for the dispersed kelp and occasional 'head', the benthic community appears similar to that observed in this water depth along the majority of the Beaufort Sea coast. Please let mc know if additional information and/or analysis is needed. Sincerely? ~,~/ Bill rose Project Manager enclosures Mr. Glenn Gray- ADGC Mr. David Johnston - AOGCC Mr. Paul Mazzolini- ARCO Formation Integrity Test (FIT) and Leak-Off Test (LOT) Procedures Note that the terms used in the procedures and the spreadsheet of FIT/LOT results are defined as follows: Formation Integrity Test (FIT) -Forrnation is tested to a pre-determined equivalent mud weight. · Leak-Off Test (LOT) - Pressure is exerted against the formation until fluid begins to discernibly pump away. Pressure at which this first occurs is the leak-off point. · LOT Limit - 16.0 ppg EMW for all surface casing shoe tests; determined from previous experience with formation breakdown problems by attempting higher leak- offs. · Open Hole LOTs (OH LOTs)- Leak-off tests performed with open hole from the casing shoe to some point above the target reservoir. Generally done when leak-off is required but could not be achieved just below the casing shoe; or where weaker formations are suspected above the target reservoir but below the casing shoe, and assurance is required of being able to achieve estimated mud weight. Procedure for FIT: 1. Drill at least 20' of new hole below the casing shoe, but not more than 50'. 2. Circulate the hole to establish a uniform mud density throughout the system. P/U into the shoe. 3. Close the blowout preventer (ram or annular). 4. Pump down the drill stem at 1/4 to 1/2 bpm. 5. On a graph with the recent caSing test already shown, plot the fluid pumped (volume or strokes) vs. drillpipe pressure until appropriate surface pressure is achieved for FIT at shoe. 6. Shut down at required surface pressure. Hold for a minimum 10 minutes or until the pressure stabilizes. Record time vs. pressure in 1-minute intervals. 7. Bleed the pressure off and record the fluid volume recovered. The pre-determined surface pressure for each formation integrity test is based on achieving an EMW at least 1.0 ppg higher than the estimated reservoir pressure, and. allowing for an. appropriate amount of kick tolerance in case well control measures are required. Formation integrity tests are conducted on all casing shoes with the exception of some surface casing situations. Where annular pumping will be done on a well, the fon~ation below the surface shoe is taken to leak-off. This ensures that future disposal fluids can pumped away without risk of damage to the surface shoe. If two attempts at establishing leak-off at the shoe are unsuccessful (using 16.0 ppg EMW LOT limit per definition above), then an open-hole LOT is performed. Where required, the LOT is perforrned in the same fashion as the formation integrity test. Instead of stopping at a pre-determined point, surface pressure is increased until the formation begins to take fluid; at this point the pressure will continue to rise, but at a slower rate. The system is shut in and pressure monitored as with an FIT. G 0al Marine Drillin Coin')a ¢ % CRITICAL PROCEDURES Subject: DRILLING PROCEDURE - TESTING DIVERTER EQUIPMENT TEST 1. Pick up two drill collars. 2. Function test annular preventer. Dived. er closing time should be less than 30 seconds. 3. Record closing time on IADC drill report. 4. Functionally test both the main diverter control unit and the remote unit. 5. Pressure test diverter to 100 psi against diverter line valves (MMS 300 psi). 6. Circulate through diverter lines with valves open to verify lines are free of obstructions, increase pumping rate (do not exceed 100 psi pressure on hole below conductor) to assure system will handle a large volume of fluid. 7. While pumping, inspect the system for leaks and excessive vibrations. 8. Open annular preventer and make certain the diverter lines valves are in the closed position for drilling operations. 9. While drilling the surface hole, the diverter lines should be frequently flushed with water to assure the lines are not plugged with cuttings. TEST PROCEDURES FOR B.O.P. SYSTEMS 1. Test pressure applied to annular preventers should not exceed 70 percent of their rated working pressure. When testing the annular, it should be closed on drill pipe not open hole. 2. Ram type preventers should be tested to stack working pressure, which is determined by the lesser pressure rating of the preventer stack, wellhead or upper part of the casing string. ^l~l')rov('d lily: Rcvision D~,te: issut' Dale: Pal4e: Index ~ XX lof5 ,171- .lobal Marine Drilling Conli. ~ny CRITICAL PROCEDURES Subject: DRILLING PROCEDURE - TESTING TEST PROCEDURES FOR B.O.P. SYSTEMS (Cont'd) o Test ram preventers and all stack and assembly components upstream of the choke (not including annular preventers) to the rated working pressure of the stack three (3) minutes with appropriate fluid to check for leaks. To ensure pressure integrity at lower pressures, a pressure test of 200 to 300 psi should also be performed. In extremely cold temperatures, an appropriate fluid may have to be used to prevent freeze-up of the B.0.P. 's. 4. Intermittent tests: A. On each trip, actuate ram-type preventers and check accumulator/pump unit for proper operation. B. Before drilling out after each subsequent string of casing is set, test B.O.P. 's and choke manifold. C. Should any pressure seal in the B.0. P., assembly to disconnected test B.0. P. and choke manifold. . Annual inspection. Disassemble and inspect all blowout preventers. Have a qualified service representative thoroughly inspect and test all components of the control system. . Miscellaneous recommendations: A. An inside blowout preventer assembly (back-pressure valve) and essentially full- opening drill string safety valve in the open position should be maintained on the rig floor to fit all pipe in the drill string. A kelly cock should be installed below the swivel and another full-opening kelly cock that can be run through the B.O.P.'s should be installed at the bottom of the kelly. B. The required sizes of either test joints or test plugs with tapped pressure ports in each size test plug used should be kept on the rig. C. One complete extra set of ring gaskets and an extra supply of B.O.P. bolts should be maintained on the rig. AIq~roved By: Revision Dale: Issue D atc: xx 2 of 5 Index No.: ,171-. ,, obal Marine Drilling Comt ay ~ CRITICAL PROCEDURES Subject: DRILLING PROCEDURE - TESTING TEST PROGRAM 1. Initial installation of the stack. A complete test of the B.O.P.'s and choke manifold is required. (alternating between control stations). 2. 2,4 hour test. Actuate ram type preventers, check accumulator/pump unit for proper operation during this test. 3. Weekly test. At least once each week test the B.O.P.'s and choke manifold, alternating between control stations. Testing shall be at staggered intervals to allow each drilling crew to operate the equipment. 4. A blowout preventer drill should be conducted with each crew to ensure that all equipment is operational. Members of each crew should be familiar with how the equipment operates and properly trained to carry out the necessary assignments during an emergency situation. Approved By: RcvLsion Dale: Issue Date: Page: lmtcx No.: MINERALS MANAGEMENT SERVICE Submit o~gina~ plus thr~ cep~ w~ OMB No. 1010-0044 APPLICATION FOR PERMIT TO DRI' (APD) om copy marked "Public Informatier Expiration Date: September 30, 1999 , , 1. 2. APl WELL NuMBp_~: 3. WELL NUMBER 11. OPERATOR NAME AND ADDRESS (Submittin~ Off, ce) ORIGINAL X W~ ARCO Alaska, inc. CORRECTION NO. ]- P O Box 100360 8. FIELD NAME 9. UNIT NUMBER 10. MSS OPERATOR NUMBER Anchorage, AK 995]_0-0360 Wildcat N/A WELL AT TOTAL DEPTH 17. WELL LOCATION AT TOTAL DEPTH (Estimated) 4. LEASE NUMBER 5. AREAI~AME 6. BLOCK NUMBER 7. OPDNUMBER Lat. 70° 02'53.6" N State of Alaska. Camden Bay Long. 144° 56' 32.4" W (NAD-83) ADL 371014 Beaufort Sea WELL AT SURFACE 12. WELL LOCATION AT SURFACE (Estimated) 13. LEASE NUMBER 14. AREA NAME 15. BLOCK NUMBER 16. OPD NUMBER Lat. 70° 02' 3~" N Camden Bay Long. 1~+° 55, 02" W (NAD-83) 0CS-Y-1663 Beaufort Sea 7067 NRO6-0~ 18. WATER DEPTH (Estimated) 19. ELEVATION AT KB (Estimated) 20. RIG NAME 21. RIG TYPE 35' 92 ASL Glomar Beaufort Sea I Submersible 22. TYPE OF WELL: 23. SPUD DATE (Proposed) 24. TOTAL DEPTH (Proposed) EXPLORATORY X Noveaber ]_, 1997 DEVELOPMENT MD 10,636 TVD 9,000ss 25. ATTACHMENTS (Attach complete well prognOSis and attach~ts required under 30 CFR 250.64~) through (g) or 30 CFR 272(c) and (d), as appropriate) SKE /LT~ACHRD LIST. ... . 26. CONTACT NAME 27. TELEPHONE NUMBER William J. Penrose (907)258-3446 (Fairweather) , :28. AUTHORIZING OFFICIAL (Type Name) 29. TITLE Mike Zanghi ., Kuparuk Drilling Superintendent ARCO Alaska, Inc. 30. AUTHoRIzING 31..DATE THIS SPACE FOR MM~S~LY ".' '. APPROVED (With Attached Conditions. ) BY TITLE (Without Co~dmons ) '" DATE · APl WELL NO. ASSIGNED TO THIS WELL ~ " PAPERWORK REDUCTION ACT STATEMENT: The Paperwork Reduction Act of 1995 (44 U.S.C. 3501 et seq.) requires us to inform you that this information is being collected to obtain knowledge of equipment and procedures to be used in drilling operations. This information will be used by MSS District Supervisors to evaluate and approve or disapprove the adequacy of the equipment and/or procedures to safely perform the proposed drilling operation. Response to this request is mandatory (43 U.S.C. 1334). Proprietary data are covered under 30 CFR 250.18. An agency may not conduct or sponsor, and a person is not required to respond to, a collection of information unless it displays a currently valid OMB Control Number. Public reporting burden for this form is estimated to average 2 hours per response, including the time for reviewing instructions, gathering and maintaining data, and completing and reviewing the form. Direct comments regarding the burden estimate or any other aspect of this form to the Information Collection Clearance Officer, Mail Stop 2053, Minerals Manage- ment Service, 381 Elden Street, Herndon, VA 20170-4817; and to the Office of Management and Budget, Office of Information ' and Regulatory Affairs, Desk Officer for the Department of the Interior (OMB No. 1010-0044), Washington, DC 20503. "I~ORM MMS-123 (Sel~tember 1996) (Replaces all previous editions of Form MMS-123 which may not be used.) DRIL-QUIP, INC. 13550 Hempstead Hwy. ~ Houston, Texas 77040 (713) 939-7711 Fax (713) 939-8063 September 2, 1997 Mr. Blair Wondzell Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 Re: Mudline Suspension Equipment Dear Blair: Further to our telephone conversation, enclosed is our MS-15 Mudline Suspension System Brochure. Following your review of same, should you have any questions, please contact us. Sincerely, /~~ 0'" Bob Mitchell BM:jrn enclosure: Brochure /NC. August 18, 1997 Mr. Jeff Walker U.S. Department of the Interior Minerals Management Service Alaska OCS Region 949 E 36th Ave, Room 110 Anchorage, Alaska 99508-43()2 Re: Final Proposed Surface Location ARCO Warthog #1 Exploratory Well Dca]' Mr. Walker, This is to confirm the sur'face location agreed upon after the August 18 joint meeting of the MMS, Fairweather, ARCO and the Arctic Biological Task Force (ABTF). We intend to set the CIDS down as close as possible to Lat. 70°02'37"N, Long. 144°54'49"W. This location was decided upon after taking into account the ABTF's desire for us to stay away from areas identified al the meeting as having higher concentrations of benthic flora as well as being a location more physically suitable (flatter, softer bottom with no cobbles) for setting the rig down. This location also has a high density of seismic, sub- bottom profiler and sonar data for the rig stability and shallow hazards analyses. Sincerel2g, ~..~. Bill Penrose Proj oct Manager C: Mr. Glenn Gray - ADGC Mr. David Johnston - AOGCC 'v/ Mr. Paul Mazzolini - ARCO 't997 An01a0ra[t0 715 1__ Slreel Arx':ho~a,qe, A!aska 99501 907) 25a {~446 I-AX (90/)'258-.5557 IN REPLY REI:ER TO: United States Department of the Interior M i N E~kLS M;UXAGEM ENT SERVI CE 9.i9 F.. 361h Avcnuc, R,x)m 603 Anchorage Alaska 99508-t302 3 1 JUL )997 Mr. Bill Penrose Senior Project Manager Fairweather E&P Services 715 L Street//4 Anchorage, Alaska 99501 Dear Mr. Penrose: Thank you for submitting the revised shallow hazards survey for the Warthog #1 well. Our review of the revised preliminary activity notice for the shallow hazards survey program should satisfy the requirements as discussed during our meeting on July 15; 1997. · ' ' : ~ ~ .' We still request that you notify this office 72 hours prior to the start of the field work. cc~ r. Bob Crandall Alaska Oil and Gas Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Mr. Mark Majors ARCO Alaska, Inc. P.O. Box 100360 Anchorage, Alaska 99510-0360 Sincerely, ' je~.~WSlker '7 Field Operation :N RI:.i'kYK.:~::R T¢) United States Department of the Interior M1NEIL-M.S MANA(;EMENT SERVICE Alaska Outer Co~!incntal Shelf Rcgkm 94t~ E. 36th .Arc,mc, Room 693 ..Xnc'horagc, Alaska 995(}8-4302 Mr. R. C. Gardner Fairweather E&P Services 715 L Street #4 ?mchorage, Alaska 99501 Dear Mr. Gardner: Our review of the preliminaW activity _notice fo,,' the Wa~hog shallow hazards survey programs have been completed. No significant environmental effects have been identified and this office has no objections to the activity proceeding as proposed. Please notif~ this office at least one week prior to the start of the field work. If it appears that the field work will continue longer than the estimated 12 days identified in your notice, or has the potential to continue into the bowhead whale migration and subsistence hunting periods, please advise this office immediately. We also request that you verify the changes to the geophysical systems to be deployed as was discussed during the meeting on June 4, 1997, with ARCO. You should be aware that the shallow hazards survey will also be used to clear the drilling site for potential biological and archaeological resources, based primarily on the presence of ice gouging. If ice gouging is not present, or an anomaly (boulder patch) is identified, additional survey work may be necessary to verify the absence of a biological or archaeological resource. You should be aware that boulders and cobbles with attached kelp exist in a small area northwest of Kangigivik Point in western Camden Bay. Accordingly, you are encouraged to provide the survey results as soon as possible to this office for review. If you have any questions, please contact Mr. Doug Choromanski at (907) 271-6066. Sincerely, cc: M.r. Mark Major ARCO Alaska, Inc. P.O. Box 100360 Anchorage, Alaska 995 !0-0360 Regional Supervisor Field Operations Mr. John Dunham North Slope Borough P.O. Box 69 Barrow, Alaska 99723 Mr. Glenn Gray Department of Governmental Coordination P.O. Box 110030 Juneau, Alaska 99811 Md(Ir. Bob Crandall Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 GLOBAL MARINE BEAUFORT SEA I 600 WEST 41sT AVENUE, SUITE 201 ANCHORAGE, ALASKA 99503 TELEPHONE: (907) 563-8030 TELEFAX: (907) 563-8012 June 20,1997 ALASKA OIL & GAS CONSERVATION COMMISSION 3001 PORCUPINE DRIVE ANCHORAGE, AK 99501 ATTN: MR. DAVE JOHNSON CHAIRMAN Dear Mr. JOHNSON: The enclosed Agreement for Mutual Indemnity is necessary and required should there be a need for you to visit or work on the Glomar Beaufort Sea I Drilling Rig in Prudhoe Bay. For your convenience, two (2) copies of the Agreement have been enclosed. Please review the Agreement and sign both copies, keeping one for your records and return the other signed copy to our office. Should you have any questions, please feel free to contact this office. Thanking you in advance, Tom B. Alleman Rig Manager TBA/sn Enclosures THIS CONTRA CT CONTAINS PRO VISIONS RELATIVE TO RELEASE, INDEMNITY AND WAIVER OF RIGHTS OF RECOURSE AGREEMENT FOR MUTUAL INDEMNITY AND WAIVER OF RECOURSE This Agreement is made as of this __ day of ,19 , between GLOBAL MARINE BEAUFORT SEA INC., a Delaware corporation with offices located at 777 N. Eldridge Parkway, Houston, Texas, 77079 ("Company") and ALASKA OIL & GAS CONSERVATION COMMISSION, a __ corporation with offices located at 3001 PORCUPINE DR., ANCHORAGE, AK 99501 ("Contractor") and is premised on the fact that: a) Company and the Contractor have each entered into agreements with Fairweather E & P Services, Inc. or its affiliated company or its client (a "Contract") regarding the supply or performance of work or services in connection with operations aboard or in support of Company's drilling unit, the vessel "Glomar Beaufort Sea I" offshore Alaska ("Operations"); b) The parties wish to modify their relationship at law and avoid entirely disputes as to their liabilities for damage or injuries to their respective property or employees by providing for a system of mutual indemnity between the parties with respect to their respective personnel and property. In consideration of the premises and the reciprocal covenants of contained herein, the parties agree as follows: 1. Definitions In this Agreement, (a) "Company Group" shall mean Company, its parent, subsidiary and affiliated companies and their subcontractors, together with their agents, employees, directors, officers, servants, owners, shareholders, vessels and insurers of each. (b) "Contractor Group" shall mean Contractor, its parent, subsidiary and affiliated companies and their subcontractors, together with their agents, employees, directors, officers, servants, owners, shareholders, vessels and insurers of each. The Contractor shall be liable and shall indemnify and hold harmless and waive all rights of recourse against Company Group, from and against any and all claims, demands or causes of action of every kind and character, brought by any person or party, for injury to, illness or death of any member of the Contractor Group or for damage to or loss of property owned or leased by the Contractor Group which injury, illness, death, damage or loss arises out of or is incident to the Operations. The Company shall be liable and shall indemnify and hold harmless and waive all rights of recourse against Contractor Group, from and against any and all claims, demands or causes of action of every kind and character, brought by any person or party, for injury to, illness or death of any member of the Company Group or for damage to or loss of property owned or leased by the Company Group which injury, illness, death, damage or loss arises out of or is incident to the Operations. 4. Indemnity Obligations - General The parties agree that where one party herein has agreed to assume a responsibility or liability and/or has agreed to indemnify and hold harmless the other party's Group under the provisions of this Agreement, it is intended to mean that the indemnifying party shall release, indemnify, hold harmless, waive all rights of recourse and defend (including payment of reasonable attorney's fees and costs of litigation) the indemnified party from and against any and all claims, liabilities, expenses, demands, causes of action, damages, judgments and awards of any kind or character, without limit and without regard to the cause or causes thereof, including pre-existing conditions, whether such conditions be patent or latent, latent defects or the unseaworthiness of any vessel or vessels, breach of representation or warranty (express or implied), any theory of tort, breach of contract or strict liability, or the negligence of any person or persons, including that of the indemnified party, whether such negligence be sole, joint, or concurrent, active, passive, or gross. The benefit of an indemnifying party's obligations contained in this Agreement shall also extend to actions in rem and/or in personam. In no event shall the Contractor nor the Company be liable to the other for indirect, consequential or punitive damages. It is the intent of the parties that all indemnity obligations and liabilities assumed by each of them under the terms of this Agreement shall not be limited in amount or scope to insurance coverage required by a Contract. . The Contractor shall obtain from its insurers a waiver of rights of subrogation against Company Group and obtain an endorsement of its policies naming Company Group as an additional insured thereunder, to the extent of Contractor's obligations and liabilities contained herein this Agreement, to the extent permitted under applicable law. . The Contractor shall identify its subcontractors whom are involved in the Operations to Company in order that such subcontractor shall execute an agreement substantially similar to this Agreement. . This Agreement may be executed in any number of counterparts but all such counterparts shall together constitute one legal instrument. 10. Governing Law This Agreement shall be construed and the relations between the parties determined in accordance with the General Maritime Law of the United States of America, not including, however, any of its conflicts of law rules which would direct or refer to the laws of another jurisdiction. IN WITNESS of their agreement, each party has caused its authorized representative to execute this instrument effective as of the date first above written. GLOBAL MARINE BEAUFORT SEA INC. ALASKA OIL &GAS CONSERVATION COMMISSION By: T.B. ALLEMAN By: DAVE JOHNSON Title: RIG MANAGER Title: CHAIRMAN Date: {~,~o///~ ';~ Date: THIS CONTRA CT CONTAINS PRO VISIONS RELATIVE TO RELEASE, INDEMNITY AND WAIVER OF RIGHTS OF RECOURSE AGREEMENT FOR MUTUAL INDEMNITY AND WAIVER OF RECOURSE This Agreement is made as of this __ day of ., 19 , between GLOBAL MARINE BEAUFORT SEA INC., a Delaware corporation with offices located at 777 N. Eldridge Parkway, Houston, Texas, 77079 ("Company") and ALASKA OIL & GAS CONSERVATION COMMISSION, a __ corporation with offices located at 3001 PORCUPINE DR., ANCHORAGE, AK 99501 ("Contractor") and is premised on the fact that: a) Company and the Contractor have each entered into agreements with Fairweather E & P Services, Inc. or its affiliated company or its client (a "Contract") regarding the supply or performance of work or services in connection with operations aboard or in support of Company's drilling unit, the vessel "Glomar Beaufort Sea I' offshore Alaska ("Operations"); b) The parties wish to modify their relationship at law and avoid entirely disputes as to their liabilities for damage or injuries to their respective property or employees by providing for a system of mutual indemnity between the parties with respect to their respective personnel and property. In consideration of the premises and the reciprocal covenants of contained herein, the parties agree as follows: 1. Definitions In this Agreement, (a) "Company Group" shall mean Company, its parent, subsidiary and affiliated companies and their subcontractors, together with their agents, employees, directors, officers, servants, owners, shareholders, vessels and insurers of each. (b) "Contractor Group" shall mean Contractor, its parent, subsidiary and affiliated companies and their subcontractors, together with their agents, employees, directors, officers, servants, owners, shareholders, vessels and insurers of each. The Contractor shall be liable and shall indemnify and hold harmless and waive all rights of recourse against Company Group, from and against any and all claims, demands or causes of action of every kind and character, brought by any person or party, for injury to, illness or death of any member of the Contractor Group or for damage to or loss of property owned or leased by the Contractor Group which injury, illness, death, damage or loss arises out of or is incident to the Operations. The Company shall be liable and shall indemnify and hold harmless and waive all rights of recourse against Contractor Group, from and against any and all claims, demands or causes of action of every kind and character, brought by any person or party, for injury to, illness or death of any member of the Company Group or for damage to or loss of property owned or leased by the Company Group which injury, illness, death, damage or loss arises out of or is incident to the Operations. 4. Indemnity Obligations - General The parties agree that where one party herein has agreed to assume a responsibility or liability and/or has agreed to indemnify and hold harmless the other party's Group under the provisions of this Agreement, it is intended to mean that the indemnifying party shall release, indemnify, hold harmless, waive all rights of recourse and defend (including payment of reasonable attorney's fees and costs of litigation) the indemnified party from and against any and all claims, liabilities, expenses, demands, causes of action, damages, judgments and awards of any kind or character, without limit and without regard to the cause or causes thereof, including pre-existing conditions, whether such conditions be patent or latent, latent defects or the unseaworthiness of any vessel or vessels, breach of representation or warranty (express or implied), any theory of tort, breach of contract or strict liability, or the negligence of any person or persons, including that of the indemnified party, whether such negligence be sole, joint, or concurrent, active, passive, or gross. The benefit of an indemnifying party's obligations contained in this Agreement shall also extend to actions in rem and/or in personam. o In no event shall the Contractor nor the Company be liable to the other for indirect, consequential or punitive damages. It is the intent of the parties that all indemnity obligations and liabilities assumed by each of them under the terms of this Agreement shall not be limited in amount or scope to insurance coverage required by a Contract. The Contractor shall obtain from its insurers a waiver of rights of subrogation against Company Group and obtain an endorsement of its policies naming Company Group as an additional insured thereunder, to the extent of Contractor's obligations and liabilities contained herein this Agreement, to the extent permitted under applicable law. The Contractor shall identify its subcontractors whom are involved in the Operations to Company in order that such subcontractor shall execute an agreement substantially similar to this Agreement. This Agreement may be executed in any number of counterparts but all such counterparts shall together constitute one legal instrument. 10. Governing Law This Agreement shall be construed and the relations between the parties determined in accordance with the General Maritime Law of the United States of America, not including, however, any of its conflicts of law rules which would direct or refer to the laws of another jurisdiction. IN WITNESS of their agreement, each party has caused its authorized representative to execute this instrument effective as of the date first above written. GLOBAL MARINE BEAUFORT SEA INC. ALASKA OIL &GAS CONSERVATION COMMISSION By: T.B. ALLEMAN By: DAVE JOHNSON Title: RIG MANAGER Title: CHAIRMAN Date: ff_z~/-~r->/~ '~ Date: E & P SERVICES, INC. April 30, 1997 Mr. David Johnston Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501-3192 Application for Permit to Drill ARCO Warthog #1 Exploration Well Dear Mr. Johnston, 0il & t~as uons. u0mllf~ _~5i~la /~chorago Fairweather E&P Services, Inc., on behalf of ARCO Alaska, Inc., hereby applies for a Permit to Drill an offshore exploratory well, the Warthog #1, in Camden Bay of the Beaufort Sea. ARCO is the leaseholder and operator of record and has employed Fairweather to plan and execute the drilling of the well. The proposed surface location for the Warthog well is in Federal OCS waters while the bottomhole location is in State of Alaska waters. This situation arises due to the water depth over the bottomhole location being insufficient to float the planned drilling unit, the Glomar Beaufort Sea I. The nearest sufficient water depth is in Federal OCS waters as described herein. A Federal Permit to Drill is being concurrently requested of the Minerals Management Service- Alaska OCS Region. Attached find the following: Designation of Agent letter from ARCO .