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Home My WebLink About188-120MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission DATE:Monday, September 22, 2025 SUBJECT:Mechanical Integrity Tests TO: FROM:Kam StJohn P.I. Supervisor Petroleum Inspector NON-CONFIDENTIAL Hilcorp Alaska, LLC 5-01 DUCK IS UNIT MPI 5-01 Jim Regg InspectorSrc: Reviewed By: P.I. Suprv Comm ________ JBR 09/22/2025 5-01 50-029-20518-00-00 180-120-0 G SPT 8941 1801200 2750 3609 3755 3730 3742 165 164 165 166 REQVAR P Kam StJohn 8/6/2025 Annual MIT-IA as per AIO 1.007 left IA higher on as left psi so less bbls returned. 30 MinPretestInitial15 Min Well Name Type Test Notes: Interval P/F Well Permit Number: Type Inj TVD PTD Test psi API Well Number Inspector Name:DUCK IS UNIT MPI 5-01 Inspection Date: Tubing OA Packer Depth 139 3051 3014 2991IA 45 Min 60 Min Rel Insp Num: Insp Num:mitKPS250806143502 BBL Pumped:5.1 BBL Returned:4.1 Monday, September 22, 2025 Page 1 of 1            • I Wallace, Chris D (DOA) From: NSK Well Integrity Supv CPF1 and 2 <n1617@conocophillips.com> Sent: Tuesday, February 13, 2018 8:38 AM To: Wallace, Chris D (DOA) Cc: Senden, R.Tyler Subject: KRU 2K-03 (PTD 188-120) Report of failed MITOA Attachments: 2K-03.pdf; 2K-03 90 day TIO trend 2-13-18.JPG; MIT KRU 2K-03 diagnostic MITIA 2-13-18.xlsx Chris, KRU water injection well 2K-03 (PTD 188-120)governed under AIO 26.016 failed a diagnostic MITOA yesterday. The well has been shut in since April 14, 2017 and will remain shut in. Following the failed MITOA a passing MITIA was achieved to prove barriers. A surface casing leak detect will be performed to determine where the leak point is. Additional correspondence will be made once a plan forward has been developed. A 90 day TIO trend,well bore schematic,and 10-426 for the passing MITIA are attached. Please let us know if you disagree or have any questions with this plan. Regards, Jan Byrne/Kelly Lyons Well Integrity Supervisor ConocoPhillips Alaska, Inc. Office phone: (907)659-7224 AINWELLS TEAM comps SCANNEV • • Wallace, Chris D (DOA) From: NSK Well Integrity Supv CPF1 and 2 <n1617@conocophillips.com> Sent: Saturday, June 10, 2017 4:56 PM To: Wallace, Chris D (DOA) Cc: Senden, R.Tyler Subject: RE: 2K-03 (AIO 26.016, PTD 188-120) Report of IA pressure anomaly update 6-10-17 Attachments: MIT KRU 2K-03 Diagnostic 4-18-17.xlsx; 2K-03 90 day TIO plot 6-10-17.jpg Chris, Following the reporting of 2K-03 in April, a passing shut-in MITIA and tubing packoff tests were achieved on April 18th. The IA was degassed at that time and an extended-monitor drawdown test has now passed. The IA has been holding steady for the last 2 months. Several days prior to the observation of the IA anomaly, we had performed an aggressive IA bleed. We therefore are speculating that the IA anomaly was caused by the liberation of gas entrained in the fluid following the bleed. CPAI plans to return the well to water injection for a 30 day monitor to confirm this theory. Following the monitor on water, if no further evidence of possible TxIA communication presents itself,the well will be returned to its normally waivered status, governed under AIO 2B.016 (for IAxOA communication). For reservoir management purposes tied to offset CTD drilling,the asset does not intend to return the well to injection until later this fall. Please let us know if you disagree with the path forward. Attached is the latest 90 day TIO plot and MITIA data. Kelly Lyons/ Brent Rogers Well Integrity Supervisor ConocoPhillips Alaska, Inc. Desk Phone (907) 659-7224 JUN 1 217, Mobile Phone (907) 943-0170 AtrE® From: NSK Well Integrity Supv CPF1 and 2 Sent: Friday,April 14, 2017 4:34 PM To: chris.wallace@alaska.gov Cc: Senden, R.Tyler<R.Tyler.Senden@conocophillips.com> Subject: 2K-03 (AIO 2B.016, PTD 188-120) Report of IA pressure anomaly 4-14-17 Chris, Injector 2K-03(AIO 2B.016, PTD 188-120) is experiencing an unexplained slow IA pressurization. The well is already waivered for IAxOA communication. As such, the well shut in and freeze protected earlier today when the anomaly was detected. DHD will be mobilizing to the well as soon a-possible to perform an MITIA and packoff and drawdown testing. The work may be delayed due to anticipated phase weather expected to hit later today. An email will be provided once the initial diagnostics are completed and a path forward is established. Attached are the schematic and 90 day TIO plot. Kelly Lyons/Brent Rogers Well Integrity Supervisor ConocoPhillips Alaska, Inc. Desk Phone (907) 659-7224 1 . • • dw®Lesfoilo . ) {] 0,T, *A t N .1, 1 .1.i. i .1.I. 1 11.I. + .1,b I 4.Al . .1,h } II T 4A7 1 11-i T . 10 11 �A M r 4 o N I V "r / 4 O a • r ! r- a n 2 4 N L. 1 _ I L w i l . r. 1 1 . 1 . 1 I..'I . rl i 1 iii , rr, la ISd • • Wallace, Chris D (DOA) From: NSK Well Integrity Supv CPF1 and 2 <n1617@conocophillips.com> Sent: Friday, April 14, 2017 4:34 PM To: Wallace, Chris D (DOA) Cc: Senden, R.Tyler Subject: 2K-03 (AIO 2B.016, PTD 188-120) Report of IA pressure anomaly 4-14-17 Attachments: 2K-03 schematic.pdf; 2K-03 90 day TIO 4-14-17.emf Chris, Injector 2K-03(AIO 2B.016, PTD 188-120) is experiencing an unexplained slow IA pressurization. The well is already waivered for IAxOA communication. As such, the well was shut in and freeze protected earlier today when the anomaly was detected. DHD will be mobilizing to the well as soon as possible to perform an MITIA and packoff and drawdown testing. The work may be delayed due to anticipated phase weather expected to hit later today. An email will be provided once the initial diagnostics are completed and a path forward is established. Attached are the schematic and 90 day TIO plot. Kelly Lyons/Brent Rogers Well Integrity Supervisor ConocoPhillips Alaska, Inc. Desk Phone (907) 659-7224 %A lta APR 2 0 2012 Mobile Phone (907) 943-0170 •n 1 • dwajfa oLij O O O c, O � O N N- , I 1 I. .1 . I . b ,1 . I . 1, 0 , . i ,I i ll. i .1 , I, I .I r 1, _ ? , — Q - Q Ci) O J �- -L i CN N- - v- .M O - — co 2- . _ ' l"V 0D O • _ _ (i) — ~ ead _0 7 - 1.-- L a 0 — MEM F- - (N N- I 1 2) 1 . 4) LL 0 _ - 1 - r CL Q -) u. — a0 N — fh- Y1 . 1 'I r Hi iI r I • I .1 1. 1 1 i 1. 1 .1 i 111 .1 11. 1 .1 co F- Q- O O OO OwO o o oto C N N "C- I ISd t� 120 ZS110 WELL LOG TRANSMITTAL To: Alaska Oil and Gas Conservation Comm. June 2, 2015 Attn.: Makana Bender 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 RECEiVED JUN 04 261 RE: Multi Finger Caliper(MFC)/Leak Detect Log: 2K-03 Run Date: 05/25/2015 and 05/22/2015 AC)G CC The technical data listed below is being submitted herewith. Please address any problems or concerns to the attention of: Fanny Sari, Halliburton Wireline & Perforating, 6900 Arctic Blvd., Anchorage, AK 99518 FRS_ANC@halliburton.com 2K-03 Digital Data(LAS), Digital Log file, Casing Inspection Report, 3D Viewer 1 CD Rom 50-103-20100-00 Leak Detect Log 1 Color Log 50-103-20100-00 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Halliburton Wireline & Perforating Attn: Fanny Sari 6900 Arctic Blvd. Anchorage, Alaska 99518 Office: 907-275-2605 Fax: 907-273-3535 FRS_ANC@halliburton.com Date: Signed: 6-44"elt MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: Jim Regg ! DATE: Monday,June 01,2015 P.I.Supervisor (.,i/(5(t`- SUBJECT: Mechanical Integrity Tests CONOCOPHILLIPS ALASKA INC 2K-03 FROM: Lou Grimaldi KUPARUK RIV UNIT 2K-03 Petroleum Inspector Src: Inspector Reviewed By: P.I.Supry NON-CONFIDENTIAL Comm Well Name KUPARUK RIV UNIT 2K-03 API Well Number 50-103-20100-00-00 Inspector