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Home My WebLink About182-093Originated: Delivered to:18-Jun-25Halliburton Alaska Oil and Gas Conservation Comm.Wireline & Perforating Attn.: Natural Resource TechnicianAttn: Fanny Haroun 333 West 7th Avenue, Suite 1006900 Arctic Blvd. Anchorage, Alaska 99501Anchorage, Alaska 99518Office: 907-275-2605FRS_ANC@halliburton.comThe technical data listed below is being submitted herewith. Please address any problems orconcerns to the attention of the sender aboveWELL NAME API # SERVICE ORDER # FIELD NAME JOB TYPE DATA TYPE LOGGING DATE PRINTS # DIGITAL # E SET#1 1B-20 50-029-23164-00 910026681 Kuparuk River Packer Setting Record Field- Final 7-May-25 0 12 1D-117 50-029-22844-00 910027101 Kuparuk River Plug Setting Record Field- Final 8-May-25 0 13 1D-133 50-029-22827-00 910010225 Kuparuk River Multi Finger Caliper Field & Processed 25-May-25 0 14 1G-02 50-029-20813-00 910036496 Kuparuk River Multi Finger Caliper Field & Processed 21-May-25 0 15 1H-08 50-029-20763-00 910080713 Kuparuk River Multi Finger Caliper Field & Processed 22-May-25 0 16 1H-08 50-029-20763-00 910080713 Kuparuk River Plug Setting Record Field- Final 22-May-25 0 17 1Q-04 50-029-21250-00 910027200 Kuparuk River Tubing Cut Record Field- Final 14-May-25 0 18 1Q-04 50-029-21250-00 910027200 Kuparuk River Tubing Cut Record Field- Final 15-May-25 0 19 1Q-22 50-029-22595-00 910027102 Kuparuk River Plug Setting Record Field- Final 16-May-25 0 110 2B-02A 50-029-21154-01 910106459 Kuparuk River Leak Detect Log Field- Final 14-Jun-25 0 1PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF:Fanny Haroun, Halliburton Wireline & Perforating, 6900 Arctic Blvd., Anchorage, AK 99518FRS_ANC@halliburton.comDate:Signed:Transmittal Date:203-115197-237197-206182-138182-093184-234195-140216-087T40582T40583T40584T40585T40586T40586T40587T40587T40588T405896/20/2025Gavin GluyasDigitally signed by Gavin Gluyas Date: 2025.06.20 08:37:34 -08'00'182-0931H-0850-029-20763-00 910080713Kuparuk RiverMulti Finger CaliperField & Processed22-May-250161H-0850-029-20763-00 910080713Kuparuk RiverPlug Setting RecordField- Final22-May-2501 Wallace, Chris D (CED) From: Well Integrity Compliance Specialist CPF1 & 2 <n1617@conocophillips.com> Sent: Saturday, May 9, 2020 3:14 PM To: Wallace, Chris D (CED) Cc: CPA Wells Supt; Well Integrity Compliance Specialist CPF1 & 2 Subject: 1 H-08 (PTD #182-093) Report of re -charging IAP Attachments: 1 H-08.pdf, 1 H-08 90 Day TIO plot.pdf Chris - 1H -08 (PTD #182-093) was reported by operations with IA re -pressurization after an IA bleed. CPAI intends to leave the well on injection during the initial diagnostic. If the diagnostics indicate the loss of IA integrity the well will be shut in and further diagnostics will be scheduled to fit the initial diagnosis. The proper correspondence for continued injection or repair will be submitted once the plan has been developed. Please let me know if you have any questions or disagree with the plan. Attached is a 90 Day pressure trend and well bore schematic. Dusty Freeborn/Jan Byrne Wells Integrity & Compliance Specialist ConocoPhillips Alaska, Inc. Office phone: (907) 659-7224 Cell phone: (907) 830-9777 WELLS TEAM Conoca%ups • • MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission DATE: Monday,August 21,2017 TO: Jim Regg '\ " 71 1 P.I.Supervisor �� SUBJECT:Mechanical Integrity Tests CONOCOPHILLIPS ALASKA,INC. IH-08 FROM: Brian Bixby KUPARUK RIV UNIT 1H-08 Petroleum Inspector Src: Inspector Reviewed By: P.I.Supry NON-CONFIDENTIAL Comm Well Name KUPARUK RIV UNIT 1H-08 API Well Number 50-029-20763-00-00 Inspector Name: Brian Bixby Permit Number: 182-093-0 Inspection Date: 8/17/2017 Insp Num: mitBDB170817164839 Rel Insp Num: Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min Well IH-08 ' Type Inj W TVD 6203 - Tubing 1910 • 1915 1915 - 1915 - PTD 1820930 - Type Test SPT Test psi 1551 IA 385 2700 - 2600 - 2570 • BBL Pumped: 3.5 BBL Returned: 3.3 OA 140 170 170_ 170 - Intervale 4YRTST P/F P Notes: SCANNED E1 6 ';01F: Monday,August 21,2017 Page 1 of 1 Ima ect Well History File Cove~ge XHVZE This page identifies those items that were not scanned during the initial production scanning phase. They are available in the original file, may be scanned during a special rescan activity or are viewable by direct inspection of the file. -/ 4L~C~- - ~2 ~,~- Well History File Identifier RESCAN DIGITAL DATA OVERSIZED (Scannable) [] Color items: [] Diskettes, No. [] Maps: // Gporayscale items: [] Other, No/Type [] Other items scannable by or Quality Originals: large scanner OVERSIZED (Non-Scannable) [] Other: [] Logs of various kinds NOTES: [] Other BY: ~,v~ Project Proofing BY; BEVERLY ROBIN VINCENT SHERYL MARIA WIND~) IsI Scanning Preparation ~'/' x 30= /C~f~'~ + ~ = TOTAL PAGES /~/_¢ BY: BEVERLY ROBIN~~SHERYL MARIA WINDY DATE/¢~,~ Production SCanning Stage 1 PAGE COUNT FROM SCANNED FILE: PAGE COUNT MATCHES NUMBER IN SCANNING PREPARATION: BY: Stage 2 X YES IF NO IN STAGE 1, PAGE(S) DISCREPANCIES WERE FOUND: YES NO NO BY; BEVERLY ROBIN VINCEF~S~ARIA WINDY (SCANNING IS COMPLETE AT THIS POINT UNLESS SPECIAL ATTENTION I$ REQUIRED ON AN INDIVIDUAL PAGE BASIS DUE TO QUALITY. GRAYSCALE OR COLOR IMAGES) RESCANNEDBY; BEVERLY ROBIN VINCENT SHERYL MARIA WINDY DATE: /S/ General Notes or Comments about this file: Quality Checked (ho.e) 12/10/02Rev3NOTScanned,wpd • • MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission DATE: Tuesday,August 27,2013 TO: Jim Regg q(7.,1l3 P.I.Supervisor SUBJECT: Mechanical Integrity Tests CONOCOPHILLIPS ALASKA INC 1H-08 FROM: Jeff Jones KUPARUK RIV UNIT IH-08 Petroleum Inspector Src: Inspector Reviewed By: P.I.Supry NON-CONFIDENTIAL Comm Well Name KUPARUK RIV UNIT 1H-08 API Well Number 50-029-20763-00-00 Inspector Name: Jeff Jones Permit Number: 182-093-0 Inspection Date: 8/11/2013 Insp Num: mitJJ130822143618 Rel Insp Num: Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min Weill 1H-08 . IType Inj w jTVD 1 6203 550 IA T Sso 2900 2800 2780 I PTD 1 1820930 Type Test SPT Test psi 1551 1 OA 3o 1 90 ' 90 100 Interval I4 TST P/F 1 P Tubing'L 2220 1 2280 • 1 2240 - 2260 1 — — t . Notes: 2.9 BBLS diesel pumped. 1 well house inspected,no exceptions noted. , am DEL 1 0 n13 Tuesday,August 27,2013 Page 1 of 1 ~ MEMORANDUM To: Jim Regg ~ + P.I. Supervisor ~~~f ~ ~ ~1a I (~ ( ~ FROM: Bob Noble Petroleum Inspector State of Alaska Alaska Oil and Gas Conservation Commission DATE: Tuesday, August 25, 2009 SUBJECT: Mechanical Integrity Tests CONOCOPHILLIPS ALASKA INC 1H-08 KUPARLJK RIV iJNIT 1H-08 Src: Inspector NON-CONFIDENTIAL ~ Reviewed By: P.I. Suprv ~_ Comm Well Name: KUPARUK RN LTNIT 1H-08 API Well Number: 50-029-20763-00-00 Inspector Name: Bob Noble Insp Num: mitRCN090815094656 permit Number: ~82-093-0 Inspection Date: g~14/2009 Rel Insp Num: Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. We]~ 1H'08 Type Inj. W 'r~ 6203 ~ IA 920 3080 ~ 2970 2960 ~ P.T.D 1820930 TypeTest SPT Test psi 3040 ~ ~L~l 30 70 65 65 Interval 4YRTST P~F P ~ Tubing 2400 2400 2400 2400 Notes: , r~~ ~ . rn~~~ ~s ~~~ss~,~ ~~ s~~~' ~-~`~ a~'`?.;.t~l v"huY'' ` ~J ... ... ,",.~6J'~ Tuesday, August 25, 2009 Page 1 oF 1 ~ Maunder, Thomas E (DOA) From: NSK Problem Well Supv [n1617@conocophillips.com] Sent: Monday, August 24, 2009 1:43 PM To: Maunder, Thomas E (DOA) • Page 1 of 2 Cc: NSK Well Integrity Proj; Fleckenstein, Robert J(DOA); Regg, James B(DOA) Subject: RE: Recent MITs and Packer Depths Attachments: 1H-19 Wellbore Schematic.pdf; H-08 ellbore Schematic.pdf Tom, '~ \~~ Attached are the requested wellbore schematics and my answers to your questions below in red font. Martin From: Maunder, Thomas E (DOA) [mailto:tom.maunder@alaska.gov] Sent: Monday, August 17, 2009 11:30 AM To: NSK Problem Well Supv ~~,~~,~ Cc: NSK Well Integrity Proj; Fleckenstein, Robert J(DOA); Regg, James B(DOA~~ ;~; , ~ Subject: Recent MITs and Packer Depths `~ All, MITs were recently submitted for several wells. As Bob has reviewed the information to enter, he has discovered some discrepancies. Would you please research your records to confirm what the top packer depth is in the foll i~ g welis? Also, please submit wellbore drawings for the wells. 1 H-1~ 192-128 According to the 10-407 submitted 7/22/93 there are two packers in the well at 8242' and 8569' md. It is my assessment that the correct packer for MIT purposes is at 8242' md which I calculate to be - 6441' tvd. I assume you are referring to the 1 H-19 (PTD# 192-128). The 1 H-19 is a selective injection well that was drilled and cased with a Parker #245 rig release date of 12/19/92. On 6/15/93, e-line set at Baker "D" permanent packer at 8567' MD which was correlated to the CET log dated 01/07/93. On 6/16/93, Nordic 1 ran the 3-1/2" completion and recorded 8569' MD as the Baker "D" permanent packer depth to account for the difference in e-line and pipe measurement. As per the tubing detail this put the uppermost packer at a depth of 8241.93' MD and according to the CPAI depth converter is equivalent to 6369.7' TVD. _~ 1 H-08 182-093 A workover was perFormed on this well in late 1985 and the well was completed with 3 packers set at 7966', 8194' and 8303' md. Another workover was performed in mid 1990 to replace collapsed tubing. It does not appear that the packers were disturbed although the depths on the 404 are slightly changed to 7985', 8213 and 8322' md. There is also a note that mentions a leak at 7978'. With the limited summary information I have available, I cannot determine how that was determined. There was some difficulty obtaining a casing test using a RBP, but it appears that a successful test was achieved. Subsequent MITs have been successful. It is my assessment that the correct packer for MIT purposes is the top packer at --7985' md which calculates to be - 6200' tvd. The 1 H-08 is a selective injection well that was drilled and cased with a Parker #141 rig release date of 07/08/82. The well was originally completed as a single with a BOT HB-1 packer set at 7940' MD on 07/07/82. On 12/12/85 a workover using Parker #141 was finished to perForm remedial cementing operations and complete the well as a triple packer selective single. According to the tubing detail the packers were set at 7966', 8193', and 8303' RKB. On 10/22/90 another workover using Nordic #1 was completed to replace a collapsed gasiift mandrel above the uppermost packer. Only the tubing string above the SBR at 8322' RKB was replaced and none of the packers were pulled. The tubing detail notes that there is a"correction of depths as noted by Nordic #1 on 10/22/90" and as a result the packer depths are listed as 7985', 8213', and 8322' RKB which agrees 8/25/2009 • • Page 2 of 2 with our current completion sketch. Using the current uppermost packer depth of 7985' and the CPAI depth converter an equivalent depth of 6203' TVD is calculated. The only reference to a leak that I have been able to find refers to a leak within the uppermost packer that prevents isolation of the "C" sand but did allow isolation from the 7" annulus. Thanks in advance. Call or message with any questions. Tom Maunder, PE AOGCC 8/25/2009 ~ _~KUP ' ConocoPhillips ~Well Attributes 'iWOllboreAPl/UWI .FieldName WeIISWtus Inclination~") A~~`'^" ~"~ 500292076300 KUPARUK RIVER UNIT INJ 55.68 . ...~ .. __ ._ _____ IC ment iH25~ppm) Data~nnotatwn EndDete ~~~ TRDP .~ 0 ~ 7/1I2008 ~LastWO. r 1023/1990 WeIlConfia--1H-08811]120C~_'.t~~ 'r~. 5chematk A a ~ ~~A otation IOepth (ftKB) End Date Annobtion ~Last Taq~, . 8.468.0 827/1994 Rev Reason: PULL VORTEC TOOL CONDUCTOR, ~ eo sssv t~ae ~ Strinp Strfnp ID I Set Depth ~ 5~~ Da~ Casing DescriPhon OD (in) (in) ToP (kKB) ~ (kK6) ~ (N CONDUCTOR ~ 16- 15.O6~ii 800 rt~ ~ - . SURFACE SURFACE 10 3l4 9J94 0.0 2255.01 PRODUCTION 7 6.751 0.0 8,708.0 . 2.z55 - Tubin Strin s Gns LiFr 25oy __...._-- ~ '~., ~~~ sa~oe Tubinp Description i OD (in) so-i~e ID (in) Top (ftKB) SetDepth i (kKB) Set Depth ( TUBING 3 V2 -..- -- ~ ~ 2.992 0.0 8.314.0~, TUBING ~ 2 7B 2.441 8.314.0 8.3320'~ cnsq,v4J __ TUBING-Abandoned I 27B 2441 8,339.0 8,358.0 Other In Hole All Jewal : Tubin Run & Retrievable Fi GAS LiFT Top (kKB) Description Com an~ ~~„ ~ - 1 J86 0 SSSV TRDP Camco TRDP-tA-; 2599.0 GAS LIFT CAMCO/KBUG/t/DMY/BK/// Comment: STA 1 cq; ~iF, 6 2~ 4.745.O ~GAS LIFT CAMCO/KBUG/1/DMY/BK/// CommenC STA 2 .` ~ 5,791.0 GAS LIFT CAMCO/KBUG/1/DMY/BK/// CommenC STA 3 GAS LIFT 6,229A GAS LIPT CAMCO/KBUG/1IDMY/BK/// CommenC STA 4 . 6; ~~ ~ - 6,726.0 GAS LIFT CAMCO/KBUG/1/DMYlBK/// Comment STA 5 7,219.0 GAS LIFT CAMCO/KBUG/1/DMY/BW// CammenC STA 6 cns uF1 i.,. - 7.596.0 GAS LIFT CAMCO/KBUG/1IDMY/BK/// CommenC STA 7 7.915.0 GAS LIFT MERLA/TPDX/1.5/DMY/T-2/// CommenC STA £ GAS LIFT 7.960.0 SBR Brown'G' . ~,sas-"-~ - 7.985.0 PACKER Brown H&1 PACKER (Packer Leak ~a 7978' on 8.021.0 ~ INJECTION MERLA/TPDX/L5/DMVlT-2/// Comment: CIOSf cnsuFL -" 8.095.O INJECTION MERLNTPDX/1.5/HFCV/RM///CommenC STA ~.ais SJ94.O INJECTION MERLA/iPDX/1.5/DMY/T-2///Commern:CLOSE 8213.0 PACKER 8rown HB-1 PACKER sea. i 9eo ~ - , 8,225.0 INJECTION CAMCO/KBUG/1/DMY/BK/// Comment~. CLOSEI PACKER.9,BB5 $,322.0 PACKER Brown 18 PACKER 8,342.0 NIPPLE Camco'D' Nipple NO GO iN~ecnaa. 8,342,0 FISH SLIP STOP 8 SLIP ARM FISH from 10/2/94 - e~~~~ GOOD PICTURE OF FISH 5/i6/1996 DROPPED 7' POST TUBING CUT 6/22007 iN~ectioN, 8.351.0'TTL e,oes "ERF, ~ 8 092~8 152 PerForations . . Shot Top (TVD) Btm (TVD) Dans Top ~ttKB) Bbn ~kKB) („KB) (ftKB) Typa Zone (ah~~~~~ Date iN~eciiau 8.19a 8,092.0 8.752.0 6,287.4 6.334.9 IPERF C-4, C3, 1H-OS 4.0 7/6/198: 8224.0 82520 6,3912 6.413.7 APERF C-1, UNIT B, 12.0 12/12/1'. 1 H-08 PACKER.B.$13 -- ~ A A~F fl A d17l1 ~ SSA !1 ~ SSR R IDC~F e_S 1uJ1R .1 !1 7/F/10R' INJECTION. 8.225 NIPPLE. 8.311 VALVE. 8,311 PACKER, 8.322- TUBMG CUT, 8.332 NIPPLE. 8.3<: FISH. 8 3<: SOS.8.35C TTL, 8,351 iFERF 30.51 1 H-08 I Depih (kKB) 8,740.0 9/772008 rine Top Thrd Comment TD, 11 /10/08 Co~ ~~i~~~~~~~r~ Schlumberger -DCS .'w ~~ ~~ ` ' ; ~i ^ ~ ,~ ~ n~~,„ . ,,..~ 2525 Gambell Street, Suite 400 ~ ~ ~ " - Anchorage, AK 99503-2838 ATTN: Beth Well Job # Log Description N0.4957 Company: Alaska Oil & Gas Cons Comm Attn: Christine Mahnken 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Field: Kuparuk Date BL Color CD 1C-119 11978488 INJECTION PROFILE 10/16/08 1 1 iJ-101 11978491 PRODUCTION PROFILE 10/19/08 1 1 3H-02 12080447 INJECTION PROFILE ~ ~~-- ~- 10/24/08 1 1 3K-24 11978500 SBHP 10/26/08 1 1 iJ-120 11978501 PRODUCTION PROFILE ~. 10/27/08 1 1 3H-24 12080454 INJECTION PROFILE 10/28/08 1 1 3S-15 11978491 SBHP SURVEY - 10!18/08 1 1 1H-OS 12100434 INJECTION PROFILE - f 10/30/08 1 1 1 H-09 12096560 INJECTION PROFILE I~ ZC ~0~3 ~~ lam} ('~ 10/30/08 1 1 Please sign and return one copy of this transmittal to Beth at the above address or fax to (907) 561-8317. Thank you. • ~ C ~~~~~ Schlumberger -DCS 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2838 ATTN: Beth Well Job # Please sign and return one copy of this transmittal to Beth at the above address or fax to (907) 561-8317. Thank you. ~~~G~- ~;~~ AUG ~ ~ 200$ Log Description ,. . 08/06/08 N0.4803 Company: Alaska Oil & Gas Cons Comm Attn: Christine Mahnken 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Field: Kuparuk ~ ~ ~~ ~ !~_o~ Date BL Color CD 1A-22 12097412 GLS l - 07/22/08 1 1 2G-04 12096519 PROD PROFILE - 07/23/08 1 1 1A-22 12097413 PROD PROFILE - ~ 07/23/08 1 1 1A-28 11996647 PROD PROFILE ~(/ 07/24/08 1 1 1A-25 11996648 PROD PROFILE ~ 07/25/08 1 1 2A-08 11996649 INJECTION PROFILE 07/26/08 1 1 1E-112 12080408 INJECTION PROFILE 07/27/08 1 1 2W-05 12080409 INJECTION PROFILE 07/28!08 1 1 3J-10 12097408 SBHP SURVEY 07!20/08 1 1 3M-28 12097411 SBHP SURVEY C - Q( 07/21/06 1 1 1 L-15 11982443 PROD PROFILE ~ 07/06/08 1 1 30-08A 12080407 SBHP SURVEY ~Cr i41~}- (93 ~ (per' 07/26/08 1 1 30-09 12080406 SBHP SURVEY /(®°~--(p~ 07/26/08 1 1 1 L-24 11978468 PRODUCTION PROFILE 07/26/08 1 1 1 F-17 12080410 PRODUCTION PROFILE L{ ~ (p 07/29/08 1 1 30-11 12100430 SBHP SURVEY -pY 07/31/08 1 1 2M-06 12100433 INJECTION PROFILE 08/02/08 1 1 1H--~, 12100434 INJECTION PROFILE l}Z.C ~ "3 {0 08/03/08 1 1 UGNU DS2-OBi 11996650 TEMPERATURE LOG 07/27/08 1 1 2X-14 12100432 LDL G ~ 08/01/08 1 1 i F-20 12100435 PRODUCTION P OFILE / 08/04/08 1 1 1H-09 12100436 INJECTION PROFILE U 08/05/08 1 1 • • ~~ ConocoPhillips ~~ P.O. BOX 100360 ANCHORAGE, ALASKA 99510-0360 March 14, 2008 Mr. Tom Maunder Alaska Oil ~i Gas Commission 333 West 7~' Avenue, Suite 100 Anchorage, AK 99501 ~~r~ '~,'~,~ t~~u ~r ~ 20~ Dear Mr. Maunder: • J - m T i ~ ~ ~ ~ ~' ! _~ ~. ~ _: ,~ ~ ' ~ y .,0~3 ~~~ Enclosed please. find a spreadsheet with a list of wells from the Kuparuk field (KRU). Each of these wells was found to have a void in the conductor. These voids were filled with cement if needed and corrosion inhibitor., engineered to prevent water from entering the annular space. As per previous agreement with the AOGCC, this letter and spreadsheet serves as notification that the treatments took place and meets the requirements of form 10-404, Report of Sundry Operations. The cement was pumped January 17, 2008 and the corrosion inhibitor/sealant was pumped on February 2, and March 8, 2008. The attached spreadsheet presents the well name, top of cement depth prior to filling, and volumes used on each conductor. Please call me or Perry Klein at 907-659-7043, if you have any questions. Sincerely, ~.-~ f ~,~~, ,~ `~,.. M.J. veland ConocoPhillips Well Integrity Projects Supervisor • • ConocoPhillips Alaska Inc. Surface Casing by Conductor Annulus Cement, Corrosion inhibitor, Sealant Top-off Report of Sundry Operations (10-404) Kuparuk Field n~ta 3/14/2008 Well Name PTD # Initial top of cement Vol. of cement um ed Final top of cement Cement top off date Corrosion inhibitor Corrosion inhibitor/ sealant date ft bbls ft al 1 H-04 182-103 23" NA 23" NA 4.5 2/2/2008 1 H-06 182-068 28' 3.2 5" 1/17/2008 5.5 2/2/2008 1 H-07 182-084 9' 3" 1 11 " 1 /17/2008 7 2/2/2008 1 H-08 182-093 SF NA SF NA 4 2/2/2008 1E-31 .197-138 4'10" NA 4'10" NA 21 3/8/2008 1 E-32 197-132 8" NA 8" NA 3.5 3/8/2008 1 E-35 198-195 12" NA 12" NA 2 3/8/2008 1 E-36 198-213 20" NA 20" NA 4.5 3/8/2008 U I-Cv /1f é) -L'113 07/27/07 ScblulIbepgep NO. 4343 Schlumberger -DCS 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2838 A TTN: Beth ~} 0 2007 f)aska Oil & Gas Cons. Commission Anchorage . ... ~ () 1 1.007 S~ANNt.D AU \J Company: Alaska Oil & Gas Cons Comm Attn: Christine Mahnken 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Field: Kuparuk Well Date BL CD Color Job# Log Description 1H·08 11850414 INJECTION PROFILE 07/23/07 1 2L-327 11665460 SBHP SURVEY 07/21/07 1 2M-28 11850413 PRODUCTION PROFILE 07/22/07 1 2M-32 11850415 GLS 07/24/07 1 2P-448A 11850403 SBHP SURVEY 07/21/07 1 1H-03 11632739 INJECTION PROFILE 07/23/07 1 2T·37 11632740 PRODUCTION PROFILE 07/24/07 1 2H-14 11632738 PRODUCTION PROFILE 07/22/07 1 l£ Please sign and return one copy of this transmittal to Beth at the above address or fax to (907) 561-8317. Thank you. . . 06/14/07 Schlumbergel' UIc... l~d- -O<=}3 -cANNE.D JUN ..~ 1. l{)t)7 5 NO. 4300 Schlumberger -DCS 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2838 ATTN: Beth '.F 0 ? {.J(".J'l ;'-cJ ¡J L _ q Company: Alaska Oil & Gas Cons Comm Attn: Christine Mahnken 333 West 7th Ave, Suite 100 Anchorage, AK 99501 f. ,f"::, Field: Kuparuk Well Job# Log Description Date BL Color CD 2M-16 11629024 SBHP SURVEY 06/06/07 1 2N-306 11629025 SBHP SURVEY 06/06/07 1 2H-07 11638870 PRODUCTION PROFILE 06/07/07 1 2N-323 11629027 SBHP SURVEY 06/08/07 1 2N-313 11629027 SBHP SURVEY 06/08/07 1 2M-29 11638871 SBHP SURVEY 06/08/07 1 1C-104 11638872 LDL 06/08/07 1 1 G-08A 11629026 PRODUCTION PROFILE 06/09/07 1 2N-308 11638874 SBHP SURVEY 06/09/07 1 2M-10 11629031 SBHP SURVEY 06/10107 1 1A-27 11638876 PRODUCTION PROFILE 06/10107 1 2M-12 11629030 SBHP SURVEY 06/10107 1 2L-311 11638881 SBHP SURVEY 06/11/07 1 2N-317 11638878 SBHP SURVEY 06/11/07 1 2B-08 11629032 INJECTION PROFILE 06/11/07 1 1 H-08 11638882 INJECTION PROFILE 06/12/07 1 Please sign and return one copy of this transmittal to Beth at the above address or fax to (907) 561-8317. Thank you. . . Scblumberger Schlumberger -DCS 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2838 ATTN: Beth Well Job # RECE}VED ¡ : ~.i (I ~ 'ìn06 ,.., \ .-, '''; i..'~U ~jëß~2 ,~ Gas O:f>5. c;:mIf~ -: ß')i :mfìQ .L" t,J '.. ,..-J..J OJ Date NO. 3831 Company: Field: BL 06/02/06 Alaska Oil & Gas Cons Comm Attn: Christine Mahnken 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Kuparuk (ß d....... üJ~ 3 rI , ~ _O'tJ Color CD e lJ~~~;:çe >Ç"':I,Ní',V'~ ) ~ ._.'¡ ,.\ ,", ...,1::.-"-..... '..... '. ".. -" ..--- Log Description 1Y-12 I~?' - ,,~¡;. 11235362 INJECTION PROFILE OS/20/06 1 1L-06 /~~/- ¡:z=z 11213748 PRODUCTION PROFILE WIDEFT 05/19/06 1 1Q-24 ¡C¡S-- i,JI 11213849 INJECTION PROFILE OS/20/06 1 1 H-04 /1f::J - I f~:1., 11213752 INJECTION PROFILE OS/23/06 1 1H-08 t~-~ 11213751 RSTIWFL OS/22/06 1 2Z-02 i~3 -.~7f(; 11235362 INJECTION PROFILE OS/28/06 1 1 H-16 /c:¿;:J - ':;:1 11235365 PRODUCTION PROFILE WIDEFT OS/24/06 1 2A-04 115«- C::5' 11213755 CROSS FLOW DETERMINATION OS/26/06 1 31-10 ¡..;{q -t.31 11213759 PRODUCTION PROFILE WIDEFT 05/30/06 1 1H-19'S::)- J;....l-?i 11320975 INJECTION PROFILE OS/29/06 1 2A-13 ;'iy-4,- - ¡'It.¡ 11320976 LDL 05/30/06 1 2Z-04 Î?í-3-C:~ 11213757 INJECTION PROFILE OS/28/06 1 2Z-12A I Cf,";)- -/.y~ 1123568? GLS OS/27/06 1 3F-02 i ~'''-~~'' 11213758 PRODUCTION PROFILE WIDEFT OS/29/06 1 c-ft e Please sign and return one copy of this transmittal to Beth at the above address or fax to (907) 561-8317. Thank you. MEMORANDUM TO: Julie Heusser ~'.,~.6'~ Commissioner State of Alaska Naska Oil and Gas Conservation Commi., DATE: July 6, 2001 ~sion SUBJECT: Mechanical Integrity Tests THRU: Tom Maunder 1~/~ .~ Phillips Alaska Inc. P.I. Supervisor ~}-~,,~' P ~>w--- - 1H Pad ~o\.~\t,~[l~l'__ 1H-03, 1H-04, 1H-07, 1H-08, 1H-09 FROM: Jeff Jones KRU Petroleum Inspector Kuparuk River Field NON- CONFIDENTIAL , . Packer Depth Pre~est Initial 15 Min. 30 Min. we~,l _'1~ 1TypelnJ. I S .I.T.V.o..I .62~ I~'~a"gl '~1 25o0 I' 2500'1 25oo' 4 P.T.D.I 18211501Typetestl P 'lT~,,PsiI 155,1 I ca~r~l ~ I~O I, ~. I .~640'l..pf., I,e". I ' Wa, t ~,-o4 ' I Type i"j:l ', $r1,' ,I'"i'.V.D. ,.! 6185., I T,~bing I 2r,~o'. I 25°~"i 2'5d0'.' ,I... 2~t ! i~q' 4- i P.T.D.I 1821030 ITyP®t~! e. I.Test PSil..1546 I ca~.g I ~0 I ~770 I ~770 I 177!!.'.. I.:. 'P'~..'l E I ' "Weill 1H-07 'lTypeinj. I S' I T:V.D. I 6424' I'YGU"g i' 232O' i '2320' i' 232O' I 232O 't""~'~1"'4 1 P:T.D.I~... 1~ IType~l ,. P ..ITestpsil .~606 l'c~.~! '~ 'l 17~':!' ;i74°'l"174o ,I, P/F, I:'P:! .. · ~Vd~I "~: I~'yPe'i,~j.'l" s '. '1: ~',v,D: '1 ~o3 I' Tua."g.i' .~.6o. I', '~0 i,, i'SSo '1 '~ ',sSO.. I!,~1', 4 p.T.D~I 1820930 ITypetestl P ITestps~l .,1.55! I, ~s!..g.! ,a60 I .2350.,,,12300, I ~' I P/F I ~ · w,~q :~H-O~ iType~.j.I' .S, I T.v.D./..6468 ~i.'T'~I 2s:~'l' "2~ i ~' 1'_255o I~! 4' ,' PiT. D.I 1930290 IType.testi. P. ITestpsil 1617 i casi"gl 67o I 1790 I ~75o I. w4o I .i~/F :1 ~ Notes: Type INJ. Fluid Codes F = FRESH WATER INJ. G = GAS INJ. S = SALT WATER INJ. N = NOT INJECTING Type Test M= Annulus Monitoring P= Standard Pressure Test R= Internal Radioactive Tracer Survey A= Temperature Anomaly Survey D= Differential Temperature Test Interval I= Initial Test 4= Four Year Cycle V= Required byVariance W= Test during Workover O= Other (describe in notes) Test's Details Friday, Jul_v 6. 