~ Application for Permit to Drill [per 20 AAC 25.005(c)] - 3 copies Application for Permit to Drill [Public Information] - 1 copy Exploration Plan (w/ Environmental Report and H2S Contingency Plan) - 3 copies Not included with this submittal are the following: Site-specific soils information Shallow hazards geophysical information Environmental loading data Rig stability analysis and third party verification ORIGINAL The site-specific shallow hazards geophysical program will be performed in the earliest possible open-water conditions, expected in mid-to-late July. Additional soils data will also be gathered at that time. Environmental loading data is currently being assembled. The rig stability analysis and third party verification will be performed immediately after all the above information has been gathered and interpreted and will be forwarded to your 715 L Street Anchorage, Alaska 99501 (907) 258-3446 FAX (907) 258-5557 Mr. David Johnston 4/3O/97 Page 2 office as soon as possible. The AOGCC is requested to begin review of this application before submittal of these items and advise Fairweather of any additional information required. The AOGCC is requested to keep confidential all information included in the Application for Permit to Drill (except the Public Information copy) as information in these documents is drawn from research and data proprietary to ARCO Alaska, Inc. If you have any questions or require additional information, please contact myself or Bob Gardner in our Anchorage office, phone 258-3446. Sincerelv, William J. Penrose Project Manager enclosures c' Mr. Paul Mazzolini - ARCO STATE OF' ALASi.'qA ALASI' .OIL AND GAS CONSERVATION C .4MISSION PERMIT TO DRILL 2O AAC 25.OO5 []Drill FIRedrill llb. Typeofwell []Exploratory FIStratigraphic Test nDevelopment Oil la. Type of work [] Re-Entry [] Deepenl []Service [] Development Gas [] Single Zone [] Mul~tiple Zone 2. Name of Old'inter .... '5. Datum Elevat'ion (DF °r KB) 10. Field and Pool ARCO Alaska, Inc. 92' RKB (ASL) Wildcat 3. Address P 0 Box 100360 6. Property Designation Anchorage~ AK 99510 ADL 371014 4. Location of well at surface 7. Unit or Property Name 11. Type Bond (See 20 AAC 25.025) Lat: 70° 02' t0"; Long: 144° 55' 35" Wildcat__ Camden Bay (p.ropos~.d) STATEWIDE At top of ~ target interval 8. Well Number Number U-630610 2370' FNL, 718 FEL, Sec. 20, TSN, R29E, UM Warthog No. 1 At total depth 9. Approximate spud date Amount $200,000.00 2384' FSL, 853' FEL, Sec. 20, TSN, R29E, IBM 11/1/97 '12. Distance to nearest property line113. Distance to nearest well 14. Number of acres in property 15. Proposed depth (MD and TVD) 2384' AO~{ 19.2 miles (Stinson) 2560 9000' TVD, ]0,025, MDSS 1i 6. To be completed for deviated wells 17. Anticipated pressure {see 20 AAC 25.035 (e) (2)} Kick Off Depth 1000' m~ Maximum Hole Angle 32 o Maximumsudace ~-,395 psig, At total depth (TVD) h-~,~.h.6 psig 1 :r18. Casing Program Specifications Setting Depth Size Tq_p.~._ Bottom i ---- Quantity of Cement ,~. (include stage data) Hole j C.a..sing, Weight ! Grade ] C.o~_p..!!ng ! Length MD t. TVD i M.D .I...T..VD ..~, ........... . Public Information Copy '; ! I I ! I I ! I 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 MD TVD Structural Conductor Surface Intermediate Production Liner Perforation depth: measured true vertical ~0. Attac'hments [] Filing Fee [] Property Plat [] BOP Sketch [] Diverter Sketch [] Ddlling Program [] Drilling Fluid Program [] Time vs Depth Plot [] Refraction Analysis [] Seabed Report [] 20 AAC 25.050 Requirements ................................ ........ Contact Engineer Name/Number: W-' J. Penrose, 258-.TCd~6 Prepared By Name/Number:w. j. Penrose, 258-3/-d,6 21. I hereby certify that the foregoing is true and correct to the best of ,my knowledge, . Commission Use Only [ ' ApprovalDate t See cover letter Permit Number APl Number i for other requirements 50- , Conditions et Approval' samples Required I' I Yes [i] No Mud Log Required I I Yes I I No Hydrogen Sulfide Measures EIYes l'i'l No Directional Survey Required t i Yes I I No Required Working Pressure forBOPE E32M; L..;3M: i'i~ 5M; [i}10M; [.' 15M Olher: by order of . _A?.!:.~.! .(:! ?_(!_..[.! ?_ Commissioner the commission Date t elm 10-,101 l;~ev. 12-01-85 Submit In Triplicate UNITED STATES COAST GUARD TEMPORARY 'CERTIFICATE OF INSPECTION This Temporary Certificate of Inspection is issued under the provisions of Title 46 United States Code, Section 399, in lieu of the regular certificate of inspection, and shall be in force only until the receipt on board said vessel of the original certificate of inspection, this certificate in no ease to be valid after one year from the date of inspection. VESSEL. OFFICIAL NUMBER CLASS GROSS TONS OWN ER/ADDR 'HOME PORT ~Flremen/Watertendar s r ---- The'fOlio-wing domPlem~nt of licensed °fficeCs' and crew is reqUired to be carrie'd; included in which there must be Certificated Li feboatmen and Certificated Tankermen: ~1 st Class Pilot Able Seamen ~Chlef Engineer I--" Chief Mate Class Pilot Ordinary Seamen ~l st Asst. Engineer ~.Ollers ~ 2 nd Mate ~ Radio Officer Deckhands . , 2 nd Asst. Engineer . Mate(s) . Operator(s) .~ ~ Engineer(s) _../ In addition the vessel may carry ~_~ addition to the crew, and other persons in the crew, passengers, persons in Total persons allowed Maximum steam pressure allowed ~.//~ , p.s.i. RoM'r, PE F~M ITTEI~ Inspection of the above vessel was completed on / ~'"'/~V~ ~--"U-O C,~,..a, u~f~HEREBY CERTIFY that on this date the vessel was in ail respects in conformity with applicable vessel inspection laws and regulations prescribed thereunder. ':ERIN Q~R ~,, ~NE INSpEcTIoN INSPECTION ' E. ~~, C~/~T_AIN, USCG ] WEEPEEN ~_~KA ! , ~;ZI~ -- ' I I i ~?. or ,,^~s,. usc6. c6-~s4 l,~v. z-7~l ANC-96-013 PREVIOUS EDITIONS ARE OBSOLETE GPO 9~6-O83 D£gLR't'W-~'T OF TRANSgOR~kTION U~I:E~ f&T£S COAST CUkRD Officer in Char&e " 'the Inspection C St., Box 17 O~CR&TrOK/PROCCDURg,' II,MS'IsSUED: _ I~6H5 ~OT suBsYs~o~zo., (~) ~es; (4) c~UsS: (5) q'au.8~.:- ~~~. ~) ~u~ss~ or ~sssc~vs u~s, ~/~ s~s~s~: · (~) . suosrs~~ (~~, _ _(~) ~Te~ (4) C~s~-: (5) q OPgRAIIO~/PROCBOgRET ITgMS-MlSS~P, _ ITEMS NOT CO/S: GU/RD SU~rS~(Z) uoc~Io~, (3) rzP~: (4) clus~: (5) q __ __ . -- ._ ,, ~ :,- IO~Z: ~ (E[. D1) IOHB~R O~ O~r~~UKrTSx~ SYSTEM: (1) sgosTs~; (z) bOCkZIOi~__(3) zreg~ _~~ ~~{-- (5) q NU'H~R CXTgGORY (~ CkSOALTY DAMAGE: -'-.--~IEL F4ILURE: OPgRATIOK/PROCED~RE~ ITgHS HISSING/OUTD&TgD~ ~ ITEMS Ohall be completod to ~he saCiafaction of nn To: Paul Mazzolini Fx' 265-6224 To: Bill Penrose Fx' 258-5557 To: Jeff Walk_er____. Fx' 271-6805 Subject: ARCO's Warthog No. 1 Well, Questions and Comments. m-wart.doc Comments 2 pages, Attachments 7 pages, Total 9 pages. For the AOGCC, we have the following questions/comments on the drilling portion of the 10/7/97 application to drill ARCO's Warthog No. 1 well. Questions/Corn ments . . What happens to the drilling fluids and cuttings? Discussion of Pressures and Potential Drilling Problems by Depth. AOGCC geologist, Robert Crandall, advises that in the interval 1000' to 4000', faults and gas sands are possible/probable and the drilling program should reflect the likelihood of encountering them. . DIVERTER SCHEMATIC. This shows a 2000 psig annular preventer, a spool with 2 - 10" side outlets, each side has a hydraulic (against the tree) and a manual 500 psig valve. Comment 1: the manual valves are not necessary and increase the possibility of malfunction in that they may be closed when needed. Comment 2: the schematic does not show or state that the annular preventer and the hydraulic valves are coupled so that the valves automatically open before the preventer closes. . BOP Closinq System and BOPE Testing. The 13-3/8" BOPE has a 5K annular preventer and 10K rams, spool and valves. The "pre-spud" test is to 75% of rated working pressure (7500 psig); thereafter, the test pressure is listed as "80% of the burst rating of the most recent string of casing in the well". Comment: to make procedures easier, after the pre spud test, we suggest the BOPE be tested to5000 psig. . DIVERTER EQUIPMENT TEST. The procedure says to test the diverter to 100 psig - since the diverter is on 20" casing, this would create a force of approximately 31,000 lbs., on the 20" which is set at 227' RKB (100' BML). Comment: don't pressure test the diverter, test for closure with water or other suitable fluid. . Diverter Equipment Test. Step 8 states "Open annular preventer and make certain the diverter lines valves are in the closed position for drilling operations." Comment: This statement indicates that the valves and preventer are not connected hydraulically so that when the diverter actuation button is pressed, the valves automatically open fully before the diverter completely closes (20 AAC 25.035. (b)(1). , TEST PROCEDURES FOR B.O.P. SYSTEMS (Cont'd). This section states that the equipment is to be tested at the high pressure, then at the lower pressure of 200 tO 300 psig. Comment: to determine BOPE integrity at Iow pressures, it must be tested at the Iow pressure (200 to 300 psig) before testing at the high pressure. Formation Integrity Test IFIT) and Leak-Off Test (LOT) Procedures. After cementing the 13-3/8" conductor and drilling out approx. 20', and FIT to leak-off must be conducted to determine the quality of the cement job and the ability of the formations to support heavier mud weights. Comments: 20 AAC 25.030. (b)(3) "after drilling no more than 10 feet of new formation 'below the shoe of the conductor' a pressure test must be obtained by testing to formation leak-off to aid in determining a formation fracture gradient." Leo J. McClure MAY, 1977 HOUSTON, TEXAS can expect surge pressures of approximately .5 ppg during drilling operations, a liner will be required to prevent lost returns by the time a mud weight of 16.7 ppg is reached. It might be possible to avoid setting a liner by drilling deeper to set easing opposite 13.0 ppg pore pressure formation. With surface easing set at 2,000 feet in normal pressure formations, however, the fracture gradient will be only 12.9 ppg at the bottom of the surface pipe. Thus, additional surface easing would be advisable. An alternative method involves preparing a set of curves of calculated fracture gradient versus depth for various values of pore pressure for the planned location. The curves can be very useful in planning the casing program, because numerous combinations of casing set- ting depths, pore pressures, and mud weights can be studied quickly. Effect of Shaliness As mentioned in the preceding discussion, one of the important factors is the nature of the rock. Increasing shaliness causes an in- crease in breakdown pressure. Unusually high fracture gradients have been observed even at shallow depths in offshore areas near the Mississippi River. PILOT tests have been used successfully there to establish K factors for materially increasing prediction reliability. Offshore Fracture Gradients Offshore fracture gradients are calculated fundamentally in the same manner as land gradients. However, since the uppermost inter- val between the sea floor and wellhead is water, which is considerably less dense than rock, the overburden pressure gradient is lower than for a comparable onshore location. As a result, fracture gradients can be lower, substantially so in deep water and shallow formation. The reduction may at times result in the fracture gradient becoming the controlling factor in the determination of the number and setting depths of conductor and surface casings. The following example shows the effect of drilling the same well (1)on dry land and (2) from a floating rig in 1,500 feet of water. Example 2 Given: (1) Casing set at 1,000 feet below the ground or below mud line. (2) Mud weight = 10 ppg; seawater weight = 8.55 ppg. (3) Po from ground or mud casing seat = 15.7 ppg (bulk density log). (4) K = .43. line Land Location Water Location fG = K(Po-Pp)+Pp Po = 1500x8.55+1000x 15.7 1500 + 1000 = .43(15.7 -- 8.6) + 8.6 = 11.4 ppg equiv. = .43(7.1) +8.6 .~G = .43(11.4-8.6)+8.6 = 3.05+8.6 = 1.2+8.6 = 11.65 ppg = 9.8 ppg Formation will not fracture Lost returns. The above, of course, assumes that the effective stress ratios will be the same for the two locations, an assumption which could be in considerable error. Field measurements have shown that, particularly in offshore areas, the K values are sensitive to depositional environ- ment, or shaliness of the rocks, so the Pressure Integrity Leak Off Tests discussed next are a must for improving reliability and accuracy of the predictions. Fortunately, it appears that in the deeper waters, particularly in the offshore areas of the Gulf of Mexico, the fracture gradients in the upper part of the hole are unusually high because of high shale content tending to offset the problem caused by the lower density water layer. Pressure Integrity Leak Off Test Accurate measurement of the fracture pressure gradient below the casing shoe is extremely important during the drilling of a well. Many of the critical decisions such as casing setting points and alternatives during well control operations are based on this value. This measurement can be made through a relatively simple field procedure, a Pressure Integrity Leak Off Test (PILOT). The same basic procedure can also be used to pressure test the casing and to check the cement job around the casing shoe. The guidelines that follow are designed for uniformity, to make interpretation easier and to minimize the cost of performing these tests by requiring less rig time. The Pressure Integrity Leak Off Tests are necessary data on critical wells, especially where abnormal pressure is anticipated, or where the final mud weight is not known. It is recommended that PILOT data be gathered on all wells where the cement job is questionable, the fracture pressure gradient is not known, and/or final mud weight is not known. This generally applies to wells that will require II -9 greater than 11.5 to 12.0 ~' mud weights. Conversely, the PILOT is not'intended for those wells where the fracture pressure gradients and final mud weights of less than 11.5 to 12.0 are certain. PILOTs are mandatory by the USGS on offshore wells in the continental U.S.A. The author recommends these tests on all wildcats and overpressured wells regardless of their location worldwide. They are preventative measures to help control formation influxes into the wellbore and prevent disastrous blowouts. The theory behind the Pressure Integrity Leak Off Test is that through the controlled imposition of a pressure upon the mud column in the wellbore, some small vertical fractures are induced into the formation. A small amount of whole mud is forced into these fractures; when this occurs, the pumping is stopped and the pressure held for a short period of time to observe the "bleed-off." The pressure is then released at the surface and drilling can be resumed immediately. ~J There is conclusive ~vide-n-ce th~'~ these sn~all fractures heal or close as soon as the pressure is released because there are no proPpants in the whole mud to hold them open. Hence, there is no damage to the~j ~ll_bgr_e.~.r-'~]~t~e "t~Ur~50'~e of this tes{ is--t° determine the maximum mud weight the hole will support before higher mud weights are required. There is now enough evidence to indicate that all types of formations, carbonate-evap- orite as well as sand-shale, can be safely pressured up to obtain the fracture pressure gradient data without any permane~ the wellbore_~. ~n '~'~C~,-tfie- hol~ in~t~ ~'as subsequent pressure te~ts ~re run! ~_epths with higher mud weights, __.__.~ General Procedure The Pressure Integrity Leak Off Test is performed by closing the top BOP and slowly pumping mud into the well until either the specified casing test pressure or the PILOT limit for uncased holes is reached. During the course of the test, a graph of surface pressure versus cumulative volume pumped must be constructed to determine when the pump should be stopped. Fig. 7 is a typical pressure versus volume plot of a PILOT test where a short section of open hole was exposed below the casing. Once the initial slack, Point A, in the system is overcome, there is a constant pressure increase for each fraction barrel of mud pumped so that the points fall on a more-or-less straight line. This is the same effect that would be seen when pressure testing a casing string prior to drilling out the cement shoe. II -10 Figure 7 Typica/ P/LO T P/ot PILOT LIMIT / ~-. ,/-~SHUT PUMPS ~ DOWN / / END OF TEST INSTANTANEOUS SHUT-IN PRESSURE SHUT-IN TIME SLACK IN SYSTEM CUMULATIVE VOLUME PUMPED~ The trend of constant pressure increases for equal volumes pumped continues until Point B, where the plotted points begin to bend to the right. Starting at Point B, the formation through tiny fractures begins to accept whole mud since less pressure increase is seen for an equal volume of mud pumped. Point B is called the PILOT "Limit", and the surface pressure is usually converted into ppg equivalent mud weight. It is sometimes necessary to record several more points as the curve continues to bend away from the straight line to ensure that the PILOT Limit has been reached. More will be said about this additional value later. At Point C, the pumps are shut down and the instantaneous shut-in pressure is recorded (Point D). Between Points D and E, the well is left shut-in to observe the rate of pressure bleed-off of filtrate into the open hole. This bleed-off time is a gauge of the porosity of the formations in the open hole as well as the water loss rheology of the drilling fluid used to conduct the test. Calculate Formation Fracture Pressure The pressure recorded at the PILOT Limit is used to calculate the formation fracture pressure (equivalent mud weight) as follows: Equivalent = Mud Wt. -I- PI LOT Limit (psi) Mud Wt. In Hole Constant x Csg Seat Depth-feet (TVD) Figure 8 Typical Surface Casing Plot 1000 9OO 800 700 ~00 soo 300 200 100 o 0 1 2 3 4 CUMULATIVE VOLUME PUMPED (BBLS) The constant is 0.052 for a pound-per-gallon system and 0.007 for a pound-per-cubic-foot system. The metric system conversion is as follows: PILOT Limit (Kg/Cm2) EMW (sp.gr.) = MW in hole + .1 x csg seat depth-meters (TVD) of the drill pipe. Close the ram preventer above the drilling spool. Begin pumping mud down the drill pipe at a constant rate. Record the drill pipe pressure for each one-fourth or one-half barrel pumped and plot versus cumula- tive volume. 3. If testing on the way out of the hole is hazardous from a well-control standpoint, then the test should be conducted on the way into the hole. After running the bit below the first sand, circulate at least the volume of the drill string to: a. Ensure a uniformly dense column of mud in the drill string. b. Wipe off the static filter cake build- up opposite the permeable sands just below the casing; if this is not done, the fracture pressure gradient is progressively marched down the hole which results in misinterpreting the PILOT Limit value as an erroneously high casing seat gradient. c. Break up the gel strengths in the annulus; then pull the bit back into the casing and proceed as in Step No. 2. Specific PILOT Procedures The procedures for running Pressure In- tegrity Leak Off Tests at the following five wellbore stations are designed to obtain maxi- mum results with a minimum of rig time and effort. They are essential on critical wells and must be carried through to completion to make sure the data yield a clear and definite inter- pretation. Recommended PILOT Procedure It is possible to perform PILOT's tripping in or out of the hole, and by pumping down the drill pipe, annulus, or both simultaneously. Each operational procedure has some merit, but can also introduce errors into the test results. Errors result from non-uniform density of the drilling fluid in the drill pipe, from the barite slug before tripping, and in the annulus from cuttings in the mud, and from pumping friction. The fewest errors are introduced by using the following procedure: 1. Perform the PILOT on the way out of the hole. Gelation of the mud is not as great at this time as it would be if the test were performed when going back into the hole. Also, if the cement job is faulty, then a squeeze tool can be picked up on the trip out of the hole after performing the PILOT. This eliminates an extra trip if the test is performed on the way into the hole with a new bit and the cement is found to be faulty. 2. Pull the bit into the casing just above the casing shoe and circulate the slug out CASING PRESSURE TEST PROCEDUI{E. Good operating practices and the various State and Federal regulatory agencies require that each string of casing be pressure tested prior to drilling out. It is suggested that this test be used as a calibration for the tests to follow. An example surface casing pressure test is shown in Fig. 8. The procedure is as follows: 1. Test before drilling out the cement and guide shoe with the bit positioned at the float collars. 2. Close a preventer above the drilling spool and begin pumping at one-fourth to one- third barrel-per-minute down the drill pipe. 3. Measure the volume and plot versus drill pipe pressure until the required test pres- sure is reached. 4. Shut down the pump and record the instantaneous shut-in pressure. Hold the pres- sure for the period of time specified by the regulatory agency. In unregulated areas, hold the pressure until you are convinced the casing is not leaking. 5. Bleed off into the trip tank and record the volume of mud recovered. Compare II -11 with the theoretical volume ~uired for that size and depth of easing (Refer to Graph 1 in the Appendix.) CEMENT PRESSURE INTEGRITY LEAK OFF TEST PROCEDURE. This test is designated to check the primary cement job around the casing shoe bonding it to the formation. The PILOT 6OO Limit from the test should be at least as high as the predicted fracture pressure gradient for the area. If the exposed formation or cement will not hold the predicted fracture pressure gradi- ~ 50o ent value, then the casing shoe may need to be ! squeeze-cemented. An example of a surface ~ -- 400 easing cement pressure test where a permeable ~= formation is not exposed in the open hole is ~ shown in Fig. 9. ~ 3o, 1. Drill out ten to fifteen feet of a new ~ hole below the casing shoe. ~ 2. Pull up into the casing above the = ~ 20l shoe. 3, Close a preventer above the drilling spool and begin pumping down the drill pipe at the same pumping rate used for the Casing ~ol Pressure Test (one-fourth to one-third barrel- per-minute). 4. Measure and plot cumulative volume pumped versus drill pipe pressure during the test until the PILOT Limit is reached. 5. Shut down the pump. Record the instantaneous shut-in pressure and trap the pressure for ten minutes or until it levels off, whichever comes first. Record shut-in pressure decline at one-minute intervals. 6. Release the pressure and record the volume of drilling fluid recovered in the trip tank. 800 7. Compare the plot with the Casing Pressure Test or with the theoretical build-up 700 curve for that casing size and setting depth. 60O (Graph 1.) ~ 8. If the cement job is good, the build- - "' 500 up curve should approximately parallel the ~ previous easing pressure test or the theoretical ~ uJ 400 build-up curve (Graph 1), If a sand is exposed ~ the high rate of filtration will require a greater ~ ~ 300 volume of mud to be pumped, so the slope of ~: the plot will not be flatter. The pump rate ~ 200 should be such that the slope of the plot is very nearly parallel to the casing pressure test slope. ~oo FIRST OPEN-HOLE TEST BELOW CASING. This test is to be conducted on the first trip for a new bit after drilling a sand section, usually a hundred or more feet. Anomalies that occur in the plot of barrels of fluid pumped versus pressure could result in premature pump shut- down before the PILOT Limit is actually reached. Be sure whole mud is pumped into the II-12 Figure 9 Typical Surface Casing Seat PILOT PILOT LIMIT (550 / ~-~ ~,~SHUT PUMPS ~ DOWN / / INSTANTANEOUS SHUT-IN PRESSURE END O F TEST F SHUT-IN ~ I 4 MIN DATA: 133/8"CASING@3,000' TD: 3020~ MUD WT = 9 PPG PUMP RATE = 1/4 BBI,/NIlN CUMULATIVE VOLUME PUMPED (BBLS) Figure 10 Typical First Open Hole PILO T Below Surface Casing / ~A~ PUMP STOPPED / ~ ___--~(~'~/~('~-)~-INSTANTANEOUS PILOT LIMIT ~ % I SHUT-IN I WELL DATA: / ~3 - 3/8" Cs~. ~ 3000' / ID - 7000' ~ ~.2 PPG Mud 1/2 B~M ~ate 1 2 3 4 5 6 CUMULATIVE VOLUME (BBLS) formation before shutting down the pump, as shown at Point C on Fig. 10. The procedure for running the test and plotting the results is the same as previously described for the cement integrity test, but the puh,g rate should be increased to ½-3/4 barrel-per-minute in order to overeome filtration loss into the sands. The PILOT plot will be very similar in shape to Fig. 10. SECOND OPEN-HOLE TEST BELOW CASING. Hole integrity should be evaluated before: (1) drilling into the transition zone while looking for a casing seat, (2)drilling into a potential lost-circulation zone, or (3)increasing the mud weight significantly. The purpose of this test is to determine whether the primary cement job is still competent or whether a less-competent zone has been drilled since the last test. If this second open-hole test shows that the hole integrity is not at least equal to the first open- hole test value, then either the primary cement job has failed or a weaker formation has been drilled. If the latter is suspected, it may be advisable to run induction--electrical and acoustic logs to define the stratigraphy, espe- cially if it is planned to set the protective casing in a very high pore pressure (13.0 to 15.0 PPg). The test procedure is the same as before; however, the pumping rate should be increased to overcome filtration losses. The rate should be in the 3/4 to 1½ barrels-per-minute range. It will depend on how many permeable formations are open and the theological properties of the drilling fluid. This test should be completed in less than 15 minutes. If it is apparent that more than 15 minutes will be required, stop pumping, release the pressure to zero, and commence pumping at a higher rate. A typical example is shown in Fig. 11. Figure 1 1 Typical Second Hole PIL 0 T Below Surface Casing 600 500 400 300 200 1 O0 0 CUMULATIVE VOLUME (BBLS) OPEN-HOLE ~i~oT ON ABANDONMENT. This test is run routinely during the plugging of a dry hole. The information gained from these tests is necessary to build empirical data for better definition of fracture gradients, especially in the less densely drilled basins. Open-hole PILOT on abandonment is an economical method to obtain the data. The portion of the hole tested by this method extends from the open-hole cement plug (if set) to the shoe of the deepest casing string and mud will be lost to the weakest formation exposed when the PILOT Limit is reached. For this abandonment PILOT to be meaningful, the following procedure should be used: 1. Set a cement retainer on drill pipe near the bottom of the deepest casing in the well. 2. Disengage drill pipe from retainer and circulate the drill string volume to ensure a consistent mud weight in the drill string. 3. Engage the retainer. Perform the PILOT by pumping at a constant rate'down the drill pipe. The pump rate will depend on how many permeable formations are exposed, but most of the time should be in the 3/4 to 1½ barrels-per-minute range. 4. After injection is established, pump in five to ten barrels and then read instanta- neous shut-in pressure upon shutting down the pumps. The shape of the resulting PILOT plot should closely resemble the PILOT plot per- formed earlier at this casing seat. 5. Proceed with the abandonment as planned. Interpretation of PILOT Plots The following plots represent ideal pres- sure integrity curves. They illustrate an incom- plete test, a complete test, and a cement channel test (poor cement bonding of the casing to the formation). INCOMPLETE TESTS--GOOD TESTS. The primary purpose of the PILOT is to determine the fracture pressure gradient of the formations exposed below the casing shoe. In Fig. 12, the test was not carried to the PILOT Limit. Although the test pressure was above the predicted fracture pressure, the actual fracture pressure was not determined because only shale was exposed in the open hole. In Fig. 13, the test was carried to comple- tion. Local experience and knowledge plus previous PILOT data quality and quantity will determine whether it is always necessary to go to the PILOT Limit as shown here. As a general rule, if only shale is exposed in the open hole it is recommended that the pressure not be run II -13 ~. ,~j, ~ .~ ; ~x ~ ~ ~: ! ~' ~ v' '~ ~' °*-'t' ' ,'~ , , ~. ' /~r~ ~2-- -- ...... ~2~ T4 ..... Incomplete Test- Possible Slowdown in Incomplete Test - Only Shale Exposed Pumping Rate Pr~dic~ ffr~c~ur~ Pr~ssur~ ~~~Volume~ I I Figure 13 Figure 15 Good Test - Only Shale Exposed Good Test - Stop Pump, Repeat to Check Bend I I ~redicted Fracture Pressure ~ressure // s/ /sto~ I / / ~ / / ~umps Vol~mo Volume excessively above the predicted fracture pres- sure because of the possibility of breaking down the cement which may not be fully cured. An incomplete test, as illustrated by Fig. 14, may be caused by a slowdown in the pump rate, a high filtration loss into permeable sands, sloppy drilling fluids, a leak in the system, or a bad cement job. If, during the test, the bend appears below the expected fracture pressure, ii is advisable to stop pumping for several minutes to allow the pressure to bleed off below the pressure at which the bend was first observed, then resume the test at the same rate (see Fig. 15). This procedure will tell whether or not the bend was due to one of the above listed causes. CEMENT FAILURE. Quite often a cement failure will cause the characteristic shape of II -14 Figure 16 Cemen.____~t Channe~l- Repeat four Confirm_~ation / Predicted Fracture Pressure Volume PETRO$: LANSMB.WERNER1 FIELD 17100. WELL 1100. Dt~PTIt ( Dmtum set to t,~;L 2000 ..... j, ...... ! ............. , ~" / . ~000 : ' ..... ~ .... , . 4000 ..... ~ .... i i ' i ......... · . ~000 ' tu_ ' ' . : '!"' ' ' · . gO00 . - :~1 · , . ~ooo .... -- , S~d2~ 8000 ....... ' ....... ' - - ~ . $000 ~ ' ' ~ ' ~ - ~ - · ...... 10000 ~ ~¢ - ' "~- ~ ~'~--~--- 17~: .... : ....... ' ~ ''" .... -~ . ; _ . ,, . ....... : ..... .,., , ,.. . ~-:; ~OO 120 , 240 · ~ ~IO~ (~) Kick/Flow Repeat Formation Drill Stem Test Production Prcssur~ Leak-off Test Lost Circulation Zone~ Formation Top Figure 1. Geopressure trend analysis and calibration at Wild Weasel well. lOOO 2000 3000 4000 5000 GO00 7O00 8000 9000 10000 0500 DEPTH 2000 4OOO 6000 8000 10000 32000 14000 Proposed well 'O'ELL: W2~J~THI3(~ 16000 80 3.00 120 140 36{D E, ? 