Name: Lou Grimaldi Permit Number: 188-120-0 Inspection Date: 5/30/2015 Insp Num: mitLG150531141546 Rel Insp Num: Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min Well 2K-03 • Type Inj W• TVD 6007 -1 Tubing 860 7 860 860 - 860 - PTD1 1881200 - Type Test SPT Test psi 3360 - IA 1350 3500- 3430 34201 Interval REQVAR PAF i P _ OA 495 566 - 573 - 577 Notes: Test to 1 2 times max injection pressure per A A 2B.016.3 2 bbl's diesel pumped,3.5 returned.All required documentation provided prior to test Sainte U 1 3 _01. Monday,June 01,2015 Page 1 of 1 Ima ect Well History File' Cover~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. / ~:~'~- / ~[' 0 Well History File Identifier RESCAN DIGITAL DATA OVERSIZED (Scannable) [] Color items: [] Diskettes, No. [] Maps: [] Grayscale items: [] Other, No/Type [] Other items scannable by large scanner [] Poor Quality Originals: ~ OVERSIZED (Non-Scannable) [] Other: , NOTES: D Logs of various kinds [] Other BY: BEVERLY BREN VINCENT SHERYL MARIA LOWELL DATE: /S/ Project Proofing BY: BEVERLY BREN VINCENT SHERYL MARIA LOWELl. DATE: /SI Scanning Preparation + /,,7_= BY: BEVERLY BREN VINCENT SHERYL MARIA LOWELL DATE: TOTAL PAGES ~SI Production Scanning Stage 1 PAGE COUNT FROM SCANNED FILE: ~ PAGE COUNT MATCHES NUMBER IN SCANNING PREPARATION: ~"~YES NO BEVERLY BREN VINCENT~MARIA LOWELL DATE:¢/~""~,,.~..~S! ~ IF NO IN STAGE 1 , PAGE(S) DISCREPANCIES WERE FOUND: YES NO Stage 2 BY~ BEVERLY BREN VINCENT SHERYL MARIA LOWELL DATE: (SCANNING IS COMPLETE AT THIS POINT UNLESS SPECIAL ATTENTION IS REQUIRED ON AN INDIVIDUAL PAGE BASIS DUE TO OUALI3Y. GRAYSCALE OR COLOR IMAGES) IS~ ReScanned (individual page [special attention] scanning completed) RESCANNEDBY~ BEVERLY BREN VINCENT SHERYL MARIA LOWELL DATE: /si General Notes or Corem ents about this file: Quality Checked (done) 10125/02Rev3NOTScanned.wpd • • MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission DATE: Thursday, July 28, 2011 TO: Jim Regg C P.I. Supervisor �1� i ��"l r1 SUBJECT: Mechanical Integrity Tests CONOCOPHILLIPS ALASKA INC 2K -03 FROM: Chuck Scheve KUPARUK RIV UNIT 2K -03 Petroleum Inspector Src: Inspector Reviewed By: P.I. Supry See-- NON- CONFIDENTIAL Comm Well Name: KUPARUK RIV UNIT 2K -03 API Well Number: 50- 103 - 20100 -00 -00 Inspector Name: Chuck Scheve Insp Num: mitCS110727063236 Permit Number: 188 -120 -0 Inspection Date: 7/26/2011 Rel Insp Num: Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. Well 1 2K -03 ' Type Inj. W . TVD 6007 / I IA 1380 -1 3400 - 3320 - 3310 - ' P.T.D 1881200 [TypeTest SPT 1 Test psi 1 3360 - OA 1 1280 1450 1450 1 1450 Interval PEQ'AR p/F P / Tubing] 2100 I 2100 2100 2100 Notes: MAD 2-6,01{,, , ire 'C( 4 r sw, e_ = tAa,k . ci r t,t i. , P ,1''" A'Ai Thursday, July 28, 2011 Page 1 of 1 • • MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission DATE: Thursday, July 14, 2011 TO: Jim Regg / P.I. Supervisor i I !r SUBJECT: Mechanical Integrity Tests CONOCOPHILLIPS ALASKA INC 2K -03 FROM: John Crisp KUPARUK RIV UNIT 2K -03 Petroleum Inspector Src: Inspector Reviewed By: P.I. Supry .� NON - CONFIDENTIAL Comm Well Name: KUPARUK RIV UNIT 2K - 03 API Well Number: 50 103 - 20100 - 00 - 00 Inspector Name: John Crisp Insp Num: mitJCrl 10627154653 Permit Number: 188 - 120 - Inspection Date: 6/24/2011 Rel Insp Num: Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. Well 2K -03 -- Type Inj. r W TVD 6007 ' I A 1120 1140 1142 1147 P.T.D 1881 zo 0 'ITypeTest SPT Test psi 1501 - OA 1128 1800 1780 1780 - Interval OTHER p/F' P - Tubing I z000 3 z000 2000 200 Notes: OAMIT not required by AA. CPAI tested for internal evaluation; no corresponding operator report. .4 bbls pumped for test. A '2.13 0 tie 5'' 201'i Thursday, July 14, 2011 Page 1 of 1 Page 1 Al �, Regg, James B (DOA) From: Regg, James B (DOA) 113111 iRg-- Zo Sent: Wednesday, July 13, 2011 11:48 AM To: 'NSK Problem Well Supv'; DOA AOGCC Prudhoe Bay Subject: RE: 2K test pressure question Thank you; just a precaution to be careful with the use of "generic max anticipated injection pressure "; be certain it complies with our conditions of approval. Jim Regg AOGCC + � Y6 � 333 W.7th Avenue, Suite 100 1R � G` 6 #� .� 2 0 Anchorage, AK 99501 907 - 793 -1236 From: NSK Problem Well Supv [mailto:n1617 @conocophillips.com] Sent: Tuesday, July 12, 2011 7:29 PM To: DOA AOGCC Prudhoe Bay Subject: 2K test pressure question Hi John, So I tracked down Brent and asked about where the 3600psi on the 2K MITIAs came from. So apparently we like using 3000psi as a generic max anticipated injection pressure, and so 1.2x3000 = 3600. We like using 3000psi because it is usually the highest that water injectors will see. Even though 2K is typically 2800psi, there's a potential for it to go higher and so we want to be within compliance at all times. Give me a call if you want to discuss further Kelly Brent Rogers / Kelly Lyons Problem Wells Supervisor ConocoPhillips Alaska, Inc. Desk Phone (907) 659 -7224 Pager (907) 659 -7000 pgr. 909 7/13/2011 • • Page 1 of 1 Regg, James B (DOA) From: Regg, James B (DOA) l 7 /i ZI 1( 11I&& 2 K —0 Sent: Monday, July 11, 2011 4:19 PM To: NSK Problem Well Supv Cc: DOA AOGCC Prudhoe Bay; Brooks, Phoebe L (DOA) Subject: RE: CPAI State Witnessed MITIAs - KRU 2K -03: AIO 2B.16 requires MIT to 1.2 times max anticipated injection pressure; most recent 90day TIO plot provided to Commission in monthly injection waiver report shows max injection pressure just shy of 2800psi (req'd test if this is anticipated max would be approximately 3360psi); unclear why report shows required test pressure of 3600psi w/o a matching test to that pressure - KRU 2K -10: AIO 2B.17 requires MIT to 1.2 times max anticipated injection pressure; most recent 90day TIO plot provided to Commission in monthly injection waiver report shows max injection pressure just shy of 2800psi (req'd test if this is anticipated max would be approximately 3360psi); unclear why report shows required test pressure of 3600psi w/o a matching test to that pressure - KRU 2Z -23: well name should be 2Z -23A Jim Regg AOGCC 333 W.7th Avenue, Suite 100 JUL 1 4 WI Anchorage, AK 99501 907 - 793 -1236 From: NSK Problem Well Supv [mailto:n1617 @conocophillips.com] Sent: Sunday, June 26, 2011 1:26 PM To: Regg, James B (DOA); DOA AOGCC Prudhoe Bay; Brooks, Phoebe L (DOA); Maunder, Thomas E (DOA) Cc: NSK Problem Well Supv Subject: CPAI State Witnessed MITIAs All, Attached for your records are the MIT forms for tests performed on Kuparuk Drilisites 2K and 2Z on 06/24/11 as witnessed by John Crisp. if you have Please contact me at your convenience questions or comments. y q Martin Martin Walters / Brent Rogers Problem Wells Supervisor ConocoPhillips Alaska Inc. Office 907 - 659 -7224 Cell 907 - 943 -1720 / 1999 Pager 907 - 659 -7000 #909 7/12/2011 • • MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission DATE: Tuesday, June 28, 2011 TO: Jim Regg P.I. Supervisor ( ( 7 o / II SUBJECT: Mechanical Integrity Tests CONOCOPHILLIPS ALASKA INC 2K -03 FROM: John Crisp KUPARUK RIV UNIT 2K -03 Petroleum Inspector Src: Inspector Reviewed By: P.I. Supry NON - CONFIDENTIAL Comm Well Name: KUPARUK RIV UNIT 2K - 03 API Well Number: 50 103 - 20100 - 00 - 00 Inspector Name: John Crisp Insp Num: mitJCr110628104111 Permit Number: 188 - 120 - Inspection Date: 6/24/2011 Rel Insp Num: Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. Well �2K-03 i Type Inj. W TVD 6007 IA 1295 2800 . 2680 2660 - 1 881200 SPT 1501 OA 1150 1260 1260 1260 P.T.D TypeTest Test psi Interval REQVAR P/F P - Tubing j 2000 2000 2000 1 1 2000 1 Notes: MITIA as per AIO 2B.016. 