20~!; I traveled to Phillips Alaska Inc.'s 1H Pad and witnessed the 4-year MIT's on wells 1H-03, 1H-04, 1H-07, 1H-0g and IH-09. The pretest tubing and casing pressures were observed and found to be stable. The standard annulus pressure test was then performed with all five wells passing the MIT's. Summary: I witnessed successful 4,year MIT's on PAl's wells ]H-03, 1H-04, 1H-0?, IH-08, and ]H-09 in the Kuparuk River Field/KRU. M.I.T.'s performed: 5_ Attachments: Number of Failures: 0_ Total Time during tests: 3.5 hrs. CC: MIT report form 5/12/00 L.G. MIT 1H Pad pg.'2 KRU 7-6-01 JJ.xls 7/16/01 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: Operation shutdown_ Stimulate _ Plugging _ Perforate _ Pull tubing _ Alter casing _ Repair well _ Other _X 2. Name of Operator Phillips Alaska, Inc. 3. Address P. O. Box 100360 Anchora~le, AK 99510-0360 4. Location of well at surface 888' FNL, 781' FEL, Sec. 33, T12N, R10E, UM At top of productive interval 1310' FSL, 1505' FWL, Sec. 33, T12N, R10E, UM At effective depth At total depth 1179' FSL, 1145' FWL, Sec. 33, T12N, R10E, UM 5. Type of Well: Development _ Explorato~__ Stratigraphic__ Servi~___X (asp's 549566, 5979815) (asp's 546601, 5976714) (asp's 546242, 5976581) 6. Datum elevation (DF or KB feet) RKB 85 feet 7. Unit or Property name Kuparuk Unit 8. Well number 1 H-08i 9. Permit number / approval number 182-093 10. APl number 50-029-20763 11. Field / Pool Kuparuk Oil Pool 12. Present well condition summary Total depth: measured true vertical 8740 feet 6810 feet Effective depth: measured 8468 feet true vertical 6587 feet Plugs (measured) Casing Length CONDUCTOR 78' SURF CASING 2170' PROD CASING 8623' Junk (measured) Size Cemented 16" 330 Sx AS II 10-3/4" 1140 Sx AS III & 250 Sx AS II 7" 1191 Sx G & 250 AS II Tagged PBTD (8/27/94) @ 8468' MD. Measured Depth True vertical Depth 78' 78' 2255' 2210' 87O8' 6784' RECEIVED Perforation depth: measured true vertical 8092 - 8152'; 8224 - 8252'; 8426 - 8432'; 8442 - 8472' 6287 - 6335'; 6392 - 6414'; 6554 - 6558'; 6566 - 6591' FEB 1 6 Z001 Alaska 0il & Gas Cons. Commission Anchorage Tubing (size, grade, and measured depth) Packers & SSSV (type & measured depth) 3.5", 9.2#, J-55 Tubing @ 8314' MD; 2-7/8", 6.5#, J-55 Tubing @ 8344' MD. Brown HB-1 Packer (Leak @ 7978': 11/19/92) @ 7985' MD; Brown HB-1 Packer @ 8213' MD. Camco TRDP-1A-SSA @ 1786' MD. 13. Stimulation or cement squeeze summary Intervals treated (measured) (see attached) Treatment description including volumes used and final pressure 14. Prior to well operation Subsequent to operation OiI-Bbl - RepresentatNe Daily AverageProductionorl~ection Data Gas-Mm W~e>Bbl - 2700 - 3300 Casing Pressure - Tubing Pressure 1800 1850 15. Attachments Copies of Logs and Surveys run _ Daily Report of Well Operations .__X 16. Status of well classification as: Oil __ Gas __ Suspended __ Service __(Water Inj).~ 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Title: Prepared by John Peirce 265-6471 SUBMIT IN DUPLICATE Form 10-404 Rev 06/15/88 · ORIGINAL 1H-08i MARCIT GEL SQUEEEZE DESCRIPTION OF WORK COMPLETED 8/29100- 8/31100: Performed a MARCIT Polymer Gel Squeeze for Injection Profile Modification as follows: MIRU & PT equipment. Pumped the treatment fluids fullbore through the open perforation intervals located at: 8092 - 8152' MD 8224 - 8252' MD 8426 - 8432' MD 8442 - 8472' MD Pumped: a) 500 bbls Seawater cool down stage @ 5 bpm & 2100 psi, followed by b) 500 bbls Gel stage @ 5 bpm, w/MARCIT Polymer @ 3000 ppm, followed by c) 5000 bbls Gel stage @ 4 - 5 bpm, w/MARCIT Polymer @ 6000 ppm, followed by d) 3000 bbls Gel stage @ 4 - 5 bpm, w/MARCIT Polymer @ 7500 ppm, followed by e) 2000 bbls Gel stage @ 4 - 5 bpm, w/MARCIT Polymer @ 9000 ppm, followed by f) 115 bbls Diesel Flush, followed by g) Shutdown. Left the well shut in for 5 days, then returned the well to water injection & obtained valid injection rate. RECEIVED FEB 1 6 2001 Naska 0ii E Gas Cons. Commission Anchorage ARCO Alaska, Inc. Date: January 31, 1996 Transmittal #: 9328 RETURN TO: ARCO Alaska, Inc. Attn.: Julie Nash Kuparuk Operations File Clerk ATO-1119 B P.O. Box 100360 Anchorage, AK 99510-0360 Transmitted below are the following open/cased hole items. Please acknowledge receipt and return one signed copy of this transmittal. Dual Burst TDT-D Dual Burst TDT-D ARC's ARC's Dual Burst TDT-D 02/05/95 01/07/95 12/15/95 11/25/95' 01/09/96 50-029-20763-00 50-029-22371-00 5172-8866 5797-8640 50-029-21433-00 Acknowledged' Date: DISTRIBUTION: Mr. Vernon E. Pringle Jr. DeGIoyler and MacNaughton One Energy Square Dallas, TX 75206 Erickson/Zuspan NSK Central Files NSK 69 Sharon AIIsup-Drake DS Development ATO - 1205 Larry Grant AOGCC 3001 Porcupine Drive Anchorage, AK 99501 Clifton Posey Geology ATO - 1251 i-~ 2 ? 1996 Anchorage GeoQuest 500 w. International Airport Road Anchorage, AK 99518-1199 ATTN: Sherrie NO. 10004 Company: 1/24/96 Alaska Oil & Gas Cons Comm Attn: Larry Grant 3001 Porcupine Drive Anchorage, AK 99501 Field: Kuparuk (Open/Cased Hole) US Well Job # Log Description Date BL RF Sepia DIR MWD Tape 1H-08 )2--~% 95064 DUAL BURSTTDT-P (BORAX) 950205 I I 1 1 Y- 24 q,~ -- ~) 72, 95036 DUAL BURST TDT-P (BORAX) 950107 I 1 3R-26 ~'~-- ~? 95406 ARC5 951215 I I 1 2X-12A ~'~-- fT(; 95382 ARC5 951125 I I I ~-~ 3A-04 ~T-,I,~ ? 95038 DUAL BURST TDT-P (BORAX) 950109 I I I SIGNED: Please sign and return one copy of this transmittal to Sherrie at the above address. Thank you. Alaska Oii Gas Conscr,~ation Q)mmission 3001 Porcupine Drive Anchora§e, Alaska 99501-3192 907-279-1 ~J33 To: ~fCo ne: Permit The following data is hereby acknowledged as being received: Description Received by: Dated: ~opySentto sender: Ycs~ No /~ ARCO Alaska, Inc.'(' Post Office Er,.,,~ 100360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 September 20, 1993 Mr. David W. Johnston, Chairman Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Dear Mr. Johnston: Attached in duplicate are multiple Reports of Sundry Well Operations (Form 10-404) notices in the Kuparuk field. The wells are listed below. WELL ACTION ,11E-15 Perforate ~.-lo2. E-15 Stimulate ~%" ~t'l H-07 Other -. 1 H-08 Other ,5~o.~ ~.! H-15 Stimulate q~.~,o~ H-22 Stimulate H-22 Other ~,-'~rl 1Q-08 Stimulate If you have any questions, please call me at 263-4241. Sincerely, P. S. White Sr. Engineer Kuparuk Petroleum Engineering , ECE!VED Aias~(s .... Anchorage ARCO Alaska, Inc. is a Subsidiary of AtlanticRichfieldCompany AR3B-6003-(~ REPORT OF SUNDRY WELL OPERATIONS 1. Operations Performed: Operation Shutdown Stimulate Plugging Perforate ~; Pull tubing ~ Alter casing ~ Repair well Other X ~'~,,,, 2. Name of Operator 5. Type of Well: 6, Datum elevation (DF or KB) V Development _ ~:~ ARCO Alaska. Iris, Exploratory _ RKB 85 feet 3. Address Stratigraphic_ 7. Unit or Property name P. O. Box 100360, Anchora~le, AK 99510 Service X Kuparuk River Unit :4. Location of well at surface 8. Well number 888' FNL, 781' FEL, Sec 33, T12N, R10E, UM 1H-08 At top of productive interval 9. Permit number/approval number 1310' FSL, 1505' FWL, Sec 33, T12N, R10E, UM 82-93/93-126 At effective depth 10. APl number 1263' FSL, 1366' FWL, Sec 33, T12N, R10E, UM 50-029-20763 At total depth 11. Field/Pool 1197' FSL~ 1145' FWL~ Sec 33~ T12N~ R10E~ UM Kuparuk River Oil Pool 12. Present well condition summary Total Depth: measured 8 7 4 0 feet Plugs (measured) None true vertical 6809 feet Effective depth: measured 8 6 0 2 feet Junk (measured) None true vertical 6 69 6 feet Casing Length Size Cemented Measured depth True vertical depth Structural Conductor 8 0' I 6" 330 SX AS II 8 0' 8 0' Surface 2223' I 0-3/4" 1000 Sx AS III & 2256' 221 1' Intermediate 250 Sx AS II, Top Job w/140 Sx AS III Production 8675' 7" 1191 Sx Class G & 8708' 6783' Liner 250 Sx AS II Perforation depth: measured 8092'-8152', 8224'-8252', 8426'-8432', 8442'-8472' true vertical 6286'-6333', 6390'-6413', 6552'-6557', 6565'-6589' Tubing (size, grade, and measured depth) 3.5", 9.2#, J-55 @ 8314' & 2.875", J-55 @ 8314'-8343' Packers and SSSV (type and measured depth) Pkr: Brown HB-1 ~ 7985'; Brown HB-1 ~.~ 8213', Brown lB ~ 8322'; SSSV: Camco TRDP-1AE wANRDP ~.~ 1936' 13. Stimulation or cement squeeze summary Converted well from oil producer to water injector on 6/13/93. ~ E ~ E IV E D Intervals treated (measured) N/A Treatment description including volumes used and final pressure S ~ ? ~_ ~ ~93 N/A 14. Reoresentative Daily Averaae Production or Iniection {~,J{a {JJJ & GaS C0~,S. {~.l~Tlrlll$$'~' OiI-Bbl Gas-Mcf Water-Bbl Casing Pressure~rich{3~.~sg Pressure Prior to well operation I 7 0 0 65 3200 1200 740 Subsequent to operation 0 0 9000 1300 1900 15. Attachments 16. Status of well classification as: Copies of Logs and Surveys run~ Water Injector .~ Daily Report of Well Operations X Oil ~ Gas ~ Suspended~ Service 17. I hereby_certify that the foregoing is true and correct to the best of my knowledge. Signed / Title Senior Engineer Date ~-'"'~--/~ Form 10-404 Rev 06/15/88 SUBMIT IN DUPLICATE KD~S MORNING WELL REPORT FOR 05/13/93 DRILLSITE 1H PAGE 1 PRODUCTION WELL STATUS GAS LIFT STATUS IGOR = 30000 SI DATA CHOKE 7" OR WC H2S CSG % FTP FTT % PPM PS I ~ B PR 17& 175M 108M 0 25 1150 10" PSI 900 GAS GAS C INJ OPT OPT H M 0 METER VOL RATE QL R I D READING MSCF MSCFD ROOTS S N E 0 350M 1194 5. I 0000 0 )TALS: 350 1194 INJECTION WELL STATUS INJECTION VOLUMES SI DATA WATER RECMD CHOKE 7" 10" INJ OR INJ CSG CSG METER VOL RATE % PSI FTT PSI PSI READING BBLS BWPD 9AS C INJ H M 0 VOL R I D MMSCF S N E tTALS: 7281 0.000 ) B SI 0 OM OM 1550 900 0 0 O~ O. 000 ~ B PW 100 2411 142 1480 725 0 7281 7281~ 0.000 ' B SI 0 OM OM 700 350 .... 0 0 O~ O. 000 ) B PW '10 800M 130 c780~ 30 0 350M O~ Oo 000 SWI' 0 + PWI' 7531 = 7531 2400 &2 0000 0 2400 52 1800 52 AFTER THE RECOMMENDED WATER INJECTION RATE INDICATES THAT THE SHOULD BE WIDE OPEN REGARDLESS OF THE LISTED RECOMMENDED RATE. ~ OIL AND ~ CONSEFIVATION GOMMI~:~,ON APPLICATION FOR SUNDRY APPROVALS 1. Type of Request: Abandon _ Suspend _ Ope hutd°WT~me exten Alter casing _ Repair well_ gig _ ' - ' _ ' _ - Change approved program .~_ Pull tubing _ Variance _ Perforate _ Other 2. Name of Operator ARCO Alaska. Inc, 3. Address P. O. Box 100360, Anchorage, AK 99510 5. Type of Well: Development Exploratory Stratigraphic Service 4. Location of well at surface 888' FNL, 781' FEL, SEC 33, T12N, R10E, UM At top of productive interval 1310' FSL, 1505' FWL, SEC 33, T12N, R10E, UM At effective depth 1263' FSL, 1366' FWL, SEC 33, T12N, R10E, UM At total depth 1197' FSL, 1145' FWL, SEC 33, T12N, R10E, UM 12. Present well condition summary Total Depth' measured Effective depth: Casing Structural Conductor Surface Intermediate Production Liner Perforation depth: 8740 feet true vertical 6 8 0 9 measured 8 6 0 2 feet true vertical 6 6 9 6 Length Size 80' 16" 2223' 1 0-3/4" 8675' 7" measured 8092'-8152', true vertical 6286'-6333,, Tubing (size, grade, and meaSured depth) 8224'-8252', 6390'-6413', 6. Datum elevation (DF or KB) RKB 85 7. Unit or Property name Kuparuk River Unit feet 8. Well number 1H-08 9. Permit number 82-93 10. APl number 50-029-20763 11. Field/Pool Kuparuk River Field Kuparuk River Oil Pool Plugs (measured) feet None Junk (measured) feet None Cemented Measured depth True vertical depth 330 Sx AS II 8 0' 8 0' 1000 Sx AS III & 2256' 221 1' 250 Sx AS II, Top Job w/140 Sx AS III 1191 Sx Class G & 8708' 6783' 250 Sx AS II 8426'-8432', 8442'-8472' 6552'-6557', 6565'-6589' RECEIVED MAY 21 199,] 3.5", 9.2#, J-55 @ 8314' & 2.875", J-55, @ 8314'-8343' Alaska0il&GasC0ns. C0mmiss Packers and SSSV (type and measured depth) wAn~.hnr~ln~./.~~ Pkr: BroWn HB-1 @ 7985,; Brown HB-1 @ 8213', BroWn lB @ 8322'; SSSV: Camco TRDP-1AE 1936' 13. Attachments Description summary of proposal X~ Convert well from oil producer to water injector. 14. Estimated date for commencing operation June. 1 16. If proposal Was verbally approved Name of approver Date approved Detailed operation program _ BOP sketch_ 15. Status of well classification as: Oil __ Gas _ Suspended Service Water I niector 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed C,~, ~ Title Engineer FOR COMMISSION USE ONLY Date ~'/20/?~ Conditions of approval: Notify Commission so representative may witness Plug integrity _ BOP Test Location clearance Mechanical Integrity Test .~ -- Subsequent form r-;quire Original Signed By David W. Johnston Approved by order of the Commission Form 10-403 Rev 06/15/88 Commissioner Approved Copy Returned IApproval_No., I ~,,~ Date ,~/Z. (,,,/~ ,,~ SUBMIT IN TRIPLICATE Attachment I "(,~ Conversion to Water Injection Kuparuk Well 1H-08 ARCO Alaska requests approval to convert Well 1 H-08 from an oil producer to a water injector. This well will be operated as a Class II UIC well in compliance with Area Injection Order No. 2. Water will be injected for the purpose of enhanced recovery into the Kuparuk interval between the depths of 6286' and 6589'. This interval correlates with the strata found in ARCO's West Sak River State Well No. 1 between the depths of 6474' and 6880' as authorized in Rule 1 of this injection order. A Mechanical Integrity Test will be pedormed before injection is initiated and every four years thereafter, in compliance with Rule 6 of this order. This well's injection volumes, average injection pressure, and average annulus pressure will be reported to the AOGCC monthly. RECEIVED MAY 2 1 199 Alaska 0il & Gas Cons. Commission Anchorage STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: Operation Shutdown Pull tubing X Alter casing Stimulate __ Plugging Perforate Repair well Other__ 2. Name of Operator ARCO Alaska, Inc, 3. Address P. O. BOX 100360, Anchorage, AK 99510 5. Type of Well: Development Exploratory Stratigraphic Service 4. Location of well at surface 888' FNL, 781' FEL, Sec. 33, T12N, R10E, UM At top of productive interval 1310' FSL, 1505' FWL, Sec. 33, T12N, R10E, UM At effective depth 1267' FSL, 1366' FWL, Sec. 33, T12N, R10E, UM At total depth 1179' FSL, 1145' FWL, Sec. 33, T12N, R10E, UM 12. Present well condition summary 6. Datum elevation (DF or KB) 85' RKB 7. Unit or Property name Kuparuk River Unit 8. Well number 1H-8 9. Permit number/approval number 82-93/90-569 10. APl number 50-029-~0763 11. Field/Pool Kupa[uk' ,.Riy,e[..O. il. P.o~ r~ RE( t: vcu Total Depth: measured 8740' true vertical 6809' Effective depth: measured 8602' true vertical 6696' Casing Length Size Structural 8 0' 1 6" Conductor Surface 2255 1 0-3/4" Intermediate Production 8708' 7" Liner Perforation depth: measured 8092'-8107', true vertical 6286'-6298', Tubing (size, grade, and measured depth) 3-1/2" 9.2# J-55 @ 8343' Packers and SSSV (type and measured depth) feet feet Plugs (measured) feet feet Junk (measured) Cemented 330 Sx AS II 250 sx AS II 1000 sx AS III 1191 sx Class G O EC - ? 1990 Alaska 011 & Gas Cons. C0mm'tss'~o~ Anchorage Measured depth True vertical depth 110' md 110' tvd 2849' md 2634' tvd 8740' md 6809' tvd 8442'-8472', 8426'-8432', 8137'-8152', 8122'-8137', 8107'-8122' 8252'-8224' 6565'-6589', 6552'-6557', 6321'-6333', 6309'-6321', 6298'-6309' 6413'-6390' feet Brown "HB-I" Pkr @ 7985', Brown "lB" Pkr @ 8213', Brown "HB-I" Pkr @ 8322, Camco "TRDP--1A" SSSV @ 1786' 13. Stimulation or cement squeeze summary Intervals treated (measured) Treatment description including volumes used and final pressure 14. Prior to well operation Subsequent to operation Reoresentative Daily Average Production or Injection Data OiI-Bbl Gas-Mcr Water-Bbl Casing Pressure Tubing Pressure 15. Attachments Copies of Logs and Surveys run Daily Report of Well Operations X 16. Status of well classification as: Water Injector__ Oil X Gas Suspended Service 17. I hereby certify that the foregoing is true and correct to the beSt of my knowledge. ~'o~;ej 1 0-404 aev~0~/17/89 Title Area Drilling Engineer SUBMIT IN DUPLICATE KUPARUK RIVER ' Auth. or W.O..o. AK4761 NORTH SLOPE Le~m or UnH ADL: 25639 ALK: 464 Tiff® Operator ARCO Date and a~ of 8.'00 10/15/90 ( TD: 0 PB: 0 SUPV: DB 10/16/90 (2) TD: 0 PB: 8602 eUPV:DB NORDIC 55.252072 Prior status if a W.O. MOVE RIG FROM3G-9 TO 1H PAD. .. DAIL¥:$4~910. CUM:$4,910 TESTING BOPE MM: 0.0 ETD: $4,910 EFC: $260,000 M~: 9.1 NaC1 FINISH MOVING RIG TO iH PAD. MOVE ON WELL 1H-8. ACCEPT RIG @ 07:30 15-0CT-90. R/U LUBRICATOR & PULL BPV. R/U OTIS SLICNLINE AND CIRCULATING LINES. TEST LUBRICATOR TO 2500 PSI START IN HOLE TO PULL DV AT 7584'. BLEED GAS OF ANN. WELL FLOWING, SHUT IN ANNULUS. PULL DV AT 7584'. POOH AND R/D OTIS. UNABLe-TO BI~ED GAS HEAD OF TUBING.. BLEED GAS OFF ANNULUS, START PUMPZNGDIESEL IN TUB. CIRC DIESEL TO GLM AT 7584:'; SHUT :.I:N BACK SIDE~, INJECT 35.BBL DIESEL TO FLUSH TAIL AND PER~S. CIRC 30 BBL D~ESEL, 70 BBL 8.5 PPG BRINE TO OU~S~ii~.I~IGH~:'.~!$U~FACE. SYSTEM'TO 9.1 PPG, CIRC ONCE A__P~, WE'LL DF~D.. SET BPV, N/D TREE, N/U BOPE, PULL BPV, SET'.T~P. TEST BOPE:'PUMP MANIFOLD, MUD CROSS, BLIND pa~s. ?o.,: 3!~oo. PSI. CUM:$71,-3~3 ETD:S71,373 EFC:$260,000 10/17/90 TD: 0 PB: 8602 SUPV:DB 10/15190( PB: 8602 SUPV: GB 4) COMP ASSY MW: 9.1 NaC1 BOPE TO 3000 PSI. CIRC ONCE AROUND TO CLEAR PULL TUBING W/ 120K%. WAIT ON AND R/U HLS. TO 1000 PSI. RIH W/ 2.7" GAUGE DUMMY AND DETERMINE THAT COLLAPSE IS GLM @ 7895' · WL TOOLS HANGING AT SSSV. RELAND RAISE STACK AND ATTACH CONTROL LINE TO STACK. HOLD.5000 PSI ON CL. REVERSE CIRC, T~S CAI~.:THRU SSSV FREELY. POOH. PICK UP 80KJ AND SET SL~S', R3~-N~ 2-5/8" CHRIS. CUTTER. CUT TUBING AT 7898' WI/q. I~A~2~X O~>TUBING S~FOR FISHING. POH. CIRC AND WORK ~,Tm~u sssv. n/~,w~ ~OLS., R/~ HLS. POOSW/ COMP DAZLY.: $t5,689 CUM: $117,062 ETD: $1~7, 062 E~C: $260,000 MN: 9.1 NaC1 POOH W/3~1/2~ BUTT COMP STRING, DRIFT MEAS & CIiR~E SEAL RINGS WHILE POH, LD CUTOFF STUBB, SET BO~L PROTECTOR, LOAD & TALLY~p$/4" DC, RU TO TIH, MU'OVERSHOT JARS & TIH, TAG W/FISH.-HANOZNGUP EVERY~FEMFT & JARRING UP HOLE. DAILY:$33,$15 CUM.:$~501577 ETD:e150,577 EFC:$260,000 AR3B-459-1-D INumbor MI daily well history fermi consecutively 80 ~oy ~ro prepared for each well Page no. Daily Well History--lnterin le~tl1~ctt~: Thie fomt il ul14 duH~ drilling or wor~ov~r ol~r~tions. If testing, coring, or peHorating, show formation name in describing work perfor~led. Number all drill stem taste slq~latlllly. AttlCll ~llcHption of all come. Work performed by Producing Section will be roported On "In.dm" sheets until final completion. Report official or ml~'tlllltlllel ~ orl "FiliI" for~. 1) Submit "lataHal" sheets when filled out but not le~s frequently then eve~ 30 days, or (2) on Wednesday o! the week in which ~tt ~ II ~ Submit weekly for workovers and following setting of oil strin; until completion. ARCO ALASKA INC. NORTH SLOPE AK /we"' Field Lea~e or Unit KUPARUK RIVER FIELD I ADL: 25639 AKL: 464 1-11H-~ Date and ~epth as of 8:00 &m. 10/19/90 ( TD: 0 PB: 8602 SUPV:GB Alas Oil & G s.ConS. 'Anchorage 10/20/90 ( -6) TD: 0 PB: 8602 SUPV:GB 10/21/90 ( 7) TD: 0 PB: 8602 SUPV:GB 10/22/90 (8) TD: 0 PB: 8602 SUPV:GB Complete record for each d~ while drilling or wor~var in pr~reu NORDIC MU HOWCO RBP MW: 9.1 NaCl JAR FISH OUT OF HOLE, LD TRISTATE TOOLS & FISH, RECOVERED CUT-OFF JT TBG, COLLAPSED GLM, PUP JT, i JT 3-1/2" TBG & SBR S&C DRILL LINE, RESET BOWL PROT, MU HOWCO RBP & PREP TO TIH · DAILY:$38,978 CUM:$189,555 ETD:SIS9,555 EFC:$260,000 REPAIR W/A VERTILOG MW: 9.1 NaC1 TIH W/ HOWCO RBP, SET AT 7929' DRILL PIPE MEASURE. TEST CSG TO 2000 PSI, LOST 1700 PSI, 7 MIN. RESET RBP AT 7939', TEST CSG TO 2000 PSI, LOST 1225 PSI, 15 MIN. RELEASE PRES., R/D TEST LINES, POOH AND L/D HOWCO RUNNING/SETTING TOOL. P/U BIT SCRAPER, TIH TO 7930'. REV. CIRC. HOLE, POOH L/D SCRAPERS. R/U WL. RIH W/ VERTILOG TOOL TO 500', TOOL MALFUNCTION, POOH W/ TOOL TO DETERMINE CAUSE OF MALFUNCTION. DAILY:S28,385 CUM:$217,940 ETD:S217,940 EFC:$260,000 RUNNING COMP STRING MW: 9.1 NaCl REPAIR W/A VERTILOG TOOL. TIH W/ VERTILOG, LOG 7924' TO 60'. R/D W/A AND R/U FLOW NIPPLE. P/U HOWCO PB RET TOOL AND TIH ON DP, LATCH ON TO HOWCO RBP AND SET 20,000# ON BP, TEST CSG TO 2000 PSI W/ 9.1 PPG BRINE FOR 30 MIN. LOST 40 PSI. TEST GOOD. RELEASE RBP, REV CIRC HOLE. POOH L/D DP AND DC. PULL BOWL PROTECTOR, R/U FLOOR TO RUN TUBING, P/U BAKER G SBR AND START RUNNING COMP STRING. DAILY:S60,746 CUM:$278,686 ETD:$278,686 EFC:$260,000 TESTING TUBING MW: 9.1 NaCl CONTINUE RIH W/ COMP STRING. SPACE OUT, LAND, RILDS. R/U & ~H W/ OTIS STANDING VALVE TO 8316'. TEST ANN TO 1000 PSI, ~EAK. TEST TUBING TO 1000 PSI, LEAK. RIH W/ OTIS "W" TEST TOOL, UNABLE TO GET THRU SSSV. POOH. RIH W/ COLLAR STOP, HUNG AT SSSV, POOH. RIH W/ 2.875" GAGE RING TO 8300'. POOH. RIH W/ TEST TOOL, HUNG AT SSSV, LOST TOOL AT SSSV. FISH TOOL FROM SSSV. RIH W/ 2.8" SWEDGE TO AVA SLEEVE. POOH, RIH W/ "W" TEST TOOL AND SET AT 7064'. PRESS TUBING TO 1000 PSI AND POOH W/ TOOL. RIH TO PULL STANDING VALVE, POOH W/ VALVE. DRESS VALVE AND RIH TO SET VALVE. TEST TUBING TO 1000 PSI. POOH W/ W.L. TEST TO 1000 PSI, LOST 300 PSI IN 3 MIN. DAILY:S28,147 CUM:$306,833 ETD:S306,833 EFC:$260,000 The above is correct Fo o 13 paration an!fLklis~ribution ."'~ see Procedures Manua~S%ction 10, ~ Drilling, Pages 86 and &Z./ AR3B-459-2-B INumber all daily well history forms consecutively as they are prepared for each well. IPage no Dally Well Histow-Final Report Illl~lUetWle: required upon operation if apace is District ARCO ALASKA Field KUPARUK RIVER FIELD I~er allowable his been reigned or well II Plu~ld. Abl~dM~td, or ~ld. for ~ In~flnite or Ipp~i~le I~ ~ fl~. ~ ~ ~ ~ ~clM ~ il n~ ~tl In bl~ pm~d. ~e "F~I ~' fo~ rely ~ u~ for m~di~ ~e ~tlm County or Parish NORTH SLOPE ILease or Unit ADL: 25639 ITItle IAccounting Stste AK co~t center code lWellno. Auth. or W.O. no. AK4761 Operator I A.R.Co. W.I. ~CO I 55. 9515 I Spudded or W.O. begun I Date and depth Complete record for each day reported aa of 8:00 a.m. NO[RDIC 10/23/90 ( TD: 0 PB: 8602 SUPV:GB 9) Iotal number of wells (active or inactive) on the% est center prior to plugging and / bandonment of this well our IPri°rStatus if a W.O. i RIG RELEASED MY: 0.0 TEST TUBING TO 1200 PSI. LOST 300 PSI IN 2.5 MIN. TEST TUBING TO 2000 PSI, LOST 100 PSI IN 30 MIN. R/D OTIS WL. TEST CAMCO SSSV, TEST GOOD, NO LEAK. L/D LANDING JT, SET N/D BOPE, N/U TREE. TEST PACK OFF SEALS, LEAK ON LOWER SEAL. TIGHTEN FLANGE AND RETEST TO 5000 PSI, LEAKS, FLANGE AND RETEST TO 5000 PSI. SEAL HOLDING, TEST TREE TO 250/5000 PSI. TEST PLUG, LEAK. PULL AND RESET T.P. TEST TREE TO 250/5000 PSI', TEST GOOD. PULL TEST PLUG. OPEN SSSV. DISPLACE WELL TO DIESEL, SITP - 600 PSI, SICP - 600 PSI. R/D CIRC LINES. SET BPV, SECURE WELL. PULL RIG OFF WELL, CLEAN UP AROUND WELL HEAD, RELEASE RIG AT 16:30 22-OCT-90. DAILY:S62,868 CUM:$369,701 ETD:S369,701 EFC:$260,000 RECEIVED DEC - 7 1990 A/asPca 0Jj & Gas C0ris, Commission Anchorage Old TD I New TD I PB Depth I I Released rig I Date I Kind ofrig I I Classifications (oil, gas, etc.) I Type completion (single, dual, etc.) I Producing method [Official reservoir name(a,,). Potential test data Well no. Date Reservoir Producing Interval Oil or gasTest time Production Oil on test Gas per day Pump size, SPM X length Choke eize ; T.P. C.P. Water % GOR Gravity Allowable Effective date corrected The above is correct For form preparation~w. ?~.u.. T.,~.u.dla~rlbutio., ~:~ / / ~ see Procedures' M'anu II/./~ectlon 10. Drilling, Pagee 86 and~7. AR3B-459-3-C lNumber all daily well history forms consecutively Page no. ee they are prepared for each well. I Obridmt M AtlantlcRIchflM(IComlwly APPLICATION FOR SUNDRY APPROVALS 1. Type of Request: Abandon _ Suspend _ Operation Shutdown _ Re-enter suspended well _ Alter casing _ Repair well ~ Plugging _ Time extension _ Stimulate _ Change approved program _ Pull tubing X Variance _ Perforate _ Other _ 6. Datum elevation (DF or KB) 2. Name of Operator ARCO Alaska. 