8 10 L~N{hmmnk ~ = -4.75754e-~ 36 , 5 L. 2000 4000 GO00 8000 10000 12000 14000 l~O00 8 Figure 2. Seismic interval transit time and Predicted mud weight at CDP 548. ARCO Exploration and P~ oduction Technology Date: May 23, 1995 Subject: From/Location: Chi Young Telephone: 509-6896 To/Location: Paul Anderson Internal ~orrespondence Time deoth relation for Geopresst~re Pre0iqation on Line CBV93-14 PRC-D3314 ATO-1410 For your reference, enclosed please find a plot and the corresponding table which shows the time-depth relationship at CDP 548 on the seismic line CBV93-14, which is near the proposed well location. On the time-depth plot, the sonic log is converted from the interval velocity curve derived from the high resolution velocity analysis of the seismic data as we discussed in the previous memo. This can provide you a rough estimate of the depth range of your target zone relates to the geopressure and seismic time section. However, since 'the seismic velocity was not calibrated with any well information, and considering the problem with converting stacking, velocity to interval velocity, we must be very careful when using this kind of time-depth relation. CC. Daly, Cathal Garrard, Dick Kuo, Lih 'Winfre4~i': Mike ".'" PRC -D2302 ATO-1320 ATO-1326 ATO'1428' ARCO Exploration and i~r°duction Technology Internal Correspondence Date: Subject: ./ From/Location: ChiYoung ~//'~ PRC-D3314 Telephone: May 17, 1995 Geouressure Predication on Line CBV93-14 T.K. Kan R~-C-D3231A 509-6896 509-6454 To/Location: Paul Anderson ATO-1410 Geopressure analysis for the seismic line CBV93-14 has been completed. For the shallow part of the seismic section, only mild geopressure anomaly is observed, with the predicted mud weight less than 13 lb/gal at around 2.5 seconds. This memo summarizes the calibration procedure and the result of the geopressure prediction. The geopressure prediction work was carried out using the AEPT software package PPFG which is based on the procedure described by Kan and Sicking (1989 AEPT RR 89-0035). Andrew Wu of AEPT processed the seismic data and used AVEL-UHCI to derive the high density velocity field. This velocity filed is used to calculate the pressure gradient. There is no well located on this seismic line. The nearby well Wild Weasel was used to calibrate the pressure prediction. We did not include the Stinson #1 well in the trend analysis, because the quality of the shallow part of the sonic log for the Stinson #1 well is not very good. The first step of the pressure prediction is to determine the normal compaction trend shown in Figure 1. On the left hand side of Figure 1, the green and red dots are interval transit time for the shale picks. The green dots are used to establish the normal compaction trend (red line) which has an intercept of 193 gsec/ft' at the surface and a logarithmic slop of -.0000476. The variation from the normal compaction trend, AAT, is an indication of pressure. This trend line and the interval l~ransit time derived from the seismic data are used to create a 2D AAT section. The second step is to determine the constants for the translation of AAT to pressure data AP based on the equation: zS~P = CO + C~(AAT) + C2(AAT)2 On the' right hand side of Figure 1, the actual mud weight used in the Wild Weasel well (green line) is compared with the mud weight predicted using the normal compaction trend and equation (1), with Co = 0.465 psi/ft, C~ = 0.0098, and C2---4.84E-05. The predicted mud weight I~om the log data is lower than the actual mud weight used in the drilling for the shallow part of the well (< 8000 ft) and is comparable for the deeper part of the well (> 8000 ft). Both predicted and actual mud weight used indicate no significant geopressure anomaly. In the Wild Weasel well, there is no information deeper than 9300 ft. In the Stinson 4/1 well the mud weight data indicates normal pressure to the depth about 12000 ft, and the pressure starts to increase rapidly. Accurate velocity field for the seismic line is crucial to the geopressure predication work. We used the high density velocity field generated by Andrew Wu of AEPT using the high resolution velocity analysis process (AVEL-UHCI processes, developed by Herb Swan of AEPT). For line CBV93- 14, we do not have a well to calibrate the velocity field. Based on our past experience, the AVEL-UHCI usually can produce reliable velocity information down to the depth about one cable length for geopressure prediction, if there is no severe structural effect or significant velocity reversal problem. The velocity field is further smoothed with a window of 100 CDPsto suppress the random noise. In general, lower velocity usually is associated with higher pressure and vice versa. How.ever, it is also likely that the velocity variation can be due to lithology changes as well as fluid effects. We must exercise caution when interpreting the result. The curve on the left in Figure 2 shows the seismic interval transit time derived from the AVEL-UItCI process at CDP 548, which is near the proposed well location. The straight line is the compaction trend generated from 'the Wild Weasel well. The curve on the right is the predicted pressure at CDP 548, which indicates normal pressure for the most part. Based on our past experience, the estimated error for the pressure prediction is about 1.24 lb/gal. The error increases for deeper part of the section ( > 2.5 seconds), because of the velocity estimation is less accurate. Figure 3 is a full scale time section plot of the geopressure in the unit of lb/gal, overlay with the migrated seismic section. There is no significant high pressure zone exists in the shallow section (< 2.5 seconds). Below 2.5 seconds, pressure seems to increase quite rapidly, which is similar to what the mud weight data indicated in the Stinson 4/1 well. Please let us know if you need other information or plots with different. scale. Garrard, Dick Kuo, Lih Daly, Cathal Winfree, Mike ATO-1320 ATO-1326 PRC - D2302 ATO-1428 DEi~TH (Dalum eette 140 120 100 80 6. 0 8. 0 ,I0. 0 12. 0 14. 00. 00. 5 J. 0 1. 5 2 0 2. S ~. 0 ~ 1000 ,, / Time Depth Chart Project- WARTHOG LYK Well- WARTHOG Time(msec) Depth 0 20 4O 6O 8O 100 120 140 160 180 200 220 240 260 280 3OO 320 34O 360 38O 4OO 42O 44O 46O 48O 5OO 52O 54O 56O 58O 6OO 620 64O 660 68O 7OO 720 74O 760 78O 8OO 82O 84O 86O 88O 9OO 920 940 960 98O 1000 1020 1040 1060 1080 1100 1120 1140 ].160 1180 0 0 '68 3 136 5 2O4 8 273 0 341 3 409 5 4';7 8 546 0 614 3 682 6 '750 8 819 1 887 3 955 6 1023 8 1092 1 1].60 4 1228 6 1296 9 1365 1 1.433 4 1501 6 1569 9 1638 1 1701 7 1756 0 1809 5 ].863 7 ]919 0 1975 5 2032 8 2091 0 21.50 4 2211 0 2273 0 2336 2 2400 6 2466.1 2532.8 2600.5 2669.4 2739.2 2810.0 2881.7 2954 2 3027 5 3101. 5 317 6 2 ~°51 7 332"7 8 3404 4 3481 7 3559 7 3638 3 3717 8 37 98 1 3879 3 3961 5 Log' CBV14_50_DT Time(msec) Depth 1200 1220 1240 1260 1280 1300 1320 1340 1360 1380 1400 1420 1440 1460 1480 1500 1520 1540 1560 1580 1600 1620 1640 1660 1680 1700 1720 1740 1760 1780 1800 1820 1840 1860 1880 1900 1920 1940 1960 1980 2000 2020 2040 2060 2080 2100 2120 2140 2160 2180 2200 2220 2240 2260 2280 2300 2320 2340 2360 2380 4128.6 4213.6 4299.6 4386.7 4474.8 4564.1 4654.4 4745.9 4838.5 4932.2 5026.8 5122.5 5219.1 5316.8 5415.5 5515.1 5615.6 5716.9 5819.0 5922.1 6026.0 6130 8 6236 3 6342 7 6449 9 6558 0 6666 9 6776 8 6887 6 6999 3 7112 0 7225.7 7340.5 7456.6 7573.8 7692.2 7811.8 7 932.6 8054.7 8178.0 8302.5 8428.2 8555.1 8683.1 8812.1 8942 1 9072 8 9204 3 9336 3 9468 8 9601 7 9734 8 9868 1 10001 4 10134 7 10267 9 10400 9 10533 7 10666 1 ii. 0798 3 Time(msec) Depth 2400 2420 2440 2460 2480 2500 2520 2540 2560 258O 2600 2620 2640 2660 2680 2700 2720 2740 2760 2780 2800 2820 2840 2860 2880 2900 2920 2940 2960 2980 3000 10930 2 11062 0 11193 6 11325 1 11456 3 11587 4 11718 2 11848 8 11979 0 12109 1 12238 8 12368 4 12497 8 12 627 0 12756 3 12885 7 13015 1 13144 4 13273 6 13402 6 13531 8 13661 0 13790 3 13919 7 14049 2 14178 8 14308 6 14438 4 14568 3 14698 3 14828 4 DIVERTER SCHEMA, I Flowline ! ! 500 psi Hydraulic (min.) Valve~ 21 - 1/4", 2,000 psi Schaffer Annular Preventer 500 psi (min.) 21-1/4", 2,000 psi / Hydraulic Valve Spool 500 psi (min.)/' ~500 psi (min.) Manual Valve Manual Valve 20", 0.812" Wall Drive Pipe Note: 10" Outlets are 90° at)ar! Overhead View Diverter Line Layout 290'-6' : ' Port Diverter Line Aft Divem;r Line /'/ : RESPONSE BOAT -,.~ EOUIPMENT'"~ AIR HEATER ~.f LIFE RAFTS -' 2 .... WATER WINCH ~ [[ L .... .J x.J ..... IL ' ...... /~ ..... ~/.1~ [.} .........'.:::4:; :"~ ~ ' ' '~ ~ , .... i ,.~ ................. ~ BOOM ~. ~ I ~ ...... HOUSE , ~' (.] , BOOM -- )~ .....J-4 I PIT, PUMP&POWER }'t~2~._.:~: 3 '' '~ L OGG'NG ......... ~l I M oOU L [ / [ ~ :4:~ LIFE -,, RAFTS "'~ ........ WINCH ........ WATER CANNON SERVICE I SPRAY WELL i MONITOR PUMP L_..J .... ~' .OUSE / QUARTERS rANK HEATING UNITS ACCOMMODATIONS LADDER ~'" GLOMAR BEAUFORT SEA I BOP Stack Schematic Diagram 13-5/8" 10,000 PSI RRSRA 1. 13-5/8", 5000 PSI Hydril type "GK" annular preventer with companion flange to bell nipple. 2. Single 13-5/8', 10,000 PSI type "U' Cameron blowout preventer with H2S trim. Fitted with pipe rams. 3. Double 13-5/8', 10,000 PSI type "U' Cameron blowout preventer with H2S trim. Top preventer fitted with blind rams, bottom preventer fitted with pipe rams. 4. 13-518', 10,000 PSI WP drilling spool. 5. 3-1/16', 10,000 PSI check valve. 6. 3-1/16", 10,000 PSI manual full opening gate valve. 7. 3-1/16", 10,000 PSI manual full opening gate valve. Choke Valves: 8. 3-1/16", 10,000 PSI hydraulic full opening gate valve. 9. 3-1/16', 10,000 PSI manual full opening gate valve. Casing Properties and Design Casing Performance Properties Size Weight (in.) (lb/12) Grade Cnxn Internal Collapse Tensile Strength Yield Resistance Joint Body TVD MD Design Safety Factor* (psi) (psi) (1,000 lbs) (12 RKB) (Pt RKB) T B C 20 169 .812"Wall S-60 13-3/8 68 L-80 BTC 9-5/8 40 L-80 BTC 7 26 L-80 BTC Drive Pipe 227 227 5,020 2,260 1,545 1,556 1,000 1,000 26.5 8.9 4.5 5,750 3,090 947 916 3,700 4,000 7.2 2.2 1.7 7,240 5,410 64i 604 9,000 10,025 3.1 1.5 1.1 * Tensile design safety factors are calculated using pipe weight less buoyancy. Burst design safety factors for 13-3/8" and 9-5/8" casing are calculated using ASP calculations. Safety factor for 7" casing is calculated using TD formation pressure. Collapse design safety factors are calculated assuming complete evacuation of the casing. Casing Setting Depth Rationale 20" 100' BML 13-3/8" 1,000' RKB, MD 9-5/8" 4,000' RKB, MD 10,025' RKB, MD Structural casing to support unconsolidated surface deposits and provide initial hole stability. Conductor casing to provide sufficient fracture gradient for use of the diverter systcm. Surface casing to provide sufficient fracture gradient and well control until TD is reached. The BOP stack will be installed on this casing. Production casing or liner to provide hole stability and pressure integrity during well testing operations. ARCO Warthog #1 Miscellaneous Items Permafrost The presence of permafrost on the North Slope becomes spotty and discontinuous as it extends offshore into the Beaufort Sea. There was some evidence of its presence near the Warthog location during an earlier geotechnical investigation, so it's presence has been assumed to a depth of 1,200' for planning the Warthog well. Lost Circulation Based on information from the offsetting wells and the inferred stratigraphic section at the Warthog location, there are no anticipated lost circulation problems a'lticipated for the 17-1/2" (surface to 1,000') and 8-1/2" (4,000' to TD) hole sections in the Warthog #1. There is, however, some possibility of minor lost circulation in the 12-1/4" (1,000' to 4,000') section. All hole sections will be monitored closely and lost circulation materials (LCM) kept on hand for such an eventuality. Production Pressures As shown on the attached pore pressure plot, the expected pressure at TD is 4,446 psi (9.5 ppg EMW) and will result in a pressure at the surface, with a full column of gas, of 4,395 psi. While a wellhead system designed for 5,000 psi WP could handle this, the completion will be designed to withstand the pressures exerted by stimulation of the interval of interest should it be deemed desirable. The completion will therefore contain 3-1/2", 9.3#, L-80 tubing and a 10,000 psi WP tubing spool, tubinghead adapter and xmas tree. Drilling Within Annular Blowout Preventer Limitations As shown in the Anticipated Surface Pressures (ASP) section, no ASPs are expected in any section of the hole which will exceed the working pressure ratings of the diverter for the structural and conductor hole sections or annular preventer below the shoe of the conductor. BOP Closing System and BOPE Testing The BOP closing system on the Glomar Beaufort Sea I is a NL Schaffer 3,000 psi accumulator with electric hydraulic triplex pump, two air-operated hydraulic pumps, a hydraulic pump control panel on the drill floor, one removed from the drill floor and manifolding valves and regulators for functioning the BOPs, HCR valve and diverter controls. System volumes are as follow: · Accumulator contains thirty four 11-gallon bottles. · The BOP stack contains four rams which each require 5.8 gallons to close. · The BOP stack also contains one annular preventer which requires 18 gallons to close (around 4-1/2" dl-ill pipe). · There are two HCR valves which each require 1.2 gallons to close. Miscellaneous Items Page 2 The BOP system will be tested weekly. It will be initially tested (before spudding the well) to 75% of rated workina, pLe. S. SU~re. Thereafie~:'-}-t--k-,~i'i'-i~"'~'{-~'~i"'t0' rating of the most recent string of casing in the well. For the 13-3/8" casing this is 4,000 psi, for the 9-5/8" casing it is 4,600 psi and for the 7" casing it is 5,800 psi. The divencr will be tested to 200 psi before use. The BOPE Testing Procedures portion of Global Marine's Critical Operations Manual is included. Directional Well The Warthog #1 will be directionally drilled to a bottomhole location located approximately 5,200' to the southwest. A directional well plan is included with this application. Directional surveys will be recorded a minimum of every 100' from the surface to TD. Rig Environmental Response Monitoring While the CiDS' Critical Operations Manual references the use of ice pressure panels for monitoring environmental forces on the sides of the rig, these panels have proven in the past to be insufficiently reliable. Rig response monitoring will instead consist of the measurement of four parameters: Lateral movement will be monitored on a small scale via the centering of the drillpipe in the rotary table. Small displacements of the rotary table relative to the vertical axis of the wellbore will be evident from the off-center behavior of the drillpipe in the hole. Larger lateral movement will be monitored via changes in the position of the walls of the moonpool relative to the wellhead. Initial measurements will be taken in four directions and changes, if any, monitored throughout operations. Vertical movement of the CIDS can occur uniformly as additional settling or by tipping as one side or comer settles relative to the other sides and comers. Uniform settling will be monitored by observation of the distance between the 20" starting flange on the structural casing and the rotary table. Tipping will be monitored via bubble inclinometers oriented in the forward-aft and port-starboard directions. Any movement indicated by these measurements will be evaluated in terms of their current or future impact on the integrity of the wellbore, continued operations and safety of personnel and .operations will be curtailed as necessary. Injection of Fluids The on_l.x.fi[!!ds planned for downhole injection are reservoir fluids produced during l testing operations and drilling/completion fluids contaminated by reservoir fluids to the point where they fail sheen testing. All injection will be via..perforations in tested interval(s). Warthog #1 MUD PROGRAM Interval Summary Fairwcathcr H&P Services, Inc. \Varth% Prospect Beaufort Sca i Drilling Fluid System Seawater- Low Solids Non Dispersed ~ · Key Products Seawater, M-I Gel, M-I Btu', Caustic, Soda Ash, Bicarb, DeR)am X,~ [~ Mica, Nut Plug, Polypac, Tannathin ~ · Solids Control Derrick Linear Motion Shakers, Desander, Desiltcr, Centri£ugc, [~ - Potential Problems Bit Galling ---~ l~','-,FF?,'::,:':b,"::,;:i,?.':.,; ", ".,,! '!', : ":' "...', :.",.' ,',.,,:.,v..,,,;:: ~..~`~Y~i.~`?~!.::!!:.~`i:~.~;~..:`:~.~..`~.`~`~'~:~.~`.:.~..~'~:~.:.~.:.::~`~..:~`.:.~.~.*~.~.::`~:~.~.~``.~:~.7~.~..:.~`.~`~:`~(~`:::.:r~;:~c.~}.~...~;..:~`~:~::..;~:;~.~:~.:~..:~.:~`.~:~:~t:~..~.~`~`~.~::~:2.~`:..~.:.~::~:~(:~:~`..~:.;~;~~ Depth Mud Plastic Yield APl HTHP Total Interval Weight Viscosity Point Fluid Loss Fluid Loss Solids (ft) (PPg) (cP) (lb/100ft2) (ml/30rnin) (ml/30min) (%) 0-1,000 8.8-10.0 8-15 5-10 N.C.- 15 N.C. <8% -- ---. ' ' ~' ' "~ ' ~ ~ '~t~',~,~ ~,t~~'A~r~,,l ~1~~ ~"..... _' ~~~~X~IA~ " ' Drill this interval with Seawater. Utilize prehydrated M-I Gel sweeps to clean hole. If gravel is encountered, raise viscosity. Mix 600 btu'rcls of kill weight Mud (10.5 ppg) using a seawater polymer tbrmulation (2 x esti- mated hole volume) Spot viscous pill on bottom prior to running 13-3/8" casing. Increase mud weight if required by hole conditions. Estimated Drilling Fluid and cuttings discharge for this interval is 1,500 barrels. M.I 1)tilling Fluids L.I..C. ~ '721 West First Avenue DRILLING s)9. o FLUIDS )'7)274-5564. Tole. ~;()'/)279-6729 Fax Interval Summary }:airwcathcr ['i&P Services, Inc. Warthog Prospect Bcaul'ort Sca Drilling' Fluid"System Seawater" P0]3'm'cr SYstmi~" ' ' "'' ""' ' "" Key Products M-I Bar, M-I Ge.], PHPA (Dry). Ho-Vis, Rcsincx, Po]ypac, Tack]c, PH-6, Caustic, Soda Ash, Bicarb, Tannathin , Solids Control Derrick Linear Motion Shakers. Dcsandcr, Dcsiltcr, Centrifuge Pot,,,. eniialPr__~,;blem__~,;LBit. B~tlliilg. l.{)stCil-culati()l.,~ .- _ , ....... ~.~ ..... --~~., ,J Depth Mud Plastic Yield APl HTHP Total Interval Weight Viscosity Point Fluid Loss Fluid Loss Solids (fi) (PPg) (cP) (lb/100ft2) (mll30min) (mll30min) (%) 1,000-4.,000 9.0- 10.0 8-15 5-10 8-10 _ N.C. <10% Build Seawater polymer mud system with PHPA (Dry) polymer, Fie-Vis, and PolyPac. Prehy- dra. ted M-I Gel can be used for additional viscosity. Estimated Drilling Fluid and cuttings discharge for this intcrwd is 2,000 bah'els. 1',1-I I')rilling Vluids L.L.C. 721 \Vest Fir,si Avenue Allc!~)rage., Alaska 99501 ¢)() :;)274-5564 Tole. t()()7 )2.79-6729 Fax DRILLING FLUID5 Interval Summary Key' Products M-i Bar, M-I Gel, Pt-tPA (Dry) F10-Vis, Rcsinex, Polypac, Tackle, PH-6, Caustic, Soda Ash, Biota-b, Tannathin Solids Control Derrick Linear Motion Shakers, Dcsandcr, Desilter, Centrifuge . ~ . . ..... . .... ~ -' . ,..~~~~~l~;~~ . .~ . , - . ;:.~i:,.','4;!'.:?i:;cii:~;?$'i:!..P 5:.,;;i'..-c~i,'.::L5:':,.~.:i'.,':~?,5:.;:?i',::.;:.:':., '.":.:~:'.':Li,: ,~ ' 5( .. . 'q:,iS. ., '. ?.:, , .. ' .~;i,~:~,¢,L~!,:' ~..'5',;; 5~,¢i!!;¢.':;';7}~,:,:~!/05!~!~;[!;!;,.i!4 :!~i':i'.!'.:~5~5~,.~!,.~=~;ii:=;5:' Depth Mud Plastic Yield APl HTHP Total Interval Weight Viscosity Point Fluid Loss Fluid Loss Solids (ft) (PPg) (cP) (Ib/100ft~) (ml/30min) (ml/30min) (%) 4,000-10,000 9.0-10.5 8-15 8-12 5-8 <i5 <10% · Use the Seawater polymer mud system used in the 12 1/4" imcrval. Treat for cement contami- nation. · Reduce fluid loss with .Polypac and Resinex · Increase theology with Fie-Vis · Maintain PHPA to minimize bit bailing, improve hole. stability, and increase solids pncapsulation. · Estimated Drilling Fluid and cuttings discharge for this interval is 2,4()(}~i,b~qTrels. .... i I ii I i i')rillino Fluids L.L.C. Firs! AvelIuc .,\~i~.l~{,ragc, Ahtska 99501 %1.-55(~ Tole. 7.)-6 7~, Fax DRILLING FLUIDS Estimated Product Requirements Fairwcathcr E&P Services, Inc. Wm'thog Prospect Beaufort Sca M-I BAR 275 Tons M-I GEL, 600-Sacks FLO-VIS 200 Sacks PHPA 200 Sacks PAC 250 Sacks RESINEX 100 Sacks TANNATHIN 100 Sacks CAUSTIC 60 Sacks SODA ASH 30 Sacks BICARB 30 Sacks DEFOAM X 30 cans * 60 Sacks SULF X ES MICA 100 Sacks NUT PLUG 100 Sacks SPOTTING FLUID 25 Barrels Contingency products for H2S and stuck pipe II I I ~1-1 l.)rilling Fluids L.L.C. '721 West First Avenue ,,\~chorage, Alaska 99501 tgt)7)274-5564 Tele. ('~()'/)279-6729 Fax DRILLING FLUID~ 2: I'q DE~^NDER tI DEGAS PIT DESAND PIT II TRIP TANK PUMP8 PILL PIT SUCTION PIT ~.9~) SUCTION PIT ~ Lii l]ll H Ii- II1 II~lt ~. H . . ,-,,', , ~, /i hIi Parker 217 (CIDS) MUD SYSTEM- LOWER LEVEL Warthog #1 CEMENTING PROGRAM Cement Program 13-3/8" Conductor Casin~ Well Data Depth 1,000'MD, 1,000'TVD Hole Size 17-1/2" Volume Excess Volume Required (no excess) Top of Cement Preflush Pipe Size 13-3/8" OD, 68# Mud Weight 9.6 ppg BHST 30°F BHCT 35°F Proposed Cement Preflush: 20 bbl H20 Lead: 487 sx (935 CF including excess) COLD SET III Tail: 432 sx (416 CF including excess) COLD SET II Cement Properties Lead 1,351 CF 100% OH 100% CH 519 CF 208 CF Surface 20 bbl, 8.34 ppg Tail Density - PPG Yield - CF/Sk Mix Water - Gal/Sk Thickening Time- Hrs:Mins Fluid Loss - CCs/30 Min Free Water -Mls Compressive Strength - PSI 12 Hrs 24 Hrs 12.2 1.92 10.53 6:30 0 __ 24 14.95 0.961 3.89 4:00 0 750 1,550 Remarks: Cement Program 13-3/8" Conductor Casing Well Data Depth 1,000'MD, 1,000'TVD Hole Size 17-1/2" Volume Excess Volume Required (no excess) Top of Cement Preflush Pipe Size 13-3/8" OD, 68# Mud Weight 9.6 ppg BHST 30°F BHCT 35°F Proposed Cement Preflush: 20 bbl H20 Lead: 487 sx (935 CF including excess) COLD SET III Tail: 432 sx (416 CF including excess) COLD SET II Cement Properties Lead 1,351 CF 100% OH 100% CH 519 CF 208 CF Surface 20 bbl, 8.34 ppg Tail Density - PPG Yield - CF/Sk Mix Water- Gal/Sk Thickening Time- Hrs:Mins Fluid Loss - CCs/30 Min Free Water - Mis Compressive Strength - PSI 12 Hrs 24 Hrs 12.2 1.92 10.53 6:30 -- 0 __ 24 14.95 0.961 3.89 4:00 -- 0 750 1,550 Remarks: Cement Program 9-5/8" Surface Casine Well Data Depth 4,000'MD, 3,700'TVD Hole Size 12-1/4" Pipe Size 9-5/8"OD, 40# Mud Weight 9.6 ppg BHST 85°F BHCT 70°F Volume Excess Volume Required Top of Cement Preflush 1,550 CF 50% OH 877 CF lead 156 CF tail 1,200' MD Preflush/Spacer Proposed Cement Preflush: 20 bbl H20 Lead: 685 sx (1,315 CF including excess) COLD SET III Tail: 204 sx (235 CF inclu~ling excess) G + 1% A-7 + 1 ghs FP-6I_, Cement Properties Lead Tail Density - PPG Yield - CF/Sk Mix Water- Gal/Sk Thickening Time- Hrs:Mins Fluid Loss - CCs/30 Min Free Water -Mls Compressive Strength - PSI 12 Hrs ~ 80°F 24 Hrs ~ 80°F 12.2 15.86 1.92 1.15 10.53 4.96 6:00 5:00 0 0 -- 1,600 26 2,100 Remarks: GHS = Gallons per hundred sacks Cement Program 7" Production CasinE Well Data Depth 10,000'MD, 9,000'TVD Hole Size 8-1/2" Pipe Size 7"OD, 26# Mud Weight 10.2 ppg BHST 220°F BHCT 140°F Volume Excess Volume Required Top of Cement Preflush 571 CF 30% OH 380 CF 8,000' Preflush/Spacer Proposed Cement Preflush: 20 bbl H20 w/2% Kcl 50 bbl MCS-4 w/2% Kcl ~ 1.0 ppg over mud weight Tail: 519 sx (571 CF) G + 1% BA-10 + 0.4% FL-32 + 0.2% CD-32 + 0.2% A-2 + 0.45% R-1 + 1 ghs FP-6L Cement Properties Slurry Density - PPG Yield - CF/Sk Mix Water- Gal/Sk Thickening Time- Hrs:Mins Fluid Loss - CCs/30 Min Free Water -Mls Compressive Strength - PSI 12 Hrs ~ 220°F 24 Hrs ~ 220°F 16.2 1.099 4.428 4:30 210 0 est 3,000 est 4,000 Remarks: Cement Program Product Description Cold Set III Extended Permafrost cementing system designed to achieve zonal isolation, support casing and set under permafrost conditions. Class G Standart Portland cement used to cement wells as a standard from 0 to 8,000 feet. With additives, this depth is extended to most depths and temperature conditions. A-7 Calcium Chloride, a cement accelerator. FP-6L Foam preventer, to prevent or reduce air entrainment in the mixing process. MCS-4 Spacer/Preflush used to assist in mud removal and act as a water-wetting agent for cement bonding. BA-10 Bonding agent, a dry powder designed to improve cement bonding to surfaces, a non-expanding additive. FL-32 Fluid loss additive, designed to prevent loss of the liquid phase during cement placement. FL-52 Fluid loss additive, designed to prevent loss of the liquid phase during cement placement. CD-32 Cement dispersant, designed to reduce friction pressure in pumped cement systems. A-2 Accelerator/Extender. In small quantities, acts as a setting accelerator. In higher concentrations (>1% by volume), extends the yield of cementing systems. R-1 Cement retarder. Delays the setting time of cement. Warthog #1 DIRECTIONAL PROGRAM Fairweat. her E & P Services, Inc. Field - Beaufort Sea Location : North Slope, Alaska S00 0 500 1000 1500 2000 2500 ~ 3000 '-._,, 3500 4000 __ 0 4500 ._ > 5ooo I--- 5500 6000 6500 7000 '7500 8000 BS()O 9000 L 20 Casing L 1 3 KSO,/p8 Casing 2.50 7.50 <- West (feet) 5bOO ,5000 2500 2000 1500 1000 500 c b C C 5O0 1000 O 1500 .__+. 2000 _+_ Vertical Section (feet) .:> Azimuth 217.0~ wit'h reference 0.00 lq, 0.00 E from slo~ #~ L 12.50 DLS: 2.50 deg per 100 ft 1 7.50 25OO 22.50 I 27.50 V 32.50 ~000 i C Warthog #1 Rvsd 19-Sep-97 3500 4000 ~~8 Casing 4500 ,~~ WELL PROFILE DATA ..... Point ..... MD Inc Oir 'i'VD North Eo~t v. Scc~ Dcg/ioo Tic on o.oo 0.00 217.09 o,oo 0.00 o.ao o,oo 0.00 KOP 1100.00 0.(]0217.091 lO0.O00.00 0.00 o.oo 0.00 End of Build 25DB.,15 35.96 217.092445.8b -34§.43 -263.40436.79 2.50 Torget 8675.17 35.96 217.097413.00 -3223.16 -2436,59 40,t0.510.00 ?~._.End of Hold 10635.85 ~5.96 217.09 9000,00 -4141.63 .-3130.92 3191.g/J 0.00 [s~ I D / 7 Csg Pi ~ ARCO Alaska, ltv, ., Pos~ Office Anchorage, Teieenone 907 ~-~ '21S April 24, 1997 TO: Distribution List RE: Warthog Exploratory Well Designation of Agent Dear Ladies and Gentlemen, Johnst~ n' As some of you may be aware, ARCO Alaska, Inc. (AAI) is planning on drilling the Warthog #1 exploration well offshore in the Camden Bay area of the Beaufort Sea in the 4th quarter of 1997. The surface location of this well is currently in Outer Continental Shelf (OCS) waters and the bottom hole location is in state waters. The Glomar Beaufort Sea #1 drilling rig (also known as the Glomar Concrete Island Drilling System or Glomar CIDS) ,.,~'"~ been selected for-^*"'" ~ o "" p,,~,_,~anc,, of ti,is drhdng operation. AAI has contracted with Fairweather E&P Services, Inc. (Fairweather) to provide mobilization, logistics, drilling, and other services for this well. This contractual arrangement also calls for Fairweather to obtain most of the permits and regulatory approvals necessary to conduct the planned operations. The most notable exceptions to this permitting arrangement are the National Marine Fisheries Services Incidental Take approvals for whales and ringed seals (if required) as well as any permits/regulatory approvals associated with well testing. Fairweather is AAI's agent for permitting matters for the Warthog #1 exploration well as outlined above. Permits and regulatory approvals for this well and its ancillary operations are being obtained in AAI's name by Fairweather. It should be pointed out that, while such a contractual arrangement is new to AAI, similar operations have been successfully conducted numerous times in the past by other oil and gas exploration and production companies (including other ARCO companies) worldwide. In view of this situation, AAI would appreciate any feedback that you may have on this matter at any time during the permitting process. If you have any questions regarding AAI's designation of Fairweather as agent for permitting and regulatory matters for the Warthog #1 well, please call me at (907) 265-6136. Sincerely, Mark Major Exploration Permits Director c: Robert Gardner, Fairweather E&p Servi ~ces, Inc. _ An~o~ E ~ }~3¢ ~ p APR 2 8 1997 .A/asI~ ¢il ,& Gas Oons. C;orn~ss~u' ~Anchorag0 2,42-2603 April 24, 1997 AAI Letter to Regulatory Agencies Warthog # 1 Exploration Well - Distribution List Mr. James Baumgartner Division of Ak & Water Quality AK Dept. of Environmental Conservation 410 Willoughby Ave., Suite 105 Juneau, AK 99801-1795 Mr. Alfred K. Bohn, P.E. Division of Ak & Water Quality AK Dept. of Environmental Conservation 555 Cordova Street Anchorage, AK 99501 Mr. Jon Dunham North Slope Borough P. O. Box 69 Barrow, AK 99723 Mr. Bradley Fristoe AK Dept. of Environmental Conservation 610 University Avenue Fairbanks, AK 99709 Mr. Glenn Gray AK Division of Governmental Coordination P. O. Box 110030 Juneau, AK 99811-0030 iris. jeanr, e Hanson National Marine Fisheries Services 222 West 7th Avenue, g43 Anchorage, AK 99513-7577 Mr. David Johnston AK Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501-3192 Mr. Leon Lynch AK Dept. of Natural Resources - Div. of Land 3700 Airport Way Fairbanks, AK 99709-4609 Ms. Laurie Mann U. S. Environmental Protection Agency Region X 1200 Sixth Avenue Seattle, WA 98101 Mr. Raymond Nye U. S. Environmental Protection Agency Region X 1200 Sixth Avenue Seattle, WA 98101 Mr. Joseph Sautner Division of Spill Prevention & Response Industry Preparedness & Pipeline Program AK Dept. of Environmental Conservation 555 Cordova Street Anchorage, AK 99501 Mr. Steven Schmitz AK Dept. of Natural Resources Division of Oil & Gas 3601 "C" Street, Suite 1380 Anchorage, AK 99503-5948 Mr. Richard Shideler AK Dept. of Fish & Game 1300 College Road Fairbanks, AK 99701-1599 Mr. Patrick Sousa U. S. Fish & Wildlife Service 1011 East Tudor Road Anchorage, AK 99503-6199 Captain E. P. Thompson U. S. Coast Guard Captain of the Port 510 "L" Street, Suite 100 Anchorage, AK 99510 Ms. Mary Weger U. S. Army Corps of Engineers Alaska District P. O. Box 898 Anchorage, AK 99506-0898 Mr. Jeffrey Walker Minerals Management Service AK Outer Continental Shelf Region 949 E. 36th Avenue, Room 603 Anchorage, AK 99508-4302 Revision Date: February 6, 1997 Page: 1 of 3 . o UNITED STATES DEPARTMENT OF THE INTERIOR MINERALS MANAGEMENT SERVICE ALASKA OCS REGION Well OCS-Y~'6~ No. 1 Send submittals to Field Operations at this address: U.S. Department of the Interior Minerals Management Service Field Operations 949 East 36th Avenue, Suite 308 Anchorage, Alaska 99508-4363 Submit a daily drilling report until the final status of the well is established (one copy, no prescribed form) outlining the following: spud date, drilling depth, bottom hole location ( if a directional well), mud weight, principal items of work done during the previous day (drilling, running casing, testing, coring, sidewall sampling, logging, etc.), casing setting depths, cement quantities, casing characteristics, PIT information, type of logging tools run, zones of abnormal pressure, lost circulation zones, depth and magnitude of kicks, and other hole difficulties encountered. The daily drilling report should also include a summary of meterological conditions and ic~-'~iSi:i~'fiiSh's~tha'tmay affect the integrity of the island, .or ability to supply drilling operations by the ice rt~l:-~)ii"~h~..