2.9 bbls pumped for test. Tuesday, June 28, 2011 Page 1 of 1 Page 1 of 1 • • Maunder, Thomas E (DOA) From: Regg, James B (DOA) Sent: Thursday, June 02, 2011 5:16 PM To: NSK Problem Well Supv Cc: Maunder, Thomas E (DOA); Brooks, Phoebe L (DOA) Subject: RE: Request permission for delay in testing 2K while SI Delaying MITs on 2K -03 and 2K -10 is acceptable. Commission preference is to do MITs while on injection; hopefully water supply to 2K pad can be restored as anticipated. Delaying the 2 MITs to be done in conjunction with the 4 -year pad test will allow for more efficient use of Commission Inspection resources. Also in support of this delay is the monthly TIO pressure data provided to the Commission for 2K -03 and 2K -10 as required in the admin approval; there have been no anomalous pressure trends identified. Please remember that the MIT anniversary date is set in those admin approvals and will not be adjusted by delaying these MITs. Jim Regg AOGCC (� 4 333 W.7th Avenue, Suite 100 + 3 U N 1 6' 2 01 , Anchorage, AK 99501 � r 907- 793 -1236 From: NSK Problem Well Supv [ mailto :n1617 ©conocophillips.com] Sent: Thursday, June 02, 2011 4:58 PM To: Regg, James B (DOA) Cc: NSK Problem Well Supv Subject: Request permission for delay in testing 2K while SI Jim, As per our phone discussion, currently there is no water injection out to 2K pad and there are 2 rigs on the pad as well. The pad is due for its 4 year witnessed MITIA's this month. There are also two wells, 2K-03 (PTD 188 -120) and 2K -10 (189 -059) that were due for their AA compliance testing on 06/01/11. Both of those wells have been S1 since 12/04/10. Water injection is tentatively planned to be restored to the pad this month. ConocoPhillips is requesting permission to perform the AA compliance testing and the pad testing once water injection has been restored to the pad. Please let me know if you have any questions. Brent Rogers /Martin Walters Problem Wells Supervisor ConocoPhillips Alaska, Inc. Desk Phone (907) 659 -7224 Pager (907) 659 -7000 pgr. 909 6/16/2011 ~ MEMORANDUM To: Jim Regg ~~~ 7 ZZ Oa P.I. Supervisor ~ ~ ~ ~ ~ FROM: Chuck Schev~ Petroleum Inspector State of Alaska • Alaska Oil and Gas Conservation Commission DATE: Wednesday, June 10, 2009 SUBJECT: Mechanical Integrity Tests CONOCOPHILLIPS ALASKA INC 2K-03 KUPARLTK RIV IJNIT 2K-03 Src: Inspector NON-CONFIDENTIAL Reviewed By: P.I. Suprv ~~ Comm Well Name: KUPARUK RN tINIT 2K-03 API Well Number: 50-103-20100-00-00 Insp Num: mitCS090605070416 Permit Number: 188-120-0 i Rel Insp Num: Inspector Name: Chuck Scheva Inspection Date: 6/4/2009 Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. Well zx-o3 Type Inj. W TVD 600~ ~ IA ~oo s6z o~ zs6o zsso r P.T.D 1881200 TypeTest SPT Test psi i 1501,75 QA 380 440 460 460 Interval ~QVAR P~` P ~ Tubing 19so 1950 1950 1950 ~ _ NOtes: Well has known slow IA x OA comunication. ~ f~' Z~ _(~ t~ . . a~ °i«,cc.., f ~ ii '7 r1(t: ~ ._ ._ ~ _, Wednesday, June 10, 2009 Page 1 of 1 ~' • MEMORANDUM To: Jim Regg / -~ c P.I. Supervisor ' ~~ ~4 ~ bl~ FROM: John Crisp Petroleum Inspector • State of Alaska Alaska Oil and Gas Conservation Commission DATE: Monday, June ls, 2009 SUBJECT: Mechanical Integrity Tests CONOCOPHILLIPS ALASKA INC 2K-03 KUPARUK RIV UNIT 2K-03 Src: Inspector NON-CONFIDENTIAL Reviewed By: P.I. Suprv~~~-- Comm Well Name: KUPARUK RIV UNIT 2K-03 API Well Number: 50-103-20100-00-00 Inspector Name: John Crisp Insp Num: mitJCr0906021s3023 Permit Number: 188-120-0 Inspection Date: s/28/2009 Rel Insp Num: Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. Well zK-o3 Type Inj. ~' T~ 60076007 IA Ilzs Ilso 9zo ass ~ ~ P.T D Isstz°° TypeTest SPT Test psi L 1800 ~i y OA soo tsoo I~3o ~7zo_~ P ~ Tubing ~ Interval REQvAR P/F zaoo ~ zaoo zaoo zaoo Notes: 2 Year test. Per CPAI 6/s/09 email - MI7'OA done per CPAI internal waiver regts (in addition to AOGCC required MITIA in AIO 2B.016) Significant pressure drop in IA attributed to aborted MITIA (See MitJcr0906021 s2727) - 20 bbl ambent temp diesel pumped into IA before aborting test caused cooling (thermal}, reducing pressure. '~' r ~ z- ~~ K n.... Monday, June 15, 2009 Page 1 of 1 ~, • MEMORANDUM To: Jim Regg Vi~~ ~,~ 1 ~~j P.I. Supervisor ````~~ FROM: John Crisp Petroleum Inspector C~ State of Alaska Alaska Oil and Gas Conservation Commission DATE: Monday, June 08, 2009 SUBJECT: Mechanical Integrity Tests CONOCOPHILLIPS ALASKA INC 2K-03 KUPARUK RIV UNIT 2K-03 Src: Inspector NON-CONFIDENTIAL Well Name: KUPARUK RIV UNIT 2K-03 API Well Number: s0-103-20100-00-00 Inspector Name: John Crisp Insp Num: mitJCr090602152727 Permit Number: 188-120-0 Inspection Date 5/28/2009 Rel Insp Num: Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. Well 2K-03 TYPe Inj. ~VD~ ~ P.T.DI lasl2oo TypeTest ~ Test psi ~~ boos I~ - ~isoL~s~A _sso I- ago i ~- ~_ Interval Other (describe in Pte, Incomplete Tubing zaoo ___ __ Notes: 20.7 BBL's pumped into IA. Aborted test until IA is full & stable. ~~- ~~ 'Z~ .~~~ Monday, June 08, 2009 Page 1 of 1 ~RE: Kuparuk State Witnessed ~ • Page 1 of 2 Regg, James B (DOA) From: NSK Problem Well Supv [n1617@conocophillips.com] Sent: Friday, June 05, 2009 8:48 AM ~~ (~,. ~ ~~ Z~~ To: Regg, James B (DOA) k Cc: Maunder, Thomas E (DOA); Fleckenstein, Robert J (DOA) _ ~ ~ ~~.~~ ~~ Subject: RE: Kuparuk State Witnessed MITs ~ ~~ 0~.~~~ Jim, ~ ti~~~ ~C,t' dq ~~Z~O i Regarding KRU 2K-03 - In the AA justification, CPAI said we would MITOA every 2 years to 1800 psi. That stipulation was not on AIO 28.016, however CPAI added to the internal waiver requirements as a barrier confirmation. -The significant IA pressure drop can be attributed to the aborted MITIA. The IA was not allowed to be filled completely up when the test was aborted. However 20 bbls of ambient temperature diesel was just added to the IA and some cooling effects of that colder diesel, combined with a smaller void in the annulus could show those kind of pressure swings. That could also be combined with the casing swell effects from the MITOA and the slight pressure drop during the MITOA as well. KRU 2K-10 -The pressure increase would be related to thermal issues as well. The ambient diesel thermaled up during the test and could show the increase in pressure during that last 15 minutes due to thermal expansion. Please let me know if you have any more questions. Brent Rogers/Martin Walters Problem Wells Supervisor ConocoPhillips Alaska, Inc. Desk Phone (907) 659-7224 Pager (907) 659-7000 pgr. 909 From: Regg, James B (DOA) [mailto:jim.regg@alaska.gov] Sent: Thursday, June 04, 2009 2:02 PM To: NSK Problem Well Supv Cc: Maunder, Thomas E (DOA); Fleckenstein, Robert J (DOA) Subject: RE: Kuparuk State Witnessed MITs KRU 2K-03 - MITOA per CPAI waiver? If waiver required per CPAI policy, shouldn't it also be covered by AA? - significant drop in IA pressure during MITOA; why? KRU 2K-10 - pressure recorded at 30 minute mark increased 15 psi (from 2970 to 2985); reason? Jim Regg AOGCC 333 W.7th Avenue, Suite 100 Anchorage, AK 99501 907-793-1236 6/5/2009 ,RE: Kuparuk State Witnessed s ~ Page 2 of 2 From: NSK Problem Well Supv [mailto:n1617@conocophillips.com] Sent: Tuesday, June 02, 2009 8:43 AM To: Fleckenstein, Robert J (DOA); Regg, James B (DOA); Maunder, Thomas E (DOA) Cc: NSK Well Integrity Proj; NSK Problem Well Supv Subject: RE: Kuparuk State Witnessed MITs «MIT KRU 2K-03 10 5-28-09.x1s» Forgot the attachment. From: NSK Problem Well Supv Sent: Tuesday, June 02, 