3. Address P. O. Box 100360, Anchorage, AK 99510 5. Type of Well: Development Exploratory Stratigraphic Service 4. Location of well at surface 888' FNL, 781' FEL, Sec. 33, T12N, R10E, UM At top of productive interval 1310' FSL, 1505' FWL, Sec. 33, T12N, R10E, UM At effective depth 1267' FSL, 1366' FWL, Sec. 33, T12N, R10E, UM At total depth 1179' FSL, 1145' FWL, Sec. 33, T12N~ R10E, UM RKB 85' 7. Unit or Property name Kuparuk River Unit feet 8. Well number 1H-0l) 9. Permit number ~2-93 10. APl number 50-029-20763 11. Field/Pool Kuparuk River Field Kuparuk River Oil Pool 12. Present well condition summary Total Depth: measured 8 7 4 0' feet true vertical 6 8 0 9' feet Effective depth: measured 8 6 0 2' feet true vertical 6 6 9 6' feet Plugs (measured) Junk (measured) None ORIGINAL Casing Length Size Structural Conductor 7 8' I 6" Surface 2 2 5 5' 1 0 Intermediate Production 8 7 0 8' 7" Liner Perforation depth: measured 8442'-8472' !' 8092'-8107, true vertical 6565'-6589', 6286'-6298', Cemented Measured depth 3/4" 330 Sx AS II 1 1 0' 250 Sx AS Il& 2 2 8 7 1000 Sx ASIII 1191 Sx Class G 8740' & 250 Sx AS II 8426'-8432', 8137'-8152', 8122'-8137', 8252'8224' MD 6552'-6557', 6321'-6333', 6309'-6321', 6413'-6390' TVD Tubing (size, grade, and measured depth) 3-1/2" J-55 set at 8324' Packers and SSSV (type and measured depth) Brown lB @ 8303', Brown HB-1 @ 7966' & 8194', Camco TRDP-1A@ 1780' True vertical depth 78' 2210' 6809' 8107'-8122' MD 6298'-6309' TVD 13. Attachments Description summary of proposal _ Repair collapsed tubing Detailed operation program X.~ BOP sketch X_~ 14. Estimated date for commencing operatior~ August 7. 1~)0 16. If proposal was verbally approved Name of approver Date approved 15. Status of well classification as: Oil X Gas __ Service P r Q d u (;; e r Suspended 17. I here.b,,v./certify that the,,~regoing.is true and correct to the best of my knowledge. - ' / FOR ~MMI~IO~USE ONL~ Conditions of approval: Notify Commission so representative may witness Plug integrity ~ BOP Test_ Location clearance ~ Mechanical Integrity Test~ Subsequent form require 10-~/ !lAppr°val No~:~) ~'[O~} Approved by the order of the Commission Form 10-403 Rev 06/15/88 Kuparuk River Unit Well 1 H-8 Preliminary Workover Procedure' Pre-Rig Operations 1. Obtain downhole BHP. (Offset BHP is 2630 psi at 6200' SS or 8.1 ppg EMW) 2. Pull bottom GLV at 7895' and leave pocket open. Dummy all other GLMs. Rig Operations 1. . e . MIRU Nordic #1. Displace tubing and annulus with 8.5 ppg seawater. necessary. Set BPV, ND tree, NU BOPs. Pull BPV and test BOPs. Pump Lite-sal kill pill if Pull 3-1/2" tubing above top Brown HB-1 packer at 7966'. (Baker SBR was sheared during completion in Dec 1985.) Tubing is collapsed at 7935' WLM (just below bottom GLM) and may not all be pulled on first attempt. Inspect and replace tubing and GLMs as necessary. ,,,~. . . Rerun 3-1/2" single completion and locate back into SBR above HB-1 packer. ND BOPs, NU tree. Reverse circulate brine from annulus and tubing with diesel. Set BPV. 8. RD, release rig. Pull BPV. PSI BOP STA(CK I I I I I i 2 , 3 1. 10-3/4" CASING HEAD 11"-3000 PSI FLANGE 2. 11" - 3000 PSI X 7 1/6" - 5000 PSI TUBING HEAD 3. 7 1/6" - 5000 PSI X 11" - 5000 PSI CROSS-OVER SPOOL 4. 11" -5000 PSI BLIND RAMS 5. 11" -5000 PSI PIPE RAMS 6. 11" -5000 PSI ANNULAR ACCUMULATOR CAPACITY TEST 1 · CHECK AND FILL ACCUMULATOR RESERVOIR TO PROPER LEVEL WITH HYDRAULIC FLUID. 2. ASSURE THAT ACCUMULATOR PRESSURE IS 3000 PSI WITH 1500 PSI DOWNSTREAM OF THE REGULATOR. 3. OBSERVE TIME, THEN CLOSE ALL UNITS SIMULTANEOUSLY AND RECORD THE TIME AND PRESSURE REMAINING AFTER ALL UNITS ARE CLOSED WITH CHARGING PUMP OFF. 4. RECORD ON THE IADC REPORT. THE ACCEPTABLE LOWER LIMIT IS 45 SECONDS CLOSING TIME AND 1200 PSI REMAINING PRESSURE. BOP STACK TEST FILL BOP STACK AND MANIFOLD WITH BRINE. CHECK THAT ALL HOLD-DOWN SCREWS ARE FULLY RETRACTED. PREDETERMINE DEPTH THAT TEST PLUG WILL SEAT AND SEAT IN WELLHEAD. RUN IN LOCK-DOWN SCREWS IN HEAD. CLOSE ANNULAR PREVENTER AND CHOKES AND BYPASS VALVES ON THE MANIFOLD. TEST ALL COMPONENTS TO 250 PSI AND HOLD FOR 10 MINUTES. INCREASE PRESSURE TO 3000 PSI AND HOLD FOR 10 MINUTES. BLEED TO ZERO PSI. 5. OPEN ANNULAR PREVENTER AND CLOSE PIPE RAMS. 6. INCREASE PRESSURE TO 3000 PSI AND HOLD FOR 10 MINUTES. 7. CLOSE VALVES DIRECTLY UPSTREAM OF CHOKES. BLEED DOWNSTREAM PRESSURE TO ZERO PSI TO TEST VALVES. TEST REMAINING UNTESTED MANIFOLD VALVES, IF ANY, WITH 3000 PSI UPSTREAM OF VALVE AND WITH ZERO PSI DOWNSTREAM. BLEED SYSTEM TO ZERO PSI. 8. OPEN PIPE RAMS. BACKOFF RUNNING JOINT AND PULL OUT OF HOLE. 9. CLOSE BLIND RAMS AND TEST TO 3000 PSI FOR 10 MINUTES. BLEED TO ZERO PSI. 1 0. OPEN BLIND RAMS AND RECOVER TEST PLUG. MAKE SURE MANIFOLD AND LINES ARE FULL OF BRINE AND ALL VALVES ARE SET IN THE DRILLING POSITION. 1 1 . TEST STANDPIPE VALVES TO 3000 PSI. 12. TEST KELLY COCKS AND INSIDE BOP TO 3000 PSI WITH KOOMEY PUMP. 13. RECORD TEST INFORMATION ON BLOWOUT PREVENTER TEST FORM. 14. SIGN AND SEND TO DRILLING SUPERVISOR. 15. PERFORM COMPLETE BOPE TEST ONCE A WEEK AND FUNCTIONALLY OPERATE BOPE DAILY. NORDIC SRE 9/89 .~.RCO Alaska. It Post Office Box 100360 Anchorage. Alaska 99510-0360 Telephone 907 276 1215 RETURN TO: ARCO ALASKA, INC. ATTN: Kuparuk Records Clerk ATO 1119 P. O. Box 100360 Anchorage AK 99510-0360 DATE 09-15- 86 TRANSMITTAL # 5761 Transmitted herewith are the following items. Please acknowledge receipt and return one signed copy of this transmittal. Final Prints: Schl: CET or CBL Logs: One * of each lA-7 12-03-85 Run #3 7585-8532 lA-14 .12-05-G5 Run #1 4550-4850 1H-4 12-26-85 Run #2 6893-7466 1H-8 12-08-86 Run #3 7875-8368 1H-8 12-09-86 Run #4 7850-8450 lQ-9 01-28-85 Run #1 4898-6534 lQ-13 06-02-85 Run #1 5300-7621 2C-16 02-19-85 Run #1 7200-8294 2E-9 01-14-85. Run #1 6780-8052 2E-15 01-12-85 Run #1 3350-6874 2E-16 01-12-85 Run #1 4840-7578 2H-10 12-05-85 Run #1 6500-7863 3A-7 11-04-85 Run #1 5726-7164 3A-11 12-15-85 Run #1 5796-7206 3A-12 12-16-85 Run #1 6426-7768 3A-13 12-29-85 Run #2 5644-7482 3A-14 12-29-85 Run #2 5462-7744 3C-13 10-30-85 Run #1 7075-9474 3F-5 11-13-85 Run #1 6947-8647 3F-6 11-13-85 Run #1 4600-7570 3F-9 12-19-85 Run #1 6188-7490 3J-5 12-22-85 Run #1 7000-8636 Receipt Acknowledged: Vault*films ~ NSK Files*bl ARCO Alaska. Inc. ~s · Sublidiary of AlllnticRichfiel(~CompanY ATTACHMENT II Drill Site lA Well No. 1A-4 1A-5 1A-7 1A-9 1A-11 1A-12 1A-14 1A-15 1A-16A KUPARUK RIVER UNIT Production Logs FEBRUARY 19, 1986 Log Date Drill Site Well No. Lo9 Date 716/83 10/29/83 2/8/82 517/82 1/25/82 3/23/83 1/19/83 3/21/83 3/8/82 4/1/82 6/5/82 5/11/82 6/8/82 lB 1B-1 12/26/81 1B-2 6/25/81 lB-3 11/16-18/81 3/12/82 1B-6 11/18/81 9/10/82 1B-7 11/23/81 1B-8 12/28/81 8/4/82 1B-9 6/24/82 8/3/84 Drill Site We m ii lC 11 No. 1C-1 1C-2 lC-3 1C-4 1C-5 1C-6 1C-7 lC-8' Log Date 5/9/81 5/8/81 7/13/81 11/8/81 3/9/81 2/26/81 11/30/81 5/19/81 5/21/81 Drill Site Well No. Log Date 1D 1D-1 · 1/80 5~23/83 1D-3 8/5/80 1D-4 7~30/80 8/13/80 1D-5 6/11/81 1D-6 6/9/81 1D-7 6/8/81 (WS-8) 5110178 Oil & rms co,,~. ,. ....... Attachment Page 2 Drill Site 1H Well No. Log Date 1H-3 8/16/82 1H-4 8/13/82 1H-6 6/21/82 1H-7 7/20/82 7/22/82 Drill Site Well No. Lo9 Date Drill Site 1E Wel 1 No. 1E-lA 1E-2 1E-3 1E-4 1E-5 1E-6 1E-7 1E-8 1E-12 1E-15 1E-16 1E-17 1E-20 1E-24 1E-25 1E-26 1E-27 1E-28 1E-29 1E-30 Log Date 8/19/81 8/17/81 1/17/84 10/18/81 11/7/81 8/4/80 9/2/81 11/5/81 10/27/81 10/21/81 11/12/82 10/28/81 8/28/81 11/1/81 !1/28/84 8/26/82 8/29/82 9/1/82 5/7/83 2/17/83 1/17/83 1/13/83 10/31/82 10/27/82 6/13/83 10/18/82 7/18/83 10/16/82 Drill Site 1G Well No. Lo9 Date 1G-1 1G-2 1G-3 1G-4 1G-5 1G-7 1G-8 Drill Site Well No. 9/7/82 9/25/82 9/28/82 i2/8/84 10/13/82 11/12/82 1F 1F-1 1F-2 1F-3 1F-4 1F-5 1F-6 3/!2/83 C.6'i V.-F Ih - ~ MA~0198~ Alaska Oil & Gas Cons. Commi::::~ Arm_.hor2~e 1F-7 Log Date 2/19/83 2/3/83 1/31/83 5/29/83 10/25/82 !0/28/82 11/19/82 5/7/83 Attach.ment Page Drill Site 1Y Wel 1 No. Log Date 1Y-1 6/6/83 10/21/83 1Y-2 6/10/83 3/4/84 6/18/83 1Y-47/2/83 1Y-56/29/83 1Y-66/27/83 1Y-86/22/83 1Y-96/20/83 511o183 ~. 11/21/83 1Y-12 5/25/83 1Y-13 5/27/83 zY- 4 5/ 3/83 5/18/83 1Y-15 5/29/83 1Y-16 5/30/83 10/23/83 Drill Site 2C Wel 1 No. Log Date 2C-4 2/19/85 2/28/85 2C-7 10/15/84 Drill Site Well No. Log Date 2Z' t~~l~/10 / 83 2Z-2 '" 6/24/83 7/19/83 2Z-3 ' 8/5/83 2Z-4 7/12/83 2Z-6 7/27/83 2Z-7 7/28/83 2Z-8 8/3/83 v~,. F: pg: 0052 A,'~chorage II Wel 1 No. ~lH-3 ~1H-4 %1H-7 ~1H-8 Log Date 8/16/82 8/13/82 6/21/82 7/20/82 7/22/82 Drill Site Well No. Log Date 1E 1E-lA ~/19/81 1E-2 ~8/17/81'-~ _'~1/17/84/ 1E-3 "10/18/81~,,. ~11/7/81,/ "','8/4/80"~ 1E-5 %10/27/81 1E-6 ~10/21/81~ ~/z2/8~/ ~1E-7 ,~/28/81~ ~10/28/81~ 1E-8 ' 8/28/8~ - ~11/1/8 1E-12 ~11/28/84 1E-15 ~/26/82 1E-16 ~/29/82 1E-17 ~9/1/82 1E-20 ~5/7/83 .1E-24 ~/17/83 1E-25 ~1/17/83 1E-26 ~1/13/83 1E-27 ~0/31/82 1E'28 ~10/27/82 ~ ~6/13/83 1E-29 ~10/18/82~ ~7/18/83 / IE-30 ~0/16/82 Drill Site 1G Well No. '%1G-1 ~,~1G-2 "~1G-3 '~1G-4 '~4G-5 %1G-8 Log Date 9/7/82 '9/25/82~,,, 9/28/82 12/8/84/ 10/13/82 11/12/82 3/12/83 1/22/83 Drill Site Well No. Log Date 1F 1F-1 2/19/83 1F-2 2/3/83 ~F-3 1/31/83 ~'1F-4 5/29/83 %1F-5 10/25/82 '~1F-6 10/28/82 '~ 1F-7 11/19/82x., ~ 5/7/83..Y ~'~ R ECEiVi "/. FEB 2 1 1986 AJaska 011 & Gas bns. C~mmlssion Anchorage Alas nc. Postf:')ffice B 00360 An~' orage, Alaska 99510-0360 phone 907 276 1215 February 14, 1986 Mr. C. V. Chatterton Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 SUBJECT: Well Completion Reports Dear Mr. Chatterton' Enclosed are the Well Completion Report for the following wells: 3J-2 3J-3 1H-8 If you have any questions, please call me at 263-4944. Sincerely, Gruber Associate Engineer JG/tw GRU13/L127 Enclosures 1 Alaska Oil & Gas Cons. Ou,,l~ission Anchorage ARCO Alaska, Inc. Is a Subsidiary of AllanticRichfieldCompany 'L WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1. Status of Well Classification of Service Well OIL [~X GAS [] SUSPENDED [] ABANDONED [] SERVICE [] 2. Name of Operator , ~ 7. Permit Number ARCO Alaska, Inc. 82-93 3. Address 8. APl Number P. O. Box 100360~ Anchoracje~ AK 99510 50- 029-20763 4. Location of well at surface 9. Unit or Lease Name 888' FNL, 781' FEL, Sec.33, T12N, R10E, UM Kuparuk River Unit At Top Producing Interval 10. Well Number 1310' FSL, 1505' FWL, Sec.33, T12N, R10E, UM 1H-8 At Total Depth 11. Field and Pool 1179' FSL, 1145' FWL, Sec.33, T12N, R10E, UM Kuparuk River Field 5. Elevation in feet (indicate KB, DF, etc.) 6. Lease Designation and Serial No. Kuparuk River 0i 1 Pool 85' RKB ADL 25639 ALK 464 12. Date Spudded 13. Date T.D. Reached 14. Date Comp., Susp. or Aband. I 15. Water Depth, if offshore 16. No. of Completions 06/17/82 06/25/82 07/07/82*I N/A feet MS L 1 17. Total Depth (MD+TVD) 18. Plug Back Depth (MD+TVD) 19. DirectionalSurvey I 20. Depth where SSSV set I 21. Thickness of Permafrost 8740 'MD ,6809 'TVD 8602 'MD ,6696 'TVD YESx~( NO [] 1780 feet MD 1900' (Ap?ox) 22. Type Electric or Other Logs Run DIL/FDC/CNL, RFT, CCL/CBL/VDL/GR, CET, Gyro, CET 23. CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD CASING SIZE WT. PER FT. GRADE TOP BOTTOM HOLE SIZE CEMENTING RECORD AMOUNT PULLED 1¢;" 65_5# H-40 Surf 78' 2~.'' 330 sx AS II ln-3/4,, 45.5# K-55 S,-rf 2255' !3-!/2' !000 s× AS Perfermed rep ?" 26,0# L-80/K-."5 5~0' 8708' 8-3/~.'' !19! sx C!ess G & 250 '.-× AS II 24. Perforations open to Production (MD+TVD of Top and Bottom and 25. TUBING RECORD interval, size and number) SIZE DEPTH SET (MD) PACKER SET (MD) 8842' - 8472' w/4 spf 8252' - 8224' w/12 spf, ~-~/~,, ~.., ~o~,-, ~o~., ~n~, 120° phasing 8426' - 8432' 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. 8137' - 8152' DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED 8122' - 8137' w/8 spf ,,,-,.,,°"~' _ ,,,.,.~G~"' ~nn.,,,, ,,,,~" ,,.~" a,s$ C 8107' - 8122' °~'~"' 8092' - 8107' 27. N/A PRODUCTION TEST Date First Production Method of Operation (Flowing, gas lift, etc.) Date of Test Hours Tested PRODUCTION FOR OIL-BBL GAS-MCF WATER-BBL CHOKE SIZE GAS-OIL RATIO TEST PERIOD Flow Tubing Casing Pressure CALCULATED,,,k OIL-BBL GAS-MCF WATER-BBL OIL GRAVITY-APl (corr) Press. 24-HOUR RATE ,,, 28. CORE DATA Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water. Submit core chips. Form 10-407 * NOTE: Wel 1 was recompleted 12/12/85. TEMP3/WC79 Submit in duplicate Rev. 7-1-80 CONTINUED ON REVERSE SIDE 29. GEOLOGIC MAR KF~R'S NAME Top Upper Sand Base Upper Sand Top Lower Sand Base Lower Sand MEAS. DEPTH 8091' 8251' 8415' 8537' TRUE VERT. DEPTH 6286' 6412' 6544' 6643' 30. FORMATION TESTS Include interval tested, pressure data, all fluids recovered and gravity, GOR, and time of each phase. Press. Test Depth Press. Build-up Time #1 3457' 1426 psi I minute 31. LIST OF ATTACHMENTS 32. I hereby certity that tne foregoing is true and correct to the best of my knowledge INSTRUCTIONS General: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. Item 1: Classification of Service Wells: Gas injection, water injection, steam injection, air injection, salt water disposal, water supply for injection, observation, injection for in-situ combustion. Item 5: Indicate which elevation is used as reference (where not otherwise shown) for depth measurements given in other spaces on this form and in any attachments. Item 16 and 24: If this well is completed for separate production from more than one interval (multiple completion), so state in item 16, and in item 24 show the producing intervals for only the interval reported in item 27. Submit..a separate form for each additional interval to be separately produced, showing the data pertinent to such interval. Item 21: Indicate whether from ground level (GL) or other elevation (DF, KB, etc.). Item 23: Attached supplemental records for this well should show the details of any multiple stage cement- ing and the location of the cementing tool. Item 27: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water In- jection, Gas Injection, Shut-in, Other-explain. Item 28: If no cores taken, indicate "none" Form 10-407 Ati'anticRiChfieldComPany ,- Daily' Well History-Initial Report Inalmetio~m-. Prap~re and submit the "Initial Revert" on the first Wednesday after a well Is spudded or work@var operations are started. Daily work prior to Spudding should be summarized on the form giving inclusive dates only. District I County or Parish Alaska Field ~ Lease or Unit Kuparuk Rlver Auth. or W.O. no. JTitie I AFE AK0561 Pool 102 Opermor ARCO Alaska, Inc. S~dd*d o. W.O. ~..- Ieste Worko~er I 12102185. 12/03/85 12/04/85 12/05/85 12/06/85 12/07/85 thru - 12/o9/85 North Slope Borough ADL 25639 Recompletton JState APl 50-029-20763 Complete mgord for each day reported I A.R.Co's W.I. IH@ur IPrior ~t~tua if a W.O. 11/30/85 1600 hrs, 56.24~ 8602' PBTD, POH w/tb8 & ch8 out collars 10.2+ NaCl/NaBr Accept rig @ 1600 hrs, 11/30/85. RU to kill well. Pull dum~. @ 7881'. Bullhead Brtdgesal pill dn tbs, ctra out ann diesel. Dtspl well, C&C brine. ND ~ree, NU & Cst BOPR~ Unseat tbs & pull tb8 & ch8 out collars to BTC AB Mod. 7" @ 8708' 8602' PBTD, CBU 10.2+ NaCl/NaBr POH, chg out collars on tbs. CBU, prep to latch onto pkr. RIH w/retrv'$ tl on DP to 7900' 7" @ 8708' 8602' PBTD, CBU 10.1+ NaCl/NaBr Ctrc, wsh over & latch pkr. Re1 EB-1 pkr, ctrc out gas bubble, POH, LD pkr & tailpipe. RU S/L, attempt to rec fsh w/o success, RD S/L. HUwsh pipe, RIH, wsh & tag PBTD @ 8606' DPM, circ. Alaska Well no. 1H-8 7" @ 8708' 8587' TOF, Prep to sqz 10.2 ppg NaCl/NaBr TOH, LD fsh ~2 + shear out sub. RU DA, rn 6.125" gage ring/JB to 8550'. RIH, set BP @ 8376' NLM. RU & perf 8364"-8366' w/4" gun, 4 SPF, 90° phasing. RIH, set EZSV recur @ 8165' NLM,~..P~.. DA. M&P 31 bbls C1 "G" cmt w/.3% D-31, .8% D-28 & .1% ~26~'7i~,.~.. .~ ~ i V~ ~!:i~i w/final press of 3000 psi. CIP @ 0500 hfs, 12/5/85. Rev Ei~c~ DP. 7" @ 8708' 8587' TOF, POOH A!aska 0il & Mas Co~s. 10.2 ppg NaC1/NaBr __~ Fin rev out, POH, LD cmt stinger. PU retry BP, RIH & set @ ' 8009'. Attempt to Cst BP, .would not Cst. POOH, no BP. RIH 27 stds, tag & engage BP, POOH, LD same. PU Bkr pkr-type BP, RIH to 4000' & set. Tst to 1500 psi. POOH w/setting Cl. 7" @ 8708' 8587' TOF, CBU 10.2 ppg NaCl/NaBr TOH, ND stack, chg out wellhead equip Co 5000#, NU & cst BOPE. TIH, engage BP, fin TIH to 800', Cst csg to 3500 psi, TOH. TIH, drl upper cmt recur &cmt, TOH. TIH w/R-3 pkr, set @ 8200'. Tst sqz perfs; OK, TOH. Rn CET log. TIH, DO lower retnr, wsh to PBTD @ 8587', CBU. The above is correct For form preparation and (~stribution, see Procedures Manual, Section 10, Drilling, Pages 86 and 87. Drilling Superintendent :, ~' AR~co Oil and Gas comPany Daily Well History-Final Report Inltnlctionl: Prepare and spbmit the "Final Report" on the first Wednesday after allowable has been assigned or well is Plugged, Abandoned, or Sold. "Final Report" should be submitted also when operations are suspended for an indefinite or appreciable length of time. On .workovers when an official test is not required upon completion, report completion and representative test data in blocks provided. The "Final Report" form may be used for reporting the entire operation if space is available. District ICounty Or Parish I Alaska Field ~Lease or Unit Kuparuk River Auth. or W.O. no. ITitle AF~. AK0561 I North Slope Borough ADL 25639 Recompletion IAccounting State cost center code Alaska Well no. 1It-8 Pool 102 AP1 50-029-20763 Operator ]A.R.Co. W.I. Al[CO Alaska, Inc. 56.24% Spudded or W.O. begun [Date Workover I 11 / 30/85 otal number of wells (active or inactive) on this, DSt center prior to plugging and / bandonment of this well /[H°ur 1600hrso I Prlor status if a w.o. Date and del)th as of 8:00 a.m. 12/lO/85 12/11/85 12/12/85 12/13/85 Complete record for each day reported ~" @ 8708' 8591' TOP, RU DA 10.2 ppg NaCl/NaBr CBU, cond brine, POH. RU Schl, rn CET lo$, RD Schl. scrpr, .TOH & LD DP. NU shooting flange, RU DA. TIH w/csg 7" @ 8708' 8591''TOP, Prep f/triple pkr compl 10.2 ppg NaCl/NaBr Perf w/5" guns f/8224'-8252'. Make gage ring/JB rn to 8500'. RD DA. MU jewelry f/triple pkr, single selective compl. 7" @ 8708' 8591' TOE, 8602' PBTD, NU tree 10.2 ppg NaCl/NaBr RIH w/263 its, 3½", 9.2#, J-55 AB Mod BTC tbg & lnd w/SSSV @ 1780', 1-B pkr @ 8303'. Set pkr. NU BOPE. Prep to NU tree. 7" @ 8708' 8591' TOF, 8602' PBTD, RR Diesel in tbg & ann NU & Cst tree. Displ well to diesel. Set BPV. RR B 1700.hfs, 12/12/85. Moving rig to PUD. Note: SSSV @ 1780', HB-1 pkr @ 7966' & 8194', lB pkr @ 8303', TT @ 8324'. O1(~ TD New TO Released rig Date 1700 hrs. Classifications (oil, gas, etc.) Oil I PB Depth 12/12/85 [Kind of rig Type completion (single, dual, etc.) Single Producing. method Official reservoir name(s) Flowing. Kuparuk Sands Potential test data 8602,' PBTD Rotary Well no. Date Reservoir Producing Interval Oil or gas Test time Production · Oil on test Gas per day Pump size, gPM X length Choke size T.P. C.P. Water % GOR Gravity Allowable Effective date corrected The above is correct Signature I Date ITitle For form preparation and dfstributton, see Procedures Manual, Section 10, Drilling, Pages 86 an~l 87. Drilling Superintendent ARCO Alaska, Inc./ Post Office B~. ~00360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 January 30, 1986 Mr. C. V. Chatterton Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK '99501 SUBJECT' Subsequent Sundry Reports Dear Mr. Chatterton: Enclosed are Subsequent Sundry Reports for the following wells' 1A-7 If you have any questions, please call me at 263-4944. Sincerely, Gruber Associate Engineer JG/tw GRU13/L43 Enclosures RECEIVED Anchor3ge ARCO Alaska, Inc. is a Subsidiary of AllanticRichfieldCompany (~' STATE OF ALASKA O(MM ALASKA OIL AND GAS CONSERVATION C ' ISSION SUNDRY NOTICES AND REPORTS ON WELLS DRILLING WELL [] COMPLETED WE LLx~ OTHER [] 2. Name of Operator ARCO Alaska, Inc. 3. Address P. 0. Box 100360, Anchorage, AK 99510-0360 4. Location of Well Surface.. 888' FNL, 781' FEL, Sec.33, T12N, R10E, ~ 5. Elevation in feet (indicate KB, DF, etc.) RKB 85 ' 12. 6. Lease Designation and Serial No. ADL 2~;-~c) Al K ~,~_ 7. Permit No. 82-93 8. APl Number 50- 029-20763 9. Unit or Lease Name Kupar'uk River Ilni~- 10. Well Number 1H-8 11. Field and Pool Kuparuk River Field ~-.~_Kup~Jl~ River Oil Pool Check Appropriate Box To Indicate Nature of Notice, Report, or Other Data NOTICE OF INTENTION TO: (Submit in Triplicate) Perforate [] Alter Casing [] Perforations Stimulate [] Abandon [] Stimulation Repair Well [] Change Plans [] Repairs Made Pull Tubing [] Other [] Pulling Tubing (Note: Report multiple completions on Form 10-407 with a submitted Form 10-407 for each completion.) SUBSEQUENT REPORT OF: (Submit in Duplicate) [] Altering Casing [] Abandonment Other 13. Describe Proposed or Completed Operations (Clearly state all pertinent details and give pertinent dates, including estimated date of starting any proposed work, for Abandonment see 20 AAC 25.105-170). Accepted rig ~ 1600 hfs, 11/30/85. Killed well, ND tree. NU BOPE & tested. Pulled 3-1/2" tubing. Recovered pkr & tailpipe. Attempted to recover wireline fish (TOF ~ 8591'). Perf'd f/836/+' - 8366'. Squeezed w/150 sx Class G. Tested csg to 3500 psi - ok. Tested squeeze perfs to 1/+00 psi - ok. Ran CRT. Perf'd the following interval w/12 spf, 120° phasing= 8252' - 822/+' Set W/L pkr ~ 8303'WLM. Ran 3-1/2" completion assy w/SSSV ~ 1780~, pkrs (~ 8303', 819/+' & 7966'~ & tail (~ 832/+'. Set pkrs. Tested tbg. ND BOPE. NU tree & ts'cd to 5000 psi - ok. Displaced tbg & annulus w/diesel Set BPV. Secured well & released rig (~ 1700 hfs, 12/12/85. 14. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed (~~ ~ . Title Associate Engineer The space bel~/~v for Commission use V Date Conditions of Approval, if any: By Order of Approved by COMMISSIONER the Commission Date Form 10-403 Rev. 7-1-80 GRU13/SN03 Submit "Intentions" in Triplicate and "Subsequent Reports" in Duplicate ARCO Alaska, InC. B(~ Post Office 100360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 January 14, 1986 Mr. C. V. Chatterton Commissioner State of Alaska Alaska Oil & Gas Conservation Commi ss ion 3001 Porcupine Drive Anchorage, AK 99501 SUBJECT: State Reports Dear Mr. Chatterton' Enclosed are the December monthly reports for the following wells- 1A-7 2H-6 3A-13 3F-12 3J-11 4-29 L2-29 1A-13 2H-7 3A-14 3F-13 3J-12 16-15 L3-5 1A-14 2H-8 3A-15 3F-14 4-23 16-19 L3-19 1H-4 2H-9 3A-16 3F-15 4-24 16-20 LB- 15 2X-8 3F-11 3J-10 4-27 L2-21 If you have any questions, please call me at 263-4944. Sincerely, Gruber Associate Engineer JG/tw GRU13/L05 Enclosures RECEIVED JAN 1 4 1986 Oil & Gas Cons. Uommis,s/on AB S -'2" A!aska. Inc. is a Subsidiary of AtlanticRichfieldCompany STATE OF ALASKA , ALASKA O~L AND GAS CONSERVATION CO~..,ISSION MONTHLY REPORT OF DRILLING AND WORKOVER OPERATIONS 1. Drilling well [] Workover operatio~iTt~] 2. Name of operator 7. Permit No. ARCO A1 aska, I nc. 82-93 3. Address 8. APl Number P. 0. Box 100360, Anchorage, AK 99510 50- 029-20763 4. Location of Well at surface 888' FNL, 781' FEL, Sec.33, T12N, RIOE, UM 5. Elevation in feet (indicate KB, DF, etc.) 85 ' RKB 6. Lease Designation and Serial No. ADL 25639 ALK 464 9. Unit or Lease Name Kuparuk River Unit 10. Well No. 1H-8 11. Field and Pool Kuparuk River Field Kuparuk River Oil Pool For the Month of December , 19 85 12. Depth at end of month, footage drilled, fishing jobs, directional drilling problems, spud date, remarks Accepted rig ~ 1600 hfs, 11/30/85. Killed well. Displaced well w/NaBr/NaCl. ND tree. NU BOPE & tstd. Pulled 3-1/2" tbg. Unable to recover wireline fish. Top of fish @ 8591'. Perf'd f/8364' - 8366', squeezed w/151 sx Class "G" cmt, & tstd. Ran CET log. Perf'd well. Set lB pkr & ran 3-1/2" completion assy. ND BOPE. NU tree & tstd. Displaced well to diesel. Secured well & RR @ 1700 hrs, 12/12/85. 