~vent..ice, or:.ic:~-~-~d conditions d effect the drillin · · ................ __ ....... evelope which can g operat~ons,.Bnt~sh Petroleum (Alaska),'lnc:..(BPX),_must identify what remedial.action'g'h'~ije or will be taken to prevent risk to the drilling'-bPeration. Daily reports may be faxed to (907) 271-6504 or delivered directly to the office. Submit as soon as available, but no later than 72 hours after completion of the run, one copy of all field prints of well logs and directional surveys. Submit mud logs, and MWD logs, on a weekly basis. Submit as soon as available, but no later than 30 days after completion of the well, two copies (one blueline and one sepia) of all final well logs, including composite mud logs and MWD logs; two copies of the composite directional surveys; and ~he copy of the digitized magnetic well log tapes (1/2" 8 track, LIS format). o o o 7~ Page: 2 of 3 Submit within 30 days of completion of the well two copies plus one public information copy of Form MMS-330, Well (Re)Completion Report and a Well Summary Report. Note all occurrences of oil, gas, sulfur, and other minerals of potential geological interest on the Well (Re)Completion Report, including all important zones of porosity and contents thereof, cored intervals, and complete details of all drill stem or formation tests. Identify rock units in time-stratigraphic terms showing the depths to the tops of the geologic marker beds on the Well (Re)CompletiOn Report or on a marker electric log. Submit a written notification (Sundry Notice and Reports on Wells, Form MMS-331; two proprietary copies and one public information copy) of intent to change any approved plan of operations for approval. 'Emergency approval may be obtained verbally, but must be followed by the written notice. A subsequent report for a casing string is to be furni~shed on Form MMS-331 for each string of casing run. When a PIT is performed at the casing shoe, furnish the results along with the casing report on Form MMS-331. The results of the PIT should include a plot of pressure vs. barrels pumped. Applications for Approval to Abandon a Well shall be submitted in accordance with 30 CFR 250.111 of Subpart G on the Notice of Intent/Report of Well Abandonment, Form MMS-332. Two proprietary copy of this form shall be submitted plus one public information copy. Submit one copy of all well reports, geochemical analyses, core (and sidewall core) descriptions, and core (and sidewall core) analyses as soon as available. Submit one copy of paleontological report identifying microscopic fossils by depth and one copy of velocity surveys, if run. ' Prior to coring or testing, notice will be given to the Minerals Management Service so that such operations may be witnessed if deemed necessary by the~'I)i, stfi_~ Supervisor. Submit a written notification (Sundry Notice, Form MMS-331; two proprietary copies and one public information copy) of the intent to test'. This notice should include the current and anticipated condition of the well, the sequence of proposed °perations, the perforated test interval depths, the surface and subsurface equipment schematics, planned pressure testing of tubulars and other equipment, plugging or isolating of perforated intervals, disposal of produced gas or fluids, and any other pertinent information. o . Page: 3 of 3 Submit one copy of field well test data within 48 hours of such tests. One copy of the interpreted results (fluid analyses, pressures, flow rates, etc.) of these tests should be submitted as soon as available. Ship samples of all cores, representative cuts, unwashed bulk, and washed (dry) ditch samples to the Minerals Management Service, Regional Supervisor, Offshore Resource Evaluation, 949 East 36th Avenue, Third Floor, Suite 308, Anchorage, Alaska 99508-4363. 10. All operations shall be subject to inspection by Federal inspectors designated by the Regional Supervisor, Field Operations. UNITED STATES DEPARTMENT OF THE INTERIOR MINERALS MANAGEMENT SERVICE NOTICE TO LESSEES AND OPERATORS OF FEDERAL OIL AND GAS LEASES IN THE OUTER CONTINENTAL SHELF NTL 97-1N Effective Date: January 31, 1997 Blowout Preventer _(BOP) Requirements for Drilling MMS is in the process of revising a part of the testing requirements for BOP systems and equipment. The revised requirement will now allow a lessee up to 14 days between BOP pressure tests. MMS makes this revision based on a recently completed study of BOP performance. This study concluded that no statistical difference exists in failure rates for BOP's tested between 0- to 7-day intervals and between 8- to 14-day intervals. MMS will begin the rulemaking process to promulgate this revision into the regulations. The following paragraphs discuss how MMS will administer this revision in the interim. ' Fourteen-day testing ~eframe. lifts revision changes the testing interval requirements in §250.57(c)(3) and §250.86(bX2) to allow up to 14 days between pressure tests. You must continue to test BOP systems according to the other testing requirements found in §250.57 and · §250.86. You may not exceed 14 days between pressure tests. This means that you must begin testing your BOP system within 14 days after the last pressure test. The operator must ensure that BOP tests are initiated prior to midnight on the 14th day subsequent to the conclusion of the previous test. District Supervisors w/Il not grant extensions to the 14-day timeframe except when you are conducting pressure-control operations or remeAial operafion.q for stuck pipe. However, you must test as soon as the situation is remedied (e.g., stuck pipe is retrieved from the well bore). Furthermore, MMS reserves the right to specify a shorter testing timeframe when warranted. New wells and current drilling activities. The revised testing timeframe applies to all drilling operations after January 31, 1997. You do not need to obtain any additional approval from the District Supervisor to test on a 14-day timelmme. Sidetrack and completion act/v/ties. The 14-day testing timeframe applies to sidetrack and completion activities if you use the same or similarly-rated rig and BOP equipment as used to originally drill the well. This becomes effective on January 31, 1997. You must state in your Sundry Notice (Form MMS-124) that you will use the same or similarly-rated rig and FlOP equipment. ~Workover activities. The 14-day timeframe for testing a BOP system does nol apply to workover activities. You must continue to test your system weekly, not to exceed 7 days. BOP prcss~c tc~inK~a_f~cr, lg.i~t~~. You mu~ centfnuc to prc~surc tcst your BOP systcm before drilling out each su-~,ng of c~,ng cr ~' :'~'z",-,- ' ' ~ .... con'z~n'amg operations in cases where you do not drill out the cement Inspection. maintenance, and performance requiremertt~. The current regulations require a lessee to inspect and maintain all BOP equipment to ensur~ that the equipment will function properly. MMS will continue to examine whether specific inspection and maintenance requirements are necessary to ensure high reliability of BOP equipment. MMS will also examine the need for performance requirement;. Date Associate'Director for Offshore Minerals Management This NT£ can also b~ found at the MM~ worldwide, weh~it~, at HTTP.'I/gFW~. MM, g GOV UNITED STA'iE $ DEPARTMLE_.NT OF THE INTERIOR Conservation Division Western Region (Supercedcs Notice) (No. 78-1 ) (Nov. 27, 1978) Not{ce No. 80-1 NOTICE TO LESSEES AND OPERATORS OF FEDERAL OIL AND GAS LEASES IN THE OUTER CONTINENTAL SHELF, ALASKA FURNISHING FOOD, QUARTERS, AS~ TRANSPORTATION TO USGS PERSO~NEL In accordance with 30 CFR 250.11 (a) (3), lessees are requested to furnish, beginning December 13, 1979, food, quarters, and transportation for U.S. Geological Survey representatives to inspect their facilities. Upon request, a lessee will be reimbursed by the United States Government for the actual costs which it incurs as a result of its providing food, quarters, and transportation for a USGS representative's stay of more than 10 hours. Such requests should be mailed to the U.S. Geological Survey, Attention: Administrative Officer, Conservation Division, 800 "A" Street, Anchorage, Alaska 99501. Questions should be referred to the Administrative Officer, at the address above or by telephone to (907) 271-4304. tant nager, "~1 aska Area Approved: February 5, 1980 DIVERTER SCHEM/~,', C I Flowline I ! 21-1/4", 2,000 psi Schaffer Annular Preventer 500 psi Hydraulic (min.) Valve~ 21-1/4", 2,000 psi Spool 500 psi (min.) Hydraulic Valve 10" Outlets* 20", 0.812" Wall Drive Pipe Note: 10" Outlets are 90° apart WELL PERMIT CHECKLIST FIELD & POOL I NIT CLASS PROGRAM: exp/~dev E] redrll F! servE] wellbore seg El ann. disposal para r._.eq, b~rq ~'~"O UNIT#/ ON/OFF SHORE . ADMINISTRATION 2. Lease number appropriate ................... 3. Unique well name and number .................. 4. Well located in a defined pool .................. 5. Well located proper distance from drilling unit bounda~ 6. Well located proper distance from other wells .......... 7. Su~cient acreage available in ~rilling unit ............ 8. If deviated, is wellbore plat included ............... ~o. Operator has appropriate bond in force ............. 11. Permit can be issued without conse~ation order ........ 12, Permit can be issued without administrative approval 13. Can permit be approved before 15-day wait ........... ENGINEERING DA/TE_/~ 14. Conductor string provided ............. 15. Surface casing protects all ~n~n' L~S'DWs ........... N 16. CMT vol adequate to circulate on conductor & surf csg ..... N ~E, .¢ k:_ ~_ 17. CMT vol adequate to tie-in long string to surf csg ........ N 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 abandonment been approved... Y N 22. Adequate wellbore separation proposed ............. N ¢.~. 23. If diverter required, does it meet regulations .......... N L/'/ 24. Drilling fluid program schematic & equip list adequate ..... N 25. BOPEs, do they meet regulation ...... _ .......... N 26. BOPE press rating appropriate; test to .~d::~ psig. N 27. Choke manifold complies w/APl RP-53 (May 84) ........ 28. Work will occur without operation shutdown ........... 29. Is presence of H2S gas probable ................. N GEOLOGY APPR DATE 30. Permit can be issued w/o hydrogen sulfide measures ..... N 31. Data presented on potential overpressure zones ....... N 32. Seismic analysis of shallow gas zones ............. N 33. Seabed condition survey (if off-shore) ............. ~N 34. Contact name/phone for weekly .pro,tress reports ....... ,exp,oratory on,y] ~'~~ GEOLOGY: RNC~ CO Comments/Instructions: © :z © HOW*'ljt- A:\FORMS\chekhst rev 09~97 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. Potential Incidents of Non-Compliance List Identification G-100 Is the facility identified as required? 15(a) W G-101 Is each completion identified as required at 15(b) W the wellhead? ............................................ ~.~ ~;~:.~ ~:~.~ ..;~. ;~;~ ~ ~:~:~ ::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::: Operations G-110 Does the lessee pedo~ all operations in a 20(a) W/C/S safe and wo~manlike manner, maintain all 20(b) equipment in a safe condition, and take all necessa~ pre~utions to co~ect and remove all hazardous oil and gas accumulation or other health, safety, or fire haza~? G-113 Does the lessee make all facilities available 21(a) W for inspe~ion by MMS pemonnel? Are operations conducted in accordance with: G-1'14 Lease ~ipulations? 4(b) W/C/S G-115 Approved appli~tions? 64(a) W/C/S G-116 Approved plans? 30 W/C/S 122 67 :~:~:~-=-:~:~:~:~:~=~:~:~=~=~=~=~=~:~:~:~-;~';~;~=~;~:~';~;~;~;~:~;~;~;~;~;~:-=~-:~-~;~:~;~;~;~;~;~;~;~;~=~;~;~=~:~:~:~:~:~:~:~':~-~-~=~;~=~;~;~:~:~;~;~;~;~;~;t;t;~;~;~;~;~;~;~;~;~;~;~;~:~;~;~;~:~:~:~:~:-~-;~;~;~;~;~;~;~;~;~;~;~;~;~;~;~:~:~;~:~:~:~:~:~;~-;~;~;~;~ Records :':':::':';':':';';':';';'::;;;;;;i'"'"'"" '"'"'"'""'"'"'"'" ................. G-117 Is required pape~o~ submiffed within the 65(b) W time frame specified by regulations 66 83 Engines G-150 Is all exhau~ piping from each diesel 123(b)(5) C engine or engine ddven equipment 52(b) equipped with spa~ a~e~om? G-152 Is each engine exhau~ or other hot 123(b)(5) C sudaces equipped to comply with the 20(a) insulation and pemonnel prote~ion requirements of APl RP 14C, Se~ion 4.2c(4)? G-153 Are all engines with ele~ri~l ignition 53(a) C sy~ems equipped with a Iow tension ignition sy~em? G-155 Are diesel engines which are continuously 51 (b)(2) C affended equipped with an operable remote 80 operated manual or automatic air intake 100 shutdown device? 123(b)(5)(ii) G-156 Are diesel engines which are not 51 (b)(2) C continuously a~ended equipped with an 80 operable automatic air intake shutdown 100 device? 123(b)(5)(ii) PINCHQ, IPINc IAuthodty IAction CK Y ININAI, Cranes G-201 Are record of crane inspections, testing, 20(c) W maintenance, and operator qualifications maintained at the lessee' nearest field office G-202 Are cranes operated only by qualified 20(c) WIG personnel? G-203 Have operator qualifications been achieved 20(c) W by either applicable offshore experience or satisfactory completion of a formalized written employer training program both of which have included work with the vadous types of cranes to be operated and maintained? G-204 Are proper crane operating practices for 20(c) W/C handling, attaching, moving, and holding the load being utilized? G-205 Have manufacturer's recommendations 20(c) W been included in establishing all inspection requirements? Have the following inspections been performed and recorded by a qualified inspector: G-206 Initial (new cranes), and after any major 20(c) C repair or modification to the crane? G-207 Pre-use (crane used 10 hours or less 20(c) C monthly)? G-208 Monthly? 20(c) C G-209 Quarterly? 20(c) C G-210 Annual (All Cranes)? 20(c) C G-211 Is the correct load rating chart for the crane 20(c) C configuration in use visible to the operator at the pdmary control? G-213 Has a crane which has been idle for a 20(c) C period of over 12 months been given an annual inspection before being placed in service? G-214 Are written, dated, and signed monthly, 20(c) W quarterly, and annual inspection reports as well as records of repairs and modifications carded out on cranes kept available at the facility or at the lessee's field office nearest the facility for a pedod of two years? G-215 Is each new crane, or crane undergoing 20(c) C major repair given an operational test by a qualified inspector to ensure crane functions perform as intended? G-216 Are load tests conducted when necessary 120(c) C by a qualified inspector using the referenced guide APl RP 2D, Appendix E? G-217 Are written reports available showing test 20(c) W procedures and confirming adequacy of , repairs or alterations? IPINC IPINC IAuthority I Action G-218 Is a preventative maintenance program 20(c) C established which takes into consideration crane type, frequency of usage, history of maintenance, and manufacturer's recommendations? G-219 Are written, dated, and signed maintenance 20(c) W records readily available at the facility or at the lessee's field office nearest the facility for a period of two years? G-220 Unless the operator is in direct voice 20 (c) W communication with the pilot during helicopter landings/take-offs, is the boom positioned and secured against swinging so as not to interfere with flight operations and is the operator not at the control station? G-221 Is there a fire extinguisher (appropriate size 20 (c) C and type) kept in the cab or vicinity of the crane? . ....... I ......... ,-- -,-,.,.,-,,,, - .... , !!iii~::~i~::i~:ii!i!!!i!i!i!i~i~!~i?.?.!~.!:.?.!i!!!!!i!i!i!i~iiii!!!!!~i~i!!!! !i~ ! ! ?..'i ~ ii !~!!!!~!~!!! ::::::::::::::::::::::::::::::::::::::::::::::::::::: Electrical G-231 Are electrical installations made in 53(c) W/C/S accordance with APl RP 500 and APl RP 14F, except Sections 7.4 and 9.4? Marking of Equipment ; ;,;;; ;~;~~~;~;~;~;~;~;~;~;~;~;~~~;~;~;~;~;~;~;~;~;~;°;~;~;~~~~~;~~~;~;:;~;~~~~~;°;~;~;~;~;~;~;~;~;~;~~`;~;~;~;~;~;~;~~~~~;~;~;~;~;°;~;~;~;';~~~;~;~;';~;~;~;~;~;~;~;~~~;~~~;~;~;~;~;~;~;~~°;';~~~~~;~;~;~;~;~;~;~~~:~~~~~~~;~~~;~~~;`;~;~;~;~~~;~~~~~;~;~~~;~:~;°:~;'~~;~~°;~;';~;~;°:~~~~~~°~°:~~°;~~~;~;~;~;~;~~~~~~~;~;~~';~;~~~;~:~~~~':°~:~~;~~~;~;'; G-250 Are all loose materials, small tools and 40(c)(1) W other small objects kept in a storage area or a marked container when not in use? G-251 Are skid-mounted equipment, portable 40(c)(3) W containers, spools or reels, and drums 40(c)(4) clearly marked with the owner's name durable enough to resist the affects of the environmental conditions? G-253 Are all materials, equipment, tools, 40(d) W containers, and other items that are lost overboard recorded on the facility's daily operations report?? Welding and Burning G-300 Is a copy of the welding, burning, and hot 52(b) W tapping plan and approval letter available on the facility G-301 Is a drawing showing the locations of safe 52(c) W welding and burning areas maintained on the facility? G-302 Is all welding and burning equipment 52(b) C inspected by the welding supervisor or the lessee's designated person in charge prior to beginning any welding, burning, or hot tapping? G-303 is equipment containing hydrocarbons or 52(a)(4) C other flammable substances relocated at least 35 feet horizontally from the welding site, 35 feet horizontally from the point of impact of slag, sparks, or burning materials at a lower elevation, or is it otherwise protected? G-304 Are welding leads insulated and in good 52(b) C condition? G-305 Are oxygen and fuel bottles secured in a 52(b) W/C safe place? G-306 Are hoses leak-free and equipped with 52(b) C fittings, gauges, and regulators? G-309 Prior to the commencement of any welding 52(d)(1) C or burning operation in areas other than approved safe welding or burning areas, has the lessee's designated person in charge issued a wdtten authorization for the work? For welding and burning operations in areas other than approved safe welding and burning areas: G-310 Have all piping, containers, tanks, or other 52(d)(4) C vessels which have contained a flammable substance, been rendered inert? G-311 Has one or more persons, with no other 52(d)(2) C duties during welding or burning operations, been designated as fire watch? G-312 Does the fire watch maintain a continuous 52(d)(2) C surveillance with a portable gas detector during the welding or burning operation if the operation is to be in an area which is not equipped with a gas detector?. G-313 Does the fire watch have usable firefighting 52(d)(3) C equipment in their possession? G-314 Does the fire watch remain on for a period 52(d)(2) W of 30 minutes after welding or burning operations have been completed? G-315 Do the well(s) in the area where drilling, 52(d)(5) C well-completion, welI-workover, or wireline operations are in progress contain noncombustible fluids and is the entry of formation hydrocarbons into the wellbore precluded during welding operations? G-316 Are all producing wells in the well-bay or 52(d)(6) C production area shut-in at the surface safety valve if welding or burning operations are conducted in or within 10 feet of a well-bay or production area? G-317 Are all water-discharge-point sources from !52(a)(3) C hydrocarbon-handling vessels monitored in order to stop welding or burning operations in case flammable fluids are discharged as a esult of equipment upset or malfunction? Pollution Prevention E-100 Is the lessee preventing pollution of 40(a) W/C offshore waters? E-101 Is the lessee disposing of drill cuffings, 40(b)(2) C/S sand, and other well solids as approved? E-102 Is the facility equipped with the curbs, 40(b)(4) W/C/S gutters, and drip pans necessary to collect all contaminates not authorized for discharge? E-103 Is each drain piped to a sump system that 40(b)(4) W/C/S automatically maintains the oil at a level to prevent discharge of oil into offshore waters? E-105 Are all gravity drains equipped with a water 40(b)(4) W/C/S trap or other means to prevent gas in the 67(m)(14) sump system from escaping through the drains? E-106 Are sump piles not used as processing 40(b)(4) C devices? E-107 Is the lessee adhedng to the prohibition on 40(b)(1) S the addition of petroleum-based substances to the mud system? E-108 Is the lessee preventing the disposal of 40(b)(6) W equipment, cables, chains, containers, and other material into offshore waters? Inspections and Reports E-120 Are records of the daily pollution 41 (a) W inspections maintained at the facility or at a nearby manned facility for 2 years? E-121 Are records of the monthly pollution 41 (b) W response equipment inspections kept for at least 2 years at a site designated in the Oil Spill Contingency Plan? E-122 Is the pollution response equipment 42(d) W/S identified in the Oil Spill Contingency Plan maintained in accordance with the requirements in the Plan? E-123 Are pollution response equipment and 42(f) W/S materials identified in the Oil Spill Contingency Plan located at the designated site(s)? Training and Drills E-130 Are the records of the pollution control 43(a) W equipment training classes available? E-131 Are the results of the pollution control 43(b) W equipment drills available for inspection? E-132 Are the pollution control equipment drills conducted in accordance with the Oil Spill Contingency Plan? IPINCr~Q, IPINC IAuth°rity Artificial Islands E-200 Are all vessels containing hydrocarbons 40(b)(5) placed inside an impervious berm or otherwise protected to contain spills? E-201 Is drainage directed away from the drilling 40(b)(5) rig to a sump? E-202 Are drains and sumps constructed to 40(b)(5) prevent seepage? ~:::::::::::~:::::::::~:::~:~:::::::::~~::~:::::::~:::~:::::::::~::::::::::::::::::::::: :::::::::::::::::::::.':::::::::::::::::::::::::::::::::::::::::::::: General (Drilling) D-100 Is the drilling unit equipped with an 51 (b)(1) operable traveling block safety device? D-101 Are the results of the operational checks of 51(b)(1) the traveling block safety device entered in the driller's report? ·;~;~;·;~;~;·;~;·;~:~;~;~;~;~;~;~;~~~;~;~;~;~~~~~;~;~;~;~;~;~;~;~~~~~;~;~;~;~;~;~;~;~;~;·;~;·;~;~;°;~;~:~;~;~;~;~;~;~:·~~~~;~;~~~;~;~;~~~;~:~;~;~;~:~;~;~;~;~~~;~;~;~;~;~;~:~~~;~;~~~'~:~;~;.:~~~;~;~;~;~;~;~;~;~:~;·:~;~;~;~;~:~;~;~;~;~;~;~;~;~~·;~;~:~;~;~~~;~;~;~~·;~;~;~;~'~;°;~~~;~;~;';~;~;~~~:~;~;·~·:~;~:~~~ :~:~:~:~;~;~;~;~:·;~;~;~;~:~:~;~;~;~;~;~:~:~:~;~;~:~:~:~:~:~:~:~:~:~:~:·;~;~;~:~:~:~:~;~;~:~:·:~:~:~:~:~:~:·:·:~:~:·:~:~:~:~:~:~:~:~:~:~:~:·:·:~:~:~:~:~:~:~:~:~:~:~:~:~:~:·:~:~:~:~:~:~;~:~:~:~:~:·:~:~:·~:~:~:~:~:~:~:~;~:~:~:~:~:~:~:·;~:~:~:~'"·:~·~·:~:·:°~;~;·:·;·;°:~:~:~:~;~:~:~ Directional Surveys :;;;:;:~:;:::;:;:::;;;:;:;:;:;:::;:;:;:;:;:;:::::::::::::::::::::;:::;:;:;:~;::';;;:~:;:;:~:;:;::::::::~::;:::;;:~::::;::;:::;:;:::::::::::::::::::::::::::::::::::;~;~;·;~;°:~;~;~;~;~:°;~;~;~;~;~;~;~;~;~;~;~;~;~;~;~;~;~:~;~;~;~;~;~;~:~;~;~;~;~;~;~;~;·;~;°;~>>;~;~;·;~;~;~:~:~;~;·>>;~;~;~;~;~;~;~;~;·;~ D-110 Are the inclinational surveys obtained on all 51(e)(2) vertical wells at intervals not exceeding 1,000 feet during the normal course of drilling? D-111 Are directional surveys giving both 51 (e)(2) inclination and azimuth obtained on all directional wells at intervals not exceeding 500 feet during the normal course of drilling? D-112 Are directional surveys giving both 51 (e)(2) inclination and azimuth obtained on all directional wells at intervals not exceeding 100 feet in all portions of the hole when angle changes are planned? D-113 Are directional surveys giving both 51 (e)(3) inclination and azimuth obtained at intervals not exceeding 500 feet prior to or upon setting surface or intermediate casing, liners, and at total depth on all wells? Moving Drilling Rigs D-120 Are all wells in the same well-bay which are 51(h) capable of producing hydrocarbons shut-in below the surface with a pump-through- type tubing plug and at the surface with a closed master valve prior to moving drilling rigs and related equipment (or as otherwise approved by the District Supervisor)? Casing Program IPINC IPINC IAuthodty IAction CK Y N NA, D-151 Is any portion of an annulus opposite a 54(a)(3) WIS permafrost zone which is not protected by cement filled with a liquid which has a freezing point below the minimum permafrost temperature to prevent internal freezeback and which is treated to minimize corrosion? D-152 Has a pressure-integrity test been run 54(a)(6) WIS below the surface casing, the intermediate casing(s), and liner(s) used as intermediate casing(s)? D-153 Are drilling operations suspended when the 54(a)(6) WIS safe margin, as approved by the District Supervisor, between the mud weight in use and the equivalent mud weight at the casing shoe is not maintained? D-154 Are the results of all tests and of hole- 54(a)(6) W behavior observations made dudng the course of drilling related to formation integrity and pore pressure recorded in the driller's report? D-155 If the hole for the drive or structural casing 54(b) W was drilled, was a quantity of cement sufficient to fill the annular space back to the mud line used? D-156 Is cement fill in the annular spaces of the 54(c)(2) WIS conductor casing verified by observation of cement returns, or in the event that observation of cement returns is not feasible, is an additional quantity of cement used to assure fill to the mud line? D-157 Is Surface casing cemented with a quantity 54(c)(3) WIS of cement that fills the calculated annular space to at least 200 feet inside the conductor casing (or as otherwise approved by the Distdct Supervisor)? D-158 Have all casings, except the drive or 55(a) WIS structural casing, been pressure tested to 70 percent of the minimum internal-yield pressure of the casing (or otherwise approved by the Distdct Supervisor)? D-159 Are the results of all casing pressure test 55(a) W recorded in the driller's log? D-161 Is the ddlling liner lap pressure test equal to 55(b) W/S or greater that the pressure that will be encountered at the liner lap when conducting planned pressure integrity tests below the liner shoe? D-162 Are the results of the liner seal tests 55(b) W recorded in the driller's report? D-163 Has the casing been pressure-tested, 55(c) WIS calipered, or otherwise evaluated every 30 days dudng prolonged operations? D-164 Is there proper waiting-on-cement time 55(d) W before drilling was resumed? , t BOP Systems and Components , D-200 Does the working-pressure rating of all 56(c) S BOP components exceed the anticipated surface pressure to which they may be subjected? D-201 Does the aCcumulator system provide 56(d)(1) S sufficient capacity to supply 1.5 times the volume of fluid necessary to close and hold closed all BOP equipment units with a minimum pressure of 200 psi above the precharge pressure without assistance from a charging system? D-202 Have accumulator regulators, supplied by 56(d)(1) S dg air and without a secondary source of pneumatic supply, been equipped with manual oven'ides or, alternately, other devices proved to ensure capability of hydraulic operations if dg air is lost? D-203 Is an automatic backup accumulator- 56(d)(2) S charging System, supplied by a power source independent from the power source to the primary accumulator-charging system, and possessing sufficient capability to close all BOP components and hold them closed, provided? D-204 Is at least one operable remote BOP 56(d)(3) control station, in addition to the one on the ddlling floor, provided in a readily accessible location away from the drilling floor?. D-205 Is a ddlling spool with side outlets provided 66(d)(4) S if side outlets are not provided in the body of the BOP stack to provide for separate kill and choke lines? D-206 Is there a choke and a kill line each 56(d)(5) S equipped with two full-opening valves? D-207 Is a least one of the valves on the choke 56(d)(5) S line and on the kill line remotely controlled? D-208 Is a fill-up line installed above the 56(d)(6) uppermost preventer?. D-209 Does the choke manifold and choke 56(d)(7)(i) S equipment subject to well and/or pump pressure have a rated working pressure at least as great as the rated working pressure of the ram-type BOP's (or as otherwise approved by the Distdct Supervisor)? D-210 Are all components of the choke manifold 56(d)(7) S system protected from the danger of (ii) freezing by heating, draining, or filling with proper fluids? D-211 If buffer tanks are installed downstream of 56(d)(7)(iii) the choke assemblies for the purpose of manifolding the bleed lines together, are , isolation valves installed on each line? , JJ",Jg,JPINC JPINC JAuthority JAction JCKJ','JNJNAJ D-212 Do valves, pipes, fleXible steel hoses, and 56(d)(8) S other fittings upstream of, and including, the choke manifold have pressure ratings at least as great as the rated working pressure of the ram-type BOP's (or as otherwise approved by the District Supervisor)? D-213 Does the wellhead assembly have a rated 56(d)(9) S working pressure that exceeds the anticipated surface pressure to which it may be subject? D-214 On a conventional drilling rig, is an 56(d)(10) (i) S essentially full-opening kelly cock installed below the swivel (upper kelly cock)? D-215 On a conventional drilling dg, is an 56(d)(10) (i) S essentially full-opening valve of such design that it can be run through the BOP stack (stdppable installed at the bottom of the kelly (lower kelly cock)? D-216 With a mud motor in service and while 56(d)(10) (i) S using drill pipe in lieu of a kelly, is one kelly cock located above and one stdppable kelly cock located below the joint of ddll pipe employed in lieu of a kelly? D-217 On a top-drive system equipped with a 56(d)(10) (i) S remotely-controlled valve, is a second and lower stdppable essentially full-opening valve installed? D-218 Is a wrench to fit each manually-operable 56(d)(10) (i) S valve in a conventional ddlling rig, mud motor, and top drive system stored in a location readily accessible to the drilling crew?. D-219 Are the inside BOP and full-opening drill- 56(d)(10) (ii) S string safety valves, fitting all sizes of pipe in the drill string, maintained in the open position on the dg floor at all times while drilling operations are being conducted? D-220 Is a safety valve available on the dg floor 56(d)(10) (iii)S assembled with a compatible connection to fit the casing string being run in the hole? D-221 Are locking devices installed on the ram- 56(d)(11) S type preventers? ::::::::::::::::::::::: ::::::i::::::: ::::::::::::~:~:~:~:::~:~iii!iiiii!ii i:iiii!!ii~!!i!ii!!!!i!!!i!!i!!!!!!!!!!!! !:i:!!