2009 8:39 AM To: 'Bob_Fleckenstein@admin.state.ak.us'; 'Jim_Regg@admin.state.ak.us'; Tom_Maunder@admin.state.ak.us' Cc: NSK Well Integrity Proj; NSK Problem Well Supv Subject: RE: Kuparuk State Witnessed MTrs Attached is the revised MIT form for 2K-03 to reflect the aborted MITIA after pumping 20 barrels of diesel and only achieving 1400 psi. Martin From: NSK Problem Well Supv Sent: Saturday, May 30, 2009 1:43 PM To: 'Bob_Fleckenstein@admin.state.ak.us'; 'Jim_Regg@admin.state.ak.us'; Tom_Maunder@admin.state,ak.us' Cc: NSK Well Integrity Proj; NSK Problem Well Supv Subject: Kuparuk State Witnessed MITs « File: MIT KRU 1 E-04 5-28-09.x1s » « File: MIT KRU 2T-05 5-28-09.x1s » « File: MIT KRU 2K-03_10 5- 28-09.x1s» « File: MIT KRU 1J-184 5-28-09.x1s» All, Attached for your records are the MITs as witnessed by John Crisp on 05/28/09. Please contact me at your convenience if you have questions or comments. Martin Martin Walters / Brent Rogers Problem Wells Supervisor ConocoPhillips Alaska Inc. Office 907-659-7224 Cell 907-943-1720 / 1999 Pager 907-659-7000 #909 6/5/2009 • • ConocoPhillips ~~ P.O. BOX 100360 ANCHORAGE, AIASKA 99510-0360 AUG : 20D8 July 29, Zoos Mr. Tom Maunder Alaska Oil & Gas Commission 333 West 7~' Avenue, Suite 100 Anchorage, AK 99501 ~~~ ~~ Dear Mr. Maunder: 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 June 30, July 4 and July 20, 2008. The corrosion inhibitor/sealant was pumped June 29, June 30, JulylO,and July 24, 2008. The attached spreadsheet presents the well name, top of cement depth prior to filling, and volumes used on each conductor. Please call MJ Loveland or Perry Klein at 907-659-7043, if you have any questions. Sincerely, .~~ M.J. Loveland 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 L Date 7/29/2008 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 2K-01 1.88-122 SF NA 10" 6/30/2008 2 6/29/2008 2K-02 188-121 SF NA 10" 6/30/2008 2 6/29/2008 2K-03 188-120 24" NA 24" 6/30/2008 8.5 6/29/2008 2K-05 188-118 SF NA 10" NA 2.55 7/10/2008 2K-06 189-082 SF NA 15" NA 1.27 7/10/2008 3K-13 189-095 8'1" 1.00 25" 7/4/2008 6.38 7/10/2008 2K-15 189-089 SF NA 6" 6/30/2008 1 6/30/2008 2K-17 189-119 10" NA 10" 6/30/2008 23.8 6/30/2008 2K-18 189-108 SF NA 11" NA 2.12 .7/10/2008 2K-21A 198-158 20' 2.70 14" 7/4/2008 4.68 7/10/2008 2K-22 189-115 6" NA 6" 6/30/2008 5.1 6/30/2008 2K-25 190-012 SF NA 12" NA 2.55 7/10/2008 2K-26 190-015 SF NA 10" 6/30/2008 2 6/29/2008 2K-28 201-154 3'10" NA 3"10" 6/30/2008 23.8 6/30/2008 2M-04 192-093 SF NA 20" NA 3.4 7/10/2008 2M-27 192-071 9'9" 1.2 18" 7/4/2008 2.55 7/10/2008 26-07 184-024 20' 2.7 34" 7/4/2008 5.95 7/10/2008 2V-01 183-158 24" NA 24" NA 20.4 7/24/2008 2V-02 183-161 11" NA 11" NA 1.3 7/24/2008 2V-03 183-164 24' 6" 3.40 8" 7/20/2008 5.5 7!24/2008 2V-04 183-165 20' 4" 2.80 8" 7/20/2008 5.1 7/24/2008 2V-05 183-176 SF NA 4" NA 2.1 7/24/2008 2V-09 185-037 SF NA 4" NA 1.7 7/24/2008 2V-11 185-049 SF NA 4" NA 1.7 7/24/2008 2V-12 185-050 40' S.4 8" 7/20/2008 8.5 7/24/2008 2V-13 185-030 18" NA 18" NA 3.8 7/24/2008 2V-14 185-031 SF NA 4" NA 1.7 7/24/2008 2V-15 185-032 SF NA 4" NA 1.7 7/24/2008 Regg, James B (DOA) From: NSK Problem Well Supv [n1617@conocophillips.com] Sent; Wednesday, October 17, 2007 5:09 AM To: Regg, James B (DOA) ~~ Subject: Emailing: MIT KRU 2K-03 05-10-07.x1s .!~~~~ ~ i/ ~~ ~ ~ ~ Attachments: MIT KRU 2K-03 05-10-07.x1s ~ .. _-'-. J MIT KRU 2K-03 05-10-07.x1s (22... «MIT KRU 2K-03 05-10-07.x1s» Jim, Enclosed is the requested MITOA for 2K-03 (PTD/~,188-120), produced water injector. Let me know if you have any questions. \.~ Perry Klein Problem Well Supervisor office (907) 659-7224 Cell (907) 943-1244 Pager (907) 659-7000 x909 n1617@conocophillips.com i . ~ . Regg, James B (DOA) From: Regg, James B (DOA) Sent: Tuesday, October 16, 2007 3:32 PM ~ ~ ~.~ ~ ~ ~ tr ? To: 'NSK Problem Well Supv' "`:`~' Subject: KRU 2K Admin Approval Requests Please send MITOAs for following: 2K-03 (PTD 188-120): MITOA dated 5/10/2007 2K-10 (PTD 189-059); MITOA dated 8/5/2007 Jim Regg AOGCC 333 W.7th Avenue, Suite 100 Anchorage, AK 99501 phone: 907-793-1236 fax: 907-276-7542 '. , ,, \' J ;, ~ 7 ~ , v r----~ ~-~ ` I~~l 10/17/2007 • STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION Mechanical Integrity Test Email to: Bob_Fleckenstein@admin.state.ak.us; Jim_Regg@admin.state.ak.us; Tom_Maunder@admin.state.ak.us OPERATOR: FIELD /UNIT /PAD: DATE: OPERATOR REP: AOGCC REP: ConocoPhillips Alaska Inc. Kuparuk/ KRU / 2K-03 05/10/07 Rogers ~C~`C~ C ~ ~-1~ .3 I ~~- 0 Packer Depth Pretest Initial 15 Min. 30 Min. Well 2K-03 Type Inj. W TVD 6,007' Tubing 2600 2600 2600 2600 Interval p P.T.D. 1881200 Type test P Test psi 1502 Casing 1050 1050 1050 1050 P/F P Notes: MITOA -not state witnesed OA 1000 1800 1780 1780 WeII Type Inj. TVD Tubing Interval P.T.D. Type test Test psi Casing P/F Notes: OA Well Type Inj. TVD Tubing Interval P.T.D. Type test Test psi Casin P!F Notes: OA Well Type Inj. TVD Tubin Interval P.T.D. Type test Test psi Casing P/F Notes: OA Well Type Inj. TVD Tubing Interval P.T.D. Type test Test psi Casing P/F Notes: OA Well Type Inj. TVD Tubing Interval P.T.D. Type test Test psi Casing P/F Notes: OA D =Drilling Waste M =Annulus Monitoring G =Gas P =Standard Pressure Test I =Industrial Wastewater R =Internal Radioactive Tracer Survey N =Not Injecting A =Temperature Anomaly Survey W =Water D =Differential Temperature Test ~ - ~~ ~~~~a~ ~ ~~~ 4 =Four Year Cycle V =Required by Variance T =Test during Workover O =Other (describe in notes} MIT Report Form BFL 9/1/05 2007-0510_MIT_KRU_2K-03.x1s MEMORANDUM . State of Alaska . Alaska Oil and Gas Conservation Commission TO: Jim Regg ~êtJú to/tolD? P.I. Supervisor { 7 DATE: Wednesday, June 06, 2007 SUBJECT: Mechanical Integrity Tests CONOCOPHILLIPS ALASKA INC 2K-03 KUPARUK RIV UNIT 2K-03 ~~ \'J.D \Có FROM: Chuck Scheve Petroleum Inspector Src: Inspector Reviewed By: P.I. Suprv ,~ Comm Well Name: KUPARUK RlV UNIT 2K-03 API Well Number: 50-103-20100-00-00 Inspector Name: Chuck Scheve Insp Num: mitCS070601 182917 Permit Number: 188- I 20-0 Inspection Date: 6/1/2007 /' Rei Insp Num: Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. Well 2K-03 Type Inj. w TVD 6007 IA 1280 3100 3040 3030 P.T.D 1881200 TypeTest SPT Test psi 1501.75 OA 860 1000 1000 1000 Interval OTHER P/F P ..,/ Tubing 2500 2500 2500 2500 Notes: Well is waivered for slow IA x OA communication. No communication noted during pretest observation or during the 30 minute pressure test NON-CONFIDENTIAL v SCANNED jUN 2 0 2007 Wednesday, June 06, 2007 Page I of 1 MEMORANDUM e State of Alaska e Alaska Oil and Gas Conservation Commission TO: Jim Regg P.I. Supervisor ':7 K,.i2~¿ S' I ell Oi.µ {{ DATE: Wednesday, May 17,2006 SUBJECT: Mechanical Integrity Tests CONOCOPHILLIPS ALASKA INC 2K-03 KUPARUK RIV UNIT 2K-03 c:rO 4>/\ \'b FROM: Chuck Scheve Petroleum Inspector Src: Inspector Reviewed By: p.I.Suprv~ Comm NON-CONFIDENTIAL Well Name: KUPARUK RIV UNIT 2K-03 API Well Number 50- 103-20 100-00-00 Inspector Name: Chuck Scheve Insp Num: mitCS0605I506I748 Permit Number: 188-120-0 Inspection Date: 5/I 4/2006 ReI Insp Num Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. i 2K-03 ¡Type Inj. ! w i TVD , I ,-- I Well 6007 i IA ! 1590 2550 2510 i 2510 ¡ ¡ I I ! P.T. i 1881200 ¡TypeTest i SPT ! Test psi I 1501.75 I OA I 1250 ! 1250 i 1250 I 1250 i ¡ Tubing I 2500 I 2500 2500 I 2500 Interval REQVAR P/F P I I I I Notes Pretest pressures were observed and found stable. This Well is waivered for IA x OA comunication with an allowable OA operating pressure of 1400 psi. .