13. Casing or liner rgn and quantities of cement, results of pressure tests 3-1/2", 9.2#/ft, J-55, BTC tbg. S$$V 8 1780' HB-1 pkr @ 7966' lB pkr ~ 8303'~ TT @ 8324' 14. Coring resume and brief description None 15. Logs run and depth where run CET - depth not available 1 6. DST data, perforating data, shows of H2S, miscellaneous data 8252' - 8224' w/12 spf, 120° phasing RECEIVED JAN ! 4 l~t85 Ajaska Oil & 6as Cons, comm~ 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. SIGNED /¢ ~ ~4 ~~~ TITLE Associate Engineer DATE /I NOTE--ReporfCon this form is required for each calendar month, regardless of the status of operations, and must be filed in duplicate with the Alaska Oil and Gas Conservation Commission by the 15th of the succeeding month, unless otherwise directed. Form 10-404 TEMP/MR03 Rev. 7-1-80 Submit in duplicate ARCO Alaska, InC. l~,. Post Office .. 360 Anchorage, Alaska 99510 Telephone 907 277 5637 November 21, 1985 Mr. C. V. Chatterton Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK. 99501 SUBJECT: 1H-8 Dear Mr. Chatterton: Enclosed is a Sundry Notice for the subject well. We propose to convert well 1H-8 to a selective single completion. Since we expect to start this work on November ~, 1985, your earliest approval will be appreciated. If you have any questions, please call me at 263-4944 or Jeff Quintana at 263-4620. Sincerely, J. Gruber Associate Engineer SN/Letter076 Enclosure ARCO Alaska, Inc. is a subsidiary of AtlanticRichfieldCompany SUNDRY NOTICES AND REPORTS ON WELLS 1. DRILLING WELL [] COMPLETED WELL;Q OTHER [] 2. Name of Operator 7. Permit No. ARCO Alaska, Inc. 82-93 3. Address 8. APl Number P. 0. Box 100360, Anchorage, AK 99510 50- 029-20763 4. Location of Well Surface: 888~ FNL, 781~ FEL, Sec.33, T12N, R10E, UN 5. Elevationinfeet(indicate KB, DF, etc.) RKB 85' 6. Lease Designation and SerialNo. ADL 25639 ALK 464 9. Unit or Lease Name .. Kuparuk River Unit 10. Well Number 1H-8 11. Field and Pool Kuparuk River Field Kuparuk River 0il Pool 12. Check Appropriate Box To Indicate Nature of Notice, Report, or Other Data NOTICE OF INTENTION TO: (Submit in Triplicate) Perforate [] Alter Casing [] Perforations 1~ Abandon [] Stimulation Stimulate Repair Well ~ Change Plans [] Repairs Made Pull Tubing ~, Other ~,, Pulling Tubing (Note: Report multiple completions on Form 10-407 with a submitted Form 10-407 for each completion.) SUBSEQUENT REPORT OF: (Submit in Duplicate) [] Altering Casing [] Abandonment [] Other [] [] [] 13, Describe Proposed or Completed Operations (Clearly state all pertinent details and give pertinent dates, including estimated date of starting any proposed work, for Abandonment see 20 AAC 25.105-170). ARCO Alaska, Inc., proposes to convert well 1H-8 to a selective single completion. The procedure will be as follows: 1. Well will be killed with brine. 2. Current completion assembly will be pulled. 3. A retrievable packer will be run to test casing. 4. The well will be completed as a selective singlexU.~/A/(~ ~"~JP,~E 5, After the rig is released, an acid and/or frac job will be done, A 13-5/8', 5000 psi, SRRA BOP stack will be used on well work. BOP equipment will be tested weekly and operationally'~ested each trip. A non-freezing fluid will be left in all uncemented annuli within the permafrost interval. A 5000 psi WP wireline lubricator will be used and tested on all wireline work. The subsurface safety valve will be installed and tested upon conclusion of the job. Estimated Start: November~, 1985 NOV 2 1985 Alaska Oil & Anchorage. 14. I hereby certify that the foregoing is true and correct to the best of my knowledge. i,,e The space below~or Commission use Conditions of Approval, if any: Approved by COMMISSIONER Approved Cof3y ,~teturr),KI .... By Order of the Commission Form 10-403 (JL0) SN/112 Rev. 7-1-80 Submit "Intentions" in TriPlicate and "Subsequent Reports" in Duplicate ARCO Alaska, In~ Post Office E, vx 100360 Anchorage, Alaska 99510 Telephone 907 276 1215 March 7, 1984 Mrs. Elaine Johnson State of Alaska Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 SUBJECT: Conductor As-Built Location Wells 1-8 Dear Elaine- Enclosed is an as-built location plat If you have any questions, please call Sincerely, Plat - 1H-Pad for the subject wells. me at 263-4944. Gruber Associate Engineer JG6/L20:tw Enclosure ARCO Alaska, Inc. is a Subsidiary of AtlanticRichfieldCompany lB, NOTES PROTRACTED SECTION CO~N'R. FUTURE WELL LOCATIONS. PERMANENT SURVEY LDCATION MONUMENTS. EXIST~G WELLHE~ F~HD THiS AS~)LT S~T ELEVATI~. PAD DIMENSIONS ~WN AgE MEA~S TAKEN AS- ~ILT SURVEY ATIONS TAKEN FgM AI~BUILT SURVEY ~TES. ELEVATIONS AN[ ~SED ~ 1~10-~ vERTICAL DATUM. J~ C~DINATES ~N ~E ~ASKA STATE C~D~NATE S~TEM, ZONE 4. P~OTRACTION ~vSTEM, TH( (NTI~E AREA LIES ALL AZI~TH WN AN[ ALASKA STATE ~AN[ GRID AZI~H ALL DISTANC~ ~N A~[ T~ I ~..~]~'~o,,~ .............. ~ . K~MiT~_~M[T~_~ _ _~[~S~[~;'~ i-~[ '~.' =;~ A "- [ ...... . . '-- I N' S,9~I,~.440 I '4t~L ~[m CENT~ATE CONDUCTOR HOLE LOCATIONS WITHIN SECTION ~' kg. I LAIITUbE , LONGIT~E ~LNI XIEI · ,-, ,-, i '~ ,o-,',o.~q ,--~' ~,.,,' ,.,,,.,,,.~o ~.,.,,o,o '" I i AS-BUILT ~',o.,,.,.,.~ ,~.-~k..' ~" I I DRILL SITE"I'H" ~'°'"'"'":1'~;"~'"";"' '" I "~' I ' I 7~' ~i' ~5~"1 ',.i~' ~.~,' ~5~I miq} ARCO Amosko, Inc.) I I A~CTIC ~VEYI~, IK. II " "~'" l I°"' ....... "' I"": "'" eMI Ii ~ ~ ~[[I I ~ I 'l' 'l NSK-3,Z.~-~il I _ SW Coil ALASKA OIL AND 8AS CONSERVATION COMMISSION RE: Permit No. ~.~- ? { Bill Sheffield Governor 3001 PORCUPINE DRIVE ANCHORAGE,ALASKA 99501~31'92 TELEPHONE (907) 279.-1433 We wish to bring to your attention that the Commission has not yet received the following required items on the subject well which our records indicated was completed ~_~-~7_~_oo~ Article 536(b) of Title 20, Chapter 25, Alaska Administrative Code, stipulates that this material shall be filed within 30 days after completion of a drilled well. Please submit the above missing material. Sincerely, Chairman D. W. Bose/Lorie L. Johnson Transmitted herewith are the follcwing: .. PT.WASE NOTE: BL- BI//ELINE, S - SEPIA, F- FILM, T- TAPE,~ __ · RDCEIPT ACKNSW~..WnGED: P~E RETURN REEEIPT TO: ATIN: LORIE L. JOHNSON - AFA/311 P. O. BOX 360 ANCHORAGE, AK. 99510 ..? ARCO Alaska, Inc. Post Office t60 Anchorage, .~.,-$ka 99510 Telephone 907 277 5637 November 22, 1982 C. V. Chatterton Alaska Oil & Gas Conservation Commission 3001~Porcupine Drive Anchorage, AK 99501 Dear Mr. Chatterton: Please find attached the well completion reports for the following producing/injecting wells: 1B-9GI 1H-3 1B-10GI 1H-4 1B-11GI 1H-6 1E-11 1H-7 1E,14 ~8 1E-15 Very truly yours, Area Operations Engineer slz Attachment cc: L. M. Sellers 'E. A. Simonsen R. L. Stramp H. C. Vickers AN0-332 w/attachments AFA-311 w/attachments AST-308 w/attachments AFA-326 w/o attachments ALASKA ..ANDGAS CONSERVATION C .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 Alaska, Inc. 82-93 --, 3. Address 8. APl Number P.0.Box 360, Anchorage, AK 99510 50- 029-20763 4. Location of well at surface Ua~! FNL, 7U1' FEL, Eec ~3~ ]IZN~ RIOE~ UN 9. Unit or Lease Name Kuparuk River Unit At Top Producing lnterval 1318' FSL, 1529' FNL, Sec 33, T12N, R10E, UN 10. WellNumber 1H-8 At Total Depth 1179' FSL, 1145' FNL, Sec 33, T12N, R10E, UN 11. Field and Pool Kuparuk River Field . 5. Elevation in feet (indicate KB, DF, etc.) I 6. Lease Designation and Serial No. 85' RKBI ADL 25639 ALK 464 Kuparuk River 0il Pool 12. Date Spudded 13. Date T.D. Reached 14. Date Comp¥ Susp. or Aband. 15. Water Depth, if offshore ] 16. No. of Completions 6/17/82 6/25/82 7/7/82~ N/A feetMSLI 1 17'. T~'tal Depth '(MD+TVD) 18.Plug Back Depth (MD+TVD) 19. DirectiOnalLSurvey 20. Depth where S~'S~ set I' 2i. Thickness of Pe;mafro~t 8740' 6809' 8602' 6696~ YESI~ NO[] 1964' feetMDI 1900' (approx) 22. TyPe Electric or Other Logs Run DIL/FDC/CNL, RFT~ CCL/CBL/VDL/GR, CET~ Gyro 23. CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD CASING SIZE WT. PER FT. GRADE TOP BOTTOM HOLE SIZE CEMENTING RECORD AMOUNT PULLED 16" -62.51f H-40 Surf 78' 24. 330 sx AS II -' 10 3/4" 45,5~ K-55 Surf 2255' 13 1/2" 1000 sx AS III & 250 sx AS II , _ 7" 261~ L-80 & Surf 5440' 8.3/4" ,119.1 .DX Class G Cmt . ,3 K-55 5440 8708 ,, 24. Perforations open to Production (MD+TVD of Top and Bottom and i..25. TUBING RECORD interval, size and number) SIZE DEPTH SET (MD) PACKER SET (MD) 8442-8472' w/8 SPF ~ 1~'2" 8007' 79M1' 8426-8432 ' · ,, ,, 81 37-8152' 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. -' 8.122'81 37' " DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED 8107-8122' R??fl-Rg??' 1fin n× r!l~nn R - 8092-8107' R19&-Rlgg' ?nn nw I-t_l~.~n _ _ 27. pRODucTION T'EST ':' Date'First P. roduction I Method of ·Operation (Flowing,, gas irt, e~c.) 7/13/82I Flowino ' ' Date of Test Hours Tested PRODUCTION FOR OIL-BBL GAS-MCF WATER~BBL CHOKE SIZE IGAS-OILRATIO "7/6/82, 16.0 TESTPERIOD !~,. 1486.5, -~?A3 , 9~/~aI 9195 FIo..w Tubing Casing Pressure CALCULATED OIL-BBL ..... (~AS-MCF WATER-BBL OIL G~qAVITY-API (co'r) 'Press- ~70 24-HOUR RATE I~% r :''"2i49, 4718 -- .? 23.2 .., 28. COP E DATA Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water. Submit core chips. · . '. , :. · · ,6'~ . :.., ,.:, : ,... , .~ . ..: ,;., -, .4!a~ka. OJf&.aas. ".L' "'.,,. " ..... .. E,-29 · ' .-.' , - '" Form 10-407 Submit in duplicate Rev. 7-1-80 CONTINUED ON REVERSE SIDE - 29. 30. GEOLOGIC MARKERS FORMATION TESTS NAME Include interval tested, pressure data, all fluids recovered and gravity, MEAS. DEPTH TRUE VERT. DEPTH GOR, and time of each phase~ Top Kuparuk N/A River Form 8050' 6258' Base Kuparuk River Form. 8537' 6643' 31. LIST OF ATTACHMENTS N/A .... 32. I hereby certify that the foregoing is true and correct to the best of my knowledge (~, Area Ops. Engr. /~ /~ Signed ~. (~~ Title Date.. '' ,~ "~., INSTRUCTIONS General: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. Item 1' Classification of Service Wells: Gas injection, water injection, steam injection, air injection, salt water disposal, water supply for injection, observation, injection for in-situ combustion. Item 5' Indicate which elevation is used as reference (where not otherwise shown) for depth measurements given in other spaces on this form and in any attachments. Item 16 and 24: If this well is completed for separate prodUction from more than one interval (multiple completion), so state in item 16, and in item 24 show the producing intervals for only the interval rep0r~ted in item 27. Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval. Item 21' Indicate whether from ground level (GL) or other elevation (DF, KB, etc.). Item 23: Attached supplemental records for this well should show the details of any multiple stage cement- ing and the location of the cementing tool. Item 27' Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water In- jection, Gas Injection, Shut-in, Other-explain. Item 28: If no cores taken, indicate "none". Form 10-407 SOHIO ALASKA PETROLEUM COMPANY SFO ARCO CHEVRON EXXON 3'I 'l 'I "C- ANCHORAGE. ALASKA I'ELEPHONE (907) 265-0000 MAIL: POUCH 6.61:2 ANCHORAGE. ALASKA 99502 GETTY To: SFO/UNIT/STATE: (-Mara tho n) MOBIL PHILLI_P_S S~E 0 ..... "" F BPAE~r'Ansmit ual Only) CENTRAL FILES(CC#'s-Transmittal Only)_ Date: 9-7-82 Trans. #: 2608 556O8 CC#: REFERENCE: OHIO CASED HOLE FINAL LOGS /~ The following material is being submitted herewith. Please acknowledge receipt by signing a copy of this letter-and returning it to this office:-- ' R'7 :' 'Otis Spinner #2 8-17-82 9800-10110 A-10 GO Spinner #1 7-31-82 9650-10000 ~ GO Spinner #1 8-3-82 9000-9420 E-9 GO Spinner #1 7-26-82 10550-10920 A-17 GO Spinner #1 7-29-82 9900-10250 SFO/ARCO ONLY: · A-19 GO ECL #6 8-8-82 8950-9300 --'-. ¢~,' ' CCL #1 8-3-82 9200-10622 --A-i-5-'----~O-- CCL #1 8-1-82 9900-11510 11 5" 5" ./82) RECEIVED DAli SEP 1 Alaska 0it & Ai"tchor~fio Karen Mestas Development .Geology We].l Records William VanAlen D. W. Bose/Lorie L. Johnson Transmitted her~qith are the follc~ing: ARCO AIASKA, INC. ATIN: LORIE L..JOHNSON 'P. O. -'BOX' 3'60' AAX:~ORAGE, AK. 99510 William VanAlen D. W. BoSe/Lorie L. Johnson Transmitted herewith are the following: PLFASE NOTE: BL-.BLUELINE, S- SEPIA, F- FILM, T- TAPE, TO: ATI'N: ~ L. JO~S~ .~a~$~3~s Cons. C°~nlission P. O, ~X 360 · Anchorage ~O~, ~. 9.9510 TO: KUPARUK ENGINEERING TRANSMITTAL D. W. Bose/Lorie L. Johnson Transmitted herewith are the following: PLEASE NOTE: ~~ F- FILM, T - TAPE R~IPT ACKNOWLEDGED: .~LEASE RETURN RECEIPT TO: . _ ~ ~ ~ REC E LV~E D, DATE: ' "AlaSKa Oil & G-,~s Cons. Commis~ ARco ALASKA, INC. Anchorage ATTN: LORIE L. JOHNSON - AFA/311 P. O. BOX 360 ANCHORAGE , AK 99510 KUPARUK ENGINEERING TRANSMITTAL # ~/ D. W. Bose/Lorie L. Johnson Transmitted herewith are the following: ,,, RECEIPT ACKNOWLEDGED: . PLEASE RETURN RECEIPT TO: .o ARCO ALASKA, INC. RECEIYEI) DATE: Alask~ Oil & Ga~ Cons. Coi~missior~ knchorag~ ATTN: LORIE L. JOHNSON - AFA/311 P. O. BOX 360 ANCHORAGE, AK 99510 ARCO Alaska, Inc. [ Post Office B(~,, 360 Anchorage, Alaska 99510 Telephone 907 277 5637 July 21, 1982 Mr. C. V. Chatterton State of Alaska Alaska Oil & Gas Conservation Commi s s i on 3001 Porcupine Drive Anchorage, AK 99501 SUBJECT- 1H-8 Well Completion Report Dear Mr. Chatterton. Enclosed are the well completion report and gyroscopic survey for Kuparuk Well 1H-8. If you have any questions, please call J~Ann Gruber at 263-4944. Sincerely, P. A. VanDusen District Drilling Engineer PAV/JG' 1 lm ..Enclosures GRU1/L52 I ECEIVED JUL 2 6 ]982 Alaska O# & ~as Cons. Commission AJ~Chorage ARCO Alaska, Inc. is a subsidiary of AtlanticRichfieldCompany ALASKA ..:~ AND GAS CONSERVATION C MISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1. Status of Well Classification of Service Well OIL~xx GAS [] SUSPENDED [] ABANDONED [] SERVICE [] , 2. Name of Operator 7. Permit Number ARCO Alaska, I nc. 82-93 3. Address 8. APl Number P. 0. Box 360, Anchorage, AK 99510 50- 029-20763 , 4. Location of well at surface - - 9. Unit or Lease Name 888' FNL, 781' FEL, Sec. 33, T12N, R10E, UN LOCATIONS! Kuparuk River Unit VERIFIED At Top Producing Interval 10. Well Number 1310' FSL, 1505' FWL, Sec. 33, T12N, R10E, UM Surf. J~-- - 1H-8 At Total Depth i B. H.__~. _ 11. Field and Pool 1179' FSL, 1145' FWL, Sec. 33, T12N, R10E, UN Kuparuk River Field 5. Elevation in feet (indicate KB, DF, etc.) I 6. Lease Designation and Serial No. Kuparuk River 0i l Pool 85' RKBJ ADL 25639 ALK 464 12. Date Spudded 13. Date T.D. Reached 14. Date Comp., Susp. or Aband. J 15. Water Depth, if offshore J 16. No. of Completions 06/17/82 06/25/82 07/07/82I N/A feet MSL[ 1 1~. Total Depth (MD+TVD) 18. Plug Back Depth (MD+TVD) 19. Directional Survey I 20. Depth where SSSV set 21. Thickness of Permafrost - 8740'MD,6809'TVD 8602'MD, 6696'TVD YES J~] NO []I 1968' feet MD 1900' (approx) 22. Type Electric or Other Logs Run D IL/FDC/CNL, RFT, CCL/CBL/VDL/GR, CRT, Gyro 23. CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD CASING SIZE WT. PER FT. GRADE TOP BOTTOM HOLE SIZE CEMENTING RECORD AMOUNT PULLED i6~ bb.b~ H-~+U Surf 78' 24"' 330sx AS II 10-3/4" 45.5# K-55 Surf 2255' 13-1/2" 1000sx.AS I II & 2.50 sx AS II 7" '26.0# L-80& Surf 5440' 8-3/4,, l191sx Class G - K-5~ 5440' 8708' "24. Perforations open to Production (MD+TVD of Top and Bottom and 25. TUBING RECOI~D interval, size and number) SIZE ' DEPTH SET (MD) PACKER SET (MD) 8442'-8/+72' 4 spf ' 2_1/2,, 8007' 7940, 8426'-8432' 8 spf 8137' -8152' 8 spf 26. ACID, FRACTURE, CEMENT SOUEEZE, ETC. 8122'-8137' 8 spf " DEPTH INTERVAL (MD) AMOUNT& KIND OF MATERIAL USED 8107'-8122 8 spf 8220'-8222' 100 SX 'Class G 8092'-8107' 8 spf 8194'-8196' 200 sx Class G · _ . _ 27. N/A ' ' PRODUCTION TEST Date First Production Method of Operation (Flowing, gas lift, etc.) Date of Test Hours Tested PRODUCTION FOR OIL-BBL GAS-MCF WATER-BBL CHOKE SIZE IGAS-OILRATIO TEST PERIOD Jl~I Flow Tubing Casing Pressure CALCULATED i~ OIL-BBL GAS-MCF WATER-BBL OIL GRAVITY-APl (corr) - · Press. 24-HOUR RATE '28. CORE DATA , _ Brief description of lithology, porosity; fractures, apparent dips and presence of oil, gas or water. Submit core chips. None RECEIVED JUL 2 Alaska Oil & Gas Cons. Ccrnmission Anchora.qe Form 10-407 Submit in duplicate Rev. 7-1-80 CONTINUED ON REVERSE SIDE GRU1/WC6 NAME Include interval tested, pressure data, all fluids recovered and gravity, MEAS. DEPTH TRUE VERT. DEPTH GOR, and time of each phase. Top Upper Sand 8091 ' 6286' N/A Base Upper Sand 8251' 6412' Top Lower Sand 8415' 6544' Base Lower Sand 8537' 6643' 31, LIST OF ATTACHMENTS Drilling History, Gyroscopic Survey (2 copies) 32, I hereby certify that the foregoing is true and correct to the best of my knowledge I Signed ~,.~/'~-¢.?~..._~,. ~_~~/. ' TitleSr' Drilling Engr' Date ~/~ O//~ ~. INSTRUCTIONS General: This form is designed for submitting a complete and Correct well completion report and log on all types of lands and leases in Alaska. Item 1' Classification of Service Wells: Gas injection, water injection, steam injection, air injection, salt water disposal, water supply for injection, observation, injection for in-situ combustion. Item 5: Indicate which elevation is used as reference (where not otherwise shown) for depth measurements given in other spaces on this form and in any attachments. Item 16 and 24: If this well is completed for separate production from more than one interval (multiple completion), so state in item .16, and in item 24 show the producing intervals for only the interval reported in item 27. Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval. Item 21' Indicate whether from ground level (GL) or other elevation (DF, KB, etc.). Item 23' Attached supplemental records for this well should show the details of any multiple stage cement- ing and the location of the cementing tool. Item 27' Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water In- jection, Gas Injection, Shut-in, Other-explain. Item 28: If no cores taken, indicate "none". Form 10-407 1H-8 DRILLING HISTORY NU Hydril & diverter. Spudded well @ 0100 hrs, 06/17/82. Drld 13-1/2" hole to 2273'. Ran 52 jts 10-3/4", K-55, 45.5#/ft, BTC csg w/shoe @ 2255'. Cmtd 10-3/4" csg w/lO00 sx AS III & 250 sx AS II. ND diverter & Hydril. Pumped top job - 140 sx AS III cmt. Instld 10-3/4" packoff & tstd to 3000 psi - ok. NU BOPE & tstd to 3000 psi - ok. Tstd csg to 1500 psi - ok. Drld FC& cmt. Tstd csg to 1500 psi - ok. Drld FS & 10' new form. Tstd form to 12.5 ppg EMW. Drld 8-3/4" hole to 8740'. Ran DIL/FDC/CNL f/8726'. Run RFT; set for sample @ 3457'. Stuck tool - top of fish @ 3431'. Make up fishing tools, TIH. TOH w/fish. Ream f/6550'-6750' & f/8350'-8740'. Circ& cond mud for RFT. Attempted to run RFT - could not get past 6620'. Ream f/6550'-6750' & f/8350'-8740'. Circ& cond hole for csg. Ran 68 jts 7" 26#/ft, K-55 csg & 136 jts 26#/ft, L-80, BTC csg w/shoe @ 8708'. Cmtd 7" csg w/1191 sx Class G cmt. Tstd csg to 1500 psi - ok. Instld 7" packoff & tstd to 3000 psi - ok. Arctic packed 7" x 10-3/4" annulus w/300 bbl H20, 250 sx AS II & 109 bbl Arctic Pack. Ran CCL/CBL/VDL/GR. Ran CET (casing evaluation tool) f/8553'-6280'. Ran CBL/VDL/GR/CCL f/8553'-2000'. Perf'd 8220'-8222' (4spf). Set EZ drill retainer @ 8104'. Tstd ann to 1500 psi - ok. Squeezed 100 sx Class G cmt. Completed squeeze job (pumped 85 sx Class G, left 15 sx in 7" csg above perfs @ 8220'-8222'). Tstd Arctic Pack - ok. Drld EZ drill & pushed downhole. Drld junk & hard cmt f/8145'-8225'. Tstd csg to 800 psi - ok. Ran CET log f/8584'-7000'. Ran CBL/VDL/GR/CCL f/8585'-7000'. Perf 8194'-8196' w/4 spf. Set EZ drill @ 8160'. Tstd csg to 1500 psi - ok. Squeezed 200 sx Class G cmt. Drld soft cmt & EZ drill. Drld cmt to 8602' PBTD. Tstd squeeze to 800 psi - ok. Ran CBL/VDL/GR/CCL. Perf'd 8442'-8472' w/4 spf. Perf'd 8426'-8432', 8137'-8152', 8122'-8137', 8107'-8122', 8092'-8107' (w/8 spf). Ran 3-1/2" perf completion assembly w/tail @ 8007' & pkr @ 7940'. SSSV @ 1968'. Tstd tbg hanger & packoff to 3000 psi - ok. ND BOPE. NU tree & tstd to 3000 psi - ok. Dropped ball & set pkr. Tstd tbg to 2200 psi & ann to 100 psi - ok. Closed SSSV. Secured well & released rig @ 1900 hrs 07/07/82. JG:llm 07/07/82 GRU1/DH25 gEC£1v£D JUL e 6 1982 Alaska Oil & Gas Cons. Commission Anchorage ARCO Alaska, Inc. Our Boss Gyroseopic Survey Job No. Boss-16078 Well: ~1 H-8 (SEC33 T12N R10E) Kuparuk Field North Slope, Alaska Survey Date: July 1, 1982 Operator: John Coogle Scale: 1" = 1000' HOR I ZONTF:tL TRUE; NORTH Surface Location (888SNL 78 II,~EL) Q. OC ' ~ --1000. QO --2000. O0 --3000, O0 ---4.000. O0 PROJECTION O. O0 1000, 00 ARCO Alaska, Inc. Our Boss Gyroscopic Survey Job No. Boss-16078 Well: ffl H-8 (SEC33 T12N R10E) Kuparuk Field North Slope, Alaska ' Survey Date: July I, 1982 Operator: John Coogle Scale: 1" = 1000' 2000. O0 3000.00. 4000. O0 5000, O0 6000. O0 7000. O0 I tO00. O0 2000. O0 3000.00 ,JO00. O0 5000.0( VEla T I ¢'~L PROJECTION Suggested form to be inserted in each "Active" well folder to c~heck for timely compliance with our regulations. Operator,-We~l N~ne a~ ' Reports and Materials to be received by: ~-- d Date Required Date Received L Ccmpletion Report ..... Yes 7_~,~_~ Wel 1 .History Yes 7- ..... ~ ..... ..... ,., ~re ~ips Core ~scription Inclination .Su~ey ,,, ,, I Drill stm Test ,., ,,., KUPARUK ENGINEERING TO: FROM: D. W. Bose/Lorie L. Johnson Transmitted herewith are the following: PLEASE NOTE:~- BLUELI~~NE, S - SEPIA, F - FILM, T - TAPE C6L./VDL. DATE: RECEIVED J U L 2 21982 E - A!asKaull&sasc0n~.C0mmission ASE RETURN RECEIPT TO: ARCO ALASKA, INC. Anchorage ATTN: LORIE L. JOHNSON - AFA/311 P. O. BOX 360 ANCHORAGE, AK 99510 ARCO Alaska, Inc. ~, Post Office.Bo[ 0 Anchorage, Alaska 99510 Telephone 907 277 5637 July 12, 1982 Mr. C. V. Chatterton State of Alaska Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 SUBJECT: State Reports Dear Mr. Chatterton: Enclosed are monthly reports for June on these drill sites: '2-24 14-22 2-25 15-6 6-17 18-1 13-22 18-2 13-25 1E-13 13-26 14-15 Also enclosed is a we'll complet'ion report for Kuparuk 1E-12, and subsequent sundry reports for: 3-14 14-6 4-9 15-3 4-15 Ei.1 een No. 1 11-4 NGI-7 (Since the information on the Eileen well is of a confidential nature, we would appreciate it if you could store it in a secure area. ) Surveys for 2-22 and 13-21 are being reran; complet'ion reports for these wells will be submitted when approved surveys are received. Sincerely, P. ^, VanDusen Regional Drilling Engineer PAV/JG:llm Enclosures JUL 1 2 1982 7[~ska OiJ & Gas Cons. Comrniss[or~ GRU1/L48 ARCO Alaska. Inc. ~s a subsidiary of AtlanticRichfieldCompany % ' STATE OF ALASKA ALASKA(~'~'_ AND GAS CONSERVATION C~' MISSION · MONTHLY REPORT'OF DRILLING AND WORKOVER OPERATIONS · Drilling welex[~ Workover operation [] 2. Name of operator 7. Permit No. ARCO Alaska, Inc. 82-93 3. Address 8. APl Number P. 0. Box 360, Anchorage, AK 99510 50- 029-20763 4. Location of Well atsurface 888~ FNL, 781~ FEL, Sec. 33, T12N, R10E, UN 5. Elevation in feet (indicate KB, DF, etc.) I 6. Lease Designation and Serial No. 85' RKBI ADL 25639 ALK 464 9. Unit or Lease Name Kuparuk River Unit 10.N~I... No. /~ DS]IH-8 l'll.x~F=~4~ld~ ~/' and Pool Kuparuk River Field Kuparuk River 0il poOl For the Month of. June ,1982 12. Depth at end of month, footage drilled, fishing jobs, directional drilling problems, spud date, remarks Spudded we]] ~ 0100 hfs, 06/17/82. Dr]d 13-1/2" hole to 2273';ran, cmtd, tstd 10-3/4" csg. Dr]d 8-3/4" hole to 8740'-ran logs. Attempted to run RFT - stuck too]; recovered. Reamed ho]e; attempt to run RFT - could not get past 6620'. Reamed hole. Circ& cond hole for csg as of 06/30/82. SEE DRILLING HISTORY 13. Casing or liner run and quantities of cement, results of pressur9 tests 16" 65 5#/ft, H-40 conductor set ~ 78' Cmtd w/330 sx AS II 10-3/4" 45 5#/ft K-55 8TC csg ~/shoe ~ 2255' Cmtd ~/lO00 ~x AS SEE DRILLING HISTORY & 250 sx AS II. ~14. Coringresumeandbriefdescription None 15. Logs run and depth where run DIL/FDC/CNL f/8726'. RFT (set ~ 8457') 16. DST data, perforating data, shows of H2S, miscellaneous data N/A RECEIVED J U L 1 2 1982 u,, & Ga~ Cons. ~,ornrnission Anchorage 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sr Dril ling Engineer SIGNED TITLE ___' ........ DATE NOTE--Re,~rt~n~th~fo~rm is ~required for each calendar month, regard,ess of the status of operations, and must be ~led~in duplicate with th~ Alaska Oil and G~s Conservation Commission by the 15th of the succeeding month, unless otherwise directed. Form 10-404 Submit i, duplicate Rev. 7-1-80 GRU1/MR19 1H-8 DRILLING HISTORY NU Hydril & diverter. Spudded well @ 0100 hrs, 06/17/82. Drld 13-1/2" hole to 2273'. Ran 52 jts 10-3/4", K-55, 45.5#/ft, BTC csg w/shoe @ 2255'. Cmtd 10-3/4" csg w/lO00 sx AS III & 250 sx AS II. ND diverter & Hydril. Pumped top job - 140 sx AS III cmt. Instld 10-3/4" packoff & tstd to 3000 psi - ok. NU BOPE & tstd to 3000 psi - ok. Tstd csg to 1500 psi - ok. Drld FC & cmt. Tstd csg to 1500 psi - ok. Drld FS & 10' new form. Tstd form to 12.5 ppg EMW. Drld 8-3/4" hole to 8740'. Ran DIL/FDC/CNL f/8726'. Run RFT; set for sample @ 8457'. Stuck tool - top of fish @ 3431'. TOH w/fish. Ream f/6550'-6750' & f/8350'-8740'. Circ & cond mud for RFT. Attempted to run RFT - could not get past 6620'. Ream f/6550'-6750' & f/8350'-8740'. Circ & cond hole for csg as of 06/30/82. JG: 1 lm 07/07/82 GRU1/DH25 RECEIVED JUL 1 2 1B82 A!~ska Oil & Gas Cons. Cornmissio~ Anchorage MEMOR NDUM Sta' e of Alaska TO: C. V4 ~~~on DaiS: June 24, i982 Chai ~ ~ THRU: Lonnie C. Smi{h TELEPHONE NO: Commissioner ~ FROM: Edgar W. Sipple, Jr. _ ~: Petroleum Inspector · · SUBJECT: Witness BOPE Test on .... ARCO~.s_~[~ruk Rive r ~~ Parker Drilling Rig No. 141 Sec. 33, T12N, R10E, MUM Permit No. 82-93 Friday, June. 18, 1982 - I left Anchorage for Prudhoe Bay via' ~laska- Airlines. upon arrival at ARCO's Kuparuk River, 1~-8, Parker Drilling Rig No. 141 was in the process of getting ready to run casing. Sa.tu~Y,_ JUne 19, 1982 - The BOPE test commenced at 4:45 p.m. and ~as concluded at 6215 p.m. There ~re no failures. I filled out the A.O.G.C.C. report which is attached. in s~ry I ~tnessed the BOPE test on ARCO's 1H-8, Parer Drilling ~g No. 141. There ~re no failures. 02-001/~(Rev.10/79) O&G 4/80 STATE (.)F AI,ASKA ALASKA OIL & GAS CONSERVATION COMMISSION B.O.P.E. Inspection Report Location: Sec .~ T/~.~' Date Representative Per.it # ~Z /O ~Casing Set .. Drilling Contractor /Q/~/t'~'~ ~ ~Rig # /~[ Representativa~+~~ Location, General ~ ACCUt1ULATOR SYSTEI.1 Well Sign ~PF~ ull Charge Pressure General Housekeeping Reserve pit . Rig ps ig Pressure After Closure /~--OO psig 200 psig Above Precharge Attained: /~ _min~ s¢~ Full Charge Pressure Attained: 7 min~2_s~ Controls: Master ~-- ~ ~ ~ Remote ~ Blinds switch cover ........................................ ~u-~ ~r~ ..~ z~- r.~-~-'~z.:rz.~z.~t ......... BOPE Stack Annul~q~r Preventer Pipe Rams Blind .R%~s ~ ~ ~hoke Line Valves H.C.R. Valve ~"~ Kill Line Valves ~D~ Check Valve Test Pressure ~0oo ~ooo .~0oo ~00o ,3 l~oo Kelly and Floor__S_a_f_e_t__y. Valves Upper Kelly '~62~k Test Pressure Lower Kelly Test Pressure Ball Type ~-- Test Pressure .r~ $ i," ,,ri -- Inside ~Op Z.-'" Tes~ pressure Choke Manifold ~ Test Pressure ~O _. No. Valves No. flanges Adjustable Chokes [-_ __~..~- O~ k g~ ttydrauically operated choke Test Results: Failures '--'-~) ..... '-'~'~-~-'~i'=:T ?;[~ .......... '/-'~-'iir$ :' '~O/W.;~- ~"~' ,,. Repair or Replacemen~ o~ ~a~led equipmen~ to be made w~¢h~n .... ~ days and Ins~ctor/Com~ss~on o~ce notified. ·Distribution orig.' - AO&GCC cc - Operator cc - Supervisor June 15, 1982 ~r. Jeffrey B. K.ewin Senior Drilling Engineer ARCO Alaska~ Inc. P. O. Box 360 Anchorage, Alaska 99510 Re: Kuparuk Unit 1H-8 ARCO Alaska, Inc. Permit No. 82-93 Sur. Loc. 888'F~L, 781'FEL, Sec 33, T12N, R10E, DM. Btmhole Loc. 1073'FSL, 1065'FWL, Sec 33, T12N, R10E, L%{. Dear Mr. Kewin~ Enclosed is the approved revised application for permit to drill the above referenced well. The provisions of the cover letter, dated June 11,1982, accompanying the original approved permit are in effect for this revision. Ve ~ trul · C. V. Chat. tert~ Chairman of ORDER OF THE COM~ISSION Alaska Oil and Gas Conservation Commission Enc lo sure cc: Department of Fish & Game, Habitat Section w/o encl. Department of Environmental Conservation w/o encl. CVC ~ be ARCO Alaska, Inc. ~' Post Office BI .~60 Anchorage, Alaska 99510 Telephone 907 277 5637 June 15, 1982 Mr. C. V. Chatterton State of Alaska Alaska Oil & Gas Conservation Commi s s i on 3001 Porcupine Drive Anchorage, AK 99501 SUBJECT' Drill Site 1H-8 Application for Permit to Drill (Revised) Dear Mr. Chatterton' Due to a change in the bottomhole location, we are resubmitting our application for Permit to Drill well DS 1H-8. Attachments include a drawing of the proposed wellbore, and a drawing and description of both the surface hole diverter system and the BOP equipment. Since we estimate spudding this well today, your earliest approval will be appreciated. If you have any questions, please call me at 263-4970. Sincerely, _4J. B. Kewin Senior Drilling Engineer JBK/JG: 1 lm Enclosure GRU1/L25 ARCO Alaska, ~nc. is a subsidiary of AtlanticRichfieldCompany RECEIVED JUN 1 5 1,o82 Alaska 0il & Gas Cons. Commission Anchorage A(rU STATE OF ALASKA c.(Oi~iM ALASK IL AND GAS CONSERVATION ISSION PERMIT TO DRILL 2O AAC 25.O05 la. Type of work. DRILL [] lb. Type of well EXPLORATORY [] SERVICE [] STRATIGRAPHIC [] REDRILL [] DEVELOPMENT OIL [] SINGLE ZONE [] DEEPEN [] DEVELOPMENT GAS [] MULTIPLE ZONE [] 2. Name of operator 3. Address P. 0. Box 360, Anchorage, AK 99510 ,/~//1~ 4. Location of well at surface -- ~,3 IV .~ ~ 9. Unit lease name -- 888' FNL, 781' FEL, Sec. 33, T12N, R10E, ~f~lO//~,~ -'.7,,0/~ or Kuparuk Unit At top of proposed producing interval ~,~ ~ , 10. Well number 1320' FSL, 1320' FWL, Sec. 33, T12N, R10E, UH ~r~,~;'~rb/;,,~. 1H-8 At total depth ~////~'/~)/) 1 1. Field and pool 1073' FSL, 1065' FWL, Sec. 33, T12N, R10E, UM Kuparuk River Field 5. Elevation in feet (indicate KB, DF etc.) ] 6. Lease designation and serial no. '" Kuparuk River 0±l Pool 85' RKBIADL 25639 ALK 464 12. Bond information (see ~0 AAC 25.025) I' ederal Insurance Co. Type St atewide Surety and/or number 8088-26-27 Amount $500,000 , 13. Distance and direction from nearest town 14. Distance to nearest property or lease line 15. Distance to nearest drilling'or c~mpleted 30 Miles NW Deadhorse miles 781' FEL at surface feet 1H7 Well 120 feet 16. Proposed depth (MD & TVD) 17. Number of acres in lease 18. Approximate spud date 8700' MD, 6819' TVD feet 2560 06/16/82 19. If deviated (see 20 AAC 25.0.50) I2o. Anticipated pressures 2793 psig@80°F Surface KICK OFF POINT 1200 feet. MAXIMUM HOLE ANGLE45° oI (see 20 AAC 25.035 (c) (2) 3210 psig@62.~0___ft. TD (TVD) 21 Proposed Casing, Liner and Cementing Program ..... SIZE CASING AND LINER SETTING DEPTH QUANTITY OF CEMENT Hole Casing Weight Grade Coupling Length MD TOP TVD MD BOTTOM TVD (include stage data) 2Z; 16" ~ 65# H-Z~0 PEB 80' 30'1 30' 110'11 110' -T- 200 cf ............ 13-1/2 10-3/4 45.5# K-55 BTC 2222' 30' I 30' 2252'I 2200' 950 sx AS III ' I 250 mx AS II '18-'3/47" 26# L-80 BTC 5412' 28' ', 28' 54~0'1 ~500' HO00 sx "G" cml 8-3/4 7" 26# iK-55 BTC 3260' 5M¢0' ', ZtS00' 8700", 6819' 22. Describe proposed program: ARCO Alaska, Inc. proposes to drill a Kuparuk River Field development well to approximately 8700' MD (6819' TVD). A 20", 2000 psi annular diverter' ~ill be installed on the 16" conduclor while drilling lhe surface hole. A 13-5/8", 5000 psi, RSRRA BOPE slack will be installed on the 10-3/4" surface pipe. It will be lested upon installation and ~eekly thereafter. Test pressure ~ill be 3000 psig (1800 psi for annular). Maximum expected surface pressure is 2793 psig. Pressure calculations are based on virgin reservoir pressure. Surface pressure calculated with unexpanded gas bubble at surface including temperature effects. Selected intervals will be logged. The well will be completed with 3-1/2", 9.2#, 0-55 buttress lbg. Non-freezing fluids will be left in uncemented annuli through the permafrost interval. Selected intevals will be perforated within the Kuparuk formation.and reported on subsemueot, report, s. A downhole safely valve will be installed c~2:~. I ~e~c'~o~d~ti~'~{ tlYe~l%~l~g~o~i'n~Jt~ue~rd ~o¥~ct.]t~l~l~ best of my knowledge The space below for Commission use CONDITIONS OF APPROVAL Samples required Mud log.required Directional Survey required I APl number I-lYES ~0 []YES ~'~0 ~Ly E S []NOI5o_ o,~-~.7~ -- Permit number Approval date I~ ~~ ~'~--~~ ~.~i~/j~'/~ ,' ISEE COVER LETTER FOR OTHER REQUIREMENITS APPROVED BY COMMISSIONER DATE T~n~ 1 by order of the Commission -- / Form 10-401 GRU7/B5 Submit in triplicate Rev. 7-1-80 ............. ~ ................. i ]_.!.L :;.: !; ;.ii _]_L.'_.:.-_Li:_i L-.iiJ_-.[.' iiii;'.'i-iiU-_Liii-_---A~ ..... J__---'----, "-~+Z '2:J , ;_ ' '-' i ' ....... ; ' I ' '; ;'! ............ ::-":x" ~'_-=- -:-; --"'~ ...... .-! .... ; ...... ?--'--; .......... ~/--I[--f'N:~-i ~ ' i: : i:. ........ I:tRCq.~.R,.-.-I.N,c---: .... ;, ...... =-=~- .................... ,-'~--~ ...... 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IRNNULRR 1 PREVgENTORJt 'x . 13-5/8" 5000 PSI RSRRA BOP sTACK 2. 3. 4. 5~ 16" Bradenhead 16" 2000 PSI × iD" 3000 PSI casing head lO" 3000 ?SI tubing head lO" 3000 PSI x 13-5/8" 5000 PSI adapter spool -~' . 13-5/8" 5000 PSI pipe rams 13-5/8" 5000 PSI drilling spool w/choke and kill lines . 13-5/8" 5000 PSI pipe rams- ' ... -- -- .' ... 13-5/8" 5000 PSI. blind rams -- _ 13-5/8" 5000 PSI annular ' _ . l__ PIPE RRMS Ill {). 7 () . . _ PiPE nn~s i -% ) 'C '-'5 TBGHD3 ' '. CSG HD ' · _ . 10. · 11. · 13. ACCI~-IULATOR CAPACITY TEST CHECK AI;D FILL ACCLE.~LATOR RESERVOIR 'fO PROPER LEVEL WITh HYDRAULIC FLUID; ~SURE TlJJT ACCD-iULATOR PRESSURE IS 3000 PSI I~ITH,1500 PSI DO~)~TREAR OF THE REC~TOR. OBSERVE TINE THEN CLOSE ALL UNITS SII~JLTANE- OUSLY /~qD RECORD THE TIME AND PRESSLJ,~ REJ'4AIIt- ING AFaR ALL UNITS ~d:IE CLOSED WITH (~GING PL~-IP OFF. RECORD ON IADC REPORT. THE ACCEPTABLE L(Y.~ER LIHIT IS 45 SECO:iDS CLOSING lIltE Af(g 1200 PSI RSV~AINI~ PRESSURE. - 13-5/8' BOP STACK TEST 1. FILL BOP STACK AND HtdtIFOLD WITH ARCTIC DIESEL. 2. CHECK I"~AT ALL HO~ D~RN SCREI~S ARE FULLY RE- TRACTED. PREDETE~,INE DEPTH THAT TEST PLUG 1.'ILL SEAT AND SEAT IN WELLHEAD. RLRI I~t LOCK DCFJN SCP~!S Iii HEAD. 3. CLOSE A~'~'~ULAR PREVENTER AND CHOKES /bid BYPASS YALVES 0,'~ /.i/~qI FOLD. 4. TEST ALL CONPONENTS TO 250 PSI AND l~g FOR l0 MINUTES. - 5. INCREASE PRESSURE TO 1800 PSI AND HOLD FOR lO MINUTES. BLEED TO ZERO PSI. 6. OP~X AI¢iULAR PREVF~qTER AJXD CLOSE TOP ~;ET OF PIPE R~."~. 7. IHCREASE-PRESSURE TO 3000 PSI AND HOLD FOR 10 HI~TES. 8. CLOSE VALVES DIRECTLY UPSTREAN OF CI-IDKES. ' BLEED D~^~NSTRF_~4 PgESSURE TO ZERO PSI TO TEST VALVES. TEST RE~IA!N!NG UNTESTED HANIFOLD VALVES, IF ANY, lJIitl 3000 PSI UPSTREX¢4 OF VALVE AIJD ZERO PSI DG"~h'STRF_~. BLEED SYST~ TO ZERO PSI. OPEN TOP SET OF P[PE RN-LS A~D CLOSE BOTTOM SET OF PIPE iNCREASE PRESSURE TO 3000 PSI A~qD HOLD FOR lO ItINUTES.- BLEED TO ZERO PSI. OPEN BOTTON SET OF PIPE R~',IS. BACK OFF RUN- NI);G JOI~T AND-PULL OUT OF HOLE. CLOSE BLIND RAHS AND TEST TO 3000 PSI FOR lO Nt~IJTES. BLEED TO ZERO PSI 12. OPE,'( BLIIID PJ~tS A~D RECOVER TEST PLUG. I, tAKE SURE HAIIIFOLD AiID LI,'JES ARE FULL OF ARCTIC DIESEL A~;D ALL VALVES ARE SET 'IN DRILLII~G POS I TI (1't. - - TEST STA~IDPIPE I/ALl/ES TO 3000 PSI.. lEST KELLY COCKS A/ID II'ISlDE BOP TO 3000 PSI RECORD TEST INFO.~'~T]O,'t ON BLO~tOUT S~2F. JJ~u".:~,:".:L&-. :'. '' T~T FOPC4 SIGN AND SEND TO. DRILLI;iG. SUPER visoR. PERFO~-I C~IPLETE B~E TEST O:ICE A ~EEK NID. . '(9. Maintenance & Op. eration ~ 1. Upon initial installation close annular ! preventer and verify that ball valves I - have opened properly. ' · I 2. Close annular preventer and blow air ~__ . through diverter lines every 12 hours. t 3~ Close annular preventer in the event 16" Conductor Surface Diver~- System I. 1. 16" Bradenhead. 2. 16" x'20" 2000 psi double studded adapter. 3. 20" 2000 psi drilling spool w/lC" side outlets. 4. 10" ball valves, hyraulically actuated, w/lO" lines to reserve pit. Valves to open automati- cally upon closure of annular preventer. 5. 20" 2000 psi annular preventer. 6. 20" bell ,nipple. that gas or fluid flow to surface is · detected. If necessary, manually over- ride and close ball valve to upwind diverter line. Do not. shut in well under anY circum~ances~-----'-' June 11, 1982 l~Ir. Jeffrey Bo liewin Senior Drilling Bngineer AR(X) Alaska, Inc. F. O. Box 360 Anchorage, Alaska 99510 lluparuk River Unit Ill-8 ARCO Alaska, Inc. Permit No. 82-91{ Sure Loc, 888tFl~L, ?81'FBL, Sec 23., T121~, ~10E, U~i. Btluhole Loc. 1425tFI~L, 1835tFI~L~ Sec Dear ~. l/eWi n.. Bnelosed is the approved application for peru~it to drill the above '-referenced ~vel I. Well samples and a ~ud log are not required. A continuous directional survey is required as per 20 AAC 25.050(b)(5), If available, a tape containing the dig-itized log info~uation shall be submitted on all logs for copyin~ except exper i~nt al logs, velocity surveys and dipmeter surveys. Many rivers in Alaska and their drainage systems have been classified as important for the spawninF~ or migration of anadr~us fish. Operations in these areas are subject to AS 16.05.870 and the regulations promulgated thereunder (Title 5, Alaska Administrative Code). Prior to o~enci~ operations you ~a.y be contacted by the Habitat Coordinator's Office, Department of ~ish and Pollution of any waters of the State is prohibited by AS 46, Chapter 3, Article ? and the re~alations prourul~ated thereunder (Title 18, Alaska Administrative Code, Chapter ?0) and by the Federal Water Pol.lution Control Act, as amended. Prior to e~encinc operations you may be contacted by a representative of the Department of Environmental Conservation. To aid us in schedulin~ field w~rk, we ivould appreciate your nottfytnc this office within 48 hours afte~ the ~ell is spudded. We would also like to be notified so that a representative of the Co~ission may ~e present to witness Mr. Mark A. Major Prudhoe Bay Unit DS 13-25 -2- ,June 11, 19t~ testing of blowout preventer equipment before surfaee easing shoe Is drilled. In the event o-f suspension or abandonment, please give this office adequate advance notifioation so that we may have a wi tness present. Very truly yours, C. ¥. Chatterton Alaska 0tl and Gas ConserVation Consntsston Erie 1 osure cox Department of Fish & Game, Habitat Section w/o enel. Department of Environmental Censer-ration w/o enel. CVC ,, be ARCO Alaska, Inc.B~L~_. Post Office 360 Anchorage, Alaska 99510 Telephone 907 277 5637 June 9, 1982 Mr. C. V. Chatterton State of Alaska Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 SUBJECT: Drill Site 1H-8 Application for Permit to Drill Dear Mr. Chatterton: Enclosed is our application for Permit to Drill well DS 1H-8 and the required $100 filing fee. Attachments include a drawing of the proposed wellbore, and a drawing and description of both the surface hole diverter system and the BOP equipment, including anticipated reservoir pressures. Since we estimate spudding this well June 17, 1982, your earliest approval will be appreciated. If you have any questions, please call me at 263-4970. Sincerely, Senior Drilling Engineer JBK/JG: 1 lm DS 1H-8 GRU1/L17 ARCO Alaska, Inc. is a st~bsidiary of AttanticRichfieldCompany JUN ~ 0 ~982 Oil &'~,,~Cborag~Gaa Cons ~" STATE OF ALASKA ~'O(~ ALASKA L AND GAS CONSERVATION C ,MISSION PERMIT TO DRILL 20 AAC 25.005 la. Type of work. DRILL [~ lb. Type of well EXPLORATORY [] SERVICE [] STRATIGRAPHIC REDRILL [] DEVELOPMENT OIL [] SINGLE ZONE [] DEEPEN [] DEV E I~1~ FVE~r~ MULTIPLE ZONE i--I 2. Name of operator ARCO Alaska, Inc. .Il IAI 1 ~ 3. Address - ~' ' - "' P. 0. Box 360, Anchorage, Aiaska 99510 Alaska0il&~r.n.o ~, ...... 4. Location of well at surface Arlch0rag. vu"tllll $~JQ~it or lease name 888' FNL, 781' FEL, Sec. 33, T12N, R10E, UH ~ Kuparuk River Unit At top of proposed producing interval 10. Well number Target: 6480' SS, 1320' FNL, 1320' FWL, 5ec.34, T12N~R10E~UN 1H-8 At total depth 11. Field and pool 1425' FNL, 1835' FEL, Sec. 34, T12N, R10E, UN Kuparuk Rive~ Field 5. Elevation in feet (indicate KB, DF etc.) I 6. Lease designation and serial no. Kuparuk River Pool 85' RKB, 54.5' PADIADL 25639 ALK 464 12. Bond information (see 20 AAC 25.025) Federal Insurance Co. Type Statewide Surety and/or number 8088-26--27 Amount $500,000 13. Distance and direction from nearest town 14. Distance to nearest property or lease line 15. Distance to nearest drilling or completed 30 mi. NW of Deadhorse miles 7E~.I' F~IL a Surface feet 1H-7wel~ 120 feet 16. Proposed depth (MD & TVD) 17. Number of acres in lease 18. Approximate ~pud date 8111' HD, 7137' TVD feet 2560 06/17/82 19. If deviated (see 20 AAC 25.050) 120. Anticipated pressures 271 ~ psig@_~O"F Surface KICK OFF POINT 3500 feet. MAXIMUM HOLE ANGLE ~ Ol(see2OAAC25.035 (c) (2) ~0_~psig@_~3_~~ ft. TD (TVD) 21 Proposed Casing, Liner and Cementing Program SIZE CASING AND LINER SETTING DEPTH QUANTITY OF CEMENT Hole Casing Weight Grade Coupling Length MD TOP TVD MD BOTTOM TVD (include stage data) Z4" 16' 65# H-40 PEB 80' 30'1 30' 110' 110' ~- 200 CF " 30' 2500' 2500' 950 sx AS III 13-1/2 10-3/4 45.5# K-55 BTC 2470' 30'I ' I 250 sx AS II 8-3/41'7" 26# K-55 BTC 8083' 28' ~ 28' 8111'1 7137' 950 sx "G" cml I I ~ I 22. Describe proposed program: ARCO Alaska, Inc., proposes to drill a Kuparuk River Field development well to app~oximateiy 7137'TVD, 8111'MD. A 20",2000 psi annuIa~ diverter wiii be instaIIed on the 16" conductor whiIe driiiing the surface hoie. A 13-5/8", 5000 psi, RSRRA BORE slack wi~I1 be instaiIed on the 10-3/4" surface pipe. It wiIi be tested upon instaliation and weekiy thereafter. Test pressure wiii be 3000 psig (1800 psi for annuIar). Expected maximum surface pressure wiiI be 2715 psig based on cooiing of a gas bubbie rising at constant voIume SeIected intervais wiii be iogged.~ The weIi wili be compIeted with 3-1/2" 9.2~! 3-55 buttress tbg. Non-freezing fiuids wiii be Ief~ in uncemented annuii through the permafrost intervaI. SeIected intervaIs wiIi be perforated within the Kuparuk formation and reported on subsequent reports. A downhoie safely vaive wiiI be instaiied and tested upon compietion of the job. 23. ~ hereby certify that the foregoing is true and correct to the best of my knowledge SIGNED , TITLE Senior Drilling Eng,. DATE Z The space bel~ f~m~si~se CONDITIONS OF APPROVAL \ Samples required Mud log required Directional Survey required ~ '~..~.~:] Apl number []YES ]~NO r-lYES ~.NO ~,.¥ ES I--INO Permit number Approval date ~ ' /' 7 by order of the Commission Form 10~401 GRU7/A13 / Submit in triplicate Rev. 7-1-E~O I . I ........ 2-t-48--F. . _ I i--~:300--i 200 .... ~ ...... 100 .... ~ p: ...... i' ....J-'~ · 200 : ..800 i' ' ......... : ; ........ ; ............ : ............ i ......... ? ....... : ......... ~ .... ! .... ~':'i' ' i ..... ~ : ~ ; ~ : ........ 500 - ..... "- t .... "' -' ....... ~ .... I ..... ~ ..... i ' ' .....~ ..... ; ....... i':: :.'!'.;' ANTICIPATED PRESSURES Expected reservoir pressure in the Kuparuk interval has been determined to be 3575 psia from RFT and pressure build-up data. This pressure @ 6280' SS = 6365' TVD will be balanced by 9.8 ppg mud weight. Normal drilling practive calls for 10.4 ppg weight prior to penetration and during drilling of the Upper Kuparuk and remaining intevals. This will result in a 187 psi overbalance. It is anticipated the surface BOPE equipment could be subjected to a maximum of 2715 psi during drilling operations. Derivation assumes a gas kick at reservoir temperature and pressure (160°F, 3255 psia), gas migration to the surface without expansion, and cooling to 60°F cellar temperature. This is well below the 5000 psig BOPE working pressure and less than the 3000 psi weekly test pressure. Pi = pressure initial (reservoir) Ti = temperature initial (reservoir) Vi = volume initial (reservoir) Pf : pressure final (surface) Tf = temperature final (surface) Vf: volume final (surface) PiVi = PfVf Ti Tf Since Vi = Vf, i.e., no expansion Pi = Pf Then Pf = PiTf : (3255 psia 60°F + 460) T-? Tf Ti (160°F + 460) Pf = 2730 psia = 2715 psig RECEIVED JUN 1 0 1,082 Anchorage Maintenance & C,~eration 1. Upon initial installation close annular preventer and verify that ball valves have opened properly. 2. Close annular preventer and blow air tZ~rough diverter lines every i2 hours. 3. Close annul~ preventer in ~h~ event that gas or fluid flow to surface is detected. If necessary, manually over-, ride and close bail valve to u,swind diver:er line. Oo not shut in well under any circu,-ns~ances. RECeIVeD JUN 1 o-i982 AI~slm Oil & Gas cons. Commiss/or~ /mchorage ']¥. r ) BLiNO R.qMS P iRE RRMS n T.SG ECEIVEI) JUN i o i982 3. :'-' ':-.-:3 :~: ~": ' ...... "~'~ PS i an~ k~il lines . 7. l ~-:'S'' 5000 PS' p~pe rams 8. i~-~/'8" ~000 2ST blind rams 1 ~ -~'S~' ~000 ?S~ annular ''"' ......... CAFAC ~ T~' TEST .o . l. CqT'_:~ ~:;O FiLL ACm...:-?dLATOR RESERVOIR TO PROPER , ,¥.~.,, .~- · L=-.'.'EL '.-.'ir~ ,~ .... ~L:u FLUIO 2- %3SC'2~ ,,'%&T ACSLf"" '-~ .... ~2 ??.£SSURE .rS ¢--~00 PSI 3. C'ESE?.'/E TiME TH-CE CLOSE ~LL Ut:ITS S!F'.JLTA:;E- OL':L: ~;O RECCRO ~'~E Ti~ AND ?RESSUF. E ....~.,,..= :.--~i ALL UiiiTS ..:,~:.,~ ,..,.OSc. D WIT'4 2U'.: CF.-". 4. .RE.:--%:-0 CS ..'ADC RC:ORT. Edl ,...u,..:..-,"'r .... ~ ,-.-_,~_~-~'" L~fEi Ti"; Li:diT -iS 45 SECC;;~ CLOSi!,'G ~,. AND 1200 PSI 13-5/8" BOP STAO~ TEST I FiLL SOP STACK A:,~O "' !FOLD 141 2. ~E:X ~AT ALL aC~ O~;~;(' SCRDKS ARE ~LLY TP-s,~ED. PZE~ETZ~-ii;;E OEPTH T~AT TEST' PLUG Wi" ~T .... S~T I'l "' DT;~ SC~,~S IX 3. CL'S'SE ~Jt';b'bqR PPETE;iTE.q ;~O C-:OKES ~g BY?~S S. ~,;_.,, -:~_r :-rS, r,. ~ur.c ....... iv !3OO PSI ~.,,u .... :4C4~ FOR IC x::;UTES. SLiiS TO ZERO PSI. 7. i?;%RE.:JE ?XESSU2E rn..~ ~:~O- PSi A¢;3 h'~ FOR Hi B~ ~z~ ~%';;ST~&~'( PRESSU7.E TO ZERO PSi TO TEST YPi":: .... TEST i~-:.:.l~i''~,'j ~,,~c'~ ,'..~,~ ~'~_ i :::: ZEE: r: ...... S,r.=~.. ~kllD SYST~'~ CFC -]? ~ SF ?:?E :~t~'S .~',3 ClPSl ..... ~. :~:: ..... ~,~ PSI. .... - : ..... -~ ~:: ~ 9:F~ :~q"tS. :~' OFF '~: i :l''~ .... :'LL "~ ~r HELl ~.OSE ........ , ...... ;,,U t cS. EL!!: ~.3 ERIC' ?Si. ~. ~.-:_- : ..... r,~q~ AS3 XEC~'c~ .'~-- ,,~, lEST ~_~. q: :: %::;:F']Lg :/;C LZ:;ES A~ :'"' ,]F ARCT;~ 3:EZEL .c;3 ~u ,..~ AXE SET :ti CRILLit;G i' .... ' ..... r~:fq ~';n ~;S~nr S,~ 70 3OCO CHECK LIST FOR NEW WELL PERMITS Company Lease & Well No. IT~M APPROVE DATE (1') Fee (2) Loc thru 8) (~ thru 11 ) (4) Casg ~~ ~//A~Z- t('l'2 thru 2 6) 1. Is 2. IS 3. IS 4. IS 5. IS 6. IS 7. IS thru '24) 8. Can permit be approved before ten-day wait .......................... YES NO e 10. 