~ !:!!!!!!~i!!!:!!!!~!!!! !:~!!! i:~ !:!!!:!!!!! !:! ! !i i:! ! i! !.'.' i i! !! !:! i ii i !.': .::.i!!!!!i!!ii!!!i!iiiiiii!ii!ii!iiiiiJii:i:!i Surface BOP Systems D-222 Prior to commencing tapered drill-pipe 56(g) S operations, is the BOP stack equipped as required? D-230 Is at least one of the valves on the kill line 56(d)(5) remotely controlled, or is a check valve installed on the kill line in lieu of the remotely-controlled valve? D-231 If a check valve is installed in lieu of a 56(d)(5) S , ' remotely controlled valve in the kill line, are two readily accessible manual valves in place and is the check valve placed between the manual valves and the pump? 10 IPINC IPINC IAut.hority IAction CK YININAI NQ, D-232 Prior to drilling below surface casing or 56(f) S intermediate casing, is a BOP system 56(g)(2) installed consisting of at least four remote- controlled, hydraulically-operated BOP's including at least two equipped with pipe rams, one with blind rams and one annular type? Subsea BOP Systems ......... .....,.....,........... ....................................................... :.:.:.:.:.;,;.;.;.;.; ........ :::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::: :::::;;;;:::: ............................................ ; T~ ~ ..~,,.~.,"~'~'l ........................ · D-240 Prior to drilling below surface casing and 56(e)(1) . S intermediate casing, are there at least four 56(g)(2) remote-controlled, hydraulically-operated BOP's including at least two equipped with pipe rams, one with blind-shear rams and one annular type? D-241 Is a subsea accumulator closing unit 56(e)(2) S installed? D-242 Does the BOP system include operable 56(e)(2) S dual-pod control systems when drilling below the surface casing? D-243 Do the record indicate that the glory hole is 56(e)(5) S of the approved depth to assure that the top of the stack is below the deepest probable ice-scour depth? r. ~,~ ....... ~ ........................ BOP Tests, Actuations, Inspections and Maintenance D-250 Prior to conducting high-pressure tests, are 57)a) WIS all BOP systems tested to a Iow pressure of 200 to 300 psi? D-251 Are the choke manifold valves, upper and 57(d) WIS lower kelly cocks, top drive, inside BOP, and the drill-string safety valves pressure tested to pipe-ram test pressures (or as otherwise approved by the District Supervisor)? D-252 Are safety'Valves assembled with 57(d) S connections actuated prior to running casing? D-253 Are surface and subsea BOP systems 57(e)(2) W/S pressure tested before ddlling out each string of casing or before continuing operations in cases where the cement is not ddlled out? D-254 Was the reason for postponing pressure 57(e)(3) W testing entered into the driller's report? D-255 Is pressure testing performed at intervals to 57(e)(3) W alloW each drilling crew to operate the equipment? D-256 Are blind and blind-shear rams actuated at 57(e)(3) W/S least once every 7 days? D-257 Are variable bore-pipe rams pressure 57(e)(5) WIS tested against all sizes of pipe in use? , 11 JPINC JPINC JAuth°rity JAot,onCKYJNJNAJ NQ, D-258 Are surface and subsea BOP systems 57(e)(6) W/S pressure tested following the disconnection or repair of any wellhead/BOP stack assembly, but limited to the affected component? D-259 Are the BOP systems and marine risers 57(0 W visually inspected at least once each day? D-260 Are the time, date, and results of all 57(g) W pressure tests, actuation, and inspections of BOP systems, system components, and marine risers recorded in the driller's report or referenced document? D-261 Are BOP test pressures on a pressure 57(g) W chart, unless otherwise approved by the District Supervisor?. , D-262 Is the test interval for each BOP 57(g) W component tested sufficient to demonstrate that the component is effectively holding pressure? D-263 Are BOP test pressure charts certified as 57(g) W correct by the operator's representative at the facility? D-264 Does the documentation indicate the 57(h)(1) W sequential order of BOP and auxiliary equipment testing and the pressure and duration of each test? D-265 Is the control station used dudng the est 57(h)(2) W identified in the driller's report or referenced documents? D-266 Are any problems or irregularities observed 57(h)(3) W during BOP and auxiliary equipment testing and any actions taken to remedy such problems or irregularities recorded in the driller's report or referenced documents? D-267 Are all records including pressure charts, 57(h)(4) W driller's report, and referenced documents of BOP tests, actuations, and inspections available at the facility for the duration of the ddlling activity? D-268 Are all such records retained for a pedod of 57(h)(4) W two years at the facility, at the lessee's field office nearest the facility, ore at another location conveniently available to the Distdct Supervisor?. Surface BOP Test D-270 Are surface BOP systems pressure tested 57(e)(1) W/S when installed? D-271 Are ram-type BOP's and the choke 57(b) W/S manifold pressure tested with water to rated working pressure (or as otherwise approved by the District Supervisor)? D-272 Is the annular-type BOP pressure tested 57(b) WIS , , with water to 70 percent of its rated working pressure (or as otherwise approved by the Distdct Supervisor)? 12 IPINCNo, IPINC IAuthodty Action ICKIYININAI D-273 Are surface BOP systems pressure tested 57(e)(3) WIS at least once each week, but not exceeding 7 days between pressure tests, alternating between control Stations? Subsea BOP Tests ........................................ ~~~~~~~~~~~~~~~~~~~~~~~~~~~.~.~~~~~~~~~~~~~~~~~.~.~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~.~~~~~;.~~~ :::::::::::::::::::::::::::::::::::::: ........ : .......... ::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::: .......... :.:.:,: :.:,:,,..:..:.:..., D-281 Are subsea BOP system components 57(c) WIS stump pressure tested at the surface With water to their rated working pressure? D-282 Are subsea annular-type BOP's stump 57(c) WIS pressure tested at the surface with water to 70 percent of their rated working pressure (or as otherwise approved by the Distdct Supervisor)? D-283 After the installation of the BOP stack on 57(c) WIS the seafloor, are the ram-type BOP's and choke manifold pressure tested to rated working pressure (or as otherwise approved by the Distdct Supervisor)? D-284 After the installation of the BOP stack on 57(c) W/S the seafloor, is the annular preventer pressure tested to 70 percent of its rated working pressure (or as otherwise approved by the District Supervisor)? D-285 Are subsea BOP systems pressure tested 57(d)(3) WiS at least once each week, but not exceeding 7 days between pressure tests, alternating between control stations and pods? D-286 For subsea Systems, is the pod used dudng 57(h)(2) W the test identified in the driller's report or referenced documents? ~ ...................................................... ...........-....;, ,. ........ ;., ,; ...... ; .......... : ....... .; ....... Well-control Drills D-290 Are well-control ddlls conducted for each 58(a) W drilling crew in accordance with § 250.58? D-291 Is a copy of the complete well-control drill 58(a)(2) W plan posted on the dg floor and/or bulletin board? D-292 Are drills conducted in accordance with the 58(a)(2) W well-control plan? D-293 Are well-control drills recorded in the 58(a)(3) W driller's report? Diverter Systems D-300 When drilling a conductor or surface hole, 59(a) S is the drilling unit equipped with a diverter system consisting of a diverter sealing element, diverter lines, and control system (or as otherwise approved by the Distdct Supervisor)? D-301 Is the diverter system equipped with 59(c) S ~ ' remotely-controlled valves in the flow and vent lines that can be operated from at least °ne remote-control station in addition to the one on the drilling floor?. 13 IPINC PINC IAuthodty IAction ICK IY IN INAI NQ, D-302 Are the diverter sealing element, diverter 59(0 W valves, and diverter-control systems including the remote-control system, actuation-tested, and the vent lines flow tested when first installed? D-303 Are subsequent actuation tests of the 59(0 W diverter sealing element, diverter valves, and diverter-control systems including the remote-control system conducted at least once every 24-hour period alternating between control stations? D-304 Are all valves used in the diverter system 59(c) S full-opening? D-$05 Are all the right-angle and sharp tums in 59(c) S the diverter lines targeted? D-306 If flexible hose is used for diverter lines 59(c) S instead of rigid pipe, does the flexible hose have integral end couplings? D-307 Is the entire diverter system firmly 59(c) S anchored and supported to prevent whipping and vibration? D-$08 Are all diverter control instruments and 59(c) S lines protected from physical damage from thrown and falling objects? D-309 Are all pressure test, flow test, and 59(0 W actuation results recorded in the driller's report? D-$10 Are diverter systems and components used 59(g) S in subfreezing conditions suitable for use under these conditions? D-$11 If the diverter system utilizes only one 59(d)(1) S spool outlet, are branch lines installed to 59(e)(1) provide downwind diversion capability? Surface Diverter Systems D-322 Is the minimum spool outlet and diverter ~59(d)(2) S line internal diameter at least 10 inches? D-323 If dual spool outlets are utilized, does each 59(d)(2) S outlet have a minimum internal diameter of at least 8 inches? D-324 If dual spool outlets are utilized, are both 59(d)(2) S outlets piped to overboard lines? D-325 If dual spool outlets are utilized, does each 59(d)(2) S line downstream of the changeover nipple at the spool have a minimum internal diameter of 10 inches? D-326 Are diverter sealing elements and diverter 59(0' W valves pressure tested to a minimum of 200 psi when nippled up on conductor casing, with no more than 7 days elapsed time between subsequent tests? Subsea Diverter Systems D-333 Are all spool outlet and diverter line intemal 59(e)(2) S diameters at least 12 inches? 14 JPINCPINC JAuthodty JAm,or, JCKJY NJNAj Ng, D-334 On dynamically-positioned drill ships, is 59(e)(3) S vessel heading maintained to allow for downwind diversion? Mud Program D-400 Has mud been properly conditioned 60(b)(1) W circulation before starling out the hole with drill pipe, or is there proper documentation in the driller's report that Circulation was not necessary? D-401 When coming out of the hole with drill pipe, 60(b)(3) W is the annulus filled with mud before the change in mud level decreases the hydrostatic pressure by 75 psi, or every five stands of ddll pipe, whichever gives a lower decrease in hydrostatic pressure? D.402 Has the number of stands of and ddll 60(b)(3) W collars that may be pulled pdor to filling the hole and the equivalent mud volume been calculated and posted near the driller's station? · D-403 For each casing stdng, is the maximum 60(b)(5) W pressure to be contained under the BOP posted near the driller's station? D-404 n areas where permafrost and/or hydrate 60(b)(8) W zones may be present or are know to be present, are dr#ling fluid temperatures controlled? D-405 Is an operable mud-gas separator and 60(b)(8) S operable degasser installed in the mud system pdor to commencement of ddlling operations and maintained for use throughout the drilling of the well? D-406 Is the mud in the hole circulated or reverse- 60(b)(9) W circulated pdor to pulling the drill-stem test 60(b)(2) tools from the hole? D-407 Is mud-testing equipment maintained on 60(c)(1) S the ddlling dg at all times (or as otherwise apProved by the Distdct Supervisor)? D-408 Are mud tests performed once each tour, or 60(c)(1) W more frequently, as conditions warrant? D-409 Are results of mud tests recorded in the 60(c)(1) W driller's report? D-410 Is a recording mud-pit level indicator with 60(c)(2)(i) S audible and visual wamings installed and used? D-411 Is a mud-volume measuring device used to 60(c)(2) (ii) S determine the mud volumes required to fill 60(b)(3) the hole on tdps? D-412 Are mud-return indicator devices which 60(c)(2) (iii) S indicate the relationship between mud- retum flow rate and pump discharge rate installed and used? ~ ' 15 D-413 Is operable gas-detecting equipment 60(c)(2)(iv) S installed to monitor drilling mud retums, with the required type of indicators located on the rig floor or in a continuously manned mud-logging unit having immediate communication with the rig floor?. D-414 Are minimum quantities of mud and mud 60(d)(1) WIS materials maintained at the drill site as '60(d)(3) necessary to ensure well control? D-415 Are records of daily inventories of mud and 60(d)(2) W mud materials maintained at the well site? Mud Handling Areas Classified as Where Dangerous Concentrations of Combustible Gas May Accumulate D-421 If not continuously activated, are 60(e)(1) S mechanical ventilation systems activated on signal from gas detectors that are operational at all times indicating the presence of 1 percent or more of gas by volume? Are all classified mud handling areas: D-422 Equipped with high-capacity mechanical 60(e)(1) S ventilation systems unless such ventilation is provided by natural means? D-423 Maintained at a negative pressure relative 60(e)(2) S to an adjacent area if mechanical ventilation is and discharges may be hazardous? D-424 Which are maintained at a negative 60(e)(2) S pressure, protected with at least one of the following: (i) a pressure- sensitive alarm, (ii) open-door alarms on each access to the area, (iii) automatic door-closing devices (iv) air locks or (v) other devices? D-425 Fitted with gas detectors and alarms except 60(e)(3) S in open areas where adequate ventilation is provided, by natural means? D-426 Equipped with either explosion-proof or 60(e)(4) S pressurized electrical equipment to prevent the ignition of explosive gases? D-427 Where air is used for pressuring, is the air 60 (e)(4) S intake located outside of, and as far as practicable from, hazardous areas? D-428 Are mechanical ventilation systems fitted 60(e)(5) S with alarms which are activated upon a failure of the system? D-429 Are gas detection systems tested for 60(e)(6) W/S operation and recalibrated at a frequency such that no more than 90 days shall elapse between tests? 16 Securing Wells D-440 Is a downhole safety device such as a 61 W cement plug, bridge plug, or packer installed when drilling operations are interupted by events such as those that force evacuation of the drilling crew, prevent station keeping, or require repairs to major drilling or well-control equipment? Supervision, Surveillance, and Training D-450 From the time drilling operations are 63(b) W initiated and until the well is completed or abandoned, is well continuously under surveillance unless the well is secured with BOP's, bridge plugs, packers, or cement plugs? D-451 Are lessee and drilling contractor personnel 63(c) W/C trained and qualified in accordance with the provisions of Subpart O of 30 CFR 250? D-452 Are records of specific training, which 63(c) W lessee and drilling contractor personnel have successfully completed, the dates of Completion and the names and dates of courses maintained at the drill site? Application for Permit to Drill D-460 Does the lessee have written or oral 64(a) S approval to drill the well? D-461 Does the lessee have written or oral approval to change plans, make changes in major drilling equipment, deepen or plug back a well, or engage in similar activities? Hydrogen Sulfide H-100 Is a copy of the approved H=S Contingency 67(f) W/S Plan available in the field area, and is that plan being followed ? H-101 Are at least two safe bdefing areas 67(0(6) S established? H-102 Are all personnel informed of the hazards 67(g)(4)(i) C of H2S and of SO2 resulting from burning 67(j)(11)(i),(ii H2S and instructed in the provisions for i) personnel safety contained in the H2S Contingency Plan? H-103 Are all personnel instructed in the use of 67(g)(4)(ii) C safety equipment which they may be required to use? -H-104 Are all personnel informed of the location 67(g)(4)(iii) C of protective-breathing equipment, H2S detectors and alarms, ventilation equipment, briefing areas, warning systems, evacuation procedures, and the direction of the prevailing winds? H-105 Are ali personnel informed of the 67(g)(4)(iv) C restrictions and corrective measures concerning beards, spectacles, and contact lenses in conformance with ANSI Z88.2 (latest edition)? H-106 Is safety information prominently posted on 67(g)(5) W the facility? H-107 Is safety information prominently posted on 67(g)(5) W vessels serving the facility? H-108 Do all operator and contract personnel 67(g)(1)(i),(ii) C receive a training session before beginning work at the facility and again within 1 year after completion of the previous class? H-109 Does each person participate in a drill 67(h)(1)(i) W/C during normal duty hours at least once every 7-day period? H-111 Are records of attendance for training 67(g)(2)(i),(ii) W maintained at the facility or does the employee carry a training completion card? H-113 Is a readily available first-aid kit of 67(k)(3)(i) W appropriate size and content for the number of personnel on the facility? H-114 Are at least three resuscitators on manned 67(k)(i)(v) C facilities, and a number equal to the personnel on board, not to exceed three, on normally unmanned facilities, complete with face masks, oxygen bottles, spare oxygen bottles, and are these items readily available? H-115 Is there at least one litter or an equivalent 67(k)(3)(ii) W device on the facility and readily available for use? H-117 Is wind-direction equipment installed in 67(i)(I) S locations visible at all times to individuals on or in the immediate vicinity of the facility? H-118 Are operational danger signs displayed at 67(i)(2)(i) W all times on facilities with wells capable of producing H2S gas in concentrations of 20 ppm or more? H-120 Doesthe facility have an H2S-detection and 67(j)(1)(i),(ii) S H2S-monitodng system which is capable of 67(j)(2)(i-viii) sensing a minimum of 10 ppm H~S and which activates audible and visual alarms when the atmospheric concentration reaches 20 ppm and are these sensing devices located at the bell nipple, mud retum line (possum belly), receiver tank pipe tdp tank, shale shaker, well-control fluid pit area, driller's station, living quarters, and other areas where H~S might accumulate? H-121 Are sensors located in rooms, buildings, 67(j)(5)(i) S deck areas, or Iow-laying deck areas not otherwise covered by 67(j)(2)? , H-122 Is at least one sensor per 400 square foot 67(j)(5)(i) S of deck area or fractional part thereof installed (or as otherwise approved by the District Supervisor)? 18 IPINCNg, PINC IAuthority IAction ICKIY NINAI H-123 Is a sensor located in buildings where 67(j)(5)(ii) S personnel have their living quarters? H-124 Is one sensor located within 10 feet of each 67(j)(5)(iii) C vessel, compressor, wellhead, manifold, or pump (or as otherwise approved by the Distdct Supervisor)? H-125 If one sensor is used to cover multiple 67(j)(5)(iv) C pieces of equipment, is each piece of equipment no more than t0 feet from the sensor (or as otherwise approved by the District Supervisor)? H-126 Is the H2S-detection system recalibrated 67(j)(6)(ii) C when functional tests are not within 2 ppm or 10 percent, whichever is greater, of the applied concentration (or as otherwise approved by the Distdct Supervisor)? H-127 Are portable H2S detectors capable of 67(k)(1)(i) W detecting 10 ppm concentrations of H=S gas in air available for use by all personnel? H-128 Are presSure-demand-type respirators with 67(j)(13)(i) S hoseli~--~'~ capability and breathing time of at67(j)(13)(v) least }~.- ~'~nutes immediately available and easily accessible to all personnel on the facility (or as otherwise approved by the District Supervisor)? H-129 Are at least two voice transmission 67(j)(13)(iii) W devices, which can be used while weadng a respirator, available for use by designated personnel? H-131 Is each breathing-air bottle labeled as 67(j)(13)(vi) C\S containing breathing-quality air for human use? H-132 Do vessels attendant to facilities carry 67(j)(13)(vii) C appropriate protective-breathing equipment for each crew member?. H-133 For authorized flights dudng H2S alerts, are 67(j)(13)(viii)C helicopter flights to and from the facility limited to the conditions specified in the H2S Contingency Plan? H-134 During authorized flights, do the flight crew 67(j)(13)(viii)C and passengers use pressure-demand type respirators? H-135 Are ail members of flight crew trained in the 67(j)(13)(viii)C use of the particular type(s) of respirator equipment made available? H-136 As appropriate to the particular 67(j))(13)(ix) S operation(s), (production, drilling, well- completion/workover, or any combination thereof), is a system of breathing-air manifolds, hoses, and masks provided on the facility and in the bdefing areas? H-137 Is a cascade air-bottle system provided for 67(j)(13)(ix) S the breathing-air manifolds to refill . individual protective-breathing apparatus ~ bottles? 19 H-138 If the cascade air-bottle system is 670)(13)(ix) S recharged by a high-pressure compressor suitable for providing breathing-quality air, is the compressor suction located in an uncontaminated atmosphere? H-140 Retrieval ropes with safety harnesses to 67(k)(1)(ii) W retrieve incapacitated personnel from contaminated areas? H-141 Chalkboards and/or note pads for 67(k)(1)(!ii) W communication purposes located on the dg floor, shale-shaker area, the cement-pump rooms, well-bay areas, production processing equipment area, gas compressor area, and pipeline-pump area? H-142 Bull horns and flashing lights? 67(k)(1)(iv) S H-143 Are audible alarms and display flags or 67(i)(2)(ii) S flashing red lights available for use on :670)(5) facilities when atmospheric concentrations 67(i)(7)(i) of H2S reach 20ppm and are signs and flags capable of being illuminated at night and under conditions of poor visibility? H-144 Are all ventilation devices explosion-proof 67(k)(2)(i-ii) C/S and installed in areas where H2S or SO2 may accumulate? H-145 Are movable, multidirectional ventilation 67(k)(2)(iii) C devices capable of dispersing H~S or SO2 vapors away from working personnel provided in work areas? H-146 If water-based, well-control fluids are used, 67(m)(2) W and if H2S is detected by air sensors, has the Garrett-Gas-Train test or comparable test techniques for soluble sulfides been conducted? H-147 Are sufficient quantities of additives 67(m)(4)(i-iii)S (scavengers, pH, and corrosion control) maintained on the facility? H-148 When H~S is detected, is drilling suspended 67(m)(4)(i) S until scavenger is circulated throughout the system? H-149 Is the pH of water-based well-contr°l fluids !67(m)(4)(ii) S maintained at a minimum of 10,07 H-150 Are well-control fluids containing H2S 67(m)(5) S degassed at the optimum location for the particular facility and are the gasses removed burned in a closed flare system? H-151 Is a safety meeting conducted for all 67(o)(1) C personnel who will be on the facility pdor to well testing? H-152 Are all gases produced dudng testing 67(q)(6) S burned through the flare system which meets the requirements of 67(q)(6)? H-153 Are flare line outlets located on the 67(q)(6) S , downwind side and as far from the facility , as is feasible? 20 IPINC IPINC IAuthority IActi°n CK Y N NAIl No, H-154 Is the flare outlet equipped with an 67(q)(6) S automatic ignition system including a pilot- light gas source or an equivalent system? H-155 Is an alternative method available for 67(q)(6) W igniting the flare? H-156 Are all vents used for H2S production 67(q)(6) C/S process equipment, tanks, relief valves, burst plates, and similar devices, piped to the flare system? H-157 Is gas containing H2S not used for 67(q)(9) . S instrument gas and if H2S is being used as fuel gas, does the operator have approval from the Distdct Supervisor?. H-158 Has the District Supervisor been notified if 67(q)(12) S produced water is disposed of by means other than subsurface injection? H-159 Are H2S leVels continuously monitored in 67(j)(4)(i-v) WIS the work areas when pulling a wet string of drill pipe, workover string, circulating bottoms-up after a ddlling break, cementing, logging, or circulating to condition mud or other well-control fluids? H-160 When conducting codng operations is 67(q)(1) WIS protective breathing equipment worn by all personnel in the work area at least 10 stands in advance of retrieving the core barrel? H-161 Are all cores to be transported seaie(~ and 67(q)(1) WIS marked for the presence of H2S? H-162 Is well-control fluid in use for loggir~ !67(q)(2) WIS operations conditicp, ed an<: tr~ate,:~ !o minimize the effect of H2S on the equipment? H-163 During stripping operations, are displaced 67(q)(3) WIS well-control fluid returns monitored by personnel? H-164 During stripping operations, is protective 67(q)(3) WIS breathing equipment worn by personnel in the work area when the atmospheric concentration of H~S reaches or exceeds 20 ppm or if the well is under pressure? H-165 Is protective breathing equipment wom by 67(q)(4) WIS personnel in the work area dudng bottoms- up when circulating out a kick and during extended kill operations? H-166 Is an effective means of monitoring and 67(q)(7) S controlling corrosion caused by acid gases used in both the downhole and surface portions of a production system? H-167 Are lubricators which may be exposed to 67(q)(8) WIS fluids containing H~S made of H2S-resistant materials? H-168 Are metals used for sensing lines and 67(q)(10) WIS · safety-control devices which are exposed to H2S bearing fluids constructed of H2S corrosion resistant materials or coated with appropriate materials so as to resist corrosion? 