- 5/LoR'1""''c( ( P IV-I..- fð (,;¿c.,"~Gj k(.....,/\ I\.£¿ l'v~~ Apt:> ,-V\l·JL CtJPI ¡\ü"h;, /"' C..: ) -tc\> R:.¿: ¡¿'-~ I t7iChù\ ~e ;J..~- í1 ! .'J "- -t:\'''L",-,l<;Siú;'':' - C· ~c. Ü-".¿\. SCANNEù JUN 1 '" ':>00i'" .¡) '- ! '0 Wednesday, May 17, 2006 Page I of I e e subject: Re: 2K-03 (PTD 188-120) j~~~~ Regg <jim_regg@admin.state.ak.us> ÍÍ<?e4t,l,~\\1\~ Date: t wed, 17 May 2006 13:46:24 -0800 To: NSK Problem well Supv <n1617@conocophillips.com> CC: Tom Maunder <tom_maunder@admin.state.ak.us>, NSK well Integrity proj <N1878@conocophillips.com> You should formally request administrative approval per AIO 2B Rule 9 for this well. Jim Regg AOGCC NSK Problem well supv wrote: KRU_2K-03_IAXOA-2006-0517.txt > Jim, > > Per your request, I have attached a copy of the IAxOA ANN COM waiver for injection well 2K-03 (PTD 188-120). > a schematic and a T/I/O plot are also attached. Also please note that the well has been waivered since 11/6/03 (corrected date from last email) and yearly waiver compliance testing and diagnostics have been completed on an on going basis. > > Let me know if you would like any more information regarding the operation of this well. > > Also, as a side thought, it is possible that there are a few more injection wells out there that are internally waivered that the AOGCC may not be aware of. prior to 2003, there was a verbal understanding with the AOGCC to only report failed MITIA'S on injection wells. In the fall of 2003 conocoPhillips supplied the AOGCC with a paper copy of all of our internal injection well waivers. I believe that was october, a month or so before this well was waivered. which would explain why you don't have a copy of it, however, I can not confirm that this is the only one that slipped through the cracks during the time inbetween. > > > > MJ Loveland > > > > > > > > > > > > > > > Thanks for the clarification about KRU 3F-04 pressures. I still have some concerns about KRU 2K-03 (PTD 1881200). > > AIO 2B, Rule 7 requires: "whenever operating pressure observances or pressure tests indicate pressure communication or leakage of any casing, tubing or packer, the operator must notify the commission on the first working day following the observation, obtain commission approval of a plan for corrective action, and when an page 1 Co no coP hi 1 1 ips Alaska well Integrity project office (907) 659-7043 Cel (907) 448-3114 supervisor t', -----original Message----- From: James Regg [mailto:jim_regg@admin.state.ak.us] Sent: Tuesday, May 16, 2006 1:50 PM To: NSK Problem well Supv Cc: Tom Maunder subject: Re: 2006 witnessed MITIA's e e KRU_2K-03_IAxOA-2006-0517.txt USDW is not endangered, obtain commission approval to continue injection." > > I have reviewed our well files and find no notice of pressure communication or leakage, and no record of a waiver for KRU 2K-03. please send a TIO plot for KRU 2K-03, well schematic, and copy of the internal waiver you are using to allow continued water injection in the well. > > Jim Regg > AOGCC > » » page 2 e e KRU 2K-03 API: 501032010000 Well Tvpe: INJ Angle @ TS: 48 deg @ 8409 SSSV Type: TRDP Orig Completion: 6/4/1989 Angle @ TD: 47 dea @ 8861 SSSV Annular Fluid: Last W/O: Rev Reason: Post FCO TAG (1797-1798, Reference Log: Ref Log Date: Last Update: 7/26/2005 OD:2.875) Last Tag: 8607 TD: 8861 ftKB Last Taa Date: 6/25/2005 Max Hole Angle: 52 deg @ 2400 Description Size Top Bottom TVD Wt Grade Thread CONDUCTOR 16.000 0 115 115 62.50 H-40 SUR. CASING 9.625 0 3598 2925 36.00 J-55 Gas Lift PROD. CASING 7.000 0 8831 6392 26.00 J-55 ,drel/Dummy :?:Y'?:fAlI Valve 1 Size I Top Bottom I TVD I Wt I Grade I Thread (2650-2651 , OD:4.750) 2.875 I 0 8337 I 6056 I 6.50 I J-55 I EUE 8RD AB-MOD if:: Interval I TVD Zone I Status I Ft SPFI Date I Type I Comment 8474 - 8511 6148 - 6173 A-4 I I 37 2 110/30/1989 4" 1180 deg. Phasing Gas Lift Super ,drel/Dummy Valve 2 St MD TVD Man Man Type V Mfr V Type VOD Latch Port TRO Date Vlv (5373-5374, Mfr Run Cmnt OD:4.750) 1 2650 2290 Merla TMPD DMY 1.0 BK 0.000 0 5/4/1992 2 5373 4103 Merla TMPD DMY 1.0 BK 0.000 0 5/4/1992 3 7260 5340 Merla TMPD DMY 1,0 BK 0,000 0 5/4/1992 4 8207 5969 Merla TGPD DMY 1..5 RK 0.000 0 5/5/1992 Gas Lift ~~fI,.'" gig ,drel/Dummy Depth TVD Type Description ID Valve 3 1797 1706 SSSV Otis 'FMX' 2.313 (7260-7261, OD:4.750) 8250 5998 PBR Baker 2.500 8264 6007 PKR Baker 'HB' 2.375 8303 6033 NIP Cameo 'D' Nipple NO GO 2,250 8337 6056 SOS Baker 2.441 Gas Lift 8338 6057 TTL 2.441 'drel/Dummy :: Valve 4 Date I Note (8207-8208, 10/22/2003 WAIVERED WELL: IA x OA COMMUNICATION OD:5.460) PBR (8250-8251, OD:2.875) PKR (8264-8265, OD:6.151) NIP (8303-8304, OD:2.875) TUBING (0-8337, OD:2.875, ID:2.441) SOS (8337-8338, OD:2.875) Perf - - (8474-8511) - - - - - - - - - - THE MATERIAL UNDER THIS COVER HAS BEEN MICROFILMED ON OR BEFORE OCTOBER 24, 2000, E E C:LORIhMFILM. DOC Pl~ EW M A T ERIA L U N D ER TH IS M A R K ER_ ARCO Alaska, Inc. Post Office Box 100360 Anchorage, Alaska 99510-0360 Telephone 907 278 !215 July 10, 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 Report of Sundry Well Operations (Form 10-404) notices in the Kuparuk field. The wells are listed below. WELL ACTION WELL ACTION 2K-03 Conversion 2M-03 Conversion 2M-14 Conversion 2M-16 Conversion 2M-1 9 Conversion 2M-26 Conversion 2Z-04 Waiver If you have any questions, please call me at 263-4281. Sincerely, P. S. White Sr. Engineer Kuparuk Petroleum Engineering J LIL - 8 Alaska Oil & Gas Cons. Anchorage ARCO Alas"'a Inc. is a Subsidiary of Ai a l~: t.:R chfieid(; :,i¢,~; :~15; STATE OF ALASKA AL~._ iOIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations Performed: Operation ShutdoWn Pull tubing Alter casing Stimulate m Plugging Repair well 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 246' FSL, 94' FEL, SEC 2, T10N, R8E, UM At top of productive interval 1346' FNL, 1338' FWL, SEC 2, T10N, R8E, UM At effective depth 1346' FSL, 1338' FEL, Sec.2, T10N, R8E, UM At total depth 1156.' FNL, 1067' FEL~ Sec. 2, T10N, R8E, UM 12. Present well condition summary Total Depth: measured 8 8 61 true vertical 6 41 2 feet Plugs (measured) feet None Effective depth: measured .8750 feet Junk (measured) true vertical 6 3 3 6 feet None Casing Length Size Cemented Structural '~'Conductor I 1 5' 1 6" §L'-;face 3598' '9 5/8" 700 Sx AS III & Intermediate 500 Sx Class G Production 8 8 31' 7" 200 Sx Class G L ner Perforation depth: measured 6. Datum elevation (DF or KB) RKB 154 7. Unit or Property name Kuparuk River Unit feet 8. Well number 2K-O3 9. Permit n, umber/approval number 8~-12o/q z- ~o~ 10. APl number 5o-1 03-201 00 11. Field/Pool Kuparuk River Oil Pool ORIGINAL Measured depth True vertical depth 115' 115' 3598' 2925' 8831' 6392' 8474'-8511' 4" Casing Gun @ 2 SPF true vertical 6,148'-6,173' Tubing (size, grade, and measured depth) 2.875" J-55 set at 8337' : Packers and SSSV (type and measured depth) ~rown HB @ 8264', Otis FMX @ 1797' Stimulation or cement squeeze summary , Intervals treated (measured) , RECEIVED J U L - 8 3993 AJaska 0il & Gas Cons. Bumrnissio Anchorage Treatment description including volumes used and final pressure 14. Reoresentative Daily Average Production or In!ection Data . OiI-Bbl Gas-Md Water-Bbl Casing Pressure Tubing Pressure -tier to well operation 5 0 0 2 5 0 0 0 1 4 0 0 3OO .iSu asequent to operation N/A N/A 2 0 0 0 6 5 0 15, A~tachments 16. Status of well classification as: C,,opies of Logs and Surveys run__ Water Injector . }( Daily Report of Well Operations X Oil _ Gas Suspended 17 I hereby certify that the foregoing is true and correct to the best of my knowledge. Service 26OO Date Form 10-404 Rev 06/15/88 SUBMIT IN DUPLICATE 'ARCO Alaska, In ~,, -' WELL SERVICE REPORT Subsidiary of Atlantic Richfield Compa, 7 ~O l~t IFIELD' DISTRICT- DAYS . CONTRACTOR[(.