11. 12. 13. 14" 15 16 17 18. 19. 20. the permit fee attached .......................................... well to be located in a defined pool ............................. well located proper distance from property line .................. / ?~_.. well located proper distance from other wells ................ sufficient undedicated acreage available in this ;;;i .... {./~.~ -- well to be deviated and is well bore plat included ............... operator the only affected party ................................. 21. 22. 23. 24. 25. Does operator have a bond in force ................ Is a conservation order needed ..... 1.[i~1111...i.~i~11.1.1...11..__ Is administrative approval needed ................................... string provided ........................................ ~'~ .,, Is conductor Is enough cement used to circulate on conductor and surface ...... Will cement tie in sUrface and intermediate or production strings Will cement cover all known productive horizons ........ .......... ii.~~'~~ -- Will surface' casing protect fresh water zones .................... Will all casing give adequate safety in collapse, tension and burs Is this well to be kicked, off from an existing wellb.ore ........... ... Is old wellbore abandonment 'procedure included on 10-403 ........ .... Is adequate well bore separation proposed ........................... Is a diverter system required ....................................... ~'~ Are necessary 'diagrams of diverter and BOP equipment attached ....~ D°es BOPE have sUfficient pressure rating- Test t° ~~ ;!!g~' Does the choke manifold comply w/AP1 RP-53 (Feb.78).' ........ .. . Additional requirements ............................................. Additional Remarks: REMARKS Geology: En'giqD~ng ttWK ~ LC S~'~BEW/ rev: 01/13/82 INITIAL GEo. UNIT ON/OFF POOL CLASS STATUS AREA NO. SHORE 7'20/0 CHECK LIST FOR NEW WELL PERMITS Company IT~ APPROVE DATE (2) Loc (72 thru 8) (3) Admin ~'~_ ~thru 11) · · 3. 4. 5. 6. 7, 8. 9~ 10. 11. Is the permit fee attached ................................ Is well to be located in a defined pool ................ Is well located proper distance from property line ..... i ' {'' Is well located proper distance from other wells ....... Is sufficient undedicated acreage available in this pool Is well to be deviated and is well bore plat included .. Is operator the only affected party ..................... Can permit be approved before ten-day wait ............. Lease & Well No. (4) Casg ~ &-/a-f~w- (12 thru 20) 12. 13. 14.' 15. 16. 17. 18. 19. 20. YES NO Does operator have a bond in force .................................. / Is a conservation order needed ...................................... Is administrative approval needed ................................... Is conductor string provided .... , .................................... Is enough cement used to circulate on conductor and surface ......... Will cement tie in surface and intermediate or production strings ... Will cement cover all known productive horizons ..................... Will surface casing protect fresh water zones ....................... Will all casing give adequate safety in collapse, tension and burst. Is this well to be kicked-off from an existing wellbore ............. Is old wellbore abandonment procedure included on 10-403 ............ Is adequate well bore separation proposed ........................... (5) (21 thru 24) 21. 22. 23. 24. Is a diverter system required ....................................... ~ Are necessary diagrams of diverter and BOP equipment attached ....... /kt~ Does BOPE have sufficient pressure rating -Test to ,~w~ psig .. z~ 'Does the choke manifold comply w/AP1 RP-53 (Feb.78) .................. (6) Add: ~.~.~. ~-/m-~'~.._ 25. Additional requirements ............................................. Additional Remarks: REMARKS ~z Geology: Engin~,~r ing: A ~ JAL ~_~_~TM ~-~ /' rev: 01/13/82 - INITIAL ' GEO. UNIT ON/OFF POOL CLASS STATUS i AREA NO. SHORE 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 effod has been made to chronologically organize this category of information. LVP 010,H01 VERIFICATION LISTING ** REEL HEADE~ SERVICE NAME ~SERVIC DATE ~82/07/29 ORIGIN : REEL NAME CONTINUATION ~ :01 PREVIOUS RE~5 COMMENTS :REEL COMMENTS ** TAPE HEADER ** SERVICE NAME :SFRVIC DATE :82/07/29 ORIGIN :1070 TAPE NAME :65351 CONTINUATION # :01 PREVIOUS TAPE : COMMENTS :TAPE COMMENTS ** FILE HEADE~ ** FILE NAME :SFRVIC.O01 SERVICE NAME : VERSION # DATE : MAXIMUM LENGTM : 1024 FILE TYPE PREVIOUS FILE : ** INFORMATION RECORDS ** MNEM CONTENTS CN FN : RANG: TOWN~ SECT~ COUN~ STAT: CTRY: MNEM ATLANTIC RICHFIELD COMPANY 1H-8 KUPARUK IOE 12N NORTH SbOP£ ALASKA U,$.A. CONTENTS PRES: DIbO01E LVP OIO,HO! VERIFICATION LISTING $~ COMMENTS *~ .. ALASKA COMP'UTING COMPANY = ATLA~TIC RICHf'IE'bD WELL ~ ~ H-8 FIELD = KUPARUK COUNTY = NORTH ~LOPE BOROUGH STATE = ALA. SKA JOB NUMBER AT ACC: 10707,65351 RUN #1, DATE LOGGEDI 26 JUN 82 5DP: ~IK 8710 F~, 2248 F . 10 3/4 8.75 IN. XC'PGLYMER BOTTOP DEPTH TOP DEPTH CASING BlT SIZE TYPE FLUID bVP OlO,MO1 VERIFICATION LISTING DENSITY VISCOSITY FLUID LOSS RM RMF RMC RM AT BHT MATRIX SAgDSTON~ 10,3 LB/G 4! 9,5 6,6 C3 2 990 DHMM ~'58 DF-- 1:857 OHM ** DATA FORMAT RECORD ** ENTRY BLOCKS TYPE SIZF ' o DATUM SPECIFICATION BLOCKS MNEM SERVICE SERVICE UNIT ID ORDER # EPT FT FLU OIL OH~ IbM OIL ILD DIL OHMM 7 SP OIL ~V 7 GR DIL GAPI 7 NPHI FDN PU 42 RHOB FDN G/C3 42 GR FDN GAPI 42 CAbI FDN IN 42 DRHO FDN G/C3 NRAT FDN NCNL FDN FCNL FDN LVP 010,N01 VERIFICATION ** DATA ** OEP? 8!36.5000 SFLU SP 39.2813 GR GR 100 1875 CALl NCNL 2122~00o0 FCNL DEPT 8700.0000 SFLU SP -37.2187 GR GR 100.1875 CALl NCNb 2122.0000 FCNb D£PT 8900 0000 SFLO Sp -36~5000 GR GR 109.0625 CALl NCNb 1978.0000 FCNL DEPT 8500.0000 SFLU SP -21 7656 GR G~ 82.'3125 CALl NCNb 2510.0000 FCNL DEPT 8~00,0000 SFLU SP 38.2187 GR GR 84 6875 CALI NCNb 2348:0000 FCNL DEPT 8300,0000 SFLU SP -43,2500 GR OR 75.6875 CALI NCNb 2614.0000 FCNL DEPT $~00,0000 SFLU Sp 24.9844 GR OR 90.6250 CALI NCNb 3150.0000 FCNL DEPT ~100,0000 SFLU SP -57,6250 GR OR 49,0625 CALl NCNb 2952.0000 FCNL OEPT 8000,0000 SFLU SP -20.5625 GR GR 120,8750 CALI NCNL 1908.0000 FCNL DEPT 7900.0000 SFLU SP -34.3438 GR GR 122.6250 CALl NCNb -999,2500 FCNL DEPT 7800.0000 SFLU LISTING 2 955~ Ib~ _ 2, ~03.1 ........ lbD ..2.,.68.~3.6~ ~.- ~ 0000 "~' ' ~'~ : -:'~ -"- ": -: ''~: '~- '~'': ':::": ':: ~: · :~ : - : tl.9656 DRH6 -~:'::::"'0'~'[~:8736~ NRAT:~' ~::' :<::: :3;: '6::': ~': 6 ~ 2.0 O00 5566 ~ L~ ~ : 2., ~-45 ? lED ..... .... 2 _1.875. 10. 2891 DRH0 :..~ _0'. t953:' NEAT::' _ :..~3:.,687E:._ :. ::. ' 488.5000 : ~;:.< -:_'::: ::.' _.' : : c ::: ::::::::::::::::::::::::::: ..... 4. 8906.. 82,3125 .NPHI 31:~..152]: RBOB:: .... 2,4L41 1I, 4141 · DRHO: ~O~::0 '.:}~' NRAT.>:~: :: ': ~':":'~ '~:~' '> ':' ' ~l].oooo ~ 9082. :I5~ -3,9551 ....... 3.74..61 - . ~,3159 DR~O ~-~0,.~.675.~ :.NRAT~.~ :3,~4.:4S ..... 75.68 .NPH.I 28,:.6621~-: RHDB_ - -.2, &2~19 ........... · ~0. 6256 .DRR:'0~': :'::: :~:L:.~':'~O':[~': ~"~:'::: NR~:AT:~::~ :: ::-: ~::' :'.'::?:'2:'~:' -<' :'. :' :-: - 3.2422 IbM. ..... :...3. 56:45 ...... I~D .:.:~, 90.62~0 NPH:~ ' ~ - <~< :~:::'~6~8~0:6'6:'.'~:.:~ :RR::0B':':~-:'"' :'::: :' ".' ~ ~: ::" ':: ' 11. 6797 ORHO . :. 0,:.0_430 NRA:.T..2.:7324-. ...... . 1055 ~ 0000 - - ~ ':';~ .:--: :':: ~'~ ':: ::: -<:' ~:~:'::':::'~ :.: ''~¥: ::::': ':'::" :' ~% :<< ~¥?: "~:::' ': ':- < ': ' : - 2~.6875- I5~:~< '' -''~:: 4~, 0625 NPHI :~ RHO:B .:: .7344- DR~O~ '~ ::' :':0:'~/05 ~:~'-'-':~::":-- 944' 5000 .6201 Ib~ L, 54i0 ..... -IbD _:,:_ ::-:-~I,463:8 · : .- · 120. 875~ NPH-I' ~: ~ :'-:47:~558~6 ~<: RHO~B '::: '::2:~:~3~20:::- :~ 9.7~8.8 _ DRHO - -0.:04:39 ..... -.N:RA~.:~ . 3.-82~62- -.: ~ 22,6250 NPHI ,.--99:~., 2..5.:00 RHOB 999~,.2..500 : - 10'2109 DR'~::0':- :' ::: 500:?~: :: -:'~: - :' :: :: '~9:99~i :0'::~:::-: ~'' : ' -999.250 bVP OIO.HO1 VERIFICATION LISTING SP GR NCNb DEPT SP NCNb DEPT SP NCNb DEPT SP NCNL DEPT SP GR NCNb DEPT SP NCNb DEPT SP NCNb DEPT SP G~ NCNb DEPT SP NCNb DEPT SP GR NCNL DEPT SP NCNb -43.5938 ~R 150,1250 CAL! -999,2500 FCNL 7Z~O!O000 SFLU 9 0625 GR 237 6250 CALI -999,2500 FCNL 00,0000 SFLU 7~48.]125 GR 166 1250 CALI -999:2500 FCNL 7500.0000 SFLU -40.0313 GR 103.5625 CALI -999.2500 FCNb 7400,0000 SFDU '5 3,0938 GR 104,8750 CALl -999,2500 FCNL 7300.0000 SFbU -45,5938 GR 139.8750 CALI -999,2500 FCNb 00,~000 SFLU 7~41. 813 GR 131.2500 CALI -999.2500 FCNL 7100,0000 SFLU 52,2500 GR ~25.0000 CALI -999,2500 FCNL 7000 0000 SFLU -62:5313 GR 134.6250 CALI -99g,2500 FCNL 6900,0000 SFLU -49.0000 GR 170.2500 CALI -999,2500 FChb 6800.0000 8FLU -20,7031 GR 14~,7500 CAbI -99 ,2500 FCNb 150 · 1250 1 O, 67 ~ 9 DRHO = _ :~.,999,250:0::- NR. AT -.999,2-500 -999.2500 2 '! 250 23';. 625.0 NPHI . ~..=999..250Q. RHOB ~:99..~9,250:0 10,187'5: DRHO- - -999.2500 2 . 8 516 Ib~ .: ~.:~ 2..8i45 !bD :;: 2...7480 16 6, ~ 250 N P~H::I I l, 00 O0. DRH. O --~. 999.2500 NRA:T:: ......... -999., 250.0. - 999,25 O0 ]. s43.o l 03.56~ 5 N PHI ~:~-:999.2500.: .:RH. OB..: -~.:: ,:999...:2:50~0 -999, 25 0 4 3-. 18 36 139,8750.- _NPHI .~:999.:2500 .... R. HOB ........ 79997.2500.:~ 10; 1562 :"D-R-'H:D. ' =~ ~'~ ~: 2':500'::`::: ~' :'~:~ ::":' :::< ::~'~ ~: -999.250 ~ .4199 1 3 .250'0- N 9.6875 DRHO .... .~, ,:999. ~500 :N:-RA ~: ' 999::; 25:.00 -999.25:00 ' ' :' ::- ':: :: ::.-.:< :.~<:: :":::: :::~:: ;;~:':"~]': ~::~::~:::: 125.00:00..NPHt .... ;:~'~"999"" 2500 ........ R:HOB- ..... ~.~::~99R,-- ~_ 2500 -999.250 ~ 34 ' u ~U':~" ':~:~~I:'' ~: ~' ~ ~:. ::~::~ ..'<:~: 11,2562 DRHO. ,~,999,.,2500 ....... NR:AT -999.,2.~00 - 999 · ~ 500'' ' :-.: : ~:~ <--:::~' :~:~: ':'::'<~:<';?~ <:~:<~:~ ?:~:: ~:' ~ ::::~: ~::'~:;'<'~:~' :~"".:~;~ ;:~:::-:'~::i~: .;~.~";~:'~;~: ~?~':~' .~'~ ':::f ;;:~:: ~;:~.: ~:.'.: 4.26t7 ~M:" 170 2500 NPHI. I0: 1328--DRH -999, 432' 9629 :IbM ......... 2~,~281,~ ..... ILD - .......... 2,3535 I ' 7500 ~ :NPH ~'='' '-"~= ~: :W ~;:~_ ~::j::.,...+. ,~:;, :~,:-~.~:'<;: .:. 9 , 6172 D RHO ..... ~9-99.,,~.25Q0.,-NRAT~ ....... .... 999~'2.500 LVP 010,~01 DEFT 670 SP 2 NCNb DEFT 660 8P -2 GR 25 NCNb -99 DEFT 650 SP -2 ER 7 NCNb -99 D£PT 640 5P -2 GR 9 NCNL -gg DEFT 6~0 SP 2 0~ 8 NCNb -99 DEFT 620 Sp GR 9 NCNb -99 DEFT 610 SP ER 8 NCNb -99 DEFT 6~0 SP 2 GE 8 NCNb -99 DEPT 5~0 SP 3 ER 9 NCNb -99 VERIFIC~*rION LISTING 0.0000 SFLD 2,2656 GR 1.8750 CALI 9.2500 FCNL 0,0000 SFLU 8.9687 GR 2.0000 CALl 9.2500 FCNL 0.0000 SFLU 9,1719 GR 4.0625 CALI 9.2500 FCNL 0,0000 SFbU 9.2]44 GR 7.6875 CALl 9,2500 FCNL 0,0000 SFLU 8.5156 GM 6.2500 CAI,! 9,2500 FCNL 0.0000 SFuU 2,0000 GR 3.4375 CALI 9.2500 WCNL 0.0000 SFLU 2500 GR '2500 CALI , 9.2500 FCNL 0,0000 SFLU 9,953! GE 3,7500 CALI 9.2500 FCND :0000 SFLU 3225 GR 8.6875 CALl 9,2500 FCNb DEFT 5~00,0000 SFLU Sp 47.2187 GR ER 207 5000 CALI NCNb -999~2500 FCNL DEPT 5700,0000 SFLU SP 50.2813 GR GR ~11.3750 CALl NCNb -999,2500 FCNL 'v 2. 9043 1LM~ 161 8750' NP. HI -~99.9.2500 RHOB 1 o: 3756 DRH'O · - ~; 99:~::2500': :'- :NR:AT -999.2500 5391 Ib~ : ~: ...2. 63.:67 ~ :tbD. : ~ 2.6:055~. 5 .ooo0 : : 99; 5oo 109 10, 500 -999. 74 ~ 0625 . NPHI- - .- -~~999..~5,00 RMOB · ':.~ ...... :~::,..2500 ........ lO 5313: DRHO ::'; 999:~:25'00' -999.2500 g27. 2637 IbM ::_: ~.339.8:~ .I.~D ~0.7422 DRHO :~ ~:~:.~.'999.2500. NRAT '999.2500 >'' ; ::: < ::;::: ~ ~ -:":: '::' ~':~::":: 1. 957:0 86.2500 NPHI ..... -9 99. 2500 .~: I0,6719 : DRH~-~: '999.2500 . 9~.2754 ~ :: : 2:. 3.08.6 10 . 7266 DR~O ~ :~-:999. 2500. ,.::- NRAT:~- . .... -999..2500: .:: <:~:.:,- 2.2 2 , 1641 I~.- : :.2.52.73~ ~0 5000 DRHO ~-.999.2500~ NRAT NP -99 500 RHOB -999 2500 6875 .... -HI ::~ ........ :9.-~,,.: ...... :: -: ........ ...- -999.2500 :~ 3. 4004 ~5~ .. 3.4766 i 0 7 · 500:0 NP~I::' :::~g'g:9:~ 0'::':: :: -99:g:.~':2: l t 9766 DRHO -_-:":999,.2500:: .NRAT ..... : ~--999:' 2500--.:.~ 3,7520: l 11,3750 NPHI ~-999,2500 RHOB _ .-999, 2500 . -999,2500 LVP 010,HO1 VERIFICATION DEPT 5~00 0000 SFLU SP 46:5938 GR GR 95 5000 CAbI NCNL -999:2500 FCNb DEPT 5500.0000 SFLU SP -51 0313 GR GR 102:1250 CALI NCNb -999.2500 FCNG DEPT 5.4~0.0000 SFbU SP 2.7813 GR GR 101 1250 CAbI NCNb -999~2500 ?CNL DEPT 5]00.0000 SFLU SP -53,9375 GR GR 84.X875 CALI NCNb -999.2500 FCNL DEPT 5~00 0000 SFLU SP -60:1875 GR GR 110.6875 CAGI NCNb -999.2500 ~CNL DEPT 5100.0000 SFLU SP 56,4688 GR GR ~04.4175 CALI NCNb -999,2500 FCNL DEPT 5000,0000 SFDU SP -55.9687 GP GR 92,0625 CALI NCNb -999.2500 FCNL DEPT 4900.0000 SFbU 5P -51.2187 GR GR 74,7500 CAbI NCNb -999.2500 FCNL DEPT 4800,0000 SFLU SP -65,4375 GR GR 105.4375 CALl NCNb -999.2500 FCNL D~PT 4700.0000 SFbU SP -51.2187 GR GR 96.0625 CALI NCNb 2442,0000 FCNL DEPT 4600.0000 SFLU SP -54.9500 GR GR 97.8125 CALI LISTING '5000' -NPHI-6777 IbM . . -,~.~ 2.9492: .IbD al ~' 3.0293 , . i0,8828 DRHO ..... --999.2500: .... NRAT: .... -'999.2.500 -999,2S00 - ~::' - ~ ' ~02,~250 NPHI ........ -- 999, 2-500 RHOB ..... ' 999"2500 ~0,8672 'DR~a - ~ ~'999~2'500~' ~R~T~-~- <~ 9"~;~.'~~ ~--' >~" - - I 01. 1250 N'PHI :~'~999.~25'0:r~<'::' ::R:HOB:~ ~::' ~:';~g99:~ ':':: :'-'; -: · ' 2. 4648 · ~,~406 -DRHO -999'2500 4.~3~ 104,4375 ..NPH:t .-: .... RHOB..:.~ ~: :. -99g,2:50:..0 ........ 12i 70-~1 -999.2500:. 2. 9687 --ISM ~. :.~3.:.-t93.::4:.~: .... 1bP .- 9~i0625 NPHI: ~'~:999:~;'25OO~';::-:'RH:OB~:.~ : .:':. :::'~ ~.: :::::::::: :::: ::::::::::-"~.:' -::~:: - : ':-.: ' t 2 625 DR flO ~--g 99.. 250.0 ..... -g9.9.2500 ~:~ ¢:..- -:~.:~:~'~:5;:. :::': :::::~'~'~::: ?:- .~::: :i 55:: ¢~:~ ~)D :~5<:- 4 ~5 :-~.::: :~(: <:: ',' :' < '- . ~o-o ]. e 027 74.7500 - ~2~28:~ 3 ~DRH:O~ ~ :~ O;;~::':::.NRA. T~:~: ::>: :~': :~'~'~ ':<:~::': ~:~:~::~~:<'9 ~ :: :::~ ::::: ::'~ :.. -999.2500 ' 403:;~ ;51'56 IbMN:PH.::~:: ~ - .1Q,D~.078.:.: .0.:~::: :RH:OB.~:.. :L :.:...:~ I:LD: ...::.. ~ 1.O.., :.023~ ..... .~ ~ O. 796g DRHO ~ .: <j 999,2500:. NRAT.:.: ".ggg~25:.O0 -999.2500 . ~ _-,:.:r: :~: ::.~:< :.~....::..~ ::~::::.. ::_:;: :: :::.: :.::,:.~:::~ ================================ /; : 3. 3672 IbM' :~: :::::'~:~' ~:': :.' :/~:::' :::<' :' :: <~: ::~:: ::' :;: -: · · 96,0625 NP. Ht · ..... ..RMOB .... : ...... 2,-289 t ........... I I. 8 359 DR'HO';': ': ?~:: ~ ::O::~i:':0~:-9'::~"<<::: :N:RA:~T:~:::;- :~' ::. :~<;:~:." ':: -. ::<.: '.: .::;:'>: ; ~:. ' 52~.00OO 3. 4336 I~M:_: .: 3-:.74:4t_:: -..~:bD .3..9Q04 97' 81~5-NPHI- ¢7:O~:~:r:~:'''~::,~":'~ ::~,:"~::"~:"~ ~:: :.: "::- - 11,9375 DRHO 0,0371 N.RAT ........... =3,9102 LVP 010,HO1 VERIFICATION LISTING NCNL DEPT NCNb OEPT SP GR NCNb DEPT GR NCNb DEPT GR NCNb DEPT SP GR NCNb GR NCNb DEPT NCNL DEPT SP G~ NCNb DEPT GR NCNb DEPT SP GR NCNb DEPT SP 2494.0000 FCNL 4500.0000 SFbU -63.7813 GR 79.B125 CALl 2502.0000 FCNL 4400.0000 6FLU -67.2500 GR 77.9375 CALI 2466.0000 FCNL 4300.0000 SFLU -25.5000 GR 7t.9375 CALl 2226.0000 FCNL 4~00.0000 SFLU 19.0469 GR 76.6250 CAbI 2510.0000 FCNb 4100.0000 SFLU -152.0000 GR 83.7500 CALl 2352.0000 FCNb 4000.0000 SFbU 36.0313 GR 90.2500 CAbI 2316.0000 FCNb 3900.0000 SFLU 167,5000 GR 72.8750 CALX 444.0000 FCNL 3800.0000 SFLU -71.6875 GR 65.8750 CibI 2396.0000 FCNL ]700.0000 SFLU -112.4375 GR 64.1250 CALI 2588.0000 FCNb ~600.0000 SFLU 113.0000 GR 83.3750 CALf 2298.0000 FCNL 3500,0000 SFLU -119.6875 GR 79,8125 NPHI 42,3828 RHOB= 1 i. 695~ ~.~H~~ : ~ '~ 3"~64:'~5 627.0000 .:- .~ : .. -: .:.- 7,371t I.b~ 7,4922- ~l_hD ~7,7-695 11.1953 DRHO .- .0,0244.. NRAT -3-,7949 624.0000 '~ ' ':' ~::: :- .:'_:?:~:~:.:~:' ~ ~- 3. 955i iSM ~ ::: >3~980>:> I'.~D-- ~- :.~<.'.:_ 1-.9375 NPHI 598 ~0000 4. 6758 IbM 629,500O 83:7500 ~PHI : 44.6289 RHOB: 2.3i.84 588.0000 5,76 56 I bM : =:6-:.. ~95 I bD -. -: 6.. 7..461 t 2,85~6 DR. HO O, 07.42 N. RA~ 3,709.0 54~.5000 ~' :::[:': :':::" -'~'::' ~ :' "': :' :' ':-:: ::[: 5. 8203 IbM. - 72.8750 NPHI 4~'0.176- .... RHOB: . 594.0000 5 3984 I b~ 5,726 6: IbD 6,.2852 ..... :'. :- ,6953 DRHO · .... 0,0-386~ .N.RAT : 4'0859 7 1680 tbM 7~:: -:I~: j: ~ :":: < ~'::' I0.910~ bgg:6 - ~g:~:' ''~ -:?; 5 6. 7461 I b M 7,8922. ,,,: ~ ~D -:._B,.6719 J;3 S6 ':::' ::- 13,2031 535.5OO0 58.9375 I 37.7188 NPHI .. . bVP 010.H01 VERIFICATION LISTING GR NCNb DEPT SP GR NCNb DEPT SP GR NCNb DEPT GR NCNb D£PT GR NCNL DEPT SD GR NCNb DEPT SP GR NCNb DEPT SP GR NCNL DEPT SP GR NCNb DEPT GR NCN5 DEPT SP GR NCNL DEPT 37.7188 CaLl 2544.0000 FCNL 3400,0000 SFGU -115.0625 GR 61.5625 CALf 2642.O000 FCNL 3300.0000 SFbU -102 ~125 GR 64~ 000 CALl 2572.0000 FCNL 3.2~0 0000 8FSU 0:2500 GR 46.0000 CALl 3134.O000 FCNL 3100.0000 SFLU -83 0000 GR 58:6875 CALl 2810.0000 FCNL 3~00.0000 SFLU 72.0000 GR 57.6875 CASI 2862.0000 FCNL 2900.0000 SFLU -40.4688 GR 60 8437 CALI 278@:0000 FCNL 2800.0000 SFLU -42.7500 GR 64 6875 CALI 2514:0000 FCNL 2700.0000 SFLU -44.7500 GR 65.0000 CALI 2742,0000 FCNL 2600.0000 SFLU -35.5000 ~R 56.1562 CALI 2854.0000 FCNL 2500.0000 SFLU -33.2500 GR 52.4688 CALI 2914.0000 FCNL 2400.0000 SFLU 8,5859 .~5M ..... ~ 9,,578i .... ILD .... 10,,1016 61.5625 NPHI'= ':~ ~ ' :4:g'~:: 2:': '~:RHOB: -- 9.4922 DRHO ~.:~ . 0-.0098: ..NRAT:.- ~..908'2::.~ 5000 ' - :'~-=-"' :""" ~':~:- - 599. "~'":':: ':''~:'--'~' - 64,500.0 ~ N. PHI ...... 4.8.-0957. RHOB~ :-.-...2.1699 ! 0 ~ 0469 :DRHO ;i:'NRAT::' :---' ::- . 9141 I.~M : ~::. ~:~ t2.:2869::: :'I~D <. ' ..- :.:,i1-.:4922 8~ ~, 5000 -: ';;~ :' >:: ===================== '::-' =:> ' -':: :: :~: :::::::::::::::::::::::::::::: ::::::::::::::::::::::::::: 760.0000: -: :::-" ::~ : : :'~:' ::-';::'~::':~:-":,:>'::':~::'~:':'::7 8437 NPH:I- := =: 4~..3848 ..... RHOB:- .... .... 2.1.680 LVP OIO.HOi VERIFICATION [,ISTING SP NCNL -63.2187 GR 51,0938 CALl 2840.0000 FCNL DEPT SP NCNL 2300.0000 SFLU -62,1875 GR 43.O938 CALl 2602.0000 FCNL DEPT 2237.5000 SFLU SP -68.5625 GR GR ]0 0938 CALI NCNL 1595~0000 FCNL ** FILE TRAILER FILE NAME :SERVIC.001 SERVICE NAME VERSION # : DATE : MAXIMUM L~NGTH : 1024 FILE TYPE NEXT FILE NAME 10,2734 700,0000 ! 5.0 t56 'I5:~ '''~: ~:'~ ii:i"'<~" i' ~' <~<i 3,0935 NPHt- .:. 38,1:3-48 .... g~iOB_: .:. 2~.07~8.t.-:-. 2 . ~ D~H,~ : '~. :~ ::::-':':~6:: :: ': :':3~-~3::75 6 9~. 5000 000 0 .IGM 20-00.0000 :t LD-.. 8.898 e . :. .;, :~ .;% ~.~.:~: 28 .5000 ...... "-"-~ ~':~:' ' ~' . ** TAPE TRAILER ** SERVICE NAME :SERVIC DATE :82/07/29 ORIGIN :1070 TAPE NAME x65351 CONTINUATION # :01 NEXT TAPE NAME : COMMENTS :TAPE COMMENTS ** REEL TRAILER SERVICE NAME :SERVIC DATE {82/07/29 ORIGIN : REEL NAME :REEL ID CONTINUATION ~ :01 NEXT REEL NAME COMMENTS :REEL COMMENTS ALASKA COMPUTING CENTER * ....... SCHLUMBERGER RECEIVED JAI',~ 2 6 ~998 Alaska Oil & Gas L;c~s, 6o~,~mission A.qchom§e COMPANY NAME : ARCO ALASKA, INC. WELL NAME : 1H-e8 FIELD NAME : KUPARUK BOROUGH : NORTH SLOPE STATE : ALASKA APZ NUMBER : 50-~29-20763-00 REFERENCE NO : 95064 LIS Tape Verification Listing Schlumberger Alaska Computing Center 23-JAN-1996 11:30 **** REEL HEADER **** SERVICE NAME : EDIT DATE : 96/01/23 ORIGIN : FLIC REEL NAME : 95~64 CONTINUATION # : PREVIOUS REEL : COMMENT : ARCO ALASKA INC, 1H-eS, KUPARUK RIVER UNIT, 50-029-2e763-e~ **** TAPE HEADER SERVICE NAME : EDIT DATE : 96/e1/23 ORIGIN : FLIC TAPE NAME : 95~64 CONTINUATION ~ : 1 PREVIOUS TAPE : COMMENT : ARCO ALASKA INC, 1H-08, KUPARUK RIVER UNIT, 5~-029-20763-e0 TAPE HEADER KUPARUK CASED HOLE WIRELINE 'LOGS WELL NAME: 1H-08 API NUMBER: ~002920763e0 OPERATOR: ARCO ALASKA, INC. LOGGING COMPANY: SCHLUMBERGER WELL SERVICES TAPE CREATION DATE: 22-JAN-96 JOB NUMBER: 95064 LOGGING ENGINEER: G.JOHNSON OPERATOR WITNESS: R.SMITH # SURFACE LOCATION SECTION: 14 TOWNSHIP: 12N RANGE: leE FNL: 888 FSL: FEL: 781 FWL: ELEVATION(FT FROM MSL e) KELLY BUSHING: 84.50 DERRICK FLOOR: 83.50 GROUND LEVEL: 54.5~ WELL CASING RECORD OPEN HOLE CASING DRILLERS CASING BIT SIZE (IN) SIZE (IN) DEPTH (FT) WEIGHT (LB/FT) 1ST STRING 7.000 8708.e 2ND STRING 3.500 8314.~ 3RD STRING 2.875 8543.0 PRODUCTION STRING CURVE SHIFT DATA - ALL PASSES TO STANDARD(MEASURED DEPTH) 26.~0 9.10 6.5e PAGE: LIS Tape Verification Listing Schlumberger Alaska Computing Center BASELINE CURVE FOR SHIFTS LDWG TOOL CODE: FDN LDWG CURVE CODE: GR RUN NUMBER: PASS NUMBER: DATE LOGGED: LOGGING COMPANY: BASELINE DEPTH GRCH 23-JAN-1996 1~:30 EQUIVALENT UNSHIFTED DEPTH TDTP 88888.e 88884.0 88884.0 8269.e 8265.e 826S.0 8242.S 824~.S 824[.S 8231.5 8228.5 8228.5 8217.0 . 82~6.0 82~6.5 8287.5 8287.5 8207.5 8[96.0 8[96.5 8[96.5 8[60.5 8[SS.e 81e6.5 8106.5 8S71.5 8~72.5 8S72.5 8e[e.e 8st[.s 8elt..~ 7994.e 7995.e 7983.e 7983.s 7972.0 7975.~ 7938.0. 7939.0 7939.~ 792[.5 7923.0 7922.5 7912.e 7913.0 7913.5 79e6.0 79e6.0 7894.e 7895.5 7895.5 7876.0 7878.5 7878.5 100.0 102.5 $ REMARKS: The depth adjustments shown above reflect cased hole GR to open hole FDN GR and cased hole SIGM to open hole GR. All o~her TDTP curves were carried wi~h %he SIGM shifts. $ $ PAGE: **** FILE HEADER **** FILE NAME : EDIT SERVICE : FLIC VERSION : eoicel DATE : 96/01/23 MAX REC SIZE : 1824 FILE TYPE : LO LAST FILE : FILE HEADER FILE NUMBER: LIS Tape Verificaf, ion Lis~,ing Schlumberger Alaska Cornpuf, ing Cent;er 23-JAN-1996 1[:30 EDITED CURVES Depth shifted and clipped curves for each pass in separate files. PASS NUMBER: DEPTH [NCREMENT: e.seee # FILE SUMMARY LDWG TOOL CODE START DEPTH STOP DEPTH GRCH 8295.e 7874.0 TDTP 8310.0 7874.e $ CURVE SHIFT DATA - PASS TO PASS(MEASURED DEPTH) BASELINE CURVE FOR SHIFTS LDWG CURVE CODE: PASS NUMBER: EQUIVALENT UNSHIFTED DEPTH BASELINE DEPTH $ REMARKS: This file con%ains TDTP Pass #1(Base pass #1). pass ~o pass shifts were applied %o ~his da~a. $ LIS FORMAT DATA No PAGE: ** DATA FORMAT SPECIFICATION RECORD ** SET TYPE - 64EB ** TYPE REPR CODE VALUE 1 66 0 2 66 0 3 73 96 4 66 1 5 66 6 73 7 65 8 68 0.5 9 65 FT ~1 66 12 68 13 66 0 14 6~ FT 16 66 0 66 0 L]:S Tape Verifica~,ion Lisf, ing Sch I umberger A I aska Compu*; ing Cenf, er ** SET TYPE - CHAN *~ 23-JAN-1996 11:30 PAGE: 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 5B0724 BB BBB BB B I ! [ 4 68 BBBBBBBBBB SIGM TDTP CU 5BB724 BB BBB BB B I [ [ 4 68 EIEIBBBBBBBO TPHI 'I'DTP PU-S 5BB724 BB BBB BB B I ! 1 4 68 BOBBB~BBBB SBHF TDTP CU 50~724 ee ~ee ee e I 1 I 4 68 eeeeeeeeee SBHN TDTP CU 5ee724 Be. Bee Be e t I I 4 68 eeeeeeeeee SIGC TDTP CU 5ee724 eB Bee ee B ! ! ! 4 68 eeeeeBeBee SIBH TDTP CU 5Be724 eB Bee ee B ! ! [ 4 68 eeBeeeeeee TRAT TDTP 500724 eB Bee BO 0 [ ! I 4 68 eeeeBeeeBB LCB1TDTP 5Be724 Be eBB ee e z z [ 4 6e eeeeeeeBBB SDSI TDTP CU 50~724 ee Bee Be e z I I 4 6e eeeeeeeBee BACK TDTP CPS 500724 BO eBB ee e z [ z 4 se eeeeeBeeBe FBAC TDTP CPS 5e0724 Be eob ee e I 1 z 4 6e eeBeeeeBBe TCAN TDTP CPS 5e0724 Oe Bee ee B i I Z 4 Se eeeeeeeeee TCAF TDTP CPS SB0724 ee Bee ee e 1 ! I 4 68 eeBeeeeeee TCND TDTP CPS 500724 eB Bee Be e 1 1 I 4 68 eeeeeBeeee TCFD TDTP CPS 5eB724 0~ eec ee e z I 1 4 68 eeeeBBeeBB TSCN 'I'DTP CPS 50B724 OB eBB eo B I [ 1 4 68 eeBeeeeeBe TSCF TDTP CPS SB0724 eB Bee ee B t t z 4 6e eeBeeBeeeB INND 'I'DTP CPS 5Be724 BO Bee eo B 1 I I 4 68 eeBBBBeeBe INFD TDTP CPS S00724 ee BBB ee B i 1 1 4 68 eeBeeeeBBB GRCH TDTP GAPI S0e724 ee Bee ee B 1 1 I 4 68 eeBeeeeeBB TENS TDTP LB 50e724 ee Bee ee B I I I 4 68 eBeBeeeeee CCL TDTP V B00724 ee eBB Be e [ [ Z 4 68 eBBBeeeeBB GR FDN GAPI SBe724 Be Bee Be e I I I 4 68 eeBeBeeeBB DATA DEPT. 835B.BOB SIGM.'I'DTP -999.2SB TPHI.TDTP -999.2SB SBHF.TDTP SBHN.TDTP -999.2SB SIGC.'I'DTP -999.25B SZBH.TDTP -999.250 TRAT.'I'DTP LC~I.TDTP -999.25B SDSI.TDTP -999.25~ BACK.TDTP -999.250 FBAC.TDTP TCAN.'I'DTP -999.250 TCAF.TDTP -999.25B TCND.TI)TP -999.250 TCFD.TDTP TSCN.'rDTP -999,25B TSCF.TDTP -999.25~ INND.TDTP -999.25B INFD.TDTP GRCH.TDTP -999.2Se TENS.TDTP -999.2S0 CCL.TDTP -999.25B GR.FDN DEPT. 784B.OeB SZGM.'I'DTP -999.25e TPHI.TDTP -999.25B SBHF.TDTP SBHN.TDTP -999.2SB SIOC.TDTP -999.25B SIBH.TDTP -999.25B TRAT.TDTP LCBI.'I'DTP -999.250 SDSI.TDTP -999.25B BACK.TI)TP -999.250 FBAC.TDTP TCAN.TDTP -999.25B TCAF.TDTP -999.2SB TCND.TDTP -999.25B TCFD.'FDTP TSCN.TDTP -999.25B TSCF.'I'DTP -999.250 INND.TDTP -999.25B INFD.TDTP GRCH.TDTP -999.250 TENS.TDTP -999.250 CCL.TDTP -999.25B GR.FDN -999.2S0 -999.250 -999.25B -999.2S0 -999.2S0 8B.S63 -999.25B -999.25B -999.250 -999.25B -999.250 ~27.B63 ** END OF DATA ** LIS Tape Verificaf, ion Lis~;ing Sch I umberger A ! aska Compu~,i ng Cen%er · ,~ FILE TRAILER ***= FILE NAME : EDIT .eO1 SERVICE : FLIC VERSION : eO1C~l DATE : 96/e1/25 MAX REC SIZE : [e24 FILE TYPE : LO LAST FILE : 23-JAN-1996 11:3e PAGE: **** FILE HEADER **** FILE NAME : EDIT .