21 ! H-169 Are all seals which may be exposed to 67(q)(11) W/S fluids containing H2S made of H2S-resistant material? H-170 Do trained employees or contractors 67(g)(3)(i) W transferred from another facility receive a supplemental bdefing on H2S equipment and procedures before beginning duty? H-171 Do visitors who remain at the facility for 67(g)(3)(ii) W more than 24 hours receive the training required for employees and contractors? H-172 Do visitors who will depart the facility within 67(g)(3)(iii) W 24 hours receive a briefing on H2S procedures? H-173 Are records of attendance in drills for 67(h)(2)(i) W drilling, well- completion, and well-workover operations maintained at the facility until operations are completed? H-174 Are records of attendance in drills for 67(h)(2)(ii) W production operations maintained at the facility or the nearest field office for 1 year?. H-175 Are portable or strategically placed fixed 67(j)(11)(i) WIS SO2 devices capable of detecting a minimum of 2 ppm of SO2 available or in use at the facility? H-176 Are portable or fixed SO2 electronic 67(j)(11)(iv) WIS sensing devices calibrated every 3 months? H-177 Are spectacle kits available for respirators 67(j)(13)(iv) W as needed? H-178 Are compressors exceeding 50 horsepower 67(j)(5)(iv) C covered by at least two sensors located within 10 feet of the compressor?. H-179 When drilling, are functional tests initiated 67(j)(7)(i) W before the bit is 1,500 feet (vertically) above the potential H2S zone? H-180 When conducting production operations, 67(j)(7)(ii) C are all detectors tested at least every 14 days? H-181 In areas classified as H2S Present, are all 67(j)(7)(i) WIS detectors tested once every 24 hours when conducting drilling, drill stem testing, well testing, well completions, or workover operations? , LIS VERIFICATION LISTING FOR: FAIRWEATHER EXPL. & PROD. ARCO WARTHOG #1 WELL WARTHOG FIELD BELOW ARE THE MNEMONICS THAT CAN BE FOUND ON THE LIS TAPE GENERATED FOR FAIRWEATHER EXPL. & PROD. ARCO WARTHOG #1 WELL WARTHOG FIELD AZT CAAM CACM CPAM CPCM GRAM GRBM INC PDBM PDCM RAAM RACM ROPS RPAM RPCM RPDM RPIM RPTM TCDM TVD WBCS Azimuth - True (Posted) Conductivity (AT) Apparent [RWD] Conductivity (AT) Borehole Corrected [RWD] Conductivity (PD) Apparent [RWD] Conductivity (PD) Borehole Corrected [RWD] Gamma Ray Memory (APl) [RWD] Gamma Ray Base [RWD] Inclination - True (Posted) Phase Difference Base [RWD] Phase Difference Borehole Corrected [RWD] Resistivity (AT) Apparent [RWD] Resistivity (AT) Borehole Corrected [RWD] Rate of Penetration Resistivity (PD) Apparent [RWD] Resistivity (PD) Borehole Corrected [RWD] Phase Difference Data Density [RWD] Phase Difference Data Density Integrated [RWD] Phase Difference Time Since Drilled [RWD] CDS Temperature [RWD] True Vertical Depth Surface Weight On Bit deg mmholm mmholm mmholm mmholm MWD-API cps deg deg deg ohm-m ohm-m fi/hr ohm-m ohm-m pt/ft pts rain deg F ff klbs Note: AT is Attenuation PD is Phase Difference MWD is Measurement While Drilling RWD is Recorded While Drilling Copyright 1987-1992 By WESTERN ATLAS INTERNATIONAL. INC. All rights reserved. PROGRAM: TAPESCAN REVISION: 3.00X Start of execution: Wed 21 JAN 98 10:38a I== ECHOING INPUT PARAMETERS INPUT PARAMETER FILE: TAPESCAN.INP I 2 3 4 5 6 7 123456789012345678901234567890123456789012345678901234567890123456789012 1 AUTOCURV = 0 , ! Automatic Curve renaming: 0=OFF, I=ON 2 AUTOFILE -- 0 , !Automatic FILE= generation: 0=OFF, I=ON 3 COMMENTS = 1 , ! Decode LIS Comment records: 0=OFF, I=ON 4 INFORECS = 1 , ! Decode LIS Information records: 0=NO, I=YES 5 LISTMETHOD = 0 , ! Listing Method: 0=depth units l=tape units 6 LISTFREQ = 50, ! Listing Frequency: Every n units 7 LISTMAX = 0 , ! Listing Maximum (0=no limit, value=list limit) 8 STATS = 0 , !Statistics generation: 0=OFF, I=ON 9 FORCETYP = 0 , ! (I=BIT,2=LIS ... thru 35=Array Accoustic) (see table) 10 WRITEASCII = 0 , ! If 1, all ascii files will be written (tile0001.dat,etc.) 11 WRITETAP = I , ! Write Tape-Image File: 0=NO, I=YES 12 SPLITLIS = 1 , ! If 1 and WRITETAP on, split LIS logical files to physical 13 SUBFILES =/0/, ! Tape Subtile write selection (WRITETAP must be on) 14 INTERPOLATE='YES' ! Set up for TAPE2WDS to interpolate datums ('YES'or'NO') 15 END ~== USER INPUT PARAMETERS AUTOCURV = 0 , AUTOFILE = 0 , COMMENTS = 1 , INFORECS = I , LISTMETHOD = 0 , LISTFREQ = 50, LISTMAX = 0, STATS = 0 , FORCETYP = 0 , WRITEASCII-- 0 , WRITETAP = 1 , SPLITLIS = 1 , SUBFILES --/0/, INTERPOLATE='YES' END I__ PROCESSING INTERVAL FROM 0.000 TO 0.000 ............. ~-- CONSTANT PARAMETERS ........................................... AUTOCURV= 0.000000E+00 AUTOFILE-- 0.000000E+00 COMMENTS= 1.00000 FORCETYP= 0.000000E+00 INFORECS= 1.00000 LISTFREQ= 50.0000 LISTMAX = 0.000000E+00 LISTMETH= 0.000000E+00 SELFTEST= 0.000000E+00 SPLITLIS= 1.00000 STATS = 0.000000E+00 WRITEASC= 0.000000E+00 WRITETAP= 1.00000 dpcoef = 1.00000 dpcte = 1.00000 drlength= 0.000000E+00 iistwave= 0.000000E+00 maxrecln= 0.000000E+00 minrecln-- 0.000000E+00 nsamples-- 0.000000E+00 numcurvs= 0.000000E+00 numdatar= 0.000000E+00 numrecfl= 0.000000E+00 tfendep -- 0.000000E+00 tflevsp = 0.000000E+00 tfstdep = 0.000000E+00 wcrbot = 0.000000E+00 wcrlevsp= 0.000000E+00 wcrtop -- 0.000000E+00 ~-- ARRAY PARAMETERS .............................................. SUBFILES(1) SUBFILES(3) SUBFILES( 5)=-9999.00 SUBFILES( 7) =-9999.00 SUBFILES( 9) =-9999.00 SUBFILES(11) = -9999.00 SUBFILES(13) = -9999.00 SUBFILES(15) = -9999.00 SUBFILES(17) -- -9999.00 SUBFILES(19) =-9999.00 SUBFILES( 21 ) = -9999.00 SUBFILES(23) = -9999.00 SUBFILES(25) = -9999.00 SUBFILES(27) = -9999.00 SUBFILES(29) = -9999.00 SUBFILES( 31) = -9999.00 SUBFILES(33) =-9999.00 SUBFILES(35) = -9999.00 SUBFILES(37) = -9999.00 SUBFILES(39) -- -9999.00 SUBFILES( 41 ) = -9999.00 SUBFILES(43) = -9999.00 SUBFILES(45) = -9999.00 SUBFILES(47) = -9999.00 SUBFILES(49) = -9999.00 SUBFILES( 51) -- -9999.00 SUBFILES(53) = -9999.00 SUBFILES(55) = -9999.00 SUBFILES(57) =-9999.00 SUBFILES(59) = -9999.00 SUBFILES( 61 ) = -9999.00 SUBFILES(63) = -9999.00 = 0.000000E+00 SUBFILES(2) -- -9999.00 =-9999.00 SUBFILES(4) =-9999.00 SUBFILES(6) =-9999.00 SUBFILES(8) =-9999.00 SUBFILES(10) = -9999.00 SUBFILES(12) =-9999.00 SUBFILES(14) =-9999.00 SUBFILES(16) = -9999.00 SUBFILES( 18)=-9999.00 SUBFILES(20) = -9999.00 SUBFILES(22) = -9999.00 SUBFILES(24) = -9999.00 SUBFILES(26) = -9999.00 SUBFILES(28) = -9999.00 SUBFILES(30) = -9999.00 SUBFILES(32) = -9999.00 SUBFILES(34) = -9999.00 SUBFILE$(36) = -9999.00 SUBFILES( 38) = -9999.00 SUBFILES(40) = -9999.00 SUBFILES(42) = -9999.00 SUBFILES(44) = -9999.00 SUBFILES(46) = -9999.00 SUBFILES(48) = -9999.00 SUBFILES(50) = -9999.00 SUBFILES(52) = -9999.00 SUBFILES(54) = -9999.00 SUBFILES(56) = -9999.00 SUBFILES(58) =-9999.00 SUBFILES(60) = -9999.00 SUBFILES(62) = -9999.00 SUBFILES(64) = -9999.00 SUBFILES(65) = -9999.00 SUBFILES(66) = -9999.00 SUBFILES(67) = -9999.00 SUBFILES(68) = -9999.00 SUBFILES(69) = -9999.00 SUBFILES(70) = -9999.00 SUBFILES( 71) = -9999.00 SUBFILES(72) = -9999.00 SUBFILES(73) = -9999.00 SUBFILES(74) =-9999.00 SUBFILES(75) = -9999.00 SUBFILES(76) =-9999.00 SUBFILES(77) =-9999.00 SUBFILES(78) =-9999.00 SUBFILES(79) = -9999.00 SUBFILES(80) =-9999.00 SUBFILES( 81) = -9999.00 SUBFILES(82) = -9999.00 SUBFILES(83) = -9999.00 SUBFILES(84) =-9999.00 SUBFILES(85) = -9999.00 SUBFILES(86) = -9999.00 SUBFILES(87) =-9999.00 SUBFILES(88) =-9999.00 SUBFILES(89) = -9999.00 SUBFILES(90) = -9999.00 SUBFILES( 91 ) = -9999.00 SUBFILES(92) = -9999.00 SUBFILES(93) = -9999.00 SUBFILES(94) = -9999.00 SUBFILES(95) = -9999.00 SUBFILES(96) = -9999.00 SUBFILES(97) = -9999.00 SUBFILES(98) = -9999.00 SUBFILES(99) = -9999.00 SUBFILES(100) = -9999.00 SUBFILES(101) = -9999.00 SUBFILES(102) = -9999.00 SUBFILES(103) = -9999.00 SUBFILES(104) = -9999.00 SUBFILES(105) = -9999.00 SUBFILES(106) = -9999.00 SUBFILES(107) -- -9999.00 SUBFILES(108) = -9999.00 SUBFILES(109) = -9999.00 SUBFILES(110) = -9999.00 SUBFILES(111 ) = -9999.00 SUBFILES(112) = -9999.00 SUBFILES(113) = -9999.00 SUBFILES(114) = -9999.00 SUBFILES(115) = -9999.00 SUBFILES(116) = -9999.00 SUBFILES(117) = -9999.00 SUBFILES(118) = -9999.00 SUBFILES(119) = -9999.00 SUBFILES(120) = -9999.00 SUBFILES(121) = -9999.00 SUBFILES(122) = -9999.00 SUBFILES(123) = -9999.00 SUBFILES(124) = -9999.00 SUBFILES(125) = -9999.00 SUBFILES(126) = -9999.00 SUBFILES(127) = -9999.00 SUBFILES(128) = -9999.00 ~-- STRING PARAMETERS ............................................. INTERPOL= YES Input Tape-Image file, LU (1) is: C:\DATA\TOMMYED\90728.TAP Output Tape-Image file, LU (2) is: C:\DATA\TOMMYED\T90728.TAP (Output Tape-Image file will be created) Listing Method ("LISTMETH") = 0, Depth Unit oriented listing. Listing Frequency ("LISTFREQ") is every ( 50) units of Depth. Listing output limiting (LISTMAX) not enabled... (to enable list limiting set LISTMAX positive) Data Statistics reporting ("STATS") has not been enabled. (Specify STATS=I to enable this feature) Automatic curve renaming has been disabled by user input (AUTOCURV=0). Automatic "FILE=n" card generation is disabled. (This is the program default, AUTOFILE=0) (Specify AUTOFILE= 1 to enable this feature) LIS comment record decoding (COMMENTS=l) has been enabled by user input. LIS information record decoding (INFORECS= i) has been enabled by user input. The WRITEASC option has not been enabled... (to write ASCII subfiles specify WRITEASC= 1) Tape Subtile I is type: LIS **** REEL HEADER **** LIS 98/01/15 TELECO Ol ** LIS CUSTOMER LIBRARY TAPE BAKER HUGHES INTEQ **** TAPE HEADER **** LIS 98/01/15 00090728 Ol TELECO DPR FOR FAIRWEATHER ARCO WARTHOG # 1 BEAUFORT. Tape Subtile: 1 2 records... Minimum record length: 132 bytes Maximum record length: 132 bytes Tape Subtile 2 is type: LIS **** FILE HEADER **** MAIN .001 1024 CN : WN : FN : WARTHOG UNIT COUN : BEAUFORT SEA STAT :ALASKA LIS COMMENT RECORD(s): 12345678901234567890123456789012345678901234567890123456789012345678901234567890 THIS FILE CONTAINS THE DPR DATA FROM FAIRWEATHER ARCO WARTHOG #1 WELL IN WARTHOG UNIT, BEAUFORT SEA, ALASKA API# 55-171-00012. KB=91 FEET. * FORMAT RECORD (TYPE# 64) Entry Type(4) Size(1) Repcode(66) Logging direction is down (value= 255) Entry Type(12) Size(4) Repcode(68) Null data value is: -999.250000 Entry Type(16) Size(1) Repcode(66) Datum Specification Block Sub-type is: Entry Block terminator. Summary of entry types encountered: 1 2 3 4 5 6 7 8 910 11 12 13 14 15 16 000 1 0000000 I 000 I Rep Code Count Bytes 68 23 92 Sum: 23 92 92 fndun a [FT ] 1.00000000 ONE DEPTH PER FRAME Tape depth ID: FT 23 Curves: APl API API API Log Crv Crv Name Tool Code Samples Units Size Length Typ Typ Cls Mod 1 ATBMMAIN 68 1 -DB 4 4 45 350 01 1 2 ATCMMAIN 68 1 -DB 4 4 45 350 01 1 3 AZT MAIN 68 I DEG 4 4 45 350 01 1 4 CAAMMAIN 68 I MMHO 4 4 45 350 01 1 5 CACMMAIN 68 I MMHO 4 4 45 350 01 1 6 CPAMMAIN 68 1 MMHO 4 4 45 350 01 1 7 CPCMMAIN 68 I MMHO 4 4 45 350 01 1 8 GRAM MAIN 68 I GAPI 4 4 95 580 03 1 9 GRBMMAIN 68 I CPS 4 4 95 580 03 1 10 INC MAIN 68 I DEG 4 4 95 800 03 1 11 PDBMMAIN 68 1 DEG 4 4 95 181 03 1 12 PDCMMAIN 68 1 DEG 4 4 95 181 03 1 13 RAAMMAIN 68 I OHMM 4 4 95 181 03 14 RACMMAIN 68 1 OHMM 4 4 95 181 03 15 ROPSMAIN 68 I FPH 4 4 95 970 01 1 16 RPAMMAIN 68 I OHMM 4 4 95 191 03 17 RPCMMAIN 68 1 OHMM 4 4 95 181 03 18 RPDMMAIN 68 1 PTFT 4 4 95 181 03 1 19 RPIMMAIN 68 I PTS 4 4 95 191 03 1 20 RPTMMAIN 68 1 MINS 4 4 95 181 03 1 21 TCDMMAIN 68 I DEGF 4 4 95 980 01 I 22 TVD MAIN 68 I FT 4 4 95 980 01 1 ., .~ WBCSMAIN 68 I KLB 4 4 95 980 01 1 92 ** Routine LEVONE detects data discrepancy: DSB indicates: I FRAMES Data Record Length indicates: I0 FRAMES * DATA RECORD (TYPE# 0) 966 BYTES* Total Data Records: 3719 Tape File Start Depth = 989.000000 Tape File End Depth = 10285.000000 Tape File Level Spacing = 0.250000 Tape File Depth Units = Feet **** FILE TRAILER **** LIS representation code decoding summary: Rep Code: 68 127047 datums Tape Subtile: 2 3725 records... Minimum record length: 62 bytes Maximum record length: 966 bytes Tape Subtile 3 is type: LIS **** TAPE TRAILER **** LIS 98/01/15 00090728 01 **** REEL TRAILER **** LIS 98/01/15 TELECO Ol Tape Subtile: 3 2 records... Minimum record length: 132 bytes Maximum record length: 132 bytes End of execution: Wed 21 JAN 98 10:38a Elapsed execution time = 5.55 seconds. SYSTEM RETURN CODE = 0 Tape Subtile 1 is type: LIS Tape Subtile 2 is ry. pe: LIS DEPTH ATBM ATCM CACM CPAM CPCM INC PDBM PDCM ROPS RPAM RPCM RPTM TCDM TVD AZT GRAM RAAM RPDM WBCS CAAM GRBM RACM RPIM 989.0000 12.9762 7.7505 194.8899 4909.0234 4907.2305 1581.1079 1581.4861 25.5575 7.8612 0.6281 39.8125 34.3954 0.2037 0.2038 -999.2500 0.6325 0.6323 4.0000 24.0000 174.0000 -999.2500 988.8417 -999.2500 989.2500 13.3696 8.1439 194.8503 5329.6777 1710.2520 1710.6013 25.6368 0.6298 41.2812 35.8642 0.1876 -999.2500 0.5847 0.5846 4.0000 174.0000 -999.2500 989.0917 -999.2500 5331.5957 7.8822 0.1876 25.0000 1000.0000 12.0061 6.7773 3934.1714 1556.5220 1556.9060 0.7022 39.4583 34.1085 -999.2500 0.6425 0.6423 179.0000 -999.2500 999.8417 193.1470 ~,.3258 0.2541 4.0000 -999.2500 3935.6733 9.9164 0.2542 65.OOO0 1050.0000 7.0656 1.8145 574.0985 615.5840 616.0090 1.0393 25.9062 20.4861 84.3696 1.6245 1.6234 42.5000 89.5437 1049.8342 185.2259 89.8601 1.7416 2.5000 -999.2500 574.1821 24.8725 1.7419 219.5000 I100.0000 7.1365 1.8863 193.9860 603.6578 609.6666 610.0911 57.2153 1.1000 25.7812 20.3657 1.6586 393.6849 1.6449 1.6437 1.0000 44.0000 86.5687 1099.8269 -999.2500 603.7311 16.2363 1.6588 330.4000 1150.0000 7.5503 2.3001 203.7501 783.9939 873.0205 873.4851 56.1646 1.5655 30.3021 24.8944 1.2755 446.1894 1.1515 1.1509 2.3333 41.0000 87.5188 1149.8147 -999.2500 784.0580 15.9584 1.2756 452.6667 1200.0000 7.2435 1.9929 210.2448 648.1840 688.4081 688.8407 77.4649 2.3478 27.2187 21.8220 1.5426 53.4143 1.4526 1.4517 4.0000 30.0000 87.7358 1199.7854 -999.2500 648.2435 21.5934 1.5428 615.0000 DEPTH ATBM ATCM AZT CAAM CACM CPAM CPCM GRAM GRBM INC PDBM PDCM RAAM RACM ROPS RPAM RPCM RPDM RPIM Pd:~TM TCDM TVD WBCS 1250.0000 7.0813 1.8279 215.1002 579.6437 579.5623 595.3217 595.7448 75.7223 21.1323 3.0002 25.5000 20.1001 1.7252 1.7254 272.5787 1.6798 1.6786 4.0000 777.9999 94.0000 88.7281 1249.7390 -999.2500 1300.0000 7.1086 1.8607 216.4020 593.0562 592.9795 595.1591 595.5820 56.2826 15.9896 4.0938 25.5000 20.0970 1.6862 1.6864 419.9571 !.6802 1.6790 2.0000 920.0000 74.0000 88.0554 1299.6340 -999.2500 1350.0000 7.0416 1.7951 217.6874 566.3470 566.2606 584.7167 585.1388 73.7674 20.6152 5.1875 25.2812 19.8954 1.7657 1.7660 295.2550 1.7102 1.7090 4.0000 1071.0000 50.0000 85.7022 1349.4680 -999.2500 1400.0000 6.9780 1.7319 218.7812 541.0857 540.9889 558.5914 559.0107 68.6297 19.2560 6.2813 24.7969 19.3829 !.8481 1.8485 101.7052 1.7902 1.7889 4.0000 1260.0000 61.0000 85.8875 1399.2190 -999.2500 1450.0000 7.1665 1.9200 218.7461 617.5796 617.5114 669.8789 670.3096 57.5380 16.3217 7.0079 26.9062 21.4892 1.6192 1.6194 24.1597 1.4928 1.4919 2.5000 1413.5000 39.5000 85.2888 1448.8772 -999.2500 1500.0000 7.1304 1.8859 217.3209 603.4332 603.3604 670.3928 670.8235 55.7225 15.8414 7.8684 26.9219 21.4986 1.6572 1.6574 317.9947 1.4917 1.4907 4.0000 1603.0000 79.0000 84.5938 1498.4622 -999.2500 1550.0000 7.0707 1.8250 214.9528 578.4716 578.3896 617.7360 618.1613 71.6465 20.0541 8.9211 25.9219 20.5267 1.7287 1.7289 101.2332 1.6188 1.6177 4.0000 1793.0000 43.0000 84.0473 1547.9275 -999.2500 1600.0000 791.8091 10.0000 141.7409 68.0000 7.5647 2.3171 213.2667 791.8704 798.3739 798.8212 71.3088 19.9648 29.1198 23.7074 1.2628 1.2629 1.2525 1.2518 4.0000 1987.0000 83.7669 1597.2463 -999.2500 DEPTH ATBM ATCM AZT CAAM CACM CPAM CPCM GRAM GRBM INC PDBM PDCM RAAM RACM ROPS RPAM RPCM RPDM RPIM RPTM TCDM TVD WBCS 1650.0000 6.7105 1.4698 211.9645 441.0327 440.8990 468.2427 468.6530 67.1436 18.8629 11.0937 22.9375 17.5095 2.2674 2.2681 154.0506 2.1356 2.1338 3.0000 2179.0000 58.0000 83.2875 1646.4016 -999.2500 1700.0000 6.7787 1.5320 213.5468 464.1194 463.9819 497.6224 498.0401 71.4333 19.9977 12.2082 23.5417 18.1371 2.1546 2.1553 254.4179 2.0096 2.0079 4.0000 2370.0000 65.0000 82.5125 1695.3713 -999.2500 1750.0000 6.9433 1.6987 216.2510 528.0139 527.9119 557.4897 557.9091 69.9117 19.5952 13.3306 24.7969 19.3611 1.8939 1.8943 113.7401 1.7938 1.7924 4.0000 2564.0000 72.0000 82.2087 1744.1360 -999.2500 1800.0000 450.0937 14.4000 103.8515 5O.OOO0 6.7368 1.4947 217.4601 450.2294 462.2192 462.6277 54.5494 15.5310 22.8125 17.3783 2.2211 2.2218 2.1635 2.1616 4.0000 2732.0000 80.9938 1792.6785 -999.2500 1850.0000 717.2288 15.4526 290.7394 71.0000 7.3878 2.1520 218.1968 717.3073 805.4189 805.8673 58.3931 16.5479 29.2812 23.8236 1.3941 1.3943 1.2416 1.2409 4.0000 2924.0000 80.8812 1840.9915 -999.2500 1900.0000 644.7362 17.2748 177.1581 48.0000 7.2265 1.9847 217.9832 644.7966 687.9700 688.4027 59.0808 16.7299 27.2656 21.8142 1.5509 1.5510 1.4536 1.4526 4.0000 3110.0000 79.4341 1888.9773 -999.2500 1950.0000 7.0972 1.8602 217.6148 592.8412 592.7646 688.0576 688.4904 67.3954 18.9295 19.2221 27.2500 21.8158 1.6868 1.6870 78.7530 1.4534 1.4525 3.0000 3289.9995 47.0000 80.0586 1936.4602 -999.2500 2000.0000 7.8619 2.6205 218.6667 936.5842 936.6918 1173.1504 1173.7371 39.1391 11.4542 20.0619 34.7604 29.2887 1.0677 1.0676 244.0926 0.8524 0.8520 4.0000 3454.0000 294.0000 79.8913 1983.5427 -999.2500 DEPTH ATBM ATCM AZT CAAM CACM CPAM CPCM GRAM GRBM INC PDBM PDCM RAAM RACM ROPS RPAM RPCM RPDM RPIM RPTM TCDM TVD WBCS 2050.0000 7.8604 2.6216 219.0000 937.1355 937.2430 1085.9429 1086.5361 57.5750 16.3315 21.5031 33.5625 28.0845 1.0671 1.0670 191.9363 0.9209 0.9204 4.0000 3603.0000 45.0000 78.5750 2030.3201 -999.2500 2100.0000 7.3838 2.1426 220.0840 713.0479 713.0597 747.3694 747.8829 51.5827 14.7462 22.8048 28.3281 22.8501 1.4024 1.4024 132.8536 1.3381 1.3372 2.0000 3781.5000 128.0000 78.5188 2076.5874 -999.2500 2150.0000 7.2041 1.9638 221.8806 635.9205 635.8817 645.5670 646.0638 47.7880 13.7423 23.3274 26.5312 21.0454 1.5725 1.5726 69.0828 1.5490 1.5478 4.0000 3929.0000 51.0000 79.5538 2122.5640 -999.2500 2200.0000 6.9280 1.6840 220.1066 522.2561 522.1356 558.1979 558.6871 56.4883 16.0440 22.9242 24.8750 19.3751 1.9148 1.9152 122.0463 1.7915 1.7899 4.0000 4127.0000 67.0000 79.4187 2168.5454 -999.2500 2250.0000 7.0677 1.8239 218.9719 577.9977 577.9147 610.3821 610.8755 69.9935 19.6168 24.6625 25.8437 20.3876 1.7301 1.7304 126.2548 1.6383 1.6370 4.0000 4327.0000 57.0000 79.3500 2214.3169 -999.2500 2300.0000 6.7934 1.5542 218.7360 472.4780 472.3195 503.3040 503.7996 67.7348 19.0193 25.8443 23.7812 18.2564 2.1165 2.1172 69.4738 1.9869 1.9849 4.0000 4524.0000 163.0000 79.8688 2259.4927 -999.2500 2350.0000 7.0834 1.8416 218.9423 585.2340 585.1562 665.7336 666.2330 58.8059 16.6571 26.6691 26.9062 21.4142 1.7087 1.7089 125.5020 1.5021 1.5010 3.0000 4717.0000 59.0000 76.5050 2304.3364 -999.2500 2400.0000 6.9137 1.6717 219.3751 517.4570 517.3339 566.8090 567.2988 61.1874 17.2871 27.3875 25.0781 19.5454 1.9325 1.9330 140.8226 1.7643 1.7627 4.0000 4893.0000 45.0000 78.6187 2348.8677 -999.2500 DEPTH ATBM ATCM AZT CAAM CACM CPAM CPCM GRAM GRBM INC PDBM PDCM RAAM RACM ROPS RPAM RPCIVl RPDM RPIM RPTM TCDM TVD WBCS 2450.0000 >60.~627 28.0646 236.2259 41.0000 7.0209 1.7804 219.8957 560.4584 599.8135 600.3060 56.2269 15.9748 25.7187 20.1861 1.7843 1.7846 1.6673 1.6659 3.5000 5059.5000 79.3668 2393.1255 -999.2500 2500.0000 597.7198 29.6167 288.5500 31.0000 7.1130 1.8723 221.2083 597.7881 660.0616 660.5603 49.2360 14.1254 26.8437 21.3111 1.6728 1.6730 1.5150 1.5139 4.0000 5225.0000 78.6125 2436.9634 -999.2500 2550.0000 518.5168 31.3875 136.2755 35.0000 6.9147 1.6747 222.7189 518.6394 509.0158 509.5123 51.9104 14.8329 23.8958 18.3741 1.9284 1.9289 1.9657 1.9637 2.0000 5343.6670 77.9000 2480.0444 -999.2500 2600.0000 624.5209 32.4250 342.4937 28.0000 7.1756 1.9368 223.8624 624.5686 677.0654 677.5664 44.7593 12.9411 27.1562 21.6189 1.6011 1.6012 1.4770 1.4759 3.0000 5480.0000 76.5750 2522.4712 -999.2500 2650.0000 7.1092 1.8700 224.9561 596.8353 596.7664 619.6438 620.1381 53.9693 15.3776 33.3625 26.0937 20.5626 1.6755 1.6757 244.0926 1.6138 1.6125 4.0000 5635.0000 41.0000 76.2426 2564.4536 -999.2500 2700.0000 7.9828 2.7444 224.6500 998.6844 998.7867 1053.4316 1054.0242 41.4186 12.0573 35.0500 33.1500 27.6220 1.0013 1.0012 191.8913 0.9494 0.9488 3.0000 5798.6670 43.3333 76.2793 2605.8110 -999.2500 2750.0000 537.5258 36.7042 366.1389 33.0000 6.9560 1.7231 224.2707 537.6368 555.7974 556.2864 58.6929 16.6272 24.8750 19.3267 1.8601 i.8605 i.7997 1.7981 1.6667 5892.6660 76.7335 2646.3091 -999.2500 2800.0000 7.2239 t.9845 223.5416 644.6860 644.6537 675.1555 675.6562 52.2669 14.9272 36.8083 27.1250 21.5845 1.5511 1.5512 393.6848 1.4811 1.4800 3.0000 6067.0000 50.0000 75.8669 2686.3677 -999.2500 DEPTH ATBM ATCM AZT CAAM CACM CPAM CPCM GRAM GRBM INC PDBM PDCM RAAM RACM ROPS RPAM RPCM RPDM RPIM RPTM TCDM TVD WBCS 2850.0000 780.0509 36.8472 215.3758 52.0000 7.5313 2.2915 222.9661 779.9991 912.2782 912.8533 45.0792 13.0257 31.0625 25.5251 1.2821 1.2820 1.0962 1.0955 4.0000 6237.0000 76.7188 2726.3774 -999.2500 2900.0000 6.6693 1.4310 223.5154 426.8711 426.7256 456.7325 457.2139 62.9856 17.7629 36.4077 22.7969 17.2579 2.3426 2.3434 72.3094 2.1895 2.1872 4.0000 6410.0000 59.0000 77.3150 2766.5044 -999.2500 2950.0000 479.6376 36.1000 164.3311 31.0000 6.8088 1.5736 223.3698 479.7955 507.7180 508.2145 68.5739 19.2412 23.8906 18.3486 2.0842 2.0849 1.9696 1.9677 4.0000 6593.0000 77.7125 2806.8462 -999.2500 3000.0000 6.7831 1.5470 221.6019 469.7929 469.6143 517.7401 518.3092 67.1048 18.8526 36.1000 24.0937 18.5564 2.1286 2.1294 198.9270 1.9315 1.9294 3.0000 6778.9990 475.0000 79.5794 2847.2515 -999.2500 3050.0000 482.2762 36.1337 105.3470 53.5000 6.8150 1.5805 219.9283 482.4525 512.1577 512.7253 62.0267 17.5092 23.9844 18.4392 2.0732 2.0740 1.9537 1.9516 3.5000 6971.5000 76.9437 2887.6519 -999.2500 3100.0000 6.8265 1.5906 218.4547 486.2664 486.0908 520.0903 520.6602 74.7934 20.8866 36.2389 24.1562 18.6048 2.0565 2.0572 121.7850 1.9227 1.9206 4.0000 7165.0000 57.0000 77.6539 2928.0083 -999.2500 3150.0000 6.7010 1.4591 218.0594 437.1637 436.9938 483.7936 484.3533 63.9146 18.0086 36.4094 23.4062 17.8439 2.2875 2.2884 95.0693 2.0670 2.0646 4.0000 7351.0000 50.0000 77.8250 2968.3062 -999.2500 3200.0000 534.2006 36.6698 212.6138 48.0000 6.9491 1.7147 219.1532 534.3153 560.1144 560.6731 49.3502 14.1556 24.9896 19.4131 1.8716 1.8720 1.7853 1.7836 4.0000 7542.0000 78.1500 3008.4819 -999.2500 DEPTH ATBM ATCM AZT CAAM CACM CPAM CPCM GRAM GRBM INC PDBM PDCM RAAM RACM ROPS RPAM RPCM RPDM RPIM RPTM TCDM TVD WBCS 3250.0000 508.7471 36.9562 171.8006 47.0000 6.8856 1.6496 219.4135 508.9116 562.3765 562.9354 65.6110 18.4574 25.0000 19.4579 1.9650 1.9656 1.7782 1.7764 4.0000 7724.0000 78.5188 3048.5161 -999.2500 3300.0000 462.1577 37.2687 196.8424 71.0000 6.7591 1.5271 218.8407 462.3359 493.4257 493.9886 69.6576 19.5279 23.6250 18.0486 2.1629 2.1638 2.0266 2.0243 4.0000 7856.0000 78.9406 3088.3892 -999.2500 3350.0000 538.3444 37.4000 131.7561 71.0000 6.9601 1.7252 218.5999 538.4551 538.0065 538.5795 60.7849 17.1807 24.5312 18.9704 1.8572 1.8575 1.8587 1.8567 4.0000 8051.0000 76.2688 3128.1255 -999.2500 3400.0000 6.7883 1.5593 218.5999 474.4078 474.2296 497.5729 498.1371 69.1443 19.3922 37.4000 23.7187 18.1361 2.1079 2.1087 98.9759 2.0098 2.0075 4.0000 8245.0000 43.0000 76.2688 3167.8423 -999.2500 3450.0000 6.8562 1.6221 218.5999 498.3230 498.1522 510.0450 510.6125 73.0144 20.4160 37.1875 23.9531 18.3970 2.0067 2.0074 166.3940 1.9606 1.9584 4.0000 8437.0000 63.0000 76.1665 3207.6030 -999.2500 3500.0000 6.9129 1.6795 218.5999 520.4886 520.3619 516.2266 516.7955 76.4.623 21.3281 36.8750 24.0937 18.5251 1.9213 1.9217 161.0856 1.9371 1.9350 4.0000 8634.0000 65.0000 77.0112 3247.5200 -999.2500 3550.0000 441.0643 36.6021 141.7746 57.0000 6.7036 1.4702 218.4812 441.2363 470.4036 470.9583 73.0103 20.4149 23.1250 17.5564 2.2664 2.2672 2.1258 2.1233 4.0000 8832.0000 76.8125 3287.5884 -999.2500 3600.0000 6.7516 1.5151 218.3250 457.8265 457.6491 500.0994 500.6643 76.6353 21.3739 36.3417 23.7812 18.1892 2.1842 2.1851 154.0819 1.9996 1.9973 4.0000 9029.0000 90.0000 75.2562 3327.7983 -999.2500 DEPTH ATBM ATCM AZT CAAM CACM CPAM CPCM GRAM GRBM INC PDBM PDCM RAAM RACM ROPS RPAM RPCM RPDM RPIM RPTM TCDM TVD WBCS 3650.0000 468.5435 36.4750 118.1295 65.0000 6.7601 1.5442 217.9938 468.7222 489.7379 490.2996 65.9410 18.5447 23.5312 17.9704 ~ 1335 ~ ..... .... ID~D 2.0419 2.0396 4.0000 9229.0000 73.8387 3368.0522 -999.2500 3700.0000 6.8569 1.6269 217.6292 500.1707 500.0011 488.4918 489.0531 69.5599 19.5021 36.6833 23.5312 17.9439 1.9994 2.0001 130.7896 2.0472 2.0448 3.5000 9428.5000 63.0000 75.7063 3408.2085 -999.2500 3750.0000 6.6641 1.4278 216.2583 425.7312 425.5687 438.4523 438.9920 76.3525 21.2991 36.3167 22.4062 16.8517 2.3489 2.3498 114.3188 2.2807 2.2779 4.0000 9619.0000 46.0000 75.9313 3448.3892 -999.2500 3800.00O0 451.3086 35.9000 126.2796 63.0000 6.7364 1.4980 214.8002 451.4846 470.1874 470.7419 71.1511 19.9230 23.1250 17.5517 2.2149 2.2158 2.1268 2.1243 4.0000 9817.0000 76.5313 3488.7944 -999.2500 3850.0000 6.8890 1.6552 215.1685 511.0612 510.9272 576.7670 577.3273 65.9551 18.5484 35.5316 25.3125 19.7407 1.9567 1.9572 185.5771 1.7338 1.7321 4.0000 10014.0000 66.0000 76.9284 3529.3853 -999.2500 3900.0000 7.1804 1.9451 215.4142 629.8418 629.8258 556.3545 556.9198 67.8547 19.0510 35.2625 24.8906 19.3189 1.6113 1.6114 86.4362 1.8100 1.8081 2.5000 10193.5000 59.0000 77.6268 3570.1616 -999.2500 3950.0000 7.6622 2.4267 214.5548 842.9270 843.0750 974.1874 974.8712 36.6817 10.8041 35.8875 32.0312 26.4579 1.1867 1.1865 263.4013 1.0282 i.0274 2.0000 10353.5000 59.0000 77.4864 3610.8306 -999.2500 4000.0000 15.5970 10.7388 214.5197 8546.5215 8539.5684 601.9296 602.9700 34.9076 13.5670 35.7906 25.3125 20.2170 0.1170 0.1171 295.3236 1.6613 1.6585 3.0000 10515.0000 7745.0000 78.1813 3651.3335 -999.2500 DEPTH ATBM ATCM AZT CAAM CACM CPAM CPCM GRAM GRBM INC PDBM PDCM RAAM RACM ROPS RPAM RPCM RPDM RPIM RPTM TCDM TVD WBCS 4050.0000 6.6521 1.6852 214.6656 524.9808 525.2463 493.6640 494.5650 87.3596 32.2999 35.5350 23.6875 18.0420 1.9048 1.9039 183.1055 2.0257 2.0220 3.0000 10687.0000 100.0000 71.6000 3691.9536 -999.2500 4100.0000 6.5639 1.6135 214.8127 497.1263 497.3809 504.7302 505.6363 94.2808 34.7717 35.2872 _~.8750 18.2748 2.0116 2.0105 244.6899 1.9813 1.9777 3.0000 10853.0000 81.0000 74.1875 3732.7104 -999.2500 4150.0000 6.5141 1.5637 214.9723 478.1488 478.3988 487.7750 488.6733 78.2952 29.0626 35.1276 23.5000 17.9170 2.0914 2.0903 253.1346 2.0501 2.0464 2.5000 11008.5000 43.0000 77.4698 3773.5601 -999.2500 4200.0000 7.2798 2.3282 215.0687 799.8528 800.1954 916.8813 917.8846 42.1809 16.1646 34.9688 31.1563 25.5904 1.2502 1.2497 215.4182 1.0907 1.0895 3.0000 11157.0000 109.0000 78.8866 3814.4976 -999.2500 4250.0000 6.4304 1.4806 214.9125 447.0384 447.2823 455.7877 456.6702 87.8384 32.4709 34.8125 22.7813 17.2248 2.2369 2.2357 254.4179 2.1940 2.1898 3.0000 11306.0000 46.0000 78.4394 3855.5083 -999.2500 4300.0000 6.3794 1.4262 214.7999 427.1077 427.3483 422.8782 423.7425 79.7054 29.5662 34.8192 22.0469 16.4857 2.3414 2.3401 261.4763 2.3647 2.3599 3.5000 11454.5000 24.0000 80.2468 3896.5874 -999.2500 4350.0000 6.4990 1.5462 214.7999 471.5272 471.7758 482.5768 483.4727 78.3507 29.0824 35.2447 23.3594 17.8061 2.1208 2.1197 269.9208 2.0722 2.0683 2.5000 11631.5000 64.0000 80.7844 3937.5298 -999.2500 4400.0000 6.4440 1.4964 214.4251 452.8905 453.1357 477.9650 478.8587 73.7644 27.4444 35.5000 23.1875 17.7076 2.2080 2.2068 244.6899 2.0922 2.0883 3.0000 11779.0000 44.0000 81.4812 3978.2720 -999.2500 DEPTH ATBM ATCM AZT CAAM CACM CPAM CPCM GRAM GRBM INC PDBM PDCM RAAM RACM ROPS RPAM RPCM RPDM RPIM RPTM TCDM TVD WBCS 4450.0000 6.4741 1.5245 213.4876 463.3923 463.6393 460.7646 461.6497 80.5196 29.8570 35.5000 22.8125 17.3342 2.1580 2.1568 223.1548 2.1703 2.1661 3.0000 11948.0000 50.0000 82.0513 4018.9800 -999.2500 4500.0000 6.6050 1.6577 213.3500 514.2140 514.4766 547.5173 548.4396 78.2121 29.0329 35.3000 24.5938 19.1514 1.9447 1.9437 208.4638 1.8264 1.8234 4.0000 12128.0000 44.0000 83.0589 4059.7124 -999.2500 4550.0000 6.5933 1.6400 214.0790 507.3741 507.6313 521.7537 522.6669 90.2007 33.3145 34.8833 24.0781 18.6279 1.9709 1.9699 157.4539 1.9166 1.9133 4.0000 12291.0000 29.0000 84.2625 4100.6250 -999.2500 4600.0000 6.4021 1.4500 214.1892 435.8052 436.0474 448.3036 449.1820 90.1486 33.2959 34.9107 22.5000 17.0592 2.2946 2.2933 50.8626 2.2306 2.2263 3.0000 12476.0000 61.0000 84.9594 4141.6797 -999.2500 4650.0000 6.4498 1.4893 213.8129 450.2552 450.5000 465.5541 466.4417 79.1190 29.3568 35.2871 22.9063 17.4389 2.2210 2.2198 295.2034 2.1480 2.1439 4.0000 12668.0000 51.0000 85.7258 4182.5879 -999.2500 4700.0000 6.5176 1.5614 213.5908 477.2862 477.5359 492.7043 493.6049 96.0390 35.3996 35.9104 23.4688 18.0217 2.0952 2.0941 145.3975 2.0296 2.0259 4.0000 12861.0000 59.0000 86.2531 4223.2617 -999.2500 4750.0000 6.7707 1.8197 213.4345 578.7081 578.9888 582.4807 583.4154 64.4405 24.1145 36.6395 25.2813 19.8420 1.7280 i.7271 166.4595 1.7168 1.7140 4.0000 13016.0000 53.0000 86.2199 4263.5742 -999.2500 4800.0000 424.3256 36.8000 130.7381 41.0000 6.3708 1.4179 213.2374 424.0854 435.8777 436.7494 81.9597 30.3713 22.2188 16.7811 2.3580 2.3567 2.2942 2.2896 4.0000 13173.0000 86.0000 4303.6230 -999.2500 DEPTH ATBM ATCM AZT CAAM CACM CPAM CPCM GRAM GRBM INC PDBM PDCM RAAM RACM ROPS RPAM RPCM RPDM RPIM RPTM TCDM TVD WBCS 4850.0000 6.3190 1.3648 213.0292 404.9822 405.2191 419.0418 419.9038 92.4330 34.1118 36.8000 21.8229 16.3977 2.4692 2.4678 267.6896 2.3864 2.3815 4.0000 13346.0000 44.0000 86.4599 4343.6523 -999.2500 4900.0000 6.4560 1.4945 213.1830 452.1872 452.4321 491.1563 492.0562 100.1180 36.8564 36.7542 23.4063 17.9889 2.2115 2.2103 95.7417 2.0360 2.0323 4.0000 13529.0000 56.0000 86.6469 4383.7012 -999.2500 4950.0000 6.2098 1.2596 213.3958 368.0433 368.2807 354.2141 355.0333 93.8966 34.6345 36.7010 20.2500 14.8436 2.7171 __.715~ 236.2589 2.8232 2.8166 4.0000 13676.0000 60.0000 87.4063 4423.7793 -999.2500 5000.0000 7.4781 1.9676 212.4811 640.0851 640.3832 744.5748 745.5520 47.8114 19.6315 36.8531 28.3437 22.7949 i.5623 1.5616 311.2924 1.3430 1.3413 3.0000 13820.0000 838.0000 87.6922 4463.8281 -999.2500 5050.0000 7.1264 1.6137 211.6123 497.2159 497.4705 543.6224 544.5433 72.0067 29.0096 36.9938 24.6250 19.0731 2.0112 2.0102 244.1406 1.8395 1.8364 4.0000 14008.0000 822.0000 89.4875 4503.7988 -999.2500 5100.0000 6.9143 !.4042 211.8186 419.1277 419.3668 447.9437 448.8220 88.7423 35.4962 36.8907 22.6250 17.0512 2.3859 2.3845 118.0861 2.2324 2.2281 4.0000 14202.0000 65.0000 81.7437 4543.7598 -999.2500 5150.0000 7.1255 1.6260 211.9306 501.9528 502.2084 526.8466 527.7618 69.7927 28.1514 36.7937 24.3125 18.7324 1.9922 1.9912 126.5673 1.8981 1.8948 4.0000 14400.0000 64.0000 83.8437 4583.7793 -999.2500 5200.0000 7.1832 1.6675 211.3517 518.0468 518.3104 495.4291 496.3310 80.9828 32.4887 36.7410 23.6875 18.0793 