~'/Z~ ~ ~ j ' ~_~ . ,~ t~/~v }1~. JOPERATION AT RE~RT TIME~~~ ~ ~' ~-- / I 91 eO P~ ~ ,5t J / RECEIVED JUL - 8 1993 Alaska 0il & Gas Cons. Co['nmissiov CHECK THIS BLOCK IF SUMMARY CONTINUED ON BACK Anchorage I Signed_..., / j~,~ knot~ ~ · ARCO Alaska, WELL SERVICE REPORT Subsidiary of Atlantic Richfield Corn< ELL CONTRACTOR MARES FIELD-DISTRICT-STATE IDA.~ IDATE OPERATION AT REPORT TIME J U L - R tqg~ Alaska Oil & c~ Cons. Corem!ss!or, Anchorag~ [-'] CHECK THIS BLOCK IF SUMMARY CONTINUED ON BACK Weather Temp. J Chill Factor I Visibility Wind VeL Report °FJ 0FI' ' miles knots ARCO Alaska, Inc. ~;¢ost Office Box 100360 /~..~chorage, A~aska 995i0-03~0 '~.~.iephone 907 276 !215 April 23, 1992 Mr. David W. Johnston, Chairman Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Dear Mr. Johnston: Attached in triplicate is an Application for Sundry Approval on the following Kuparuk well. Well Action Anticipated Start Date 2K-03 Convert to Water Inj. May, 1992 If you have any questions, please call me at 263-4281. Sincerely, C. W. Strickland Operations Engineer cc: J.D. Bolling ATO-1196 KOE1.4-9 (w/o attachments) (w/o attachments) Alaska, Inc. is a Subsidiary of .*4t ~ ,t¢ch c ~f,,-:, ,,_ ~,~:,~,~., RECEIVED APR 2 2 ~992 Alasl~a Oil & Gas Cons. L;ornl'r~Jss~O~ Anchorage STATE OFALASKA 0 R ALASKA OIL AND GAS CONSERVATION COMMISSION 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 _ Variance _ Perforate _ Other ...._ 6. Datum elevation (DF or KB) 2. Name of Operator ARCO Alaska. Inc. 3. Address ~P. O. Box 100360, Anchorage, AK 99510 5. Type of Well: Development X Exploratory _ Stratigraphic _ Service _ RKB 1~4 7. Unit or Property name Kuparuk River Unit feet 4. Location of well at surface 246' FSL, 94' FEL, SEC 2, T10N, R8E, UM At top of productive interval 1346' FNL, 1338' FWL, SEC 2, T10N, R8E, UM At effective depth 1346' FSL, 1338' FEL, Sec.2, T10N, R8E, UM At total depth 1156' FNL, 1067' FEL~ Sec. 2, T10N~ R8E~ UM 12. Present well condition summary Total Depth: measured 8 8 61 true vertical 6 41 2 Effective depth: measured 8 7 5 0 true vertical 6 3 3 6 Casing Length Size Structural Conductor 1 1 5' 1 6" Surface 3 5 9 8' 9 5/8" Intermediate Production 8 8 3 1 ' 7" Liner Perforation depth: measured feet Plugs (measured) feet None feet Junk (measured) feet None 8. Well number 2K-03 9. Permit number 88-12o 10. APl number sod 03-201 oo 11. Field/Pool Kuparuk River Field Kuparuk River Oil Pool Cemented Measured depth True vertical depth 115' 115' 700 Sx AS III & 3598' 2925' 500 Sx Class G 200 Sx Class G 8 831' 6 39 2' 8474'-8511' 4" Casing Gun @ 2 SPF true vertical 6,148'-6,173' Tubing (size, grade, and measured depth) 2.875" J-55 set at 8337' Packers and SSSV (type and measured depth) Brown HB @ 8264', Otis FMX @ 1797' RECEIVED -,.,~ 2 z 7'392 Alaska Oil & Gas Cons. Commissio,~ /~nch0rage 13. Attachments Description summary of proposal _ Detailed operation program ~X Convert well from oil producer to water injector. (Wellbore schematic attached). 14. Estimated date for commencing operation I 15. Status of well classification as: May 1992 [ oil _ Gas _ 16. If proposal was verbally approved Name of approver Date approved Service Water 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sic~ned C' (~. ~ Title Operations Enc~ineer FOR COMMISSION USE ONLY BOP sketch Suspended Iniector Date Conditions of approval: Notify Commission so representative may witness Plug integrity_ BOP Test_ Location clearance Mechanical Integrity Test ~. Subsequent form require 10-~'~/ Approved by order of the Commis~ss~ Form 10-403 Rev 0g/12/90 ~ IApproval No. .: , ?; :?:.~ ' 5-~-.?.~_ ...... Commissioner Date SUBMIT IN T~IPLICATE Well 2K-03 Conversion to Water Injection ARCO Alaska requests approval to convert Well 2K-03 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 8408' and 8614'. 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 performed 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. Alaska Oil & t~as Cons. Anchorage Well 2K-03 Water Injection Conversion AFC #996572 for 1992 KRU Waterflood Component AFC Downhole Charge Code: 4/20/92 Conversions K83339 1) Obtain final 12 hour welltest. Notify Operations Engineer to insure that Sundry Approval has been received prior to initiating wellwork. 2 ) SI well. MIRU Slickline and diesel pump truck. 3 ) RI H and set SV in Camco 'D' nipple at 8303' MD-RKB. 4 ) Pump diesel down casing while taking returns from tubing. Fill annulus with diesel. Casing displacement to bottom mandrel and mandrel depth are listed below: 2K-03 247 bbls 8207' MD-RKB 5 ) RIH to replace all GLV's with DV's. Ensure annulus is filled with diesel and hold at least 2000 psi surface casing pressure. 6 ) Pressure test tubing to 2500 psi to ensure DV's are set. 7) RIH and pulISV. 8) RDMO Slickline. Notify the State of the upcoming Mechanical Integrity Test(MIT). 9 ) Conduct MIT test with approximately 2500 psi surface WHP. Packer depth and 7" annular pressure necessary is shown below. completing test. Bleed the 7" annulus to 1500 psi after TVD Depth Required Casing Well Of Packer Pressure for MIT 2K-03 6007' 3525 PSI I 0) Initiate water injection until the maximum injection pressure is reached. VELL 2K-03 PRODUCER APl # 501032010000 SURFACE LOCATION: 246' FSL, 94' FEL, SEC 2, T10N, R8E, UM TOP KUPARUK: 1307' FNL, 1283' FWL, SEC 2, T10N, R8E, UM DEPTHS: REFERENCED TO 0' RKB TUBING SPOOL ELEV: 31' RKB ALL DEPTHS MD-RKB 16": 62,5# H-40 @ 115' 9 5/8": 36# J-55 @ 3598' TREE: FMC GEN IV 5000 PSI BAKER PBR: 2.500' ID @ 8250' BROWN HB PKR: 2.375' ID @ 8264' CAMCO 'D' NIPPLE: 2.25' ID @ 83O3' SHEAR OUT: 2.441" ID @ 8336' L ~, GLMI' GLM2: GLM3: GLM4: SPUD: 5/27/89 COMPLETION: 11/1/89 SSSV · OTIS FMX ID 2.313' @ 1797' 2650' / 5373' / 7260' / 8207' / 1.0"TMPD /GLV -1/4" 1.0"TMPD/GLV -1/4" 1.0"TMPD /GLV -1/4" 1.5"TGPD /OV - 3/16" 2.875" 6.5# J-55 EUE ABMOD IPC TUBING TAIL @ 8337' 7": B A5 A4 26# J-55 @ 8831' PBTD: 8760' HOLE ANGLE ACROSS KUPARUK = 47 DEGREES MAX HOLE ANGLE = 51 DEGREES @ 2400' VOLUME TO TOP P ~ 8474' ,Ar,~choraila 37' ~. 2 SPF ~. 180° PHASING ORIENTED 148° CCW 8511' FILL TAGGED AT 8505' ON 5/10/90 RATHOLE: -6' LAST RIH: 08/07/90 '"'~ STATE OF ALASKA A,~ ALASKA ~L AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1. Status of Well Classification of Service Well / OIL ~ GAS ,Fl SUSPENDED [] ABANDONED [] SERVICE [] 2. Name of' Operator 7. Permit Number ARCO Alaska, Inc. 88-120 3. Address 8. APl Number P.O. Box 100360, Anchorage, AK 99510-0360 50- 103-20100 4. Location of well at surface 9. Unit or Lease Name 246' FSL, 94' FEL, Sec. 2, T10N, R8E, UN Kuparuk River Unit At Top Producing Interval 10. Well Number 1346' FNL, 1338' FWL, Sec. 2, T10N, R8E, UM 2K-3 At Total Depth 11. Field and Pool 1156' FNL, 1067' FWL, Sec. 2, T10N, R8E, UM Kuparuk River/ 5. Elevation in feet (indicate KB, DF, etc.) I 6. Lease Designation and Serial No. 154' RKBI ADL:25588 ALK:2674 Kuparuk 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 05/27/89 6/01/89 11/01/89*J N/A feet MSL 1 17. TotalDepth(MD+TVD) 18.PlugBackDepth(MD+TVD, ,9. Dire~ionalSurvey)YES LC_J NO [] I 20' Depth where SSSV set l 21'Thickness°fPermafr°Stfeet MD 8861'MD/6412' TV~) 8750' MD/6336' TV 1797' N/A 22. Type Electric or Other Logs Run DI L/SP/GR/SFL. FDC/CNL/CAL. CRT. Gyro 23. CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD CASINGSlZE!WT. PER FT. GRADE TOP BOTTOM HOLE SIZE CEMENTING RECORD AMOUNT PULLED 16" Surf 115 -- 7" 26# J-55 Surf 883! 