~02 SERVICE : FLIC VERSION : ~lCel DATE : 96/~1/23 MAX REC SIZE : 1e24 FILE TYPE : LO LAST FILE : FILE HEADER FILE NUMBER: 2 EDITED CURVES Depth shifted and clipped curves for each pass in separate files, PASS NUMBER: 2 DEPTH INCREMENT: FILE SUMMARY LDWG TOOL CODE START DEPTH STOP DEPTH GRCH 8295.0 7873.e TDTP 8310.0 7873.0 $ CURVE SHIFT DATA - PASS TO PASS(MEASURED DEPTH) BASELINE CURVE FOR SHIFTS LDWG CURVE CODE: GRCH PASS NUMBER: 1 EQUIVALENT UNSHIFTED DEPTH BASELINE DEPTH GRCH TDTP 88888.e 88885.0 88884.e 8297.5 8293.5 8293.5 8290.e 8289.5 8285.5 8273.5 8269.5 8269.5 8266.e 826S.S 8262.~ 8262.5 8259.5 8261.5 8259.~ 8258.5 8255.5 8257.5 8255.e LIS Tape Ver|fication Listing Schlumberger Alaska Computing Cente~ 8254.S 8252.~ 8253.5 8251.5 8250.S 8248.~ 8246.S 8244.S 8242.5 824e.5 8241.5 8239.5 8238.5 8237.e 8237.5 8236.5 8230.5 8229.e 8226.5 8226.e 8214.5 8214.e 8213.S 8213.5 8210.5 8211.~ 8209.5 82~9.5 82e5.5 8206.0 8201.5 8202.0 8197.5 8197.5 8194.5 8195.0 8193.S 8194.0 819~.5 8191.S 8189.S 819~.5 8186.5 8187.~ 8185.5 8186.0 8181.5 8182.5 8178.5 8179.0 8177.5 8179.0 8174.5 8174.S 8173.5 8174.~ 8170.5 8171.~ 8169.5 8171.5 8166.5 8167.~ 8165.5 8166.5 8162.5 8163.5 8161.5 8162.5 8157.5 8160.0 8154.5 8155.5 8153.5 8155.5 8150.5 8151.~ 8146.5 8147.S 8145.5 8147.5 8141.5 8144.0 8137.S 8139.5 8125.5 8127.5 8122.5 8123.5 8121.5 8122.5 8118.5 812~.~ 8117.5 8118.5 8114.5 8115.5 8113.5 8115.5 811~.5 8111.5 8106.5 81~8.0 8105.5 8107.5 8182.5 8103.5 8101.5 81e3.e 8098.5 8~99.5 23-JAN-1996 11:3~ PAGE: LTS Tape Verification Lis~,|ng Sch I umberger A I aska Computi ng Cen~er 8e94.5 8096.0 8090.5 8091.5 8085.5 8e87.e 8e81.5 8e82.5 8077.S 8079.e 8073.5 8e74.5 8070.5 8071.5 8~69.5 8~7~.e 8~66.5 8068.0 8065.5 8066.5 8062.5 8063.5 8e61.5 8~63.0 8~57.5 8~58.5 8053.5 8~54.5 8049.5 8~51.0 8045.5 8~47.e 8~4~.5 8~43.5 8~37.5 8039.5 8~22.5 8023.5 8021.5 8~22.5 8018.5 8020.0 8014.5 8~15.5 8~13.5 8014.5 8~09.5 8~11.0 80~5.S 80~6.5 8001.5 8~02.~ 7997.5 7998.5 7993.S 7994.5 7989.5 7991.e 7985.5 7987.0 7966.5 7967.5 7962.5 7964.0 7958.5 7959.e 7954.5 7956.0 7950.5 7951.5 7946.5 7948.e 7945.5 7946.0 7942.5 7943.5 7941.5 7942.5 7937.5 7938.5 7934.5 7935.5 7933.5 7935.5 7930.5 7932.~ 7929.5 7931.5 7925.5 7926.5 7917.5 7918.5 7913.5 7914.0 7910.5 7912.e 79e9.S 7910.5 7906.5 7907.S 7905.S 7906.0 7902.5 7904.0 7897.5 7898.5 7893.5 7893.5 23-JAN-S996 11:3~ PAGE: LIS Tape Verificaf, ion Lis~,ing Sch I umberger A I aska Compu%i ng Cenf, er 23-JAN-1996 11:30 $ REMARKS: This file contains TDTP Pass #2(Base pass #2). The depth shifts shown above relecC GRCH pass #2 ~o GRCH pass #1 and SIGM pass #2 ~o SIGM pass #1. $ LIS FORMAT DATA PAGE: DATA FORMAT SPECIFICATION RECORD ** SET TYPE'- 64EB ** TYPE REPR CODE VALUE 1 66 0 2 66 ~ 3 73 92 4 66 1 S 66 6 73 7 65 8 68 0.S 9 65 FT 12 68 13 66 0 14 65 FT 15 66 68 16 66 1 0 66 I ** SET TYPE - CHAN ** NAME SERV ID UNIT SERVICE API ORDER # LOG API APl APl FILE NUMB NUMB TYPE CLASS MOD NUMB SAMP ELEM SIZE REPR CODE PROCESS (HEX) DEPT SIGM TPHI SBHF SBHN SIGC SIBH TRAT LCO1 SDSI BACK FBAC TCAN TCAF TDTP TDTP TDTP TDTP TDTP TDTP TDTP TDTP TDTP TDTP TDTP TDTP TDTP FT 50~724 eO CU 500724 Be PU-S 50~724 Be CU 500724 Be CU 5~0724 00 CU 500724 ~0 CU 5ee724 eo 50e724 00 50e724 eo CU S00724 00 CPS 5ee724 00 cps 5e0724 00 CPS 50e724 Be CPS S~0724 00 ~0~ 0~ ~ 2 I 1 0~0 ~ 0 2 1 ~00 00 0 2 1 1 ~0 0~ ~ 2 1 1 0~ 00 0 2 1 ~00 0~ 0 2 1 00~ 0~ 0 2 1 0~0 ~ 0 2 I 1 00e 00 e 2 I 1 000 ~0 0 2 I 1 e00 eO 0 2 I 1 0e0 00 0 2 1 1 000 00 0 2 I 1 000 Be 0 2 1 I 68 68 68 68 68 68 68 68 68 68 68 68 68 68 LIS Tape Verification Listing Schlumberger Alaska Computing Center 23-JAN-J996 1[:3e PAGE: NAME SERV UNIT SERVICE AP1 AP1 AP1 AP1 FILE NUMB NUMB SIzE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUMB SAMP ELEM CODE (HEX) TCND TDTP CPS 5Be724 ee BBB Be B 2 ! I 4 68 eBBBBeeBBO TCFD TDTP CPS S0~724 ~ ~B ~ 0 2 I ! 4 68 BBBB~BB~BB TSCN TDTP CPS 5B~724 ~B ~B~ ~ B 2 1 I 4 68 ~BBB~BBO~ TSCF 'FDTP CPS 5BB724 B~ 0~ ~e B 2 1 I 4 68 ~ee~B~oeo INND TDTP CPS 5B~724 Be BBO B~ B 2 1 ! 4 68 ~BBBOBBOeB INFD TDTP CPS 5e~724 B~ eBB e~ B 2 i ! 4 68 B~BBBBOBB TENS TDTP LB 5ee724 eo eBB Be e 2 I ! 4 68 BBBOBeBOBe eCL TDTP V 5e0724 ee eee ee B 2 t ! 4 68 BBeBeeBBBB ** DATA ** DEPT. 83B6.BBB SIGM.TDTP 29.379 TPHI.TDTP 71.242 SBHF.TDTP SBHN.TDTP 80.678 SIGC.TDTP e.eeB SIBH.TDTP 286.7B6 TRAT.TDTP LCB1.'rT)TP 3.627 SDSI.TDTP B.727 BACK.TDTP 85.6B2 FBAC.TDTP TCAN.TDTP 10231.494 TCAF.TDTP 2457.127 TCND.TDTP 9868.791 TCFD.TDTP TSCN.TDTP 1238.039 TSCF.TDTP 341.3~9 INND.'rDTP 189S.878 INFD.'rDTP GRCH.TDTP -999.25~ TENS.TDTP 1055.~0B CCL.'rDTP 0.~ DEPT. 7873.BBB SIGM.'I'DTP 47.563 TPHI.'rDTP 75.971 SBHF.TDTP SBHN.TDTP 61.12B SIGC.'rDTP B.196 SIBH.TDTP 18S.B70 TRAT.TDTP LCO1.TDTP 3.976 SDSI.TDTP 1.B21 BACK.TDTP lel.607 FBA¢.TDTP TCAN.TDTP 16S38.645 TCAF.TDTP 38S4.625 TCND.TDTP 11743.811 TCFD.TDTP TSCN.TDTP 899.989 TSCF.TDTP 226.341 INND.TDTP 1878.705 INFD.TDTP GRCH.TDTP -999.250 TENS.TDTP lelS.eee CCL.TDTP 0.e~0 ** END OF DATA ** 65.451 2.345 25.5B6 1599.37B 182.893 52.181 1.8~5 18.820 2529.239 256.314 **** FILE TRAILER **** FILE NAME : EDIT SERVICE : FLIC VERSION : BBlCB1 DATE : 96/B1/23 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : LIS Tape Verification L|stJng Schlumberger Alaska Comput|ng Center **** FILE HEADER **** FILE NAME : EDIT .0e3 SERVICE : FLIC VERSION : 0~1C01 DATE : 96/01/23 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : 23-JAN-1996 11:30 PAGE: 10 FILE HEADER FILE NUMBER: 3 EDITED CURVES Depth sh|fted and clipped curves for each pass in separate files. PASS NUMBER: 3 DEPTH INCREMENT: e.seee # FILE SUMMARY LDWG TOOL CODE START DEPTH STOP DEPTH GRCH 8295.0 7853.0 TDTP 831~.0 7853.0 $ CURVE SHIFT DATA - PASS TO PASS(MEASURED DEPTH) BASELINE CURVE FOR SHIFTS LDWG CURVE CODE: GRCH PASS NUMBER: EQUIVALENT UNSHIFTED DEPTH BASELINE DEPTH GRCH TDTP 88888.e 88885.e 88883.5 8297.5 8293.e 8277.5 8273.e 8273.5 827e.0 8269.5 8265.5 8265.5 8261.e 8262.5 8259.5 8261.5 8257.0 8258.5 8255.5 8257.5 8254.0 8254.5 8252.e 8253.5 8251.0 82S0.5 8247.5 8249.5 8247.5 8246.5 8244.S 8245.S 8242.5 8241.5 8238.5 8237.5 8235.e 8233.5 8230.5 8230.5 8228.5 8226.5 822S.0 LIS Tape Veri~|cation Listing Schlumberger Alaska Computing Center 23-JAN-1996 11:30 PAGE: 11 8222.5 8221,5 8221,5 8218.5 8218,5 8217,0 8217.5 8216,e 8214,5 8213,e 8213,5 8212,5 8210,5 8210.~ 8209,5 82e9,~ 8205,5 82~5,~ 8201,5 8201,5 8197,5 8197,5 8194,5 8194,0 8193,5 8192,5 8190,5 8190,5 8189,5 8189,0 8186.5 8187.e 8185.5 8185,5 8182,5 8183,e 8181,5 8181,5. 8178,5 8178,5 8177,5 8178,0 8174,5 8174,0 8173,5 8174,0 8170,5 8171,0 8169,5 8170.5 8166,5 8167.e 8165.5 8166.0 8162,5 8163,5 8161,5 8162,5 8157,5 8159,5 8154,5 8155,5 8153,5 8155,0 815~,5 8151,0 8149,5 8150,5 8146.5 8147.5 8130.5 8131,5 8118.5 812e.0 8117.5 8118.5 8114.5 8115.~ 8113.5 8115,0 8109,5 811e,0 8105,5 81~6,0 8101,5 8102,5 8097,5 8e99.0 8093.5 8~94.5 8090,5 8e91.0 8089.5 809e.0 8086,5 8e86,5 8085.5 8e85,5 8082,5 8e82.5 8081.5 8081.5 8078,5 8~79,e 8077.5 8078.0 8074,5 8e74.5 8070.5 8~71.0 LIS Tape Verification Listing Schlumberger Alaska Computing Center 23-JAN-1996 11:30 PAGE: 12 8057.5 8e58.e 8054.5 8053.5 8053.5 805e.5 8051.5 8042.5 8043.5 8~38.5 8~39.~ 8~37.5 8~38.~ 8e34.5 803S.S 8030.5 8026.5 8e27.S 8021.5 8e22.e 8018.5 8~19.S 8014.S 8elS.e 8005.5 80e5.5 8002.5 8ee3.e 8001.5 80el.0 7998.5 7999'.s 7997.5 7998.e 7977.5 7978.~ 7973.5 7975.e 7965.5 7965.5 7962.5 7963.s 7958.5 7959.0 7957.5 7957.5 7954.5 7955.5 7953.5 7954.s 7937.5 7938.5 7933.5 7935.e 7929.5 7930.5 7921.5 7922.5 7917.5 7918.0 7897.5 7898.5 7893.5 7896.0 10e.0 lel.e 102.s $ REMARKS: This file contains Borax pass #! of the TDTP. The depth correction shown above reflect Borax pass #1GRCH to base pass #1GRCH and Borax pass #! SIGMA to base pass #1 SIGMA. All other TDTP curves were carried with the SIGMA shifts. $ LIS FORMAT DATA LIS Tape Verification Listing Schlumberger Alaska Computing Center 23-JAN-1996 11:30 DATA FORMAT SPECIFICATION RECORD SET TYPE - 64EB ** TYPE REPR CODE VALUE 1 66 0 2 66 3 73 92 4 66 6 66 6 73 7 8 68 9 66 FT 12 68 13 66 14 65 FT 15 66 68 16 66 ~ 66 1 PAGE: 13 SET TYPE - CHAN ** NAME SERV UNIT SERVICE AP! API AP[ API FILE NUMB NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUMB SAMP ELEM CODE (HEX) DEPT FT BOe724 00 e00 SZGM 'I'DTP CU 60e724 ee e00 TPHI TDTP PU-S S~724 Oe ~0 SBHF TDTP CU 50~724 ~0 000 00 ~ 3 1 I 4 68 00000000~ SBHN 'I'DTP CU 6~724 ~0 e~O S[GC TDTP CU 500724 ee eeo 0~ e 3 i I 4 68 00000eoeeo SIBH TDTP CU 50~724 00 00~ 00 ~ 3 I 1 4 68 00~000~0~0 TEAT TDTP 600724 ee e00 LC01TDTP 600724 ee eoe SDS[ TDTP CU 50~724 ~0 e00 BACK 'I'DTP CPS 5ee724 00 Eleo 00 0 3 1 1 4 68 00eooeooee FBAC TDTP CPS 5~e724 00 00e TCAN TDTP CPS 5e~724 ee eeo TCAF TDTP CPS 500724 00 000 TCND TDTP CPS 500724 00 ~ TCFD TDTP CPS 5ee724 oe 0e0 eo 0 3 I I 4 68 00eooooooe TSCN TDTP CPS 60e724 00 eeo TSCF TDTP CPS 6ee724 eo 000 eo 0 3 1 I 4 68 oeeeoe0000 INND TDTP CPS 60e724 eO 0e0 Oe e 3 1 1 4 68 oeooeoeo~o INFD TDTP CPS 60e724 ee ~oe eo e 3 1 I 4 68 00000ee000 GRCH TDTP GAPI 5~0724 ~0 000 0~ 0 3 I I 4 68 0~0~000~00 TENS TDTP LB 500724 eO 0e0 CCL TDTP V 5~0724 eO ~e~ LIS Tape Verification Listing Schlumberger Alaska Computing Center DATA DEPT. 83es.soe SIGM.'rDTP SBHN.'rDTP le3.786 SIGC.TDTP LCO1.TDTP 2.896 SDSI.TDTP TCAN.TDTP 6968.471 TCAF.TDTP TSCN.TDTP 843.954 TSCF.TDTP GRCH.TDTP -999.2S~ TENS.TDTP DEPT. 7854.00~ SIGM.TDTP SBHN.TDTP -999.250 SIGC.TDTP LCB1.TDTP -999.25e SDSI.TDTP TCAN.I'DTP -999.25e TCAF.'rDTP TSCN.TDTP -999.25e TSCF.I'DTP GRCH.TDTP 63.781 TENS.TDTP 23-JAN-1996 11:30 29.681 TPHI.TDTP e.eeO SIBH.TDTP e.657 BACK.TDTP 22e7.825 TCND.TDTP 291.38~ INND.'I'DTP 113e.~ CCL.TDTP 46.8S6 4e6.788 79.14S 59e8.862 1877.115 e.O~ -999.250 TPHI.'rDTP -999.25e -999.250 SIBH.TDTP -999.2Se -999.25e BACK.TDTP -999.250 -999.25~ TCND.'I'DTP -999.25e -999.25e INND.TDTP -999.25e -999.25~ CCL.TDTP -999.2Se SBHF.TDTP TRAT.TDTP FBAC.TDTP TCFD.TDTP INFD.TDTP SBHF.TDTP TRAT.I'DTP FBAC.TDTP TCFD.TDTP INFD.TDTP PAGE: 14 88.178 1.828 41.831 1290.6S0 191.129 -999.250 -999.250 -999.250 -999.25~ -999.250 ** END OF DATA ** **** FILE TRAILER' FILE NAME : EDIT .0e3 SERVICE : FLIC VERSION : 0~1Cel DATE : 96/~1/23 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : **** FILE HEADER FILE NAME : EDIT SERVICE : FLIC VERSION : eOlCel DATE : 96/el/23 MAX REC SIZE : le24 FILE TYPE : LO LAST FILE : FILE HEADER FILE NUMBER: 4 EDITED CURVES Depth shifted and clipped curves PASS NUMBER: 4 DEPTH INCREMENT: 0.50~0 FILE SUMMARY LDWG TOOL CODE START DEPTH for each pass STOP DEPTH GRCH 8295.0 785e.0 TDTP 8310.0 7850.0 in separate files. LIS Tape Verification Listing Schlumberger Alaska Computing Center 23-JAN-1996 11:39 CURVE SHIFT DATA - PASS TO PASS(MEASURED DEPTH) BASELINE CURVE FOR SHIFTS LDWG CURVE CODE: GRCH PASS NUMBER: I E~UIVALENT UNSHIFTED DEPTH, BASEL[NE DEPTH GRCH TDTP 88888.9 88887.9 88884.S 8297.5 8294.9 8293.5 8299.9 8289.5 8285.5 8285.5 8281.e 8281.5 8278.9 8277.5 8274.9 8273.5 8279.5 8269.5 8266.9 8261.5 8258.9 8257.5 8255.5 8246.s 8245.5 824s.5 8243.5 8242.5 8249.5 8237.5 8234.9 8233.5 8239.9 8239.5 8228.5 8229.5 8227.9 8226.5 8225.5 8225.5 8223.9 8221.5 82[9.5 8218.5 8217.5 8217.5 8216.5 8214.5 8215.9 8213.5 8213.9 8219.5 8211.9 8299.5 8299.9 8296.5 8296.5 8295.5 8295.5 8291.5 8292.9 8198.5 8198.5 8197.5 8198.9 8194.5 8195.9 8195.5 8193.5 8199.5 8191.5 8189.5 819~.9 8185.5 8187.5 8181.5 8183.0 8178.5 8179.5 8174.5 8174.~ 8170.5 8171.5 8169.5 8171.0 8166.5 8167.5 8165.5 8166.5 8162.5 8164.0 PAGE: 15 LIS Tape Veri~icat|on L|st|ng Schlumberger Alaska Comput|ng Cen~er 23-JAN-1996 PAGE: 16 8161.5 8163.e 81S7.S 8159,5 8154.5 8156.e 81S0.5 8151.S 8149.5 8151.5 8146.5 8147.S 814S.S 8147.e 8142.5 8144.0 8141.5 8143.5 8138.5 814e.~ 8137.S 8139.S 8134.5 8135.5 8133.S 8136.e 8130.5 8132.0 8129.S 8131.0 8125.5 8127.5 8122.5 8124.e 8121.5 8122.5 8118.5 8119.5 8117.S 8118.5 8114.5 8115.0 8113.5 811S.e 8098.5 8099.e 8097.S 8099.e 8094.5 8096.0 8093.5 8~94.5 8090.S 8091.0 8089.5 8e91.~ 8086.5 8086.5 8085.S 8086.e 8082.S 8083.5 8081.5 8~81.5 807~.5 8~71.5 8069.5 8~71.0 8066.5 8068.0 8~62.5 8063.5 8061.5 8~63.5 8058.S 8059.5 8057.5 8~59.0 8054.5 8056.0 8~53.5 8~53.5 8049.5 8049.5 8~46.5 8048.0 8~45.5 8~46.~ 8042.5 8043.S 8~41.5 8e42.5 8038.5 8040.0 8034.5 8035.5 8021.5 8~24.0 8013.5 8014.5 8009.5 8011.0 8005.5 8~06.0 8~01.5 8001.5 7997.5 7998.0 LIS Tape Verification Listing Schlumberger Alaska Comput|ng Center 23-JAN-1996 11:3~ 7993.5 7994.~ 7989.5 7991.5 7985.5 7987.5 7982.5 7983.5 7981.5 7982.5 7978.5 7980.e 7977.5 7978.5 7974.5 7976.~ 797~.$ 7971.5 7961.5 7963.0 7958.5 7959.5 7957.5 7959.5 7954.5 7956.e 7953.5 7956.~ 795~.5 7952.0 7949.5 7952.~ 7946.5 7947.5 7934.5 7935.5 7933.5 7935.5 793B.5 7932.0 7929.5 7930.5 7925.5 7926.5 7921.5 7923.0 7918.5 792e.0 7917.5 7919.~ 7914.5 7915.5 7913.5 7914.5 79e9.5 79e9.5 79~5.5 7905.0 7901.5 7899.5 7897.5 7896.0 1~.0 1~1.~ 98.5 REMARKS: This file contains Borax pass #2 of the TDTP. The depth correct|on shown above reflect Borax pass #2 GRCH to base pass ~1GRCH and Borax pass #2 SIGMA to base pass #1 SIGMA. All other TDTP curves were carried with the SIGMA shifts. $ # LIS FORMAT DATA PAGE: 17 DATA FORMAT SPECIFICATION RECORD SET TYPE - 64EB ** TYPE REPR CODE VALUE 1 66 0 2 66 0 3 73 92 LIS Tape Verification Listing Schlumberger Alaska Computing Center 23-JAN-1996 11:30 PAGE: 18 TYPE REPR CODE VALUE 4 66 5 66 6 73 7 65 8 68 9 65 FT 11 66 11 12 68 13 66 14 65 FT 15 66 68 16 66 1 ~ 66 I SET TYPE - CHAN ** NAME SERV UNIT SERVICE AP1 APl AP1 AP1 FILE NUMB NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUMB SAMP ELEM CODE (HEX) DEPT FT 5e0724 De Dee eo e 4 1 I 4 68 eeooe00000 SIGM TDTP CU 5e0724 De ~ee TPHI TDTP PU-S 5~0724 00 ~00 SBHF TDTP CU 500724 ~0 ~0~ 0~ ~ 4 1 I 4 68 000000~000 SBHN 'rDTP CU 500724 ~0 000 00 0 4 i I 4 68 00~0~0~0~0 SIGC TDTP CU 5e0724 De eeo 00 0 4 SIBH TDTP CU 500724 De 0e0 TRAT TDTP 500724 00 e00 LCel TDTP 5e0724 eD 000 SDSI TDTP CU 50~724 00 000 00 0 4 BACK TDTP CPS 5e0724 ee 000 oe e 4 I I 4 68 eoeoe00000 FBAC TDTP CPS 500724 00 e00 eD 0 4 1 I 4 68 eeooeoe000 TCAN TDTP CPS 500724 00 eeo 00 0 4 TCAF TDTP CPS 50~724 00 ~0 TCND TDTP CPS 5e0724 ~0 0e0 00 e 4 I I 4 68 cee0000000 TCFD TDTP CPS 5~0724 00 ~e TSCN TDTP CPS 5ee724 ee eee ee e 4 TSCF 'rDTP CPS 50e724 00 e00 eD e 4 I 1 4 68 oeeoeooooe INND TDTP CPS 5ee724 e~ e00 INFD TDTP CPS 500724 00 eee ee 0 4 1 1 4 68 0000000e00 GRCH TDTP GAPI 5e0724 00 00e eD e 4 ! I 4 68 oeooooooeo TENS TDTP LB 500724 00 00e 00 0 4 CCL TDTP V 500724 00 eoe 00 0 4 ** DATA DEPT. 8506.5e0 SIGM.'rDTP 31.618 TPHI.TDTP 94.124 SBHF.TDTP SBHN.TDTP 99.739 SIGC.TDTP 0.0e0 SIBH.TDTP 385.760 TRAT.TDTP LCO1.TDTP 4.435 SDSI.TDTP 0.665 BACK.TDTP 80.139 FBAC.TDTP TCAN.TDTP 84~2.842 TCAF.TDTP 1865.670 TCND.TDTP 7062.253 TCFD.TDTP 85.04e 2.630 51.571 1206.335 LIS Tape Verifica%ion Lis%ing Schlumberger Alaska Compu%ing Cen%er 23-JAN-1996 11:30 TSCN.TDTP 1847.204 TSCF.TDTP 236.121 INND.TDTP 2182.588 GRCH.TDTP -999.25~ TENS.TDTP 1148.eee CCL.TDTP 0.0~0 DEPT. 7848.500 SIGM.TDTP 47.790 TPHI.TDTP 86.909 SBHN.TDTP 66.e81 SIGC.TDTP e.eee SIBH.TDTP 218.433 LCel.TDTP 4.414 SDSI.TDTP e.967 BACK.TDTP 93.597 TCAN.TDTP 14278.992 TCAF.TDTP 3362.25S TCND.TDTP 1~3~1.2S8 TSCN.TDTP 794.691 TSCF.TDTP 188.858 INND.TDTP ~8~9.069 GRCH.TDTP -999.258 TENS.TDTP le75.eee CCL.TDTP ~.0~'~ END OF DATA INFD.TDTP SBHF.TDTP TRAT.TDTP FBAC.TDTP TCFD.TDTP INFD.TDTP PAGE: 19 198.366 58.85! 1.942 28.580 2282.059 258.676 *=** FILE TRAILER ***, FILE NAME : EDIT .ee4 SERVICE : FLIC VERSION : eelCO! DATE : 96/01/23 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : ***= FILE HEADER **** FILE NAME : EDIT SERVICE : FLIC VERSION : eelCel DATE : 96/~1/23 MAX REC SIZE : ~824 FILE TYPE : LO LAST FILE : FILE HEADER FILE NUMBER: 5 EDITED CURVES Dep%h shif%ed and clipped curves for each pass in separa%e files. PASS NUMBER: 5 DEPTH INCREMENT: 0.Se00 FILE SUMMARY LDWG TOOL CODE START DEPTH STOP DEPTH GRCH 8295.e 7850.0 TDTP 8318.~ 7850.0 $ CURVE SHIFT DATA - PASS TO PASS(MEASURED DEPTH) BASELINE CURVE FOR SHIFTS LDWG CURVE CODE: GRCH PASS NUMBER: 1 LIS Tape Verificat|on Listing Schlumberger Alaska Comput|ng Center 23-JAN-1996 11:30 PAGE: 20 BASELINE DEPTH 88888.e 8297.5 8277.5 8273.5 8269.5 8265.5 8262.5 8261.5 8257.5 8253.5 825~.5 8249.5 8246.5 8245.5 8242.5 8241.5 8238.5 8237.5 8233.5 8230.5 8229.5 8226.5 8225.5 8222.5 8221.5 8217.5 8214.5 8213.5 821~.5 82~6.5 8205.5 82e2.5 8201.5 8194.5 8193.5 819e.5 8189.5 8185.5 8181.5 8178.5 8177.5 8174.5 8173.5 8170.5 8169.5 8165.5 8162.5 8161.5 8158.5 8157.5 8154.5 .......... EQUIVALENT UNSHIFTED GRCH 88886.0 8260.5 8248.5 8245.0 8241.0 8237.5 8229.5 8226.0 8222.5 8214.5 8211.0 82e7.5 8203.0 8195.0 8192.0 818e.0 8175.5 8172.0 8164.0 8160.5 8156.5 *I'DTP 88885.0 8294.5 8274.5 827~.~ 8266.5 8262.e 8259.5 8255.5 8252.e 8248.0 8243.~ 8239.e 8235.5 8231.e 8227.~ 8223.5 8221.0 8217.5 8214.e 8206.~ 8202.5 8194.5 8191.5 8187.5 8183.e 8179.5 8175.e 8171.5 8167.0 8162.5 8159.5 DEPTH LIS Tape Veriflcat|on Listing Schlumberger Alaska Computing Center 23-JAN-1996 11:3e PAGE: 21 8153.5 815e.5 8152.0 8149.5 8145.5 8142.5 8144.e 8141.5 8138.5 814~.5 8129,5 8125.5 8121.5 8118.5 812~.5 8117.5 8114.5 8116.0 8113.5 81~9.5 8098.5 810~.0 8e94.5 8e96.5 8093.5 8~90.5 8e92.0 8e89.5 8e86.5 8e87.5 8085.5 8~82.5 8~83.5 8e81.5 8078.5 8~8~.~ 8077.5 8e73.5 807~.5 8072.~ 8e69.5 8066.5 8068.5 8~65.5 8062.5 8064.0 8~61.5 8057.5 8053.5 8021.5 8017.5 8e~5.5 8eel.5 799e.5 7992.0 7986.5 7987.5 7982.5 7984.0 7973.5 7969.5 7966.5 7968.e 7962.5 7964.5 7958.5 7960.0 7957.5 7946.5 7948.0 7942.5 7943.5 7937.5 7934.5 7935.5 7933.5 7930.5 7932.0 7929,5 8155.5 8150.5 8148.e 8144.e 8132.5 8128.e 8123.5 8119.5 8116.e 8111.5 8095.5 8092.0 8~87.~ 8e84.5 8~8~.e 8e75.5 8070.5 8067.5 8o64.e 8059.5 8056.e 8024.e 8~18.5 80~6.5 8ee2.e 7974.5 7970.5 7957.5 7939.e 7935.0 7930.5 LIS Tape Verification Listing Schlumberger Alaska Computing Center 23-JAN-1996 11:30 7925.5 7917.5 7913.5 7909.5 7905.5 7901.5 7897.5 REMARKS: 7927.0 7919.0 7916.0 7911.0 7901.5 7896.5 99.0 This file contains Borax pass #$ of the TDTP. The depth correction shown above reflect Borax pass #3 GRCH to base pass #1GRCH and Borax pass #3 SIGMA to base pass #1 SIGMA. All other TDTP curves were carried with the SIGMA shifts. $ LIS FORMAT DATA PAGE: 22 DATA FORMAT SPECIFICATION RECORD ** SET TYPE - 64EB ** TYPE REPR CODE vALUE 1 66 2 66 3 73 92 4 66 5 66 6 73 7 65 8 68 0.5 9 65 FT 11 66 11 12 68 13 66 14 65 FT 1G 66 68 16 66 1 0 66 1 SET TYPE - CHAN ** NAME SERV UNIT SERVICE AP1 AP1 AP1 AP1 FILE NUMB NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUMB SAMP ELEM CODE (HEX) DEPT FT 500724 00 000 00 0 5 1 1 4 68 0000000000 SIGM TDTP CU 500724 00 000 00 0 5 1 1 4 68 0000000000 TPHI TDTP PU-S 500724 00 000 00 0 5 1 1 4 68 0000000000 SBHF TDTP CU 500724 00 000 00 0 5 1 1 4 68 0000000000 LIS Tape Verification Listing Schlumberger Alaska Computing Center 23-JAN-1996 11:30 PAGE: 23 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) SBHN 'r'DTP CU 50e724 00 eE~ ee 0 5 I Z 4 68 SIGC TDTP CU S00724 Oe oee ee e 5 ! I 4 68 SIBH TDTP CU 5~724 ~e e~ 0~ 0 S 1 ! 4 68 TRAT TDTP 5~0724 Oe 0~0 ~ e 5 1 I 4 68 LC01 TDTP 5e0724 ~0 0e0 Oe ~ 5 1 ! 4 68 eoeooooeee SDSI TDTP CU 5e0724 eO eee oe e s 1 1 4 68 BACK TDTP CPS 58~724 00 0~e ~ e 5 1 I 4 68 oeeeoeoeoe FBAC TDTP CPS 588724 ee eee e0 0 s 1 ! 4 68 eeeeee~eee TCAN TDTP CPS 508724 ee 080 ee e s ! I 4 68 eeeeeeeeee TCAF TDTP CPS 508724 ee eee ee e s 1 ! 4 68 ~eeeeeeeee TCND TDTP CPS 588724 ee eee ee e s 1 I 4 68 e~e~e~eee TCFD TDTP CPS 588724 00 eee ~e e s 1 ! 4 68 e~e~eeeeee TSCN TDTP CPS 588724 ee cee ~0 0 5 1 I 4 68 eee~eeeeee TSCF TDTP CPS 588724 ee eee ee e s t I 4 68 eeeeeeeeee INND TDTP CPS 588724 ee eee ee e s 1 i 4 68 eeeeeeeeee INFD TDTP CPS 588724 ee eec 08 e 5 1 I 4 68 eeeeeeeeee ORCH TDTP GAPI 588724 ee eee ee e s 1 I 4 68 eeeeeeeee~ TENS TDTP LB 580724 80 800 ee 0 5 I I 4 68 eeeeeeeeee CCL TDTP V 500724 ee eee ee 0 5 1 1 4 68 eeeeeeeeee ** DATA DEPT. 83~7.000 SIGM.TDTP 30.~23 TPHI.TDTP- 55.104 SBHF.TDTP SBHN.TDTP 95.729 SIGC.'T'DTP e.000 SIBH.TDTP 364.919 TRAT.TDTP LCO1.TDTP 3.245 SDSI.'r'DTP 0.614 BACK.TDTP 74.485 FBAC.TDTP TCAN.'T'DTP 7926.975 TCAF.'I'i)TP 2347.036 TCND.'i'DTP 6771.417 TCFD.TDTP TSCN.TDTP 927.420 TSCF.TDTP 285.79e INND.TDTP 1750.367 INFD.TDTP GRCH.TDTP -999.250 TENS.'T'DTP 1170.ee0 CCL.TDTP e.oee DEPT. 7869.800 SIGM.TDTP 47.464 TPHI.TDTP 84.162 SBHF.TDTP SBHN.TDTP 61.984 SIGC.TDTP 0.137 SIBH.TDTP 189.561 TRAT.TDTP LCel.TDTP 4.077 SDSI.TDTP 0.924 BACK.TDTP 96.250 FBAC.TDTP TCAN.TDTP 16888.723 TCAF.TDTP 3925.704 TCND.TDTP 11682.1~4 TCFD.TDTP TSCN.TDTP 922.089 TSCF.TDTP 226.155 INND.TDTP 1720.434 INFD.TDTP GRCH.TDTP -999.258 TENS.TDTP 1075.808 CCL.TDTP e.080 79.289 1.993 32.813 1405.576 178.862 55.213 1.917 20.226 2520.694 270.678 ** END OF DATA ** LIS Tape Verificat|on List|ng Schlumberger Alaska Computing Center **** FILE TRAILER **** FILE NAME : EDIT .~5 SERVICE : FLIC VERSION : eelcel DATE : 96/el/23 MAX REC SIZE : ~e24 FILE TYPE : LO LAST FILE : 23-JAN-1996 11:30 PAGE: 24 **** FILE HEADER **** FILE NAME : EDIT .0e6 SERVICE : FLIC VERSION : ~1C~1 DATE : 96/01/23 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : FILE HEADER FILE NUMBER: 6 AVERAGED CURVES Pulsed Neutron: Unaveraged edited Pass 1 Gamma Ray and backround counts; arithmetic average of edited static baseline passes for all other curves. DEPTH.INCREMENT e.seee # PASSES INCLUDED IN AVERAGE LDWG TOOL CODE PASS NUMBERS TDTP 1, 2, $ REMARKS: The arithmetic average of passes I & 2 was computed after all depth shifts and clipping was applied. $ LIS FORMAT DATA ** DATA FORMAT SPECIFICATION RECORD ** SET TYPE - 64EB ** TYPE REPR CODE VALUE 1 66 2 66 3 73 4 66 5 66 6 73 LIS Tape Verification Listing Schlumberger Alaska Computing Center 23-JAN-1996 1~:30 PAGE: 25 TYPE REPR CODE VALUE 7 65 8 68 9 65 FT 11 66 12 12 68 13 66 14 65 FT 15 66 68 16 66 ~ 66 1 SET TYPE - CHAN ** NAME SERV UNIT SERVICE API API API API FILE NUMB NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUMB SAMP ELEM CODE (HEX) DEPT FT 5e0724 ee eeo SIGM PNAV CU 5e~724 e~ oee TPHI PNAV PU-S 5~724 ~ 0~ SBHF PNAV CU 5~724 ~0 00~ 0~ 0 6 I I 4 68 00000~0~0 SBHN PNAV CU B~724 ~ 000 SIGC PNAV CU Se~724 ee 00e SIBH PNAV CU S00724 ee eee TRAT PNAV S0~724 ee 00e eo e 6 I I 4 68 00eoeooeoe SDSI PNAV CU 5ee724 ee 0e0 BACK TDTP CPS 5ee724 ee e00 eo 0 6 1 i 4 68 eoooeeoooe FBAC TDTP CPS 50~724 ~0 e00 00 0 6 ! I 4 68 000~0~00~0 TCAN PNAV CPS 5ee724 ee eoe eo e 6 I I 4 68 00000eoe00 TCAF PNAV CPS 50e724 eO 000 eO 0 6 I I 4 68 0000eooooe TCND PNAV CPS 50e724 ee eoe eo 0 6 1 I 4 68 0000eoe000 TCFD PNAV CPS 5e0724 eO oee TSCN PNAV CPS 5ee724 eo eee TSCF PNAV CPS 5ee724 ee oee ee e 6 I 1 4 68 000000000e INND PNAV CPS 5~724 ~ 000 00 0 6 ! I 4 68 0~0~000~0 INFD PNAV CPS S~724 0~ ~0~ 00 ~ 6 ! I 4 68 ~000000 LC01 PNAV 50e724 ee eee ee 0 6 1 i 4 68 eeeeeeeeee GRCH TDTP GAPI 5~724 0~ 0~ ee e 6 ~ 1 4 68 eeeeeeeeee DATA ** DEPT. 8306.0~0 SIGM.PNAV 30.171 TPHI.PNAV 83.695 SBHF.PNAV SBHN,PNAV 8e.212 SIGC,PNAV o.eee SIBH,PNAV 284.285 TRAT.PNAV SDSI.PNAV e.655 BACK.TDTP 35.128 FBAC.TDTP 7,814 TCAN,PNAV TCAF,PNAV 2362.294 TCND.PNAV le260.793 TCFD.PNAV t614,40e TSCN.PNAV TSCF.PNAV 317.917 INND.PNAV 1928.657 INFD.PNAV 191,784 LCO1.PNAV GRCH,TDTP -999.25e 68.774 2.522 10476.367 1264.616 4.