1.9303 1.9293 104.6317 2.0185 2.0148 4.0000 14548.0000 45.0000 85.0438 4623.8281 -999.2500 DEPTH ATBM ATCM AZT CAAM CACM CPAM CPCM GRAM GRBM INC PDBM PDCM RAAM RACM ROPS RPAM RPCM RPDM RPIM RPTM TCDM TVD WBCS 5250.0000 6.9839 1.4778 211.0587 446.0043 446.2479 485.8585 486.7559 73.4784 29.5800 36.7454 23.4687 17.8762 2.2421 2.2409 170.6937 2.0582 2.0544 3.0000 14714.0000 32.0000 85.8125 4663.9062 -999.2500 5300.0000 1082.8347 36.9515 253.1346 48.OO00 8.4136 2.8999 211.7805 1082.4626 1217.9753 1218.9846 34.6367 14.5251 35.5000 29.8871 0.9238 0.9235 0.8210 0.8204 2.0000 14843.0000 86.4798 4703.9160 -999.2500 5350.0000 7.2591 1.7492 212.1958 550.3047 550.5773 554.0674 554.9921 67.1809 27.1391 37.0554 24.8906 19.2824 1.8172 1.8163 343.5356 1.8048 1.8018 4.0000 14997.0000 53.0000 86.5063 4743.8281 -999.2500 5400.0000 7.0163 1.5203 211.8235 461.8068 462.0533 478.0290 478.9227 85.7487 34.3360 36.8957 23.3125 17.7090 2.1654 2.1643 118.1326 2.0919 2.0880 4.0000 15144.0000 60.0000 87.7437 4783.7793 -999.2500 5450.0000 7.4200 1.9105 211.3053 616.1068 616.3979 528.3745 529.2904 102.8981 40.9830 36.7368 24.4375 18.7637 1.6231 1.6223 145.3975 1.8926 1.8893 3.0000 15294.0000 51.0000 88.5144 4823.7988 -999.2500 5500.0000 6.9600 1.4468 210.5683 434.6147 434.8563 489.1606 490.0596 84.3065 33.7769 36.5790 23.5937 17.9465 2.3009 2.2996 101.2500 2.0443 2.0406 4.0000 15487.0000 51.0000 89.3268 4863.9160 -999.2500 5550.0000 6.7421 1.2459 210.2000 363.3170 363.5534 393.9705 394.8170 96.4493 38.4834 36.3828 21.4219 15.8121 2.7524 2.7506 201.4245 2.5383 2.5328 4.0000 15687.0000 75.0000 89.8510 4904.1113 -999.2500 5600.0000 6.6753 1.1686 210.2000 337.0745 337.3032 353.5826 354.4014 100.3017 39.9766 36.1484 20.4844 14.8277 2.9667 2.9647 54.3755 2.8282 2.8217 4.0000 15885.0000 37.0000 90.9500 4944.4238 -999.2500 DEPTH ATBM ATCM AZT CAAM CACM CPAM CPCM GRAM GRBM INC PDBM PDCM RAAM RACM ROPS RPAM RPCM RPDM RPIM RPTM TCDM TVD WBCS 5650.0000 6.7690 1.2541 210.2000 366.1320 366.3691 402.9778 403.8301 97.9621 39.0698 35.9141 21.7187 16.0246 2.7313 2.7295 141.7554 2.4815 2.4763 2.0000 16061.0000 67.0000 91.2875 4984.8633 -999.2500 5700.0000 6.6637 1.1427 210.8784 328.4410 328.6769 366.2299 367.0970 99.7377 39.7580 35.8515 20.8125 15.1418 3.0447 3.0425 85.6415 2.7305 2.7241 4.0000 16238.0000 95.0000 91.6250 5025.3711 -999.2500 5750.0000 6.8453 1.3459 211.6001 398.2407 398.4908 444.4601 445.3790 92.4491 36.9330 35.8000 22.6458 16.9736 2.5110 2.5095 51.2779 2.2499 2.2453 4.0000 16403.0000 109.0000 92.6375 5065.9277 -999.2500 5800.0000 6.6547 1.1389 211.4438 327.1661 327.4014 340.9129 341.7603 84.4459 33.8310 35.9563 20.1875 14.5074 3.0566 3.0544 180.2978 2.9333 2.9260 4.0000 16596.0000 71.0000 92.3818 5106.4258 -999.2500 5850.0000 7.1605 1.6393 211.2375 507.0798 507.3542 556.2627 557.2345 100.3590 39.9988 36.1042 25.0781 19.3262 1.9721 1.9710 137.8097 1.7977 1.7946 4.0000 16792.0000 !12.0000 92.4285 5146.8652 -999.2500 5900.0000 7.7092 2.1956 210.4563 739.4161 739.7645 869.9178 870.9717 105.9072 42.1493 36.1562 30.5844 24.8574 1.3524 1.3518 122.6618 1.1495 1.1481 4.0000 16975.0000 78.0000 93.1250 5187.2461 -999.2500 5950.0000 6.7836 1.2696 209.8908 371.4911 371.7356 424.1675 425.0742 93.3217 37.2712 36.2165 22.2500 16.5152 2.6919 2.6901 82.6858 2.3576 2.3525 4.0000 17168.0000 58.0000 93.7947 5227.6074 -999.2500 6000.0000 6.6946 1.2159 210.4578 353.0424 353.2878 364.8347 365.7008 89.4951 35.7880 36.3196 20.7969 15.1074 2.8325 2.8306 168.7564 2.7410 2.7345 4.0000 17353.0000 70.0000 94.1409 5267.9199 -999.2500 DEPTH ATBM ATCM AZT CAAM CACM CPAM CPCM GRAM GRBM INC PDBM PDCM RAAM RACM ROPS RPAM RPCM RPDM RPIM RPTM TCDM TVD WBCS 6050.0000 6.7976 1.3018 211.3517 382.7101 382.9570 388.4585 389.3416 90.9277 36.3433 36.4000 21.3437 15.6809 2.6129 2.6113 95.7806 2.5743 2.5684 4.0000 17549.0000 268.0000 94.1844 5308.1836 -999.2500 6100.0000 6.8386 1.3274 213.4043 391.7097 391.9583 401.3144 402.2062 94.7797 37.8363 36.4000 21.6875 15.9856 2.5529 2.5513 78.7484 2.4918 2.4863 4.0000 17744.0000 65.0000 93.3125 5348.4277 -999.2500 6150.0000 6.8792 1.3690 214.4968 406.4742 406.7259 402.6448 403.5376 94.0805 37.5653 36.4000 21.6875 16.0168 2.4602 2.4587 214.1036 2.4836 2.4781 3.0000 17936.0000 150.0000 92.9300 5388.6816 -999.2500 6200.0000 6.7116 1.1979 213.5496 346.9492 347.1925 368.5186 369.3874 92.5838 36.9852 36.4000 20.9062 15.1981 2.8823 2.8802 145.3420 2.7136 2.7072 4.0000 18124.0000 52.0000 89.6000 5428.9258 -999.2500 6250.0000 6.5781 1.0709 213.0884 304.8429 305.0667 329.9789 330.8172 91.2058 36.4511 36.4442 19.9375 14.2262 3.2804 3.2780 221.4026 3.0305 3.0228 3.0000 18302.0000 54.0000 92.9375 5469.1699 -999.2500 6300.0000 6.7537 1.2595 213.2990 367.9824 368.2320 405.5130 406.4077 76.1503 30.6156 36.5495 21.7812 16.0840 2.7175 2.7157 187.6004 2.4660 2.4606 4.0000 18480.0000 51.0000 93.8187 5509.3652 -999.2500 6350.0000 6.7131 1.2012 213.6707 348.0503 348.2940 374.5927 375.4659 88.8756 35.5479 36.5458 21.1250 15.3465 2.8731 2.8711 131.2550 2.6696 2.6634 2.0000 18673.0000 99.0000 94.6625 5549.5117 -999.2500 6400.0000 6.0923 0.5814 214.1917 159.1015 159.2542 132.5503 133.1621 39.1345 16.2684 36.4417 13.8047 7.9918 6.2853 6.2793 20.3451 7.5443 7.5096 4.0000 18852.0000 43.0000 96.0125 5589.7168 -999.2500 DEPTH ATBM ATCM AZT CAAM CACM CPAM CPCM GRAM GRBM INC PDBM PDCM RAAM RACM ROPS RPAM RPCM RPDM RPIM RPTM TCDM TVD WBCS 6450.0000 6.9405 1.4238 213.8633 426.2268 426.4825 429.9294 430.8396 71.8402 28.9450 36.4000 22.4375 16.6465 2.3462 2.3448 146.4844 2.3260 2.3210 4.0000 19040.0000 59.0000 96.8000 5629.9512 -999.2500 6500.0000 6.6591 1.1422 212.9685 328.2645 328.5003 348.2221 349.0752 91.2653 36.4742 36.4000 20.5000 14.6926 3.0465 3.0443 194.9280 2.8722 2.8652 3.0000 19228.5000 48.0000 97.4750 5670.1953 -999.2500 6550.0000 6.7193 1.2152 213.0723 352.8067 353.0522 401.1150 402.0068 82.9526 33.2522 36.4745 21.7656 15.9809 2.8344 2.8324 85.6054 2.4931 2.4875 4.0000 19421.0000 71.0000 98.1500 5710.4297 -999.2500 6600.0000 6.6661 1.1635 213.6042 335.3519 335.5908 359.2180 360.0798 89.7655 35.8928 36.5808 20.7344 14.9684 2.9819 2.9798 95.7417 2.7838 2.7772 4.0000 19619.0000 78.0000 98.2625 5750.6055 -999.2500 6650.0000 7.0315 1.5146 214.6064 459.6405 459.9390 420.7339 421.7327 89.3221 35.7210 36.8158 22.3229 16.4366 2.1756 2.1742 94.4723 2.3768 2.3712 4.0000 19817.0000 65.0000 98.7125 5790.7031 -999.2500 6700.0000 6.6047 1.0847 215.7117 309.3037 309.5533 341.4030 342.3373 91.3395 36.5029 37.0789 20.4125 14.5199 3.2331 3.2305 67.8168 2.9291 2.9211 4.0000 20008.0000 53.0000 100.0175 5830.6641 -999.2500 6750.0000 6.5897 1.0780 214.9937 307.1247 307.3730 334.5131 335.4410 93.2216 37.2324 37.1000 20.2187 14.3434 3.2560 3.2534 130.3564 2.9894 2.9811 4.0000 20201.0000 44.0000 100.5330 5870.5469 -999.2500 6800.0000 6.5849 1.0722 214.1175 305.2536 305.5005 339.5466 340.4792 80.2617 32.2092 37.1000 20.3542 14.4725 3.2760 3.2733 168.7564 2.9451 2.9370 4.0000 20397.0000 49.0000 100.9625 5910.4297 -999.2500 DEPTH ATBM ATCM AZT CAAM CACM CPAM CPCM GRAM GRBM INC PDBM PDCM RAAM RACM ROPS RPAM RPCM RPDM RPIM RPTM TCDM TVD WBCS 6850.0000 6.5347 1.0128 214.9958 286.1564 286.3911 311.5325 312.4384 78.8514 31.6625 37.2054 19.6432 13.7413 3.4946 3.4917 131.7561 3.2099 3.2006 4.0000 20592.0000 64.0000 101.6170 5950.2832 -999.2500 6900.0000 6.8702 1.3621 215.6925 403.9865 404.2691 357.8990 358.8482 93.3593 37.2858 37.3126 20.8125 14.9356 2.4753 2.4736 36.5349 2.7941 2.7867 4.0000 20789.0000 89.0000 102.2281 5990.0781 -999.2500 6950.0000 6.6764 1.1464 214.7980 329.6218 329.8827 359.7839 360.7347 72.5247 29.2104 37.4179 20.9062 14.9824 3.0338 3.0314 126.4643 2.7794 2.7721 4.0000 20981.0000 59.0000 101.8216 6029.8145 -999.2500 7000.0000 6.5378 1.0246 214.1819 289.9150 290.1522 318.8451 319.7582 74.1047 29.8227 37.5117 19.8170 13.9353 3.4493 3.4465 125.5246 3.1363 3.1274 4.0000 21178.0000 46.0000 102.0875 6069.5020 -999.2500 7050.0000 6.5652 1.0562 214.5542 300.0676 300.3116 414.5073 415.5016 74.7979 30.0914 37.5649 22.1295 16.2932 3.3326 3.3299 177.1942 2.4125 2.4067 4.0000 21369.0000 699.0000 102.7625 6109.1504 -999.2500 7100.0000 6.7790 1.2658 214.6033 370.1547 370.4274 366.4747 .367.4312 81.6244 32.7374 37.5642 21.0045 15.1478 2.7016 2.6996 114.4409 2.7287 2.7216 4.0000 21567.0000 78.0000 100.2875 6148.7793 -999.2500 7150.0000 6.4893 0.9707 214.0241 272.8918 273.1175 288.5169 289.3992 89.5644 35.8149 37.4590 19.0000 13.1152 3.6645 3.6614 98.4412 3.4660 3.4554 4.0000 21766.0000 64.0000 99.9500 6188.4375 -999.2500 7200.0000 6.4409 0.9214 213.9496 257.5734 257.7842 282.0902 282.9656 86.2418 34.5271 37.4000 18.8437 12.9356 3.8827 3.8795 61.3309 3.5459 3.5349 3.0000 21956.5000 230.5000 100.7600 6228.1445 -999.2500 DEPTH ATBM ATCM AZT CAAM CACM CPAM CPCM GRAM GRBM INC PDBM PDCM RAAM RACM ROPS RPAM RPCM RPDM RPIM RPTM TCDM TVD WBCS 7250.0000 6.5940 1.0837 214.5164 308.9868 309.2361 308.3018 309.2044 95.2641 38.0241 37.4000 19.5208 13.6548 3.2364 3.~aao 51.8191 3.2436 3.2341 4.0000 22151.0000 101.0000 100.1750 6267.8711 -999.2500 7300.0000 6.7649 1.2572 214.8780 367.1724 367.4493 316.2137 317.1242 88.5398 35.4178 37.3740 19.7708 13.8658 2.7235 2.7215 221.4927 3.1624 3.1533 4.0000 22350.0000 88.0000 100.9464 6307.5977 -999.2500 7350.0000 7.8798 2.3627 215.0342 815.8224 816.2628 973.1324 974.4053 42.0954 17.4160 37.3218 a2.a4a7 ~.6.44a4 1.2258 1.2251 38.9586 1.0276 1.0263 4.0000 22549.0000 73.0000 102.2000 6347.3437 -999.2500 7400.0000 6.3356 0.8210 214.4721 227.1746 227.3798 244.0309 244.9066 86.4885 34.6227 37.2701 17.7344 11.8309 4.4019 4.3979 93.2601 4.0978 4.0832 4.0000 22748.0000 66.0000 103.1000 6387.1191 -999.2500 7450.0000 6.5039 0.9929 213.3896 279.8345 280.0776 317.9460 318.9066 91.4723 36.5544 37.2185 19.8229 13.9116 3.5735 3.5704 66.5838 3.1452 3.1357 4.0000 22946.0000 48.0000 103.5219 6426.9238 -999.2500 7500.0000 6.5213 1.0051 212.9999 283.7111 283.9570 302.9561 303.9008 93.7680 37.4442 37.1663 19.4330 13.5108 3.5247 3.5217 90.7949 3.3008 3.2905 4.0000 23142.0000 78.0000 104.4313 6466.7578 -999.2500 7550.0000 6.4121 0.8956 212.9999 249.6502 249.8682 276.8589 277.7744 86.7455 34.7223 37.1137 18.7187 12.7887 4.0056 4.0021 174.3861 3.6119 3.6000 4.0000 23331.0000 54.0000 105.5047 6506.6113 -999.2500 7600.0000 6.6278 1.1042 212.9999 315.6866 315.9534 340.7292 341.7125 74.0831 29.8144 37.2990 20.4375 14.5027 3.1677 3.1650 121.9742 2.9349 2.9264 4.0000 23525.0000 97.0000 106.6437 6546.4551 -999.2500 DEPTH ATBM ATCM AZT CAAM CACM CPAM CPCM GRAM GRBM INC PDBM PDCM RAAM RACM ROPS RPAM RPCM RPDM RPIM RPTM TCDM TVD WBCS 7650.0000 6.9217 1.4091 212.9999 420.8479 421.1536 459.1416 460.2225 63.2555 25.6176 37.5677 23.2083 17.2986 2.3762 2.3744 53.2035 2.1780 2.1729 4.0000 23713.0000 81.0000 106.1825 6586.1523 -999.2500 7700.0000 6.9491 1.4336 213.6484 429.7177 430.0261 432.3419 433.4035 64.6097 26.1425 37.8316 22.6250 16.7012 2.3271 2.3254 133.3024 2.3130 2.3073 4.0000 23910.0000 46.0000 107.2625 6625.7227 -999.2500 7750.0000 7.0727 1.5559 214.3851 475.1011 475.4240 492.3267 493.4295 55.7332 22.7020 38.0947 23.9375 18.0137 2.1048 2.1034 252.0224 2.0312 2.0266 4.0000 24105.0000 50.0000 108.5000 6665.1367 -999.2500 7800.0000 7.0127 1.4970 -999.2500 453.0378 453.3536 482.9327 484.0297 54.6462 22.2807 -999.2500 23.7500 17.8137 2.2073 2.2058 159.2222 2.0707 2.0660 4.0000 24299.0000 55.0000 108.8375 -999.2500 -999.2500 7850.0000 6.8821 1.3679 -999.2500 406.0181 406.3188 480.3565 481.4517 49.7437 20.3805 -999.2500 23.6875 17.7590 2.4629 2.4611 214.1036 2.0818 2.0771 4.0000 24490.0000 54.0000 109.6250 -999.2500 -999.2500 7900.0000 6.7129 1.2035 -999.2500 348.7766 349.0612 372.4771 373.4900 72.9030 29.3570 -999.2500 21.1953 15.2949 2.8672 2.8648 205.1874 2.6847 2.6774 4.0000 24680.0000 192.0000 110.2489 -999.2500 -999.2500 7950.0000 6.5855 1.0706 -999.2500 304.7200 304.9802 326.2538 327.2229 72.2975 29.1223 -999.2500 20.0312 14.1293 3.2817 3.2789 58.1287 3.0651 3.0560 4.0000 24879.0000 81.0000 105.4625 -999.2500 -999.2500 8000.0000 6.5638 1.0513 -999.2500 298.4734 298.7294 309.6816 310.6334 71.3687 28.7623 -999.2500 19.5937 13.6918 3.3504 3.3475 77.8559 3.2291 3.2192 4.0000 25076.0000 79.0000 106.5875 -999.2500 -999.2500 DEPTH ATBM ATCM AZT CAAM CACM CPAM CPCM GRAM GRBM INC PDBM PDCM RAAM RACM ROPS RPAM RPCM RPDM RPIM RPTM TCDM TVD WBCS 8050.0000 6.5851 1.0711 -999.2500 304.8881 305.1482 331.3057 332.2798 73.0284 29.4056 -999.2500 20.1562 14.2606 3.2799 3.2771 72.2653 3.0184 3.0095 4.0000 25274.0000 287.0000 107.5550 -999.2500 -999.2500 8100.0000 6.7506 1.2338 -999.2500 359.1080 359.3972 346.5085 347.4974 68.6028 27.6902 -999.2500 20.5469 14.6496 2.7847 2.7824 89.3197 2.8859 2.8777 4.0000 25472.0000 74.0000 107.9375 -999.2500 -999.2500 8150.0000 6.6385 1.1212 -999.2500 321.2571 321.5272 340.4436 341.4267 67.6034 27.3029 -999.2500 20.3958 14.4955 3.1128 3.1102 160.9545 2.9373 2.9289 4.0000 25671.0000 55.0000 106.7000 -999.2500 -999.2500 8200.0000 6.6996 1.1731 -999.2500 338.5494 338.8289 395.8826 396.9155 60.0303 24.3676 -999.2500 21.7656 15.8574 2.9538 2.9513 69.0420 2.5260 2.5194 4.0000 25870.0000 135.0000 107.8250 -999.2500 -999.2500 8250.0000 6.7272 1.2103 -999.2500 351.1036 351.3893 364.1381 365.1436 60.6298 24.5999 -999.2500 21.0000 15.0903 2.8482 2.8458 35.4388 2.7462 2.7386 4.0000 26067.0000 102.0000 107.4875 -999.2500 -999.2500 8300.0000 6.3971 0.8808 -999.2500 245.1359 245.3512 262.3106 263.2089 79.4099 31.8790 -999.2500 18.2812 12.3715 4.0794 4.0758 98.4412 3.8123 3.7993 4.0000 26265.0000 48.0000 108.8254 -999.2500 -999.2500 8350.0000 6.6272 1.1099 -999.2500 317.5392 317.8073 350.5331 351.5259 79.0333 31.7330 -999.2500 20.6812 14.7512 3.1492 3.1466 91.5527 2.8528 2.8447 4.0000 26465.0000 80.0000 109.6812 -999.2500 -999.2500 8400.0000 6.4035 0.8816 -999.2500 245.3901 245.6055 270.1215 271.0291 81.9425 32.8607 -999.2500 18.5144 12.5969 4.0751 4.0716 121.9463 3.7020 3.6896 4.0000 26663.0000 159.0000 110.8625 -999.2500 -999.2500 DEPTH ATBM ATCM AZT CAAM CACM CPAM CPCM GRAM GRBM INC PDBM PDCM RAAM RACM ROPS RPAM RPCM RPDM RPIM RPTM TCDM TVD WBCS 8450.0000 6.3208 0.7907 -999.2500 218.2299 218.4308 244.0637 244.9395 79.8212 32.0385 -999.2500 17.8010 11.8319 4.5823 4.5781 31.3363 4.0973 4.0826 4.0000 26859.0000 135.0000 108.9500 -999.2500 -999.2500 8500.0000 6.7318 1.2185 -999.2500 353.9057 354.1926 346.6320 347.6210 67.2222 27.1551 -999.2500 20.6094 14.6528 2.8256 2.8233 74.5676 2.8849 2.8767 4.0000 27056.0000 95.0000 110.5531 -999.2500 -999.2500 8550.0000 6.3466 0.8317 -999.2500 230.3702 230.5770 254.6068 255.4957 92.1175 36.8044 -999.2500 18.1042 12.1460 4.3408 4.3369 90.8688 3.9276 3.9140 4.0000 27255.0000 85.0000 112.0812 -999.2500 -999.2500 8600.0000 6.2928 0.7780 -999.2500 214.5065 214.7059 259.0944 259.9888 70.6661 28.4899 -999.2500 18.2437 12.2777 4.6619 4.6575 101.2538 3.8596 3.8463 4.0000 27454.0000 216.0000 111.8750 -999.2500 -999.2500 8650.0000 6.4776 0.9523 -999.2500 267.1161 267.3458 294.6913 295.6270 79.9062 32.0714 -999.2500 19.3125 13.2856 3.7437 3.7405 33.8883 3.3934 3.3826 4.0000 27654.0000 91.0000 110.0187 -999.2500 -999.2500 8700.0000 6.9801 1.4632 -999.2500 440.5707 440.8825 482.9572 484.0541 53.5088 21.8398 -999.2500 23.8333 17.8142 2.2698 2.2682 82.4159 2.0706 2.0659 4.0000 27854.0000 79.0000 112.9062 -999.2500 -999.2500 8750.0000 6.5532 1.0226 -999.2500 289.2788 289.5285 318.0841 319.0447 64.6786 26.1692 -999.2500 19.9375 13.9152 3.4569 3.4539 101.1714 3.1438 3.1344 4.0000 28054.0000 119.0000 113.7072 -999.2500 -999.2500 8800.0000 6.1281 0.6081 -999.2500 166.3537 166.5378 178.3276 179.1107 52.6484 21.5064 -999.2500 15.7135 9.7038 6.0113 6.0046 107.3904 5.6077 5.5831 4.0000 28253.0000 118.0000 113.7875 -999.2500 -999.2500 DEPTH ATBM ATCM AZT CAAM CACM CPAM CPCM GRAM GRBM INC PDBM PDCM RAAM RACM ROPS RPAM RPCM RPDM RPIM RPTM TCDM TVD WBCS 8850.0000 6.3873 0.8644 -999.2500 240.1913 240.4015 251.5076 252.3927 72.4031 29.1632 -999.2500 18.0937 12.0543 4.1633 4.1597 65.3433 3.9760 3.9621 4.0000 28453.0000 83.0000 114.0125 -999.2500 -999.2500 8900.0000 6.4006 0.8714 -999.2500 242.3011 242.5145 263.8721 264.7723 77.7354 31.2300 -999.2500 18.4625 12.4168 4.1271 4.1235 82.1185 3.7897 3.7768 4.0000 28653.0000 70.0000 116.0150 -999.2500 -999.2500 8950.0000 6.5522 1.0340 -999.2500 292.9255 293.1779 296.1166 297.0539 65.8394 26.6191 -999.2500 19.3359 13.3246 3.4138 3.4109 76.1257 3.3770 3.3664 4.0000 28852.0000 133.0000 116.8025 -999.2500 -999.2500 9000.0000 6.4448 0.9226 -999.2500 257.9093 258.1328 274.4348 275.3475 69.7003 28.1156 -999.2500 18.7500 12.7199 3.8773 3.8740 57.6252 3.6439 3.6318 4.0000 29049.0000 114.0000 117.3875 -999.2500 -999.2500 9050.0000 6.4356 0.9214 -999.2500 257.5612 257.7843 271.3466 272.2557 71.7389 28.9058 -999.2500 18.5573 12.6319 3.8826 3.8792 80.5428 3.6853 3.6730 4.0000 29245.0000 2891.0000 116.5813 -999.2500 -999.2500 9100.0000 6.2936 0.7733 -999.2500 213.1197 213.3185 222.2831 223.1300 75.6070 30.4051 -999.2500 17.1042 11.1616 4.6922 4.6878 32.0155 4.4988 4.4817 4.0000 29445.0000 91.0000 110.8625 -999.2500 -999.2500 9150.0000 6.2653 0.7579 -999.2500 208.6367 208.8338 223.6243 224.4825 76.5567 30.7731 -999.2500 17.1354 11.2038 4.7930 4.7885 38.9586 4.4718 4.4547 4.0000 29645.0000 81.0000 109.3250 -999.2500 -999.2500 9200.0000 6.1482 0.6346 -999.2500 173.6735 173.8595 112.7503 113.4174 55.3396 22.5495 ~999.2500 13.1094 7.1684 5.7579 5.7518 58.0965 8.8692 8.8170 1.0000 29845.0000 80.0000 109.3550 -999.2500 -999.2500 DEPTH ATBM ATCM AZT CAAM CACM CPAM CPCM GRAM GRBM INC PDBM PDCM RAAM RACM ROPS RPAM RPCM RPDM RPIM RPTM TCDM TVD WBCS 9250.0000 6.3060 0.7771 -999.2500 214._>>~ 214.4545 233.5042 234.3665 73.1382 29.4481 -999.2500 17.5187 11.5106 4.6673 4.6630 66.8113 4.2826 4.2668 4.0000 30041.0000 300.0000 112.3437 -999.2500 -999.2500 9300.0000 6.4710 0.9577 -999.2500 268.7908 269.0260 274.0501 274.9624 58.1128 23.6244 -999.2500 18.6875 12.7090 3.7204 3.7171 30.2896 3.6490 3.6369 4.0000 30236.0000 135.0000 115.3250 -999.2500 -999.2500 9350.0000 6.6159 1.0869 -999.2500 310.0293 310.2926 313.0760 314.0315 63.4734 25.7021 -999.2500 19.8125 13.7824 3.2255 3.2228 83.2298 3.1941 3.1844 4.0000 30436.0000 121.0000 115.6775 -999.2500 -999.2500 9400.0000 6.3546 0.8237 -999.2500 227.9945 228.2002 254.4125 255.3012 67.4675 27.2502 -999.2500 18.1719 12.1402 4.3861 4.3821 58.0492 3.9306 3.9169 4.0000 30636.0000 134.0000 116.7406 -999.2500 -999.2500 9450.0000 6.3537 0.8377 -999.2500 232.1730 232.3808 259.9681 260.8635 71.2266 28.7072 -999.2500 18.3021 12.3033 4.3071 4.3033 52.0735 3.8466 3.8334 4.0000 30835.0000 125.0000 117.9500 -999.2500 -999.2500 9500.0000 6.2179 0.6917 -999.2500 189.6741 189.8648 210.9847 211.8160 77.2610 31.0461 -999.2500 16.8438 10.8012 5.2722 5.2669 73.8309 4.7397 4.7211 4.0000 31035.0000 210.0000 119.1875 -999.2500 -999.2500 9550.0000 6.2726 0.7410 -999.2500 203.7544 203.9495 227.1962 228.0497 74.4232 29.9462 -999.2500 17.3656 11.3153 4.9079 4.9032 66.5838 4.4015 4.3850 4.0000 31235.0000 162.0000 119.4125 -999.2500 -999.2500 9600.0000 6.2876 0.7569 -999.2500 208.3575 208.5543 227.8986 228.7530 93.8663 37.4823 -999.2500 17.3984 11.3371 4.7994 4.7949 11.3223 4.3879 4.3715 4.0000 31435.0000 128.0000 120.6500 -999.2500 -999.2500 DEPTH ATBM ATCM AZT CAAM CACM CPAM CPCM GRAM GRBM INC PDBM PDCM RAAM RACM ROPS RPAM RPCM RPDM RPIM RPTM TCDM TVD WBCS 9650.0000 6.3526 0.8188 -999.2500 226.5193 226.7242 248.3048 249.1859 74.7449 30.0709 -999.2500 18.0313 11.9590 4.4146 4.4106 55.4865 4.0273 4.0131 4.0000 31634.0000 231.0000 122.4219 -999.2500 -999.2500 9700.0000 204.2163 -999.2500 48.1477 1452.0000 6.2531 0.7419 -999.2500 203.9773 235.0400 236.0630 78.6672 31.5912 17.4972 11.5577 4.9025 4.8968 4.2546 4.2362 4.0000 31834.0000 123.3219 -999.2500 -999.2500 9750.0000 6.1358 0.6083 -999.2500 166.3779 166.6040 191.8340 192.7840 89.4235 35.7603 -999.2500 16.1719 10.1684 6.0104 6.0023 14.9356 5.2128 5.1872 4.0000 32034.0000 332.0000 111.0875 -999.2500 -999.2500 9800.0000 6.1439 0.6382 -999.2500 174.6086 174.8380 191.5777 192.5273 87.0519 34.8410 -999.2500 16.1648 10.1597 5.7271 5.7196 22.5725 5.2198 5.1941 4.0000 32233.0000 221.0000 115.5312 -999.2500 -999.2500 9850.0000 6.1617 0.6368 -999.2500 174.2402 174.4695 195.2680 196.2242 86.4656 34.6138 -999.2500 16.3250 10.2840 5.7392 5.7317 19.1561 5.1212 5.0962 4.0000 32433.0000 198.0000 118.6250 -999.2500 -999.2500 9900.0000 6.1792 0.6456 -999.2500 176.6731 176.9032 200.1120 201.0766 81.2418 32.5891 -999.2500 16.5333 10.4455 5.6602 5.6528 31.0867 4.9972 4.9732 4.0000 32633.0000 141.0000 119.5250 -999.2500 -999.2500 9950.0000 6.2356 0.7018 -999.2500 192.4820 192.7165 209.0705 210.0505 79.6717 31.9805 -999.2500 16.8333 10.7392 5.1953 5.1890 30.2415 4.7831 4.7608 4.0000 32833.0000 157.0000 121.3250 -999.2500 -999.2500 10000.0000 6.2185 0.6785 -999.2500 185.8737 186.1076 209.9841 210.9657 89.7087 35.8708 -999.2500 16.8661 10.7688 5.3800 5.3732 21.9288 4.7623 4.7401 4.0000 33033.0000 175.0000 123.6312 -999.2500 -999.2500 DEPTH ATBM ATCM CACM CPAM CPCM INC PDBM PDCM ROPS RPAM RPCM RPTM TCDM TVD 10050.0000 6.1690 0.6422 175.9690 193.2227 194.1752 -999.2500 16.2969 10.2153 25.7166 5.1754 5.1500 150.0000 124.4187 -999.2500 10100.0000 6.2500 0.7229 198.7320 212.8588 213.8452 -999.2500 16.9323 10.8616 29.2791 4.6979 4.6763 179.0000 125.6562 -999.2500 10150.0000 6.1517 0.6279 171.9832 199.3896 200.3530 -999.2500 16.5000 10.4215 19.0531 5.0153 4.9912 166.0000 123.5750 -999.2500 10200.0000 6.1653 0.6347 173.8758 193.6601 194.6134 -999.2500 16.3304 10.2300 53.6952 5.1637 5.1384 103.0000 125.0375 -999.2500 AZT CAAM GRAM GRBM RAAM RACM RPDM RPIM WBCS -999.2500 175.7391 82.6901 33.1504 5.6903 5.6828 4.0000 33233.0000 -999.2500 -999.2500 198.4951 77.8901 31.2900 5.0379 5.0319 4.0000 33433.0000 -999.2500 -999.2500 171.7548 77.1709 31.0112 5.8223 5.8145 4.0000 33633.0000 -999.2500 -999.2500 173.6467 83.3391 33.4020 5.7588 5.7512 4.0000 33833.0000 -999.2500 10250.0000 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 29.2969 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 126.5562 -999.2500 -999.2500 10285.0000 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 33.0935 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 127.8500 -999.2500 -999.2500 Tape File Start Depth = 989.000000 Tape File End Depth = 10285.000000 Tape File Level Spacing = 0.250000 Tape File Depth Units = Feet Tape Subtile 3 is type: LIS Schlumberger Page ***************************** . ***************************** * S CHL UMB ER G ER * ***************************** SCHLUMBERGER WELL SERVICES ALASKA DIVISION COMPUTER CENTER 500 WEST INTERNATIONAL AIRPORT ROAD ANCHORAGE, ALASKA 99518 907/562-2654 TAPE VERIFICATION LISTING LIS FORMAT LIS TAPE VERIFICATION FOR MDT FIELD TAPE Job Number Company Name Well Name Field Name County State Service Order Number Date Acquired Run Number Date Processed Files Included 97552 ARCO ALASKA INC W~THOG #1 WILDCAT 1157034 12-JAN-98 lViDT FIELD DATA Schlumberger Page 3 ============================ LIST Command Listing KEY I LIST SOPE4ARYFiNE~ONICS Summary output is created by LIST~SUmMARY summaries written for Logical LIS structures: FILE (Abbrev: F) LIS logical file info TAPE (Abbrev: T) LIS logical tape info REEL (Abbrev: R) LIS logical reel info and for the entire LIS/A input logical unit: LU (Abbrev: L) LIS/A logical unit info The field labels appear on some or all of these summaries, as indicated by the abbrev, on right. Summary Field Labels: REELS Number of logical reels on (L ) TAPES Number of logical tapes on (LR ) FILES Number of logical files on (LRT ) #PR Number of physical records (LRTF) #LR Number of logical records (LRTF) #DR Number of data records ( F) #ENC Number of encrypted records ( F) #FM Number of data frames ( F) MAXPI Maximum primary index value ( F) MINPI Minimum primary index value ( F) IN ANATTEMPT TO KEEP THIS LISTING TO A REASONABLE LENGTH, ONLY SPECIFIC CHANNELS AND CONSTANTS ARE LISTED. THIS LISTING DOES NOT INCLUDE MANY OF THE CHANNELS AND CONSTANTS INCLUDED ON THE FIELD TAPE. Schlumberger LIST MUAO : [] LISA.DAT; Reel header Default 12-JAN-98 12:48:07 Page 4 ** REEL HEADER ** SERVICE NAME : PS 1 _ DATE : 97/11/27 ORIGIN : DLIS REEL NAME : Default CONTINUATION #: 1 PREVIOUS REEL : COMMENT : PROCESSED BY SCHLUMBERGER DLIS TO LIS CONVERTER UTILITY (EOF) Tape header Default ** TAPE HEADER ** SERVICE NAME : FPS 1 _ DATE : 97/11/27 ORIGIN : DLIS TAPE NAME : Default CONTINUATION #: 1 PREVIOUS TAPE : COMMENT : PROCESSED BY SCHLUMBERGER DLIS TO LIS CONVERTER UTILITY File header PS 1 .042 _ ** FILE HEADER ** FILE NAME : PS 1 .042 SERVICE NAME : STATIO VERSION # : 8C0-609 DATE : 97/11/27 MAX. REC. LEN.: 8192 FILE TYPE : DL PREVIOUS FILE : Table type CONS Listing of set 8 type CONS OBJNAM STAT TUNI PUNI DESC VALU ................................. End of set Table type CONS Listing of set 10 type CONS OBJNAM STAT TONI PUNI DESC VALU End of set Schlumberger LIST MUAO : £] LISA.DAT; Table type CONS Listing of set 12 type CONS ................................. OBJNAM STAT TUNI PUNI DESC VALU End of set 12-JAN-98 12:48:07 Page 5 Table type CONS Listing of set 13 type CONS ................................. OBJNAM STAT TUNI PUNI DESC VALU End of set Data format specification record Listing of set 1 type 64EB object 0 ENTRY VALUE REPCODE SIZE 1 0 66 1 2 0 66 1 3 816 79 2 4 255 66 1 5 0 66 1 6 0 73 4 7 IN 65 2 8 600 73 4 9 .SMS 65 4 11 10 66 1 12 -999.25 68 4 13 1 66 1 14 .5MS 65 4 15 73 66 1 16 1 66 1 0 66 0 End of set Listing of set 0 type CHAN NAME SERV UNIT SERVICE API API API API FILE NUMB NUMB SIZE REP PROCESS ID ORDER # LOG TYP CLS MOD NUMB ELEM SAMP COD (HEX) TDEP PS 1 .liN 98 636 21 0 42 1 1 4 68 0000000000 _ BSG1 PS 1 PSI 98 000 O0 0 42 1 1 4 68 0000000000 _ BFR1 PS 1 OH~ 98 000 O0 0 42 1 1 4 68 0000000000 _ BQP1 PS 1 PSI 98 000 O0 0 42 1 1 4 68 0000000000 _ ETIM PS 1 S 98 636 21 0 42 1 1 4 68 0000000000 _ FCOL PS 1 98 000 O0 0 42 1 1 4 68 0000000000 _ POPV PS 1 C3 98 000 O0 0 42 1 1 4 68 0000000000 POS3 PS 1 98 000 O0 0 42 1 1 4 68 0000000000 _ POHP PS 1 PSI 98 000 O0 0 42 1 1 4 68 0000000000 _ Schlumberger LIST MUAO:[]LISA.DAT; 12-JAN-98 12:48:07 Page 6 End of set Data record type 0 TIME 8198833 .SMS TDEP 421418. BSG1 1616.473 BFR1 0.3100258 BQP1 1641.852 ETIM O. FCOL -999.25 POPV O. POS3 O. POHP O. File trailer PS 1 .042 _ ** FILE TRAILER ** FILE NAME : PS 1 .042 _ SERVICE NAME : STATIO VERSION # : 8C0-609 DATE : 97/11/27 MAX. REC. LEN.: 8192 FILE TYPE : DL NEXT FILE : FILE SU~!