8-~" 200 sx C~.~ss 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) 2-7/8" ,6.5#,J-5J~ 8337 ' 8264 ' 8474'-8511' MD w/4" super omnikone @ 2spf 6148 ' -6173 ' TVD 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED 27. PRODUCTION TEST Date First Production I Method of Operation (Flowing, gas lift, etc.) I Date of Test Hours Tested PRODUCTION FOR OIL-BBL GAS-MCF WATER-BBL CHOKESlZE IGAS-OILRATIO TEST PERIOD ~ Flow Tubing Casing Pressure CALCULATED=~ OIL-BBL GAS-MCF WATER-BBL OIL GRAVITY-APl (corr) Press. 24~HOUR RATE 28. CORE DATA Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water. Submit core chips. N/A Form 10-407 Submit in duplicate Rev. 7-1-80 WC1/22 CONTINUED ON REVERSE SIDE 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. Kuparuk C 8408' 6104' None Kuparuk A " 8431' 6119' , ~ I 31. LIST OF ATTACHMENTS Gyro 32. I hereby certify that the 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 !: 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~ lng 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 ARCO Oil and Gas Company Well History - Initial Report - Daily Instructions; Prepare .~nd sucm~ ~he "Initial Report" on the f;rst Wednesday after a well is spuddea or workover .>p~:rahons are started. Daily work prior to spudding shou;d be summarized on the form giving inclusive dates only. District Field ARCO ALASKA INC. KUPARUK RIVER UNIT County, parish or borough NORTH SLOPE ILease or Unit ADL: 25588 ALK: 2674 ITitle COMPLETIONS j State AK 2K-3 iWell no. Auth, or W.O. no. AK3587 Operator R~CO Spudded or W.O~ begun IDate Hour SPUD I 05/27/89 15: 00 Date and depth as of 8:00 a.m. 10/31/89 ( TD: 8861 PB: 8.750 . SUPV:GB 11/Ol/89 (lO) Complete record for each day repo~ed .NORDIC #1 IARCO W.I. 55.8533 Prior status if a W,O. TD: 8861 PB: 8750 SUPV:GB TIH W/ TBG OPEN ENDED 7"@ 8831' MW: 0,.,0 NaCl MOVE RIG FROM 2K-5, ACCEPT RIG AT 1600 10/30/89, ND DRYHOLE TREE, NU BOPE, TEST BOPE TO 3000 PSI, RU WESTERN. E-LINE, PERF 8491-8511 & 8474-8491 AT 2 SPF, RD WEST[RN, MONITOR WELL (SHUT IN PRESS. 50 PSI), RU AND TIH W/ 2-7/8" TBG OPEN ENDED DAILY:S50,432 CUM:$763,542 ETD:S763,542 EFC:$1,384,000 TIH W/2-7/8" COMPLETION 7"@ 8831' MW: 0.0 NaCl CONT. TIH W/ 2-7/8" TBG, CIRC. AT 5000', RAISE BRINE WGT TO 10.6, CONT TIH TO 8521', CIRC., WELL DEAD, TOH, PU & TIH W/ 2-7/8" SINGLE COMPLETION DAILY:S41,440 CUM:$804,982 ETD:S804,982 EFC:$1,384,000 The above I~roct ~or form preplretlon ~dlatdbutlon, see Procedures Manu~l,~ection 10, Drilling, Pages 86 ancr"87. IDate / / AR3B-45g.-1.-D ' INumber ell dally well history form,, consecutively es they are prepared for each well. iPage no. ARCO ~J~l and Gas Company Daily Well History-Final Report. {nslructions: Prepare and submi! the "Final Report" on the first Wednesday after allowable has been assigned or wel~ is PhJgged, 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. Accounting cost center code County or Parish lState NORTH SLOPE Field ILease or Unit J Well no. KU?ARUK RIVER UNIT I ADL: 25588 ALK:2674 2K-3 I Title I COMPLETIONS District ARCO ALASKA INC. Auth. or W.O. no. AK3587 Operator A~CO Spudded or W.O. begun otal number of wells (active or inactive) on this~ est center prior to plugging and J labandonment of this well IHour IPrlor status if a W.O, 15:00 SPUD Date and depth as of 8:00 a.m. 11/02/89 (11) TD: 8861 PB: 8750 SUPV:GB A.R.Co. W.I. I 55.85330 IDate I 05/27/89 Complete record for each day reposed NORDIC #1 RIG RELEASED 7"@ 8831' MW: 0.0 NaCl CONT. TIH W/ 2-7/8 COMPLETION, TEST CONTROL LINE, LAND TBG, DROP BALL, PRESS. UP TBG AND SET PKR (TBG OK), BLED PRESS., PU AND SHEAR PBR, RELAND TBG, RILDS, PRESS. TEST ANNULUS TO 2500 PSI (OK), CLOSE SSSV, BLED TBG PRESS., SSSV OK, PRESS. TBG TO 3700 PSI AND SHEAR BALL, BLED PRESS., CLOSE SSSV, SET BPV, ND BOPE, NU TREE, TEST TREE TO 5000 PSI, OPEN SSSV, DISPLACE ANNULUS WITH 6 BBLS DIESEL, BULLHEAD 1BBL DIESEL DOWN TBG, CV HOLDING, RELEASE RIG AT 1230 11/1/89 DAILY:S101,829 CUM:$906,811 ETD:S906,811 EFC:$1,384,000 Old TD New TD PB Depth Released rig Date Kind of r g Classifications (oil, gas, etc.) I Type completion (single, dual, etc.) Producing method I Official reservoir name(s) 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 size T.P. C,P. Water % GOR Gravity Allowable !Effective date corrected AR3B.-459-3-C INumber ell daily welt history forms consecutively aa they are prepared for each well. iPage no. DIvlMml of AtlantlcRIchfleldCompa~y ORIGINAL August 17, 1989 Mr. Brit Brown Drilling Manager ARCO Alaska, Inc. P.O. Box 100360 Anchorage, Alaska 99510 Re: Boss Gyroscopic Survey Job No. AK-BO-90067 Well: 2K-3 Field: Kuparuk Survey Date: 7/17/89 Operator: T. McGuire Mr. Brown: Please find enclosed the "Original" and one (1) copy of our Boss Gyroscopic Survey on the above well. Also enclosed is one diskette. As per A. Thompson, copie~: have been sent to UNOCAL and BP EXPL. Thank you for giving us this opportunity to be of service. Sincerely, Ken Broussard District Manager Directional Services Enclosure 8537 Corbin Drive (99507) · RO. Box 231649 ° Anchorage, Alaska 99523 (907) 267-0200 ° Fax (907) 522-3432 A R~rmid SPERRY-SUN DRILLING SERVICES ANCHORAGE ALASKA PAGE i ARCO ALASKA, INC. 2K-3 KUPARUK ALASKA COMPUTATION DATE: 7/19/89 DATE OF SURVEY: 07-17-89 BOSS GYROSCOPIC SURVEY JOB NUMBER: AK-BO-90067 KELLY BUSHING ELEV. = 154.00 FT. OPERATOR: T. MCGUIRE TRUE SUB-SEA COURS COURSE DLS TOTAL MEASD VERTICAL VERTICAL INCLN DIRECTION RECTANGULAR COORDINATES VERT. DEPTH DEPTH DEPTH DG MN DEGREES DG/100 NORTH/SOUTH EAST/WEST SECT. 0 .00 -154.00 0 0 N .00 E .00 .00 .00 .00 100 100.00 -54.00 0 18 N 63.20 E .30 .12N .23E -.09 200 200.00 46.00 0 21 N 43.50 E .13 .46N .68E -.18 300 300.00 146.00 0 25 N 32.70 E .09 1.00N 1.10E -.11 400 399.99 245.99 0 40 N 19.20 E .28 1.86N 1.49E .19 500 499.97 345.97 I 34 N 10.70 W 1.05 3.77N 1.42E 1.55 550 549.93 395.93 2 54 N 23.10 W 2.82 5.61N .80E 3.27 600 599.80 445.80 4 54 N 30.30 W 4.11 8.63N .78W 6.48 650 649.55 495.55 6 31 N 34.50 W 3.34 12.82N 3.47W 11.31 700 699.20 545.20 7 4 N 35.40 W 1.10 17.67N 6.86W 17.11 800 797.94 643.94 10 57 N 35.50 W 3.89 900 895.93 741.93 12 1 N 34.80 W 1.07 1000 993.52 839.52 13 10 N 34.70 W 1.15 1100 1090.29 936.29 15 59 N 34.20 W 2.82 1200 1185.59 1031.59 19 13 N 35.30 W 3.26 30.43N 15.95W 32.47 46.72N 27.41W 51.98 64.64N 39.84W 73.31 85.40N 54.07W 97.91 110.24N 71.33W 127.50 1300 1279.42 1125.42 21 11 N 36.00 W 1.97 1400 1371.56 1217.56 24 31 N 36.20 W 3.34 1500 1461.29 1307.29 27 48 N 37.10 W 3.30 1600 1548.35 1394.35 31 6 N 39.70 W 3.54 1650 1590.77 1436.77 32 47 N 40.40 W 3.46 138.30N 91.47W 161.40 169.68N 114.36W 199.58 205.05N 140.70W 243.00 243.54N 171.28W 291.65 263.79N 188.31W 317.93 1700 1631.59 1477.59 37 42 N 40.30 W 9.80 1750 1670.45 1516.45 40 16 N 40.10 W 5.15 1800 1708.56 1554.56 40 25 N 40.30 W .40 1850 1746.86 1592.86 39 34 N 40.10 W 1.70 1900 1785.38 1631.38 39 38 N 40.10 W .13 285.78N 206.99W 346.60 309.80N 227.29W 377.85 334.53N 248.18W 410.01 359.07N 268.93W 441.94 383.46N 289.46W 473.61 1950 1823.26 1669.26 41 51 N 41.00 W 4.59 2000 1859.72 1705.72 44 28 N 41.60 W 5.28 2100 1930.99 1776.99 44 37 N 41.60 W .16 2200 2000.05 1846.05 48 0 N 40.80 W 3.42 2300 2066.76 1912.76 48 17 N 41.20 W .42 408.25N 310.68W 506.05 433.94N 333.26W 540.10 486.40N 379.83W 609.97 540.81N 427.45W 681.94 597.03N 