~e6 LIS Tape Verif|ca~ion List|ng Schlumberger Alaska Computing Cen~er 23-JAN-1996 11:30 DEPT. 7876.5e0 SIGM.PNAV 46.84e TPHI.PNAV 76.567 SBHN.PNAV 64.672 SIGC.PNAV 0.175 SlBH.PNAV 203.527 SDSI.PNAV 0.862 BACK.TDTP 72.455 FBAC.TDTP 13.771 TCAF.PNAV 3964.042 TCND.PNAV 12e12.629 TCFD.PNAV 2548.8e2 TSCF.PNAV 24e.8e8 INND.PNAV 1872.12e INFD.PNAV 263.567 GRCH.TDTP 59.156 SBHF.PNAV TRAT.PNAV TCAN.PNAV TSCN.PNAV LC~I.PNAV PAGE: 26 58.059 1.822 16757.918 932.176 3.873 END OF DATA **** FILE TRAILER FILE NAME : EDIT .ee6 SERVICE : FLIC VERSION : DATE : 96/e1/23 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : **** FILE HEADER **** FILE NAME : EDIT .ee7 SERVICE : FLIC VERSION : eelcel DATE : 96/~1/23 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : FILE HEADER FILE NUMBER 7 RAW CURVES Curves and log header data for each pass in separate files; raw background pass in las~ file PASS NUMBER: 1 DEPTH INCREMENT: ~.5~0 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH TDTP 8310.e $ LOG HEADER DATA DATE LOGGED: SOFTWARE VERSION: TIME LOGGER ON BOTTOM: TD DRILLER (FT): TD LOGGER(FT): TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): 7874.0 05-FEB-95 CP42.2 133e eS-FEB-FE 8335.0 7870.0 8312.0 LIS Tape Vet i t~ | ca~, i on L i s~, ing Sch I umberger A I aska Compu~,i ng Cent;er 2S-JAN-1996 l[:3e LOGGING SPEED (FPHR): DEPTH CONTROL USED (YES/NO): TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE NO TOOL NUMBER TDTP TDTP TDTP TDTP CCL TDTP $ TDTP SONDE GENERATOR TDTP SONDE DETECTOR TDTP CARTRIDGE TELEMETRY CARTRIDGE COLLAR LOG THERMAL DECAY TOOL TNG-P-236 TND-P-75 TNC-P-141 ATC-CB-1163 CAL-UB-1269 CTSM-A-324 BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLERS CASING DEPTH (FT): LOGGERS CASING DEPTH (FT): BOREHOLE CONDITIONS FLUID TYPE: FLUID DENSITY '(LB/G): SURFACE TEMPERATURE (DEGF): BOTTOM HOLE TEMPERATURE (DEGF): FLUID SALINITY (PPM): FLUID LEVEL (FT): FLUID RATE AT WELLHEAD (BPM): WATER CUTS (PCT): GAS/OIL RATIO: CHOKE (DEG): 8708.e PRODUCED WATER INJ. NEUTRON TOOL TOOL TYPE (EPITHERMAL OR THERMAL): MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): BLUELINE COUNT RATE NORMALIZATION IN OIL ZONE TOP NORMALIZING WINDOW (FT): BASE NORMALIZING WINDOW (FT): BLUELINE COUNT RATE SCALES SET BY FIELD ENGINEER FAR COUNT RATE LOW SCALE (CPS): 0 FAR COUNT RATE HIGH SCALE (CPS): 12eee NEAR COUNT RATE LOW SCALE (CPS): 0 NEAR COUNT RATE HiGH SCALE (CPS): 3eooe TOOL STANDOFF (IN): REMARKS: TIED INTO INJ PROFILE DATED ll/12/94 **** JOB SEQUENCE **** ~) RAN 1ST BASE PASS (PRODUCED WATER IN HOLE) 2) RAN 2ND BASE PASS 3) PUMPED 26 BBLS OF BORAX WATER OUT THE TBG TAlL 4) MADE 1ST BORAX PASS S) PUMPED 32 MORE BBLS BW OUT TAlL PAGE: 27 LIS Tape Verification Listing Schlumberger Alaska Computing Center 23-JAN-1996 11:30 6) MADE 2ND BORAX PASS 7) PUMPED 27 MORE BBLS BW OUT TAIL 8) MADE 3RD BORAX PASS This is Base pass ~1. $ LIS FORMAT DATA PAGE: 28 DATA FORMAT SPECIFICATION RECORD ** SET TYPE - 64EB ** TYPE REPR CODE VALUE 1 66 2 66 3 73 92 4 66 1 5 66 6 73 7 65 8 68 9 65 FT 11 66 12 68 13 66 0 14 65 FT 15 66 68 16 66 ~ 66 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 5ee724 ee eeo SIGM PS1 CU 50e724 00 oee TPHI PS1 PU 50~724 ~0 ~00 00 0 7 ! 1 4 68 000000000~ SBHF PS1 CU 5e0724 ~e 00~ SBHN PS1 CU 500724 eO e00 SIGC PS1 CU 500724 00 0~0 ~0 0 7 I I 4 68 00000000~0 SIBH PS1 CU 500724 eO 000 00 0 7 ! I 4 68 00000e0000 TRAT PS1 500724 00 000 00 e 7 1 I 4 68 00000000~0 LC01 PS1 5e0724 00 000 00 0 7 1 1 4 68 0000eeooeo SDSI PS1 CU 500724 oe 00e 00 0 7 1 BACK PS1 CPS Be0724 00 00e FBA¢ PS1 CPS 5~724 ~ ~0~ TCAN PS1 CPS 500724 00 00e TCAF PS1 CPS 50e724 00 eee TCND PS1 CPS 50e724 00 000 LIS Tape Verif|cat|on L|st|ng Schlumberger Alaska Compu~|ng Cen%er 23-JAN-J996 1[:30 PAGE: 29 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) TCFD PS[ CPS 50e724 TSCN PS[ CPS 5e0724 eO 0ee ee e 7 1 z 4 68 oeeeooooeo TSCF PS[ CPS 5e~724 INND PS[ CPS 5ee724 ee eee ee INFD PS[ CPS 5ee724 TENS PS[ LB 5ee724 ee eee ee e 7 [ 1 4 68 eeeeeeeeee GR PS[ GAPI 5e0724 ee eee oe e 7 [ z 4 68 eeeeeeeeee CCL PS[ V 5e~724 ee eee ee e 7 1 ! 4 68 eeeeeeeeee DATA DEPT. 8319.500 SIGM.PS[ 22.656 TPHI.PS! 72.564 SBHF.PS1 SBHN.PS[ 60.780 SIGC.PS[ ~.0~ SIBH.PSl 84.071 TRAT.PSl LCO[.PS[ 4.502 SDSI.PS[ [8.336 BACK.PS1 36.765 FBAC.PS! TCAN.PS[ 6386.548 TCAF.PS! [4[8.7[0 TCND.PS1 [0906.355 TCFD.PS1 TSCN.PS[ 1295.543 TSCF.PS[ 287.792 INND.PSl [948.635 INFD.PS[ TENS.PS1 845.~e0 GR.PSI 31.594 CCL.PS1 e.ess DEPT. 7873.5e0 SIGM.PS[ 46.216 TPHI.PS[ 76.9[1 SBHF.PS[ SBHN.PS[ 62.754 SIGC.PS[ e.2[[ SlBH.PS1 [93.56e TRAT.PSl LCO[.PS[ 3.886 SDSI.PS[ 0.722 BACK.PS1 72.115 FBAC.PS1 TCAN.PS[ [6755.352 TCAF.PS[ 3898.[e4 TCND.PS[ [[863.074 TCFD.PS[ TSCN.PS[ 943.690 TSCF.PS[ 242.838 INND.PS1 [835.6e6 INFD.PS[ TENS.PS[ 985.0ee GR.PS1 59.625 CCL.PS1 e.eee END OF DATA 82.921 2.689 3.098 [714.9e6 214.886 53.602 [.840 13.302 251[.481 270.490 **** FILE FILE NAME SERVICE VERSION DATE MAX REC SIZE FILE TYPE LAST FILE TRAILER : EDIT .e~7 : FLIC : : 96/0[/23 : 1024 : LO : **** FILE FILE NAME SERVICE VERSION DATE MAX REC SIZE FILE TYPE LAST FILE HEADER : EDIT .0e8 : FLIC : 0~1C01 : 96/el/23 : le24 : LO : LIS Tape Ver|ficat|on List|ng Schlumberger Alaska Computing Center 23-JAN-1996 11:30 PAGE: 30 FILE HEADER FILE NUMBER' 8 RAW CURVES Curves and log header da~a for each pass in separate files; raw background pass in last file PASS NUMBER: 2 DEPTH INCREMENT: e.5~ # FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH TDTP $ LOG HEADER DATA 831e.0 7873.e DATE LOGGED: SOFTWARE VERSION: TIME LOGGER ON BOTTOM: TD DRILLER (FT): TD LOGGER(FT): TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): LOGGING SPEED (FPHR): DEPTH CONTROL USED (YES/NO): TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE eS-FEB-95 CP42.2 1330 eS-FEB-FE 8335.~ 787e.~ 8312.e NO TOOL NUMBER TDTP TDTP TDTP TDTP CCL TDTP $ 'rDTP SONDE GENERATOR TDTP SONDE DETECTOR TDTP CARTRIDGE TELEMETRY CARTRIDGE COLLAR LOG THERMAL DECAY TOOL BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLERS CASING DEPTH (FT): LOGGERS CASING DEPTH (FT): BOREHOLE CONDITIONS FLUID TYPE: FLUID DENSITY (LB/G): SURFACE TEMPERATURE (DEGF): BOTTOM HOLE TEMPERATURE (DEGF): FLUID SALINITY (PPM): FLUID LEVEL (FT): FLUID RATE AT WELLHEAD (BPM): WATER CUTS (PCT): GAS/OIL RATIO: CHOKE (DEG): NEUTRON TOOL TOOL TYPE (EPITHERMAL OR THERMAL): MATRIX: TNO-P-236 TND-P-75 TNC-P-141 ATC-CB-1163 CAL-UB-1269 CTSM-A-324 8708.0 PRODUCED WATER INJ. LIS Tape Verification Listing Schlumberger Alaska Computing Center 23-JAN-Z996 ~[:30 PAGE: 31 MATRIX DENSITY: HOLE CORRECTION (IN): BLUELINE COUNT RATE NORMALIZATION IN OIL ZONE TOP NORMALIZING WINDOW (FT): BASE NORMALIZING WINDOW (FT): BLUELINE COUNT RATE SCALESSET BY FIELD ENGINEER FAR COUNT RATE LOW SCALE (CPS): 0 FAR COUNT RATE HIGH SCALE (CPS): 12eee NEAR COUNT RATE LOW SCALE (CPS): 0 NEAR COUNT RATE HIGH SCALE (CPS): 3eeee TOOL STANDOFF (IN): REMARKS: TIED INTO INJ PROFILE DATED 11/12/94 **** JOB SEQUENCE **** 1) RAN 1ST BASE PASS (PRODUCED WATER IN HOLE) 2) RAN 2ND BASE PASS 3) PUMPED 26 BBLS OF BORAX WATER OUT THE TBG TAIL 4) MADE 1ST BORAX PASS S) PUMPED 32 MORE BBLS BW OUT TAlL 6) MADE 2ND BORAX PASS 7) PUMPED 27 MORE BBLS BW OUT TAlL 8) MADE 3RD BORAX PASS This is Base pass #2. $ # LIS FORMAT DATA DATA FORMAT SPECIFICATION RECORD SET TYPE - 64EB ** TYPE REPR CODE VALUE 1 66 2 66 0 3 73 92 4 66 5 66 6 73 7 65 8 68 0.5 9 65 FT 12 68 13 66 0 14 65 FT 15 66 68 16 66 1 0 66 LIS Tape Verificat|on List|ng Schlumberger Alaska Comput|ng Center SET TYPE - CHAN ** 23-JAN-1996 11:30 PAGE: 32 NAME SERV UNIT SERVICE AP1 AP1 AP1 AP1 FILE NUMB NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUMB SAMP ELEM CODE (HEX) DEPT FT 588724 SIGM PS2 CU 588724 TPHI PS2 PU 5~724 SBHF PS2 CU 5~724 SBHN PS2 CU 5~0724 0~ 0~0 ~ ~ 8 1 I 4 68 0~0~00~0~0 SIGC PS2 CU 588724 SIBH PS2 CU S08724 TRAT PS2 580724 LCel PS2 S80724 SDSI PS2 CU 508724 BACK PS2 CPS 580724 FBAC PS2 CPS 5~724 TCAN PS2 CPS 588724 TCAF PS2 CPS 588724 TCND PS2 CPS 5~724 TCFD PS2 CPS 500724 80 ~00 08 e 8 1 1 4 68 oe8oo~o8o TSCN PS2 CPS 58~'724 TSCF PS2 CPS 5~0724 0~ 0~0 00 e 8 1 I 4 68 eeeeeeeeee INND PS2 CPS 508724 08 cee 0~ e 8 1 1 4 68 eeeeeeeeee INFD PS2 CPS 588724 ee eee ee e 8 1 I 4 68 eeeeeeeeee TENS PS2 LB 588724 ee OR PS2 GAPI 588724 CCL PS2 V S08724 DATA DEPT. 8320.080 SIGM.PS2 47.398 TPHI.PS2 83.267 SBHF.PS2 SBHN.PS2 S8.038 SIGC.PS2 0.389 SIBH.PS2 77.832 TRAT.PS2 LCel.PS2 4.14S SDSI.PS2 0.80S BACK.PS2 91.079 FBAC.PS2 TCAN.PS2 16281.758 TCAF.PS2 3432.417 TCND.PS2 9647.027 TCFD.PS2 TSCN.PS2 1214.765 TSCF.PS2 293.861 INND.PS2 1693.961 INFD.PS2 TENS.PS2 810.e80 GR.PS2 51.719 CCL.PS2 o.eee DEPT. 7872.see SIGM.PS2 47.428 TPHI.PS2 75.758 SBHF.PS2 SBHN.PS2 59.947 SIGC.PS2 0.264 SIBH.PS2 178.975 TRAT.PS2 LC~I.PS2' 3.964 SDSI.PS2 1.046 BACK.PS2 103.989 FBAC.PS2 TCAN.PS2 16235.845 TCAF.PS2 3802.126 TCND.PS2 11536.328 TCFD.PS2 TSCN.PS2 888.718 TSCF.PS2 222.185 INND.PS2 1875.426 INFD.PS2 TENS.PS2 10~S.~00 GR.PS2 81.75~ CCL.PS2 0.~00 46.283 2.S92 13.772 1524.981 179.069 5S.000 1.807 19.167 2490.833 254.810 ** END OF DATA ** LIS Tape Verification List|ng Schlumberger Alaska Computing Center · ,,~ FILE TRAILER -~* FILE NAME : EDIT .~08 SERVICE : FLIC VERSION : ~01C~1 DATE : 96/01/23 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : 23-JAN-1996 11:30 PAGE: 33 **** FILE HEADER **** FILE NAME : EDIT .0~9 SERVICE : FLIC VERSION : ~01C01 DATE : 96/~1/23 MAX REC SIZE : le24 FILE TYPE : LO LAST FILE : FILE HEADER FILE NUMBER 9 RAW CURVES Curves and log header data for each pass in separate files; raw background pass in last file PASS NUMBER: 3 DEPTH INCREMENT: ~.5~ FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH TDTP $ LOG HEADER DATA 831~.~ 7853.~ DATE LOGGED: SOFTWARE VERSION: TIME LOGGER ON BOTTOM: TD DRILLER (FT): TD LOGGER (FT): TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): LOGGING SPEED (FPHR): DEPTH CONTROL USED (YES/NO): TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE eS-FEB-g5 CP42.2 1330 ~5-FEB-FE 8335.~ 7870.e 8312.0 NO TOOL NUMBER TDTP TDTP TDTP TDTP CCL TDTP TDTP SONDE GENERATOR TDTP SONDE DETECTOR TDTP CARTRIDGE TELEMETRY CARTRIDGE COLLAR LOG THERMAL DECAY TOOL TNG-P-236 TND-P-75 TNC-P-141 ATC-CB-1165 CAL-UB-1269 CTSM-A-3~4 LIS Tape Verification Listing Schlumberger Alaska Computing Center 23-JAN-1996 l[:3e PAGE: 34 BOREHOLE AND CASING DATA OPEN HOLE BlT SIZE (IN): DRILLERS CASING DEPTH (FT) LOGGERS CASING DEPTH (FT) 87e8.o BOREHOLE CONDITIONS FLUID TYPE: FLUID DENSITY (LB/G): SURFACE TEMPERATURE (DEGF): BOTTOM HOLE TEMPERATURE (DEGF): FLUID SALINITY (PPM): FLUID LEVEL (FT): FLUID RATE AT WELLHEAD (BPM): WATER CUTS (PCT): GAS/OIL RATIO: CHOKE (DEG): PRODUCED WATER INJ. NEUTRON TOOL TOOL TYPE (EPITHERMAL OR THERMAL): MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): BLUELINE COUNT RATE NORMALIZATION IN OIL ZONE TOP NORMALIZING WINDOW (FT): BASE NORMALIZING WINDOW (FT): BLUELINE COUNT RATE SCALES SET BY FIELD ENGINEER FAR COUNT RATE LOW SCALE (CPS): e FAR COUNT RATE HIGH SCALE (CPS): ~2e00 NEAR COUNT RATE LOW SCALE (CPS): 0 NEAR COUNT RATE HIGH SCALE (CPS): 3eooe TOOL STANDOFF (IN): REMARKS: TIED INTO INJ PROFILE DATED 11/12/94 **** JOB SEQUENCE 1) RAN 1ST BASE PASS (PRODUCED WATER IN HOLE) 2) RAN 2ND BASE PASS 3) PUMPED 26 BBLS OF BORAX WATER OUT THE TBG TAlL 4) MADE 1ST BORAX PASS 5) PUMPED 32 MORE BBLS BW OUT TAIL 6) MADE 2ND BORAX PASS 7) PUMPED 27 MORE BBLS BW OUT TAlL 8) MADE 3RD BORAX PASS This is Borax pass $ LIS FORMAT DATA LIS Tape Verification Listing Schlumberger Alaska Computing Center 23-JAN-1996 11:30 DATA FORMAT SPECIFICATION RECORD SET TYPE - 64EB ** TYPE REPR CODE VALUE 1 66 ~ 2 66 0 3 73 92 4 66 1 5 66 6 73 7 65 8 68 0.5 9 65 FT 12 68 13 66 ~ 14 65 FT 15 66 68 16 66 1 0 66 1 PAGE: 35 SET TYPE - CHAN ** NAME SERV UNIT SERVICE API AP1 AP1 AP1 FILE NUMB NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUMB SAMP ELEM CODE (HEX) DEPT FT 5ee724 ee eeo ee 0 9 1 i 4 68 eoeoeoe000 SIGM PS3 CU 50e724 Oe 00e 00 TPHI PS3 PU 5~724 0~ ~ SBHF PS3 CU 5~724 00 ~00 ~0 0 9 1 1 4 68 ~0~000~000 SBHN PS3 CU 5~0724 ~0 ~ ~0 0 9 1 I 4 68 00~00~0~00 SIGC PS3 CU 50e724 ee 000 SIBH PS3 CU 5ee724 eo eoe TRAT PS3 50e724 00 00e e~ 0 9 1 I 4 68 000eoe0000 LC01 PS3 5ee724 eo 00e SDSI PS3 CU 5ee724 00 e00 ee e 9 1 I 4 68 eeee000000 BACK PS3 CPS 5~724 00 ~0 FBAC PS3 CPS 50e724 ~e oee eo e 9 1 I 4 68 ~000000e00 TCAN PS3 CPS 5ee724 eo eeo TCAF PS3 CPS 50~724 00 000 ~ 0 9 1 1 4 68 0000~0000 TCND PS3 CPS 50~724 ~0 000 ~ e 9 1 1 4 68 ~00000~0~ TCFD PS3 CPS 50~724 eO 0e0 Oe 0 9 I 1 4 68 0000000e00 TSCN PS3 CPS 50e724 00 eeo oe e 9 I I 4 68 e~ooeoe000 TSCF PS3 CPS 5~0724 00 000 ~ 0 9 1 1 4 68 ~0000000~0 INND PS3 CPS 50~724 00 000 INFD PS3 CPS 50e724 00 0e0 eO e 9 I 1 4 68 000e000000 TENS PS3 LB 50e724 ee oee oe 0 9 1 I 4 68 000eoeoeoe GR PS3 GAPI 5e0724 eO 000 eO 0 9 1 1 4 68 oeeooe0000 CCL P$3 V 5ee724 ee e00 LIS Tape Verification Listing Schlumberger Alaska Computing Center DATA DEPT. 8321.5ee SIGM.PS3 SBHN.PS3 69.S70 SIGC.PS3 LCO1.PS3 3.245 SDSI.PS3 TCAN.PS3 le938.883 TCAF.PS3 TSCN.PS3 862.552 TSCF.PS3 TENS.PS3 76o.oee GR.PS3 DEPT. 78s3.eeo SIGM.PS3 SBHN.PS3 69.415 SIGC.PS3 LCel.PS3 3.855 SDSI.PS3 TCAN.PS3 13536.432 TCAF.PS3 TSCN.PS3 71e.267 TSCF.PS3 TENS.PS3 1115.0~0 GR.PS3 23-JAN-1996 11:3e 48.421 TPHI.PS3 e.eeo SIBH.PS3 1.e98 BACK.PS3 275e.928 TCND.PS3 265.790 INND.PS3 56.875 CCL.PS3 48.921 TPHI.PS3 0.071 SIBH.PS3 e.948 BACK.PS3 3365.918 TCND.PS3 184.261 INND..PS3 63.781 CCL.PS3 85.856 1e4.e11 87.324 6134.888 2121.184 0.0e0 73.616 228.178 1~1.731 996~.4~4 1915.~56 0.00e SBHF.PS3 TRAT.PS3 FBAC.PS3 TCFD.PS3 INFD.PS3 SBHF.PS3 TRAT.PS3 FBAC.PS3 TCFD.PS3 INFD.PS3 PAGE: 36 56.205 2.095 44.082 1140.123 201.023 61.187 1.745 17.761 2216.e67 263.779 END OF DATA ** **** FILE TRAILER **** FILE NAME : EDIT .009 SERVICE : FLIC VERSION : O~lCel DATE : 96/01/23 MAX REC SIZE : le24 FILE TYPE : LO LAST FILE : **** FILE HEADER **** FILE NAME : EDIT .~1~ SERVICE : FLIC VERSION : 001C01 DATE : 96/01/23 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : FILE HEADER FILE NUMBER RAW CURVES Curves and log PASS NUMBER: DEPTH INCREMENT: FILE SUMMARY VENDOR TOOL CODE TDTP $ header data 4 0. 5000 START DEPTH 831~.0 for each pass in separate files; raw STOP DEPTH 7850.0 background pass in last file LIS Tape Verification Listing Schlumberger Alaska Computing Cen~er 23-JAN-Z996 11:30 LOG HEADER DATA DATE LOGGED: SOFTWARE VERSION: TIME LOGGER ON BOTTOM: TD DRILLER (FT): TD LOGGER(FT): TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): LOGGING SPEED (FPHR): DEPTH CONTROL USED (YES/NO): TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE 05-FEB-95 CP42.2 133e eS-FEB-FE 833B.e 7870.e 8312.e NO TOOL NUMBER - TDTP TDTP TDTP TDTP CCL TDTP $ TDTP SONDE GENERATOR TDTP SONDE DETECTOR TDTP CARTRIDGE TELEMETRY CARTRIDGE COLLAR LOG THERMAL DECAY TOOL TNG-P-236 TND-P-75 TNC-P-141 ATC-CB-1163 CAL-UB-1269 CTSM-A-324 BOREHOLE AND CASING DATA OPEN HOLE BlT SIZE (IN): DRILLERS CASING DEPTH (FT): LOGGERS CASING DEPTH (FT): 87e8.0 BOREHOLE CONDITIONS FLUID TYPE: FLUID DENSITY (LB/G): SURFACE TEMPERATURE (DEGF): BOTTOM HOLE TEMPERATURE (DEGF): FLUID SALINITY (PPM): FLUID LEVEL (FT): FLUID RATE AT WELLHEAD (BPM): WATER CUTS (PCT): GAS/OIL RATIO: CHOKE (DEG): PRODUCED WATER INJ. NEUTRON TOOL TOOL TYPE (EPITHERMAL OR THERMAL): MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): BLUELINE COUNT RATE NORMALIZATION IN 0IL ZONE TOP NORMALIZING WINDOW (FT): BASE NORMALIZING WINDOW (FT): BLUELINE COUNT RATE SCALES SET BY FIELD ENGINEER FAR COUNT RATE LOW SCALE (CPS): ~ FAR COUNT RATE HIGH SCALE (CPS): 1200e NEAR COUNT RATE LOW SCALE (CPS): 0 NEAR COUNT RATE HIGH SCALE (CPS): 3eoeo PAGE: 37 LIS Tape Verification Lis~ing Schlumberger Alaska Computing Cen~er 23-JAN-Z996 11:3~ TOOL STANDOFF (IN): REMARKS: TIED INTO INJ PROFILE DATED 11/12/94 **** JOB SEQUENCE **** 1) RAN 1ST BASE PASS (PRODUCED WATER IN HOLE) 2) RAN 2ND BASE PASS 3) PUMPED 26 BBLS OF BORAX WATER OUT THE TBG TAlL 4) MADE 1ST BORAX PASS 5) PUMPED 32 MORE BBLS BW OUT TAlL 6) MADE 2ND BORAX PASS 7) PUMPED 27 MORE BBLS BW OUT TAlL 8) MADE 3RD BORAX PASS This is Borax pass #2. $ LIS FORMAT DATA PAGE: 38 DATA FORMAT SPECIFICATION RECORD ** ** SET TYPE - 64EB ** TYPE REPR CODE VALUE 1 66 ~ 2 66 0 3 73 92 4 66 1 S 66 6 73 7 65 8 68 0.5 9 65 FT 11 66 11 12 68 13 66 0 14 65 FT 1S 66 .68 0 66 1 ** SET TYPE - CHAN ** NAME SERV UNIT SERVICE AP1 AP1 AP1 AP1 FILE NUMB NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUMB SAMP ELEM CODE (HEX) DEPT FT 5ee724 eo 00e eo 0 10 I 1 4 68 eoeooeoe00 SIGM PS4 CU 5ee724 ee oee ee 0 le i I 4 68 eeeeeeee~e TPHI PS4 PU 500724 ~0 ~Oe ~0 ~ 10 I 1 4 68 ~00~0e0~0 SBHF PS4 CU 5~724 00 0~0 00 0 10 I 1 4 68 0~00000~0 SBHN PS4 CU 500724 00 ~00 00 0 10 I 1 4 68 0~000000~ SIGC PS4 CU 500724 00 00e 00 0 10 I 1 4 68 0000eoooeo LIS Tape Verification LJst|ng Schlumberger Alaska Comput|ng Center 23-JAN-1996 11:3~ PAGE: 39 NAME SERV UNIT SERVICE API API API API FILE NUMB NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUMB SAMP ELEM CODE (HEX) SIBH PS4 CU 500724 0~ eee oe e 10 I I 4 68 eeoooeooeo TRAT PS4 5~0724 ~0 0~ ~ ~ 10 I I 4 68 00~00~0~00 LCd1 PS4 5~0724 ~ ~0 ~ ~ 10 1 1 4 68 0~000~0 SDSI PS4 CU 5~0724 BACK PS4 CPS 5~0724 FBAC PS4 CPS 5~0724 TCAN PS4 CPS 50e724 TCAF PS4 CPS 5ee724 TCND PS4 CPS 500724 0~ 0~ ~ ~ 1~ 1 ! 4 68 ~0~00000 TCFD PS4 CPS 5ee724 TSCN PS4 CPS 500724 00 TSCF PS4 CPS 5~0724 ~ ~ ~0 0 10 1 ! 4 68 00~0~00~0 INND PS4 CPS S00724 ~0 00e 00 e 10 1 ! 4 68 oeeo~oe000 INFD PS4 CPS 5e0724 ee eec 0~ e 10 1 ! 4 68 oeoeoe0000 TENS PS4 LB 500724 GR PS4 GAPI 50~724 00 CCL PS4 V 5e0724 00 DATA DEPT. 8321.e0~ SIGM.PS4 43.698 TPHI.PS4 48.391 SBHF.PS4 SBHN.PS4 60.582 SIGC.PS4 e.435 SIBH.PS4 83.622 TRAT.PS4 LCO1.PS4 3.558 SDSI.PS4 ~.99~ BACK.PS4 1~.181 FBAC.PS4 TCAN.PS4 15610.822 TCAF.PS4 3816.249 TCND.PS4 10854.787 TCFD.PS4 TSCN.PS4 896.084 TSCF.PS4 251,878 INND.PS4 1822.213 INFD.PS4 TENS.PS4 81e.e00 GR.PS4 59.063 CCL.PS4 0.0e0 DEPT. 7849.5ee SIGM.PS4 46.843 TPHI.PS4 80.919 SBHF.PS4 SBHN.PS4 66.642 SlGC.PS4 e.eee SlBH.PS4 213.766 TRAT.PS4 LCel.PS4 4.181 SDSI.PS4 e.e4e BACK.PS4 92.165 FBAC.PS4 TCAN.PS4 14936.637 TCAF.PS4 3565.741 TCND.PS4 10483.521 TCFD.PS4 TSCN.PS4 848.449 TSCF.PS4 2e2.944 INND.PS4 1797.650 INFD.PS4 TENS.PS4 1080.0e0 GR.PS4 71.375 CCL.PS4 o.eeo B~.~IO 1.752 18.236 2433.756 272.966 58.218 1.882 20.227 2276.529 260.e16 END OF DATA =*** FILE TRAILER FILE NAME : EDIT .010 SERVICE : FLIC VERSION : OelCel DATE : 96/~1/23 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : LIS Tape Verif|cation Listing Schlumberger Alaska Computing center .t** FILE HEADER **~ FILE NAME : EDIT .011 SERVICE : FLIC VERSION : 001C~! DATE : 96/~1/25 MAX REC SIZE : 1~24 FILE TYPE : LO LAST FILE : 23-JAN-1996 11:3e PAGE: 40 FILE HEADER FILE NUMBER 11 RAW CURVES Curves and log header data for each pass in separate files; raw background pass in last file PASS NUMBER: 5 DEPTH INCREMENT: ~.5~ FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH TDTP $ LOG HEADER DATA 8310.~ 7870.0 DATE LOGGED: SOFTWARE VERSION: TIME LOGGER ON BOTTOM: 'ID DRILLER (FT): TD LOGGER(FT): TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): LOGGING SPEED (FPHR): DEPTH CONTROL USED (YES/NO): TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE OS-FEB-9S CP42.2 1330 eS-FEB-FE 8335.0 7870.0 83[2.0 NO TOOL NUMBER TDTP TDTP TDTP TDTP CCL TDTP $ TDTP SONDE GENERATOR TDTP SONDE DETECTOR TDTP CARTRIDGE TELEMETRY CARTRIDGE COLLAR LOG THERMAL DECAY TOOL BOREHOLE AND CASING DATA OPEN HOLE BlT SIZE (IN): DRILLERS CASING DEPTH (FT): LOGGERS CASING DEPTH (FT): BOREHOLE CONDITIONS FLUID TYPE: FLUID DENSITY (LB/G): TNG-P-236 TND-P-75 TNC-P-141 ATC-CB-1163 CAL-UB-1269 CTSM-A-324 8708.0 PRODUCED WATER INJ. LIS Tape Veri~|ca%|on L|s%ing Schlumberger Alaska Compu~|ng Cen~er 23-JAN-1996 1[:30 SURFACE TEMPERATURE (DEGF): BOTTOM HOLE TEMPERATURE (DEGF): FLUID SALINITY (PPM): FLUID LEVEL (FT): FLUID RATE AT WELLHEAD (BPM): WATER CUTS (PCT): GAS/OIL RATIO: CHOKE (DEG): NEUTRON TOOL TOOL TYPE (EPITHERMAL OR THERMAL): MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): BLUELINE COUNT RATE NORMALIZATION IN OIL ZONE TOP NORMALIZING WINDOW (FT): BASE NORMALIZING WINDOW (FT): BLUELINE COUNT RATE SCALES SET BY FIELD ENGINEER FAR COUNT RATE LOW SCALE (CPS): ~ FAR COUNT RATE HIGH SCALE (CPS): 12eee NEAR COUNT RATE LOW SCALE (CPS): e NEAR COUNT RATE HIGH SCALE (CPS): 3eeee TOOL STANDOFF (IN): REMARKS: TIED INTO INJ PROFILE DATED 1~/~2/94 **** JOB SEQUENCE **** ~) RAN lST BASE PASS (PRODUCED WATER IN HOLE) 2) RAN 2ND BASE PASS 3) PUMPED 26 BBLS OF BORAX WATER OUT THE TBG TAlL 4) MADE 1ST BORAX PASS 5) PUMPED 32 MORE BBLS BW OUT TAlL 6) MADE 2ND BORAX PASS 7) PUMPED 27 MORE BBLS BW OUT TAlL 8) MADE 3RD BORAX PASS This is Borax pass #3. $ LIS FORMAT DATA PAGE: 41 DATA FORMAT SPECIFICATION RECORD ** SET TYPE - 64EB ** TYPE REPR CODE VALUE ! 66 0 2 66 e 3 73 <32 4 66 ;[ 5 66 LTS Tape Verif|ca%|on Listing Schlumberger Alaska Computing Center 23-JAN-J996 [1:3e PAGE: 42 TYPE REPR CODE VALUE 6 73 7 65 8 68 9 65 FT 11 66 11 12 68 13 66 0 14 65 FT 15 66 68 16 66 ~ 66 SET TYPE - CHAN ** NAME SERV UNIT SERVICE AP1 AP1 AP1 API FILE NUMB NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUMB SAMP ELEM CODE (HEX) DEPT FT Se0724 SIGM PS5 CU 5e0724 TPHI PS5 PU 5~0724 SBHF PS5 CU 5~0724 0~ ~00 ~ 0 11 I I 4 68 0~0~0000 SBHN PS5 CU 5~724 SIGC PS5 CU 5ee724 SIBH PS5 CU 5~724 ~ 0~0 ~0 ~ 11 1 I 4 68 0~0~0~0~00 TRAT PS5 S00724 ~ 0~0 ~ 0 11 I I 4 68 0000000~0~ LC01 PS5 500724 SDSI PS5 CU 500724 0~ ~ 0~ 0 11 I I 4 68 ~000~0~00 BACK PS5 CPS 5e0724 FBAC PS5 CPS 5ee724 TCAN PS5 CPS 5e0724 TCAF'PS5 CPS 5ee724 eo 0~0 ~0 ~ 11 I I 4 68 0~000~000 TCND PS5 CPS 500724 TCFD PS5 CPS 500724 00 TSCN PS5 CPS 500724 00 TSCF PS5 CPS 5e0724 00 INND PS5 CPS 500724 INFD PS5 CPS 5ee724 Ge cee ee e 71 i 1 4 68 eeeeeeeeee TENS PS5 LB 5ee724 GR PS5 GAPI 5ee724 CCL PS5 V 5ee724 00 DATA DEPT. 8320.000 SIOM.PS5 50.005 TPHI.PS5 72.965 SBHF.PS5 SBHN.PS5 95.265 SIGC.PS5 ~.eoe SIBH.PS5 162.3ee TRAT,PS5 LC~Z,P$5 4.03g $D$Z,P$5 1.289 BACK.PS5 64,117 FBAC.PS5 TCAN.PS5 52~7.145 TCAF.PS5 954.836 TCND.PS5 5755.464 TCFD.PS5 TSCN.PS5 212.294 TSCF.PS5 52.561 INND.PS5 1818.856 INFD.PS5 TENS.PS5 775.000 OR.PS5 62.594 CCL.PS5 0.~0 95.398 1.773 le.725 792.205 175,699 LIS Tape Veri~icat|on List|ng Sch I umberger Alaska Compu~|ng Center 23-JAN-1996 11:30 PAGE: 43 DEPT. 7869.ee0 SIGM.PS5 SBHN.PS5 59.816 SIGC.PS5 LCel.PS$ 4.183 SDSI.PS5 TCAN.PS5 16641.840 TCAF.PS5 TSCN.PS5 898.303 TSCF.PS5 TENS.PS5 1115.00~ GR.PS5 47.965 TPHI.PSS 0.098 SIBH.PSS e.984 BACK.PSS 3876.889 TCND.PSS 214.744 INND.PS5 92.75e CCL.PS5 82.326 [78.293 97.315 1~618.529 1735.798 SBHF.PS5 TRAT.PS5 FBAC.PS5 TCFD.PS5 INFD.PS5 56.135 1.886 21.165 25e~.024 262.408 END OF DATA **** FILE TRAILER **** FILE NAME : EDIT .eli SERVICE : FLIC VERSION : ~1C~1 DATE : 96/el/23 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : **** TAPE TRAILER SERVICE NAME : EDIT DATE : 96/el/23 ORIGIN : FLIC TAPE NAME : 9S~64 CONTINUATION # : 1 PREVIOUS TAPE : COMMENT : ARCO ALASKA INC, 1H-~8, KUPARUK RIVER UNIT, S~-~29-2~763-~ **** REEL TRAILER SERVICE NAME : EDIT DATE : 96/el/23 ORIGIN : FLIC REEL NAME : 9S064 CONTINUATION # : PREVIOUS REEL : COMMENT : ARCO ALASKA INC, 1H-e8~ KUPARUK RIVER UNIT~ S~-029-2e763-eo