~ARY #LR #PR #ENC #DR #FM PI PI UNITS MAXPI MINPI _ 150 187 0 126 1256 TIME .SMS 8198833 8951833 (EOF) File header PS 1 .043 _ ** FILE HEADER ** FILE NAME : PS 1 .043 SERVICE NAME : STATIO VERSION # : 8C0-609 DATE : 97/11/27 MAX. REC. LEN.: 8192 FILE TYPE : DL PREVIOUS FILE : Table type CONS Listing of set 8 type CONS OBJNAM STAT TUNI PUNI DESC VALU End of set Schlumberger LIST MUAO: [] LISA. DAT; Table type CONS Listing of set 10 type CONS OBJNAM STAT TUNI PUNI DESC VALU End of set 12-JAN-98 12:48:07 Page 7 Table type CONS Listing of set 12 type CONS ................................. OBJNAM STAT TUNI PUNI DESC VALU End of set Table type CONS Listing of set 13 type CONS OBJNAM STAT TUNI PUNI DESC VALU ................................. End of set Data format specification record Listing of set 3 type 64EB object 0 ENTRY VALUE REPCODE SIZE 1 0 66 1 2 0 66 1 3 816 79 2 4 255 66 1 5 0 66 1 6 0 73 4 7 IN 65 2 8 600 73 4 9 .SMS 65 4 11 10 66 1 12 -999.25 68 4 13 1 66 1 14 .SMS 65 4 15 73 66 1 16 1 66 1 0 66 0 End of set Listing of set 0 type CHAN NAME SERV UNIT SERVICE API API API API FILE NUMB NUMB SIZE REP PROCESS ID ORDER # LOG TYP CLS MOD NUMB ELEM SAMP COD (HEX) Schlumberger LIST MUAO: []LISA.DAT; 12-JAN-98 12..48:07 Page 8 TDEP PS 1 .liN 98 636 21 0 43 1 1 4 68 0000000000 _ BSG1 PS 1 PSI 98 000 O0 0 43 1 1 4 68 0000000000 _ BFR1 PS 1 OH~M 98 000 O0 0 43 1 1 4 68 0000000000 _ BQP1 PS 1 PSI 98 000 O0 0 43 1 1 4 68 0000000000 _ ETIM PS 1 S 98 636 21 0 43 1 i 4 68 0000000000 _ FCOL PS 1 98 000 O0 0 43 1 I 4 68 0000000000 _ POPV PS 1 C3 98 000 O0 0 43 1 1 4 68 0000000000 _ POS3 PS 1 98 000 O0 0 43 1 I 4 68 0000000000 _ POHP PS 1 PSI 98 000 O0 0 43 1 1 4 68 0000000000 _ End of set Data record type 0 TIME 11752457 .5MS TDEP 499368. BSG1 1877.213 BFR1 0.1340745 BQP1 1904.835 ETIM O. FCOL -999.25 POPV O. POS3 O. POHP O. File trailer PS 1 .043 ** FILE TRAILER ** FILE NAME : PS 1 .043 _ SERVICE NAME : STATIO VERSION # : 8C0-609 DATE : 97/11/27 MAX. REC. LEN.: 8192 FILE TYPE : DL NEXT FILE : FILE SUMMARY #LR #PR #ENC #DR #FM PI PI UNITS MAXPI MINPI _ 128 165 0 104 1040 TIME .SMS 11752457 12375857 (EOF) File header PS 1 .044 _ ** FILE HEADER ** FILE NAME : PS 1 .044 _ SERVICE NAME : STATIO VERSION # : 8C0-609 DATE : 97/11/27 MAX. REC. LEN.: 8192 FILE TYPE : DL PREVIOUS FILE : Schlumberger LIST MUAO: []LISA.DAT; Table type CONS Listing of set 8 type CONS OBJNAM STAT TUNI PUNI DESC VALU End of set 12-JAN-98 12:48:07 Page 9 Table type CONS Listing of set 10 type CONS OBJNAM STAT TUNI PUNI DESC VALU End of set Table type CONS Listing of set 12 type CONS ................................. OBJNAM STAT TUNI PUNI DESC VALU End of set Table type CONS Listing of set 13 type CONS ................................. OBJNAM STAT TONI PUNI DESC VALU ................................. End of set Data format specification record Listing of set 5 type 64EB object 0 ENTRY VALUE REPCODE SIZE 1 0 66 1 2 0 66 1 3 816 79 2 4 255 66 1 5 0 66 1 6 0 73 4 7 IN 65 2 8 600 73 4 9 .SMS 65 4 11 10 66 1 12 -999.25 68 4 13 1 66 1 14 .SMS 65 4 15 73 66 1 16 1 66 1 Schlumberger LIST MUAO:[]LISA.DAT; 12-JAN-98 12:48:07 Page 10 0 66 0 End of set Listing of set 0 type CHAN NAME SERV UNIT SERVICE API API API API FILE NUMB NUMB SIZE REP PROCESS ID ORDER # LOG TYP CLS MOD NUMB ELEM SAMP COD (HEX) 98 636 21 0 44 1 1 4 68 0000000000 PS 1 _ PS 1 _ PS 1 _ PS 1 _ PS 1 _ PS 1 _ PS 1 _ PS 1 _ PS 1 _ .liN PSI 98 000 O0 0 44 1 1 4 68 0000000000 OHF~4 98 000 O0 0 44 1 1 4 68 0000000000 PSI 98 000 O0 0 44 1 1 4 68 0000000000 S 98 636 21 0 44 1 1 4 68 0000000000 98 000 O0 0 44 1 1 4 68 0000000000 C3 98 000 O0 0 44 1 1 4 68 0000000000 98 000 O0 0 44 1 1 4 68 0000000000 TDEP BSG1 BFR1 BQP1 ETIM FCOL POPV POS3 POHP PSI 98 000 O0 0 44 1 1 4 68 0000000000 End of set Data record type 0 TIME 12659801 .5MS TDEP 501040. BSG1 1881.416 BFR1 0.1279504 BQP1 1909.43 ETIM O. FCOL O. POPV O. POS30. POHP O. File trailer PS 1 .044 _ ** FILE TRAILER ** FILE NAME : PS 1 .044 _ SERVICE NAME : STATIO VERSION # : 8C0-609 DATE : 97/11/27 MAX. REC. LEN.: 8192 FILE TYPE : DL NEXT FILE : FILE S~Y .......................................................................... #LR #PR #ENC #DR #FM PI PI UNITS MAXPI MINPI _ 173 210 0 149 1486 TIME .SMS 12659801 13550801 (EOF) File header PS 1 .045 _ Schlumberger LIST MUAO: []LISA.DAT; 12-JAN-98 12..48:07 Page 11 * * FILE HEADER * * FILE NAME : PS 1 .045 _ SERVICE NAME : STATIO VERSION # : 8C0-609 DATE : 97/11/27 MAX. REC. LEN.: 8192 FILE TYPE .. DL PREVIOUS FILE : Table type CONS Listing of set 8 type CONS OBJNAM STAT TUNI PUNI DESC VALU ................................. End of set Table type CONS Listing of set 10 type CONS OBJNAM STAT TONI PUNI DESC VALU End of set Table type CONS Listing of set 12 type CONS OBJNAM STAT TUNI PUNI DESC VALU End of set Table type CONS Listing of set 13 type CONS OBJNAM STAT TUNI PUNI DESC VALU ................................. End of set Data format specification record Listing of set 7 type 64EB object 0 ENTRY VALUE REPCODE SIZE 1 0 66 1 2 0 66 1 3 816 79 2 4 255 66 1 5 0 66 1 Schlumberger LIST MUAO:[]LISA.DAT; 12-JAN-98 12:48:07 Page 12 6 0 73 4 7 IN 65 2 8 600 73 4 9 .SMS 65 4 11 10 66 1 12 -999.25 68 4 13 1 66 1 14 .SMS 65 4 15 73 66 1 16 1 66 1 0 66 0 End of set Listing of set 0 type CHAN NAME SERV UNIT SERVICE API API API API FILE NUMB NUMB SIZE REP PROCESS ID ORDER # LOG TYP CLS MOD NUMB ELEM SAMP COD (HEX) TDEP PS 1 .liN 98 636 21 0 45 1 1 4 68 0000000000 _ BSG1 PS 1 PSI 98 000 O0 0 45 1 1 4 68 0000000000 _ BFR1 PS 1 Ot{MM 98 000 O0 0 45 1 1 4 68 0000000000 _ BQP1 PS 1 PSI 98 000 O0 0 45 1 1 4 68 0000000000 _ ETIM PS 1 S 98 636 21 0 45 1 1 4 68 0000000000 FCOL PS 1 98 000 O0 0 45 1 1 4 68 0000000000 _ POPV PS 1 C3 98 000 O0 0 45 1 1 4 68 0000000000 _ POS3 PS 1 98 000 O0 0 45 1 1 4 68 0000000000 _ POHP PS 1 PSI 98 000 O0 0 45 1 1 4 68 0000000000 _ End of set Data record type 0 TIME 13789721 .SMS TDEP 504760. BSG1 1893.789 BFR1 0.1286139 BQP1 1921.875 ETIM O. FCOL -999.25 POPV O. POS3 O. POHP O. File trailer PS 1 .045 ** FILE TRAILER ** FILE NAME : PS 1 .045 _ SERVICE NAME : STATIO VERSION # : 8C0-609 DATE : 97/11/27 MAX. REC. LEN.: 8192 FILE TYPE : DL NEXT FILE : Schlumberger LIST MUAO: []LISA.DAT; 12-JAN-98 12:48:07 Page 13 FILE SUPff4ARY #LR #PR #ENC #DR #FM PI PI UNITS MAXPI MINPI _ 162 199 0 138 1377 TIME .SMS 13789721 14615321 (EOF) File header PS 1 .046 _ * * FILE HEADER * * FILE NAME : PS 1 .046 _ SERVICE NAME : STATIO VERSION # : 8C0-609 DATE : 97/11/27 MAX. REC. LEN.: 8192 FILE TYPE : DL PREVIOUS FILE : Table type CONS Listing of set 8 type CONS OBJNAM STAT TUNI PUNI DESC VALU ................................. End of set Table type CONS Listing of set 10 type CONS OBJNAM STAT TUNI PUNI DESC VALU End of set Table type CONS Listing of set 12 type CONS OBJNAM STAT TUNI PUNI DESC VALU End of set Table type CONS Listing of set 13 type CONS OBJNAM STAT TUNI PUNI DESC VALU ................................. End of set Schlumberger LIST MUAO : [] LISA. DAT; 12-JAN-98 12:48:07 Page 14 Data format specification record Listing of se~ 9 type 64EB objec~ 0 ................................ ENTRY VALUE REPCODE SIZE ................................ 1 0 66 1 2 0 66 1 3 816 79 2 4 255 66 1 5 0 66 1 6 0 73 4 7 IN 65 2 8 600 73 4 9 .SMS 65 4 11 10 66 1 12 -999.25 68 4 13 1 66 1 14 .SMS 65 4 15 73 66 1 16 1 66 1 0 66 0 End of set Listing of set 0 type CHAN NAME SERV UNIT SERVICE API API API API FILE NUMB NUMB SIZE REP PROCESS ID ORDER # LOG TYP CLS MOD NUMB ELEM SAMP COD (HEX) 98 636 21 0 46 1 1 4 68 0000000000 .lin PSI 98 000 O0 0 46 1 1 4 68 0000000000 OH~ 98 000 O0 0 46 1 1 4 68 0000000000 PSI 98 000 O0 0 46 1 1 4 68 0000000000 S 98 636 21 0 46 1 1 4 68 0000000000 98 000 O0 0 46 1 1 4 68 0000000000 C3 98 000 O0 0 46 1 1 4 68 0000000000 98 000 O0 0 46 1 1 4 68 0000000000 TDEP PS 1 _ BSG1 PS 1 _ BFR1 PS 1 _ BQP1 PS 1 _ ETIM PS 1 FCOL PS 1 POPV PS 1 _ POS3 PS 1 _ POHP PS 1 _ PSI 98 000 O0 0 46 1 1 4 68 0000000000 End of set Data record type 0 TIME 19338576 .5MS TDEP 883720. BSG1 3173.984 BFR1 0.1040461 BQP1 3196.59 ETIM O. FCOL O. POPV O. POS3 O. POHP O. File trailer PS 1 .046 Schlumberger LIST MUAO:[]LISA.DAT; 12-JAN-98 12:48:07 Page 15 ** FILE TRAILER ** FILE NAME : PS 1 .046 SERVICE NAME : STATIO VERSION # : 8C0-609 DATE : 97/11/27 MAX. REC. LEN.: 8192 FILE TYPE : DL NEXT FILE FILE SUMMARY #LR #PR #ENC #DR #FM PI PI UNITS MAXPI MINPI _ 115 152 0 91 902 TIME .5MS 19338576 19879176 (EOF) File header PS 1 .047 _ ** FILE HEADER ** FILE NAME : PS 1 .047 _ SERVICE NAME : STATIO VERSION # : 8C0-609 DATE : 97/11/27 MAX. REC. LEN.: 8192 FILE TYPE : DL PREVIOUS FILE : Table type CONS Listing of set 8 type CONS OBJNAM STAT TUNI PUNI DESC VALU End of set Table type CONS Listing of set 10 type CONS OBJNAM STAT TUNI PUNI DESC VALU End of set Schlumberger LIST MUAO: []LISA.DAT; Table ~ype CONS Listing of se~ 12 type CONS ................................. OBJNAM STAT TUNI PUNI DESC VALU ................................. End of set 12-JAN-98 12:48:07 Page 16 Table type CONS Listing of set 13 type CONS OBJNAM STAT TUNI PUNI DESC VALU End of set Data format specification record Listing of set 11 type 64EB object 0 ENTRY VALUE REPCODE SIZE 1 0 66 1 2 0 66 1 3 816 79 2 4 255 66 1 5 0 66 1 6 0 73 4 7 IN 65 2 8 600 73 4 9 .SMS 65 4 11 10 66 1 12 -999.25 68 4 13 1 66 1 14 .SMS 65 4 15 73 66 1 16 1 66 1 0 66 0 End of set Listing of set 0 type CHAN NAME SERV UNIT SERVICE API API API API FILE NUMB NUMB SIZE REP PROCESS ID ORDER # LOG TYP CLS MOD NUMB ELEM SAMP COD (HEX) TDEP PS 1 .lin 98 636 21 0 47 1 1 4 68 0000000000 _ BSG1 PS 1 PSI 98 000 O0 0 47 1 1 4 68 0000000000 _ BFR1 PS 1 OHM~ 98 000 O0 0 47 1 1 4 68 0000000000 _ BQP1 PS 1 PSI 98 000 O0 0 47 1 1 4 68 0000000000 _ ETIM PS 1 S 98 636 21 0 47 1 1 4 68 0000000000 _ FCOL PS 1 98 000 O0 0 47 1 1 4 68 0000000000 _ POPV PS 1 C3 98 000 O0 0 47 1 1 4 68 0000000000 _ POS3 PS 1 98 000 O0 0 47 1 1 4 68 0000000000 _ POHP PS 1 PSI 98 000 O0 0 47 1 1 4 68 0000000000 _ Schlumberger LIST MUAO: []LISA.DAT; 12-JAN-98 12:48:07 Page 17 End of set Data record type 0 TIME 20256832 .SMS TDEP 909397. BSG1 3257.565 BFR1 0.1026832 BQP1 3281.789 ETIM O. FCOL -999.25 POPV O. POS3 O. POHP O. File trailer PS 1 .047 _ ** FILE TRAILER ** FILE NAME : PS 1 .047 _ SERVICE NAME : STATIO VERSION # : 8C0-609 DATE : 97/11/27 MAX. REC. LEN.: 8192 FILE TYPE : DL NEXT FILE : FILE SUMMARY #LR #PR #ENC #DR #FM PI PI UNITS MAXPI MINPI _ 122 159 0 98 977 TIME .SMS 20256832 20842432 (EOF) File header PS 1 .048 ** FILE HEADER ** FILE NAME : PS 1 .048 _ SERVICE NAME : STATIO VERSION # : 8C0-609 DATE : 97/11/27 MAX. REC. LEN.: 8192 FILE TYPE : DL PREVIOUS FILE : Table type CONS Listing of set 8 type CONS OBJNAM STAT TUNI PUNI DESC VALU End of set Schlumberger LIST MUAO: []LISA.DAT; Table type CONS Listing of set 10 type CONS ................................. OBJNAM STAT TUNI PUNI DESC VALU End of set 12-JAN-98 12:48:07 Page 18 Table type CONS Listing of set 12 type CONS OBJNAM STAT TUNI PUNI DESC VALU End of set Table type CONS Listing of set 13 type CONS OBJNAM STAT TUNI PUNI DESC VALU End of set Data format specification record Listing of set 13 type 64EB object 0 ENTRY VALUE REPCODE SIZE 1 0 66 1 2 0 66 1 3 816 79 2 4 255 66 1 5 0 66 1 6 0 73 4 7 IN 65 2 8 600 73 4 9 .5MS 65 4 11 10 66 1 12 -999.25 68 4 13 1 66 1 14 .SMS 65 4 15 73 66 1 16 1 66 1 0 66 0 End of set Listing of set 0 type CHAN NAME SERV UNIT SERVICE API API API API FILE NUMB NUMB SIZE REP PROCESS ID ORDER # LOG TYP CLS MOD NUMB ELEM SAMP COD (HEX) Schlumberger LIST MUAO : [] LISA.DAT; 12-JAN-98 12:48:07 Page 19 TDEP PS 1 .liN 98 636 21 0 48 1 1 4 68 0000000000 _ BSG1 PS 1 PSI 98 000 O0 0 48 1 1 4 68 0000000000 _ BFRI PS 1 OHl~q 98 000 O0 0 48 1 1 4 68 0000000000 _ BQPI PS 1 PSI 98 000 O0 0 48 1 ! 4 68 0000000000 _ ETIM PS 1 S 98 636 21 0 48 1 1 4 68 0000000000 _ FCOL PS 1 98 000 O0 0 48 i 1 4 68 0000000000 _ POPV PS 1 C3 98 000 O0 0 48 1 1 4 68 0000000000 _ POS3 PS 1 98 000 O0 0 48 1 1 4 68 0000000000 _ POHP PS 1 PSI 98 000 O0 0 48 1 1 4 68 0000000000 End of set Data record type 0 TIME 21274604 .5MS TDEP 928721. BSG1 3321.829 BFR1 0.1015349 BQP1 3345.587 ETIM O. FCOL -999.25 POPV O. POS3 O. POHP O. File trailer PS 1 .048 ** FILE TRAILER ** FILE NAME : PS 1 .048 _ SERVICE NAME : STATIO VERSION # : 8C0-609 DATE : 97/11/27 MAX. REC. LEN.: 8192 FILE TYPE : DL NEXT FILE : FILE SUMMARY #LR #PR #ENC #DR #FM PI PI UNITS MAP[PI MINPI _ 115 152 0 91 904 TIME .SMS 21274604 21816404 (EOF) File header PS 1 .049 ** FILE HEADER ** FILE NAME : PS 1 .049 SERVICE NAME : STATIO VERSION # : 8C0-609 DATE : 97/11/27 MAX. REC. LEN.: 8192 FILE TYPE : DL PREVIOUS FILE : Schlumberger LIST MUAO : [] LISA. DAT; Table type CONS Listing of set 8 type CONS OBJNAM STAT TUNI PUNI DESC VALU End of set 12-JAN-98 12:48:07 Page 20 Table type CONS Listing of set 10 type CONS OBJNAM STAT TUNI PUNI DESC VALU End of set Table Type CONS Listing of set 12 type CONS OBJNAM STAT TUNI PUNI DESC VALU End of set Table type CONS Listing of set 13 type CONS OBJNAM STAT TUNI PUNI DESC VALU End of set Data format specification record Listing of set 15 type 64EB object 0 ENTRY VALUE REPCODE SIZE 1 0 66 1 2 0 66 1 3 816 79 2 4 255 66 1 5 0 66 1 6 0 73 4 7 IN 65 2 8 600 73 4 9 .SMS 65 4 11 10 66 1 12 -999.25 68 4 13 1 66 1 14 .SMS 65 4 15 73 66 1 16 1 66 1 Schlumberger LIST MUAO : [] LISA.DAT; 0 66 0 ................................ End of set 12-JAN-98 12:48:07 Page 21 Listing of set 0 type CHAN NAME SERV UNIT SERVICE API API API API FILE NUMB NUMB SIZE REP PROCESS ID ORDER # LOG TYP CLS MOD NTJA~ ELEM SAMP COD (HEX) 98 636 21 0 49 1 1 4 68 0000000000 PS 1 _ PS 1 _ PS 1 _ PS 1 _ PS 1 _ PS 1 _ PS 1 _ PS 1 _ PS 1 _ .liN PSI 98 000 O0 0 49 1 1 4 68 0000000000 Ot{MM 98 000 O0 0 49 1 1 4 68 0000000000 PSI 98 000 O0 0 49 1 1 4 68 0000000000 S 98 636 21 0 49 1 1 4 68 0000000000 98 000 O0 0 49 1 1 4 68 0000000000 C3 98 000 O0 0 49 1 1 4 68 0000000000 98 000 O0 0 49 1 1 4 68 0000000000 TDEP BSG1 BFR1 BQP1 ETIM FCOL POPV POS3 POHP PSI 98 000 O0 0 49 1 1 4 68 0000000000 End of set Data record type 0 TIME 22129510 .SMS TDEP 936501. BSG1 3346.942 BFR1 0.09959672 BQP1 3370.396 ETIM O. FCOL -999.25 POPV O. POS3 O. POHP O. File trailer PS 1 .049 _ ** FILE TRAILER ** FILE NAME : PS 1 .049 _ SERVICE NAME : STATIO VERSION # : 8C0-609 DATE : 97/11/27 MAX. REC. LEN.: 8192 FILE TYPE : DL NEXT FILE : FILE SUMMARY #LR #PR #ENC #DR #FM PI PI UNITS MAXPI MINPI _ 108 145 0 84 833 TIME .SMS 22129510 22628710 (EOF) File header PS 1 .050 _ Schlumberger LIST MUAO: []LISA.DAT; 12-JAN-98 12:48:07 Page 22 ** FILE HEADER ** FILE NAME : PS 1 .050 _ SERVICE NAME : STATIO VERSION # : 8C0-609 DATE : 97/11/27 MAX. REC. LEN.: 8192 FILE TYPE : DL PREVIOUS FILE : Table type CONS Listing of set 8 type CONS OBJNAM STAT TUNI PUNI DESC VALU End of set Table type CONS Listing of set 10 type CONS OBJNAM STAT TUNI PUNI DESC VALU End of set Table type CONS Listing of set 12 type CONS OBJNAM STAT TUNI PUNI DESC VALU End of set Table type CONS Listing of set 13 type CONS OBJNAM STAT TUNI PUNI DESC VALU End of set Data format specification record Listing of set 17 type 64EB object 0 ENTRY VALUE REPCODE SIZE 1 0 66 1 2 0 66 1 3 816 79 2 4 255 66 1 5 0 66 1 Schlumberger LIST MUAO: []LISA.DAT; 12-JAN-98 12:48:07 Page 23 6 0 73 4 7 IN 65 2 8 600 73 4 9 .5MS 65 4 11 10 66 1 12 -999.25 68 4 13 1 66 1 14 .5MS 65 4 15 73 66 1 16 1 66 1 0 66 0 End of set Listing of se~ 0 ~ype CHAN NAME SERV UNIT SERVICE API API API API FILE NUMB NUMB SIZE REP PROCESS ID ORDER # LOG TYP CLS MOD NUmB ELEM SAMP COD (HEX) TDEP PS 1 .liN 98 636 21 0 50 1 1 4 68 0000000000 BSG1 PS 1 PSI 98 000 O0 0 50 1 1 4 68 0000000000 BFR1 PS 1 OH~ 98 000 O0 0 50 1 1 4 68 0000000000 _ BQP1 PS 1 PSI 98 000 O0 0 50 1 1 4 68 0000000000 _ ETIM PS 1 S 98 636 21 0 50 1 1 4 68 0000000000 FCOL PS 1 98 000 O0 0 50 1 1 4 68 0000000000 _ POPV PS 1 C3 98 000 O0 0 50 1 1 4 68 0000000000 _ POS3 PS 1 98 000 O0 0 50 1 1 4 68 0000000000 _ POHP PS 1 PSI 98 000 O0 0 50 1 1 4 68 0000000000 _ End of set Data record ty~e 0 TIME 22858282 .$MS TDEP 943949. BSG1 3371.765 BFR1 0.09866314 BQP1 3395.046 ETIM O. FCOL -999.25 POPV O. POS3 O. POHP O. File trailer PS 1 .050 _ ** FILE TRAILER ** FILE NAME : PS 1 .050 _ SERVICE NAME : STATIO VERSION # : 8C0-609 DATE : 97/11/27 MAX. REC. LEN.: 8192 FILE TYPE : DL NEXT FILE : Schlumberger LIST MUAO : [] LISA. DAT; 12-JAN-98 12:48:07 Page 24 FILE SUMMARY #LR #PR #ENC #DR #FM PI PI UNITS MAXPI MINPI _ 106 143 0 82 814 TIME .SMS 22858282 23346082 (EOF) File header PS 1 .051 _ ** FILE HEADER ** FILE NAME : PS 1 .051 _ SERVICE NAME : STATIO VERSION # : 8C0-609 DATE : 97/11/27 MAX. REC. LEN.: 8192 FILE TYPE : DL PREVIOUS FILE : Table type CONS Listing of set 8 type CONS OBJNAM STAT TUNI PUNI DESC VALU End of set Table type CONS Listing of set 10 type CONS OBJNAM STAT TUNI PUNI DESC VALU End of set Table type CONS Listing of set 12 type CONS OBJNAM STAT TUNI PUNI DESC VALU End of set Table type CONS Listing of set 13 type CONS OBJNAM STAT TUNI PUNI DESC VALU End of set Schlumberger LIST MUAO:[]LISA.DAT; 12-JAN-98 12:48:07 Page 25 Data format specification record Listing of set 19 type 64EB object 0 ENTRY VALUE REPCODE SIZE i 0 66 1 2 0 66 1 3 816 79 2 4 255 66 1 5 0 66 1 6 0 73 4 7 IN 65 2 8 600 73 4 9 .5MS 65 4 11 10 66 1 12 -999.25 68 4 13 1 66 1 14 .5MS 65 4 15 73 66 1 16 1 66 1 0 66 0 End of set Listing of set 0 type CHAN NAME SERV UNIT SERVICE API API API API FILE NUMB NUMB SIZE REP PROCESS ID ORDER # LOG TYP CLS MOD NUMB ELEM SAMP COD (HEX) TDEP PS 1 .lin 98 636 21 0 51 1 1 4 68 0000000000 _ BSG1 PS 1 PSI 98 000 O0 0 51 1 1 4 68 0000000000 BFR1 PS 1 OH~ 98 000 O0 0 51 1 1 4 68 0000000000 _ BQP1 PS 1 PSI 98 000 O0 0 51 1 1 4 68 0000000000 _ ETIM PS 1 S 98 636 21 0 51 1 1 4 68 0000000000 _ FCOL PS 1 98 000 O0 0 51 1 1 4 68 0000000000 _ POPV PS 1 C3 98 000 O0 0 51 1 1 4 68 0000000000 POS3 PS 1 98 000 O0 0 51 1 1 4 68 0000000000 _ POHP PS 1 PSI 98 000 O0 0 51 1 1 4 68 0000000000 _ End of set Data record type 0 TIME 23625704 .SMS TDEP 950083. BSG1 3390.516 BFR1 0.09758851 BQP1 3413.462 ETIM O. FCOL O. POPV O. POS3 O. POHP O. File trailer PS 1 .051 _ Schlumberger LIST MUAO: []LISA.DAT; 12-JAN-98 12:48:07 Page 26 * * FILE TRAILER * * FILE NAME : PS 1 .051 _ SERVICE NAME : STATIO VERSION # : 8C0- 609 DATE : 97/11/27 MAX. REC. LEN.: 8192 FILE TYPE : DL NEXT FILE : FILE SUM~J~Y #LR #PR #ENC #DR #FM PI PI UNITS MAXPI MINPI -- 101 138 0 77 765 TIME .SMS 23625704 24084104 (EOF) File header PS 1 .052 _ ** FILE HEADER ** FILE NAME : PS 1 .052 _ SERVICE NAME : STATIO VERSION # : 8C0-609 DATE : 97/11/27 MAX. REC. LEN.: 8192 FILE TYPE : DL PREVIOUS FILE : Table type CONS Listing of set 8 type CONS OBJNAM STAT TUNI PUNI DESC VALU End of set Table type CONS Listing of set 10 type CONS OBJNAM STAT TUNI PUNI DESC VALU End of set Schlumberger LIST MUAO : [] LISA.DAT; Table type CONS 12-JAN-98 12:48:07 Page 27 Listing of set 12 type CONS OBJNAM STAT TUNI PUNI DESC VALU End of set Table type CONS Listing of set 13 type CONS OBJNAM STAT TUNI PUNI DESC VALU End of set Data format specification record Listing of set 21 type 64EB object 0 ENTRY VALUE REPCODE SIZE 1 0 66 1 2 0 66 1 3 816 79 2 4 255 66 1 5 0 66 1 6 0 73 4 7 IN 65 2 8 600 73 4 9 .$MS 65 4 11 10 66 1 12 -999.25 68 4 13 1 66 1 14 .SMS 65 4 15 73 66 1 16 1 66 1 0 66 0 End of set Listing of set 0 type CHAN NAME SERV UNIT SERVICE API API API API FILE ArUMB NUMB SIZE REP PROCESS ID ORDER # LOG TYP CLS MOD NUMB ELEM SAMP COD (HEX) TDEP PS_i .lin 98 636 21 0 52 1 1 4 68 0000000000 BSG1 PS_i PSI 98 000 O0 0 52 1 1 4 68 0000000000 BFR1 PS_i OP~4~ 98 000 O0 0 52 1 1 4 68 0000000000 BQP1 PS_i PSI 98 000 O0 0 52 1 1 4 68 0000000000 ETIM PS_I S 98 636 21 0 52 1 1 4 68 0000000000 FCOL PS_I 98 000 O0 0 52 1 1 4 68 0000000000 POPV PS_i C3 98 000 O0 0 52 1 1 4 68 0000000000 POS3 PS_I 98 000 O0 0 52 1 1 4 68 0000000000 POHP PS_I PSI 98 000 O0 0 52 1 1 4 68 0000000000 Schlumberger LIST MUAO:[]LISA.DAT; 12-JAN-98 12:48:07 Page 28 End of set Data record type 0 TIME 24315262 .5MS TDEP 952737. BSG1 3399.176 BFR1 0.0969463 BQP1 3421.884 ETIM O. FCOL -999.25 POPV O. POS3 O. POHP O. File trailer PS 1 .052 _ ** FILE TRAILER ** FILE NAME : PS 1 .052 _ SERVICE NAME : STATIO VERSION # : 8C0-609 DATE : 97/11/27 MAX. REC. LEN.: 8192 FILE TYPE : DL NEXT FILE : FILE SU~4MARY #LR #PR #ENC #DR #FM PI PI UNITS MAXPI MINPI _ 106 143 0 82 813 TIME .SMS 24315262 24802462 (EOF) File header PS 1 .054 _ ** FILE HEADER ** FILE NAME : PS 1 .054 _ SERVICE NAME : STATIO VERSION # : 8C0-609 DATE : 97/11/27 MAX. REC. LEN.: 8192 FILE TYPE : DL PREVIOUS FILE : Table type CONS Listing of set 8 type CONS OBJNAM STAT TUNI PUNI DESC VALU End of set Schlumberger LIST MUAO: []LISA.DAT; Table type CONS Lis~ing of set 10 type CONS OBJNAM STAT TUNI PUNI DESC VALU ................................. End of set 12-JAN-98 12:48:07 Page 29 Table type CONS Listing of set 12 ~ype CONS OBJNAM STAT TUNI PUNI DESC VALU ................................. End of se~ Table type CONS Listing of set 13 type CONS OBJNAM STAT TUNI PUNI DESC VALU End of set Data format specification record Listing of set 23 type 64EB object 0 ENTRY VALUE REPCODE SIZE 1 0 66 1 2 0 66 1 3 816 79 2 4 255 66 1 S 0 66 1 6 0 73 4 7 IN 65 2 8 600 73 4 9 .5MS 65 4 11 10 66 1 12 -999.25 68 4 13 1 66 1 14 .5MS 65 4 15 73 66 1 16 1 66 1 0 66 0 End of set Listing of set 0 type CHAN NAME SERV UNIT SERVICE API API API API FILE NUMB NUMB SIZE REP PROCESS ID ORDER # LOG TYP CLS MOD NUMB ELEM SAMP COD (HEX) Schlumberger LIST MUAO:[]LISA.DAT; 12-JAN-98 12:48:07 Page 30 TDEP PS 1 .liN 98 636 21 0 54 1 1 4 68 0000000000 _ BSG1 PS 1 PSI 98 000 O0 0 54 1 1 4 68 0000000000 _ BFR1 PS 1 Ot{F~I 98 000 O0 0 54 1 1 4 68 0000000000 _ BQP! PS 1 PSI 98 000 O0 0 54 1 1 4 68 0000000000 _ ETIM PS 1 S 98 636 21 0 54 1 1 4 68 0000000000 _ FCOL PS 1 98 000 O0 0 54 1 1 4 68 0000000000 _ POPV PS 1 C3 98 000 O0 0 54 1 1 4 68 0000000000 _ POS3 PS 1 98 000 O0 0 54 ! 1 4 68 0000000000 _ POHP PS 1 PSI 98 000 O0 0 54 1 1 4 68 0000000000 _ End of set Data record type 0 TIME 25171016 .SMS TDEP 970973. BSG1 3458.663 BFR1 0.09603344 BQP1 3481.243 ETIM O. FCOL O. POPV O. POS30. POHP O. File trailer PS 1 .054 _ ** FILE TRAILER ** FILE NAME : PS 1 .054 _ SERVICE NAME : STATIO VERSION # : 8C0-609 DATE : 97/11/27 MAX. REC. LEN.: 8192 FILE TYPE : DL NEXT FILE : FILE SUM~3L~Y #LR #PR #ENC #DR #FM PI PI UNITS MAXPI MINPI _ 106 143 0 82 818 TIME .SMS 25171016 25661216 (EOF) File header PS 1 .055 _ ** FILE HEADER ** FILE NAME : PS 1 .055 _ SERVICE NAME : STATIO VERSION # : 8C0-609 DATE : 97/11/27 MAX. REC. LEN.: 8192 FILE TYPE : DL PREVIOUS FILE : Schlumberger LIST MUAO: []LISA.DAT; Table type CONS Listing of set 8 type CONS OBJNAM STAT TUNI PUNI DESC VALU ................................. End of set 12-JAN-98 12:48:07 Page 31 Table type CONS Listing of set 10 type CONS OBJNAM STAT TUNI PUNI DESC VALU End of set Table type CONS Listing of set 12 type CONS OBJNAM STAT TUNI PUNI DESC VALU End of set Table type CONS Listing of set 13 type CONS OBJNAM STAT TUNI PUNI DESC VALU End of set Data format specification record Listing of set 25 type 64EB object 0 ENTRY VALUE REPCODE SIZE 1 0 66 1 2 0 66 1 3 816 79 2 4 255 66 1 5 0 66 1 6 0 73 4 7 IN 65 2 8 600 73 4 9 .5MS 65 4 11 10 66 1 12 -999.25 68 4 13 1 66 1 14 .SMS 65 4 15 73 66 1 16 1 66 1 Schlumberger LIST MUAO: []LISA.DAT; 0 66 0 End of set 12-JAN-98 12:48:07 Page 32 Listing of set 0 type CHAN NAME SERV UNIT SERVICE API API API API FILE NUMB NUMB SIZE REP PROCESS ID ORDER # LOG TYP CLS MOD NUMB ELEM SAMP COD (HEX) TDEP PS_I .lin 98 636 21 0 55 1 1 4 68 0000000000 BSG1 PS 1 PSI 98 000 O0 0 55 1 1 4 68 0000000000 _ BFR1 PS_I OH~ 98 000 O0 0 55 1 1 4 68 0000000000 BQP1 PS_i PSI 98 000 O0 0 55 1 1 4 68 0000000000 ETIM PS 1 S 98 636 21 0 55 1 1 4 68 0000000000 _ FCOL PS_i 98 000 O0 0 55 1 1 4 68 0000000000 POPV PS_i C3 98 000 O0 0 55 1 1 4 68 0000000000 POS3 PS_I 98 000 O0 0 55 1 1 4 68 0000000000 POHP PS_i PSI 98 000 O0 0 55 1 1 4 68 0000000000 End of set Data record type 0 TIME 27665564 .SMS TDEP 1041541 BSG1 3689.099 BFR1 0.09449336 BQP1 3709.254 ETIM O. FCOL O. POPV O. POS3 O. POHP O. File trailer PS 1 .055 ** FILE TRAILER ** FILE NAME : PS 1 .055 _ SERVICE NAME : STATIO VERSION # : 8C0-609 DATE : 97/11/27 MAX. REC. LEN.: 8192 FILE TYPE : DL NEXT FILE : FILE SUM~N~Y #LR #PR #ENC #DR #FM PI PI UNITS MAXPI MINPI -- 98 135 0 74 734 TIME .SMS 27665564 28105364 (EOF) File header PS 1 .056 _ Schlumberger LIST MUAO:[]LISA.DAT; 12-JAN-98 12:48:07 Page 33 ** FILE HEADER ** FILE NAME : PS ! .056 _ SERVICE NA~E : STATIO VERSION # : 8C0-609 DATE : 97/11/27 MAX. REC. LEN.: 8192 FILE TYPE : DL PREVIOUS FILE : Table type CONS Listing of set 8 type CONS OBJNAM STAT TUNI PUNI DESC VALU End of set Table type CONS Listing of set 10 type CONS OBJNAM STAT TUNI PUNI DESC VALU End of set Table type CONS Listing of set 12 type CONS OBJNAM STAT TUNI PUNI DESC VALU End of set Table type CONS Listing of set 13 type CONS OBJNAM STAT TUNI PUNI DESC VALU End of set Data format specification record Listing of set 27 type 64EB object 0 ENTRY VALUE REPCODE SIZE 1 0 66 1 2 0 66 1 3 816 79 2 4 255 66 1 5 0 66 1 Schlumberger LIST MUAO: []LISA.DAT; 12-JAN-98 12:48:07 Page 34 6 0 73 4 7 IN 65 2 8 600 73 4 9 .5MS 65 4 11 10 66 1 12 -999.25 68 4 13 1 66 1 14 .5MS 65 4 15 73 66 1 16 1 66 1 0 66 0 End of set Listing of se~ 0 type CHAN NAME SERV UNIT SERVICE API API API API FILE NUMB NUMB SIZE REP PROCESS ID ORDER # LOG TYP CLS MOD NUMB ELEM SAMP COD (HEX) TDEP PS_i .liN 98 636 21 0 56 1 1 4 68 0000000000 BSG1 PS_I PSI 98 000 O0 0 56 1 1 4 68 0000000000 BFR1 PS_I 0H~94 98 000 O0 0 56 1 1 4 68 0000000000 BQP1 PS_I PSI 98 000 O0 0 56 1 1 4 68 0000000000 ETIM PS_i S 98 636 21 0 56 1 1 4 68 0000000000 FCOL PS_I 98 000 O0 0 56 1 1 4 68 0000000000 POPV PS_i C3 98 000 O0 0 56 1 1 4 68 0000000000 POS3 PS_i 98 000 O0 0 56 1 1 4 68 0000000000 POHP PS_i PSI 98 000 O0 0 56 1 1 4 68 0000000000 End of set Data record type 0 TIME 28335942 .SMS TDEP 1045632 BSG1 3701.032 BFR1 0.09346734 BQP1 3722.121 ETIM O. FCOL O. POPV O. POS30. POHP O. File trailer PS 1 .056 _ ** FILE TRAILER ** FILE NAME : PS 1 .056 SERVICE NAME : STATIO VERSION # : 8C0-609 DATE : 97/11/27 MAX. REC. LEN.: 8192 FILE TYPE : DL NEXT FILE : Schlumberger LIST MUAO:[]LISA.DAT; 12-JAN-98 12:48:07 Page 35 FILE SU~gVlARY #LR #PR #ENC #DR #FM PI PI UNITS MAXPI MINPI -- 97 134 0 73 726 TIME .SMS 28335942 28770942 (EOF) File header PS 1 .061 _ ** FILE HEADER ** FILE NAME : PS 1 .061 _ SERVICE NAME : STATIO VERSION # : 8C0-609 DATE : 97/11/27 MAX. REC. LEN.: 8192 FILE TYPE : DL PREVIOUS FILE : Table type CONS Listing of set 8 type CONS OBJNAM STAT TUNI PUNI DESC VALU ................................. End of set Table type CONS Listing of set 10 type CONS OBJNAM STAT TUNI PUNI DESC VALU End of set Table type CONS Listing of set 12 type CONS OBJNAM STAT TUNI PUNI DESC VALU End of set Table type CONS Listing of set 13 type CONS OBJNAM STAT TUNI PUNI DESC VALU End of set Schlumberger LIST MUAO : [] LISA. 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FCOL -999.25 POPV O. POS3 1. POHP O. File trailer PS 1 .061 _ Schlumberger LIST MUAO:[]LISA.DAT; 12-JAN-98 12:48:07 Page 37 ** FILE TRAILER ** FILE NAME : PS 1 .061 SERVICE NAME : STATIO VERSION # : 8C0-609 DATE : 97/11/27 MAX. REC. LEN.: 8192 FILE TYPE : DL NEXT FILE : FILE SUMPLARY #LR #PR #ENC #DR #FM PI PI UNITS MAXPI MINPI _ 1343 1380 0 1319 13190 TIME .SMS 773840 8687240 (EOF) Tape trailer Default ** TAPE TRAILER ** SERVICE NAME : FPS 1 _ DATE : 97/11/27 ORIGIN : DLIS TAPE NAME : Default CONTINUATION #: 1 NEXT TAPE COMMENT : PROCESSED BY SCHLUMBERGER DLIS TO LIS CONVERTER UTILITY TAPE SUMMARY ........................... FILES #LR #PR 15 3032 3587 Reel trailer Default ** REEL TRAILER ** SERVICE NAME : PS 1 _ DATE : 97/11/27 ORIGIN : DLIS REEL NAME : Default CONTINUATION #: 1 NEXT REEL : COMMENT : PROCESSED BY SCHLUMBERGER DLIS TO LIS CONVERTER UTILITY REEL SUI~r~ARY FILES TAPES #LR #PR 15 1 3034 3589 Schlumberger LIST MUAO: []LISA.DAT; 12-JAN-98 12:48:07 Page 38 (EOF) (EOD) LU S~mfARY FILES TAPES REELS #LR #PR 15 1 1 3034 3589 ! , End of lis¢ing MUAO: []LISA.DAT; ! * ALASKA COMPUTING CENTER * ****************************** * ............................ * ....... SCHLUMBERGER ....... * ............................ COMPANY NAME : ARCO ALASKA INC. WELL NAME : WARTHOG~ #1 FIELD NAME : WILDCAT BOROUGH : NORTH SLOPE STATE : ALASKA API NUMBER : 55-171-00012-00 REFERENCE NO : 97552 LIS Tape Verification Listing Schlumberger Alaska Computing Center 4-JAN-1998 12:16 PAGE: **** REEL HEADER **** SERVICE NAME : EDIT DATE : 98/01/ 4 ORIGIN : FLIC REEL NAME : 97552 CONTINUATION # : PREVIOUS REEL COI~VIENT : ARCO AJ=ASKA INC, WARTHOG #1, WILDCAT, API #55-171-00012-00 **** TAPE HEADER **** SERVICE NAME : EDIT DATE : 98/01/ 4 ORIGIN : FLIC TAPE NAME : 97552 CONTINUATION # : 1 PREVIOUS TAPE : CO~4ENT : ARCO ALASKA INC, WARTHOG #1, WILDCAT, API #55-171-00012-00 TAPE HEADER Wildcat OPEN HOLE WIRELINE LOGS WELL NAME: API NIIMBER: 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 O) KELLY BUSHING: DERRICK FLOOR: GROUND LEVEL: WELL CASING RECORD 1ST STRING 2NDSTRING RUN1 97552 Rachel Walsh W Campaign Warthog #1 551710001200 ARCO Alaska Inc. SCHLUMBERGER WELL SERVICES 4 -JAN-98 RUN 2 RUN 3 20 8N 29E OPEN HOLE CASING DRILLERS BIT SIZE (IN) SIZE (IN) DEPTH (FT) 12. 250 9. 625 4020.0 91.00 90.00 -36.00 LIS Tape Verification Lis~ing Schlumberger Alaska Computing Center 4-JAN-1998 12:16 3RD STRING PRODUCTION REMARKS: STRING CONTAINED HEREIN IS THE DATA ACQUIRED ON ARCO ALASKA'S WARTHOG #1 WELL. AT THE CLIENTS REQUEST THIS DATA IS IN A MODIFIED LDWG FORMAT. THE FIRST FILE CONTAINS BAKER HUGHES DPR RESISTIVITY LOG. THE SENCOArD FILE CONTAINS SCHLUMBERGER LITHODENSITY, COMPENSATED NEUTRON, BOREHOLE COMPENSATED SONIC AND DIPOLE SONIC WIRELINE LOGS. $ $ PAGE: **** FILE HEADER **** FILE NAME : EDIT .001 SERVICE : FLIC VERSION : O01CO1 DATE : 98/01/ 4 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE FILE HEADER FILE NIJMBER: 1 EDITED OPEN HOLE MAIN PASS All tool strings; Depth shifted and clipped curves; all runs merged; no cased hole data. DEPTH INCREMENT: O. 5000 FILE SUMMARY LDWG TOOL CODE $ BASELINE CURVE FOR SHIFTS: CURVE SHIFT DATA (MEASURED DEPTH) START DEPTH STOP DEPTH 10286.0 979.0 BASELINE DEPTH $ MERGED DATA SOURCE LDWG TOOL CODE $ REMARKS: THIS FILE CONTAINS BAKER HUGHES DPR RESISTIVITY DATA. THE DATA IN THIS FILE IS THE PRIMARY DEPTH CONTROL LOG. $ .......... EQUIVALENT UNSHIFTED DEPTH .......... MWD RUN NO. PASS NO. ............... MERGE TOP MERGE BASE LIS FORMAT DATA LIS Tape Verification Listing Schlumberger Alaska Computing Center 4-JAN-1998 12:16 PAGE: 3 ** DATA FORMAT SPECIFICATION RECORD ** ** SET TYPE - 64EB ** .............................. TYPE REPR CODE VALUE 1 66 0 2 66 0 3 73 28 4 66 1 5 66 6 73 7 65 8 68 O. 5 9 65 FT 11 66 36 12 68 13 66 0 14 65 FT 15 66 68 16 66 1 0 66 0 ** 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 1115734 O0 000 O0 0 1 1 1 4 68 0000000000 GR MWD GAPI 1115734 O0 000 O0 0 1 1 1 4 68 0000000000 RA MWD 0HP~1115734 O0 000 O0 0 1 1 1 4 68 0000000000 RP MWD OHMMll15734 O0 000 O0 0 1 1 1 4 68 0000000000 ROP MWD FPHR 1115734 O0 000 O0 0 1 1 1 4 68 0000000000 AZ MWD DEG 1115734 O0 000 O0 0 1 1 1 4 68 0000000000 DEV MWD. DEG 1115734 O0 000 O0 0 1 1 1 4 68 0000000000 ** DATA ** DEPT. 10286.000 ROP.MWD -999.250 GR.MWD -999.250 RA.MWD -999.250 RP.MWD -999.250 AZ.MWD -999.250 DEV. MWD. -999.250 ** END OF DATA ** LIS Tape Verification Lis~ing Schlumberger Alaska Computing Center 4-JAN-1998 12:16 PAGE: **** FILE TRAILER **** FILE NAME : EDIT .001 SERVICE : FLIC VERSION : OOICO1 DATE : 98/01/ 4 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE **** FILE HEADER **** FILE NAME : EDIT .002 SERVICE : FLIC VERSION : O01CO1 DATE : 98/01/ 4 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : FILE HEADER FILE NUMBER: 2 EDITED OPEN HOLE MAIN PASS Ail tool strings; Depth shifted and clipped curves; all runs merged; no cased hole data. DEPTH INCREMENT: 0.5000 FILE SUMMARY LDWG TOOL CODE START DEPTH SDN 10256.0 CNTH 10240.0 BCS 9551.0 DAS 10244.0 $ BASELINE CURVE FOR SHIFTS: GR CURVE SHIFT DATA (MEASURED DEPTH) BASELINE DEPTH 88888.0 10214.0 10197.0 10178.5 10176.5 10167.5 10154.0 10153.5 10144.0 10139.5 10138.5 10121.0 10119.5 STOP DEPTH 4027.0 226.0 4027.0 3483.0 .......... EQUIVALENT UNSHIFTED DEPTH .......... 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CNTH 955.359 -999.250 -999.250 17.364 -999.250 76.235 194.795 ** END OF DATA ** **** FILE TRAILER **** FILE NAME : EDIT .002 SERVICE : FLIC VERSION : O01CO1 DATE : 98/01/ 4 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : * * * * TAPE TRAILER * * * * SERVICE NAME : EDIT DATE : 98/01/ 4 ORIGIN : FLIC TAPE NAME : 97552 CONTINUATION # : PREVIOUS TAPE : COI~ENT : ARCO ALASKA INC, WARTHOG #1, WILDCAT, API #55-171-00012-00 **** REEL TRAILER **** SERVICE NAME : EDIT DATE : 98/01/ 4 ORIGIN '. FLIC REEL NAME : 97552 CONTINUATION # : PREVIOUS REEL : COI~MENT : ARCO ALASKA INC, WARTHOG #1, WILDCAT, API #55-171-00012-00