476.32W 756.06 2400 2130.99 1976.99 51 46 N 42.60 W 3.63 2500 2193.46 2039.46 50 54 N 42.50 W .86 2600 2257.34 2103.34 49 40 N 42.30 W 1.25 2700 2322.33 2168.33 49 15 N 42.00 W .47 2800 2387.71 2233.71 49 5 N 41.60 W .35 654.05N 711.57N 768.38N 824.72N 881.13N 527.51W 832.42 580.31W 910.29 632.18W 987.0C 683.19W 1062.7~ 733.62W 1138.15 SPERRY-SUN DRILLING SERVICES ANCHORAGE ALASKA PAGE 2 ARCO ALASKA, INC. 2K-3 KUPARUK ALASKA COMPUTATION DATE: 7/19/89 DATE OF SURVEY: 07-17-89 BOSS GYROSCOPIC SURVEY JOB NUMBER: AK-BO-90067 KELLY BUSHING ELEV. = 154.00 FT. OPERATOR: T. MCGUIRE TRUE SUB-SEA COURS COURSE DLS TOTAL MEASD VERTICAL VERTICAL INCLN DIRECTION RECTANGULAR COORDINATES VERT. DEPTH DEPTH DEPTH DG MN DEGREES DG/100 NORTH/SOUTH EAST/WEST SECT. 2860 2427.11 2273.11 48 48 N 41.40 W .53 2900 2453.49 2299.49 48 39 N 41.30 W .44 3000 2519.92 2365.92 48 5 N 40.90 W .63 3100 2587.10 2433.10 47 28 N 40.80 W .62 3200 2655.41 2501.41 46 20 N 40.10 W 1.24 915.02N 763.61W 1183.21 937.59N 783.47W 1213.14 993.92N 832.61W 1287.53 1049.94N 881.05W 1361.21 1105.51N 928.44W 1433.80 3300 2724.85 2570.85 45 41 N 40.00 W .66 3350 2759.84 2605.84 45 28 N 40.80 W 1.22 3400 2794.34 2640.34 47 17 N 45.30 W 7.47 3450 2827.66 2673.66 49 8 N 48.10 W 5.57 3500 2860.44 2706.44 48 55 N 48.10 W .42 1160.59N 974.74W 1505.27 1187.79N 997.88W 1540.76 1214.21N 1022.60W 1576.87 1239.77N 1049.73W 1614.15 1264.98N 1077.84W 1651.89 3550 2893.44 2739.44 48 27 N 48.30 W 1.01 3600 2926.62 2772.62 48 24 N 48.40 W .18 3700 2993.57 2839.57 47 32 N 50.20 W 1.59 3800 3060.92 2906.92 47 47 N 51.20 W .78 3900 3128.42 2974.42 47 17 N 51.40 W .51 1290.02N 1105.83W 1689.44 1314.87N 1133.78W 1726.82 1363.31N 1190.08W 1801.02 1410.13N 1247.29W 1874.76 1456.26N 1304.86W 1948.30 4000 3195.63 3041.63 48 14 N 49.10 W 1.95 4100 3261.86 3107.86 48 48 N 47.60 W 1.26 4200 3327.41 3173.41 49 16 N 47.80 W .48 4300 3392.81 3238.81 49 2 N 47.90 W .24 4400' 3458.38 3304.38 49 0 N 48.10 W .15 1503.60N 1361.77W 2022.19 1553.40N 1417.75W 2097.08 1604.22N 1473.60W 2172.58 1654.98N 1529.69W 2248.22 1705.50N 1585.80W 2323.70 4500 3523.91 3369.91 49 6 N 48.20 W .13 4600 3589.52 3435.52 48 53 N 48.40 W .27 4700 3655.29 3501.29 48 51 N 48.40 W .03 4800 3721.13 3567.13 48 46 N 48.50 W .11 4900' 3786.97 3632.97 48 52 N 48.60 W .12 1755.90N 1642.07W 2399.21 1806.11N 1698.41W 2474.66 1856.12N 1754.74W 2549.95 1906.04N 1811.07W 2625.18 1955.87N 1867.49W 2700.42 5000 3853.00 3699.00 48 28 N 48.90 W .45 5100 3919.59 3765.59 48 I N 49.20 W .51 5200 3986.55 3832.55 47 54 N 49.40 W .19 5300 4053.83 3899.83 47 31 N 47.10 W 1.74 5400 4120.65 3966.65 48 36 N 45.10 W 1.84 2005.38N 1923.95W 2775.46 2054.28N 1980.30W 2850.0] 2102.71N 2036.60W 2924.2( 2151.96N 2091.79W 2998.1~ 2203.54N 2145.37W 3072.5~ 5500 4186.82 4032.82 48 31 N 45.30 W .17 5600 4253.20 4099.20 48 17 N 45.50 W .27 5700 4319.78 4165.78 48 12 N 45.80 W .24 5800 4386.06 4232.06 48 45 N 46.20 W .63 5900 4450.96 4296.96 50 17 N 45.40 W 1.66 2256.37N 2198.57W 3147.45 2308.89N 2251.83W 3222.2~ 2361.05N 2305.19W 3296.8~ 2413.06N 2359.05W 3371.71 2466.10N 2413.58W 3447.7~ SPERRY-SUN DRILLING SERVICES ANCHORAGE ALASKA PAGE 3 ARCO ALASKA, INC. 2K-3 KUPARUK ALASKA COMPUTATION DATE: 7/19/89 DATE OF SURVEY: 07-17-89 BOSS GYROSCOPIC SURVEY JOB NUMBER: AK-BO-90067 KELLY BUSHING ELEV. = 154.00 FT. OPERATOR: T. MCGUIRE TRUE SUB-SEA COURS COURSE DLS TOTAL MEASD VERTICAL VERTICAL INCLN DIRECTION RECTANGULAR COORDINATES VERT. DEPTH DEPTH DEPTH DG MN DEGREES DG/100 NORTH/SOUTH EAST/WEST SECT. 6000 4514.97 4360.97 50 5 N 45.80 W .37 6100 4579.13 4425.13 50 5 N 46.00 W .15 6200 4643.29 4489.29 50 5 N 46.20 W .15 6300 4707.64 4553.64 49 48 N 46.40 W .32 6400 4772.38 4618.38 49 29 N 46.50 W .33 2519.85N 2468.46W 3524.58 2573.23N 2523.55W 3601.27 2626.41N 2578.82W 3677.97 2679.30N 2634.16W 3754.52 2731.81N 2689.39W 3830.73 6500 4837.19 4683.19 49 43 N 46.70 W .28 6600 4902.02 4748.02 49 26 N 47.20 W .47 6700 4967.19 4813.19 49 13 N 47.90 W .57 6800 5032.52 4878.52 49 11 N 48.50 W .46 6900 5098.46 4944.46 48 17 N 49.10 W 1.00 2784.14N 2744.73W 3906.89 2836.10N 2800.36W 3983.02 2887.30N 2856.33W 4058.86 2937.76N 2912.77W 4134.55 2987.28N 2969.33W 4209.67 7000 5165.31 5011.31 47 47 N 50.80 W 1.36 7100 5232.83 5078.83 47 16 N 52.00 W 1.03 7200 '5300.37 5146.37 47 45 N 50.80 W 1.01 7300 5367.09 5213.09 48 31 N 49.20 W 1.42 7400 5433.33 5279.33 48 30 N 49.40 W .15 3035.13N 3026.25W 4283.91 3081.15N 3083.89W 4357.43 3127.16N 3141.52W 4430.92 3175.04N 3198.56W 4505.27 3223.89N 3255.36W 4580.11 7500 5499.38 5345.38 48 49 N 49.90 W .50 7575 5548.75 5394.75 48 49 N 5'0.20 W .30 7600 5565.23 5411.23 48 43 N 50.40 W .74 7700 5631.19 5477.19 48 43 N 50.60 W .15 7800 5697.37 5543.37 48 24 .N 51.00 W .44 3272.50N 3312.58W 4655.10 3308.75N 3355.86W 4711.46 3320.76N 3370.33W 4730.23 3368.57N 3428.32W 4805.22 3415.95N 3486.42W 4880.00 7900 5763.86 5609.86 48 13 N 51.80 W .62 8000 5830.51 5676.51 48 10 N 52.40 W .45 8100 5897.37 5743.37 47 54 N 53.00 W .53 8200 5964.41 5810.41 47 54 N 53.60 W .45 8300 6031.38 5877.38 48 I N 54.40 W .61 3462.55N 3544.79W 4954.44 3508.35N 3603.62W 5028.67 3553.41N 3662.77W 5102.62 3597.75N 3722.26W 5176.33 3641.40N 3782.34W 5250.00 8330 6051.48 5897.48 47 49 N 54.30 W .68 8400 6098.35 5944.35 48 6 N 54.70 W .58 8500 6165.62 6011.62 47 19 N 55.00 W .81 8600 6233.75 6079.75 46 46 N 55.00 W .55 8700 6302.22 6148.22 46 47 N 55.00 W .02 3654.38N 3800.43W 5272.07 3684.57N 3842.76W 5323.59 3727.17N 3903.26W 5396.83 3769.15N 3963.22W 5469.27 3810.96N 4022.92W 5541.39 8800 6370.67 6216.67 46 47 N 55.00 W .00 8861 6412.43 6258.43 46 47 N 55.00 W .00 3852.77N 4082.64W 5613.53 3878.28N 4119.06W 5657.53 THE CALCULATION PROCEDURES ARE BASED ON THE USE OF THREE-DIMENSION RADIUS OF CURVATURE METHOD. HORIZONTAL DISPLACF24ENT = 5657.53 FEET AT NORTH 46 DEG. 43 MIN. WEST AT MD = 8861 VERTICAL SECTION RELATIVE TO WELL HEAD VERTICAL SECTION COMPUTED ALONG 313.28 DEG. SPERRY-SUN DRILLING SERVICES ANCHORAGE ALASKA PAGE 4 ARCO ALASKA, INC. 2K-3 KUPARUK ALASKA COMPUTATION DATE: 7/19/89 DATE OF SURVEY: 07-17-89 JOB NUMBER: AK-BO-90067 KELLY BUSHING ELEV. = 154.00 FT. OPERATOR: T. MCGUIRE INTERPOLATED VALUES FOR EVEN 1000 FEET OF MEASURED DEPTH TRUE SUB-SEA MEASDVERTICALVERTICAL DEPTH DEPTH DEPTH 0 .00 -154.00 1000 993.52 839.52 2000 1859.72 1705.72 3000 2519.92 2365.92 4000 3195.63 3041.63 TOTAL RECTANGULAR COORDINATES MD-TVD VERTICAL NORTH/SOUTH EAST/WEST DIFFERENCE CORRECTION .00 .00 .00 64.64 N 39.84 W 6.48 6.48 433.94 N 333.26 W 140.28 133.80 993.92 N 832.61 W 480.08 339.80 1503.60 N 1361.77 W 804.37 324.29 5000 3853.00 3699.00 6000 4514.97 4360.97 7000 5165.31 5011.31 8000 5830.51 5676.51 8861 6412.43 6258.43 2005.38 N 1923.95 W 1147.00 342.63 2519.85 N 2468.46 W 1485.03 338.02 3035.13 N 3026.25 W 1834.69 349.66 3508.35 N 3603.62 W 2169.49 334.80 3878.28 N 4119.06 W 2448.57 279.08 THE CALCULATION PROCEDURES ARE BASED ON THE USE OF THREE-DIMENSION RADIUS OF CURVATURE METHOD. SPERRY-SUN DRILLING SERVICES ANCHORAGE ALASKA PAGE 5 ARCO ALASKA, INC. 2K-3 KUPARUK ALASKA COMPUTATION DATE: 7/19/89 DATE OF SURVEY: 07-17-89 JOB NUMBER: AK-BO-90067 KELLY BUSHING ELEV. = 154.00 FT. OPERATOR: T. MCGUIRE INTERPOLATED VALUES FOR EVEN 100 FEET OF SUB-SEA DEPTH TRUE SUB-SEA MEASD VERTICAL VERTICAL DEPTH DEPTH DEPTH 0 .00 -154.00 54 54.00 -100.00 154 154.00 .00 254 254.00 100.00 354 354.00 200.00 TOTAL RECTANGULAR COORDINATES MD-TVD VERTICAL NORTH/SOUTH EAST/WEST DIFFERENCE CORRECTION .00 .00 .00 .02 N .03 E .00 .00 .26 N .48 E .00 .00 .72 N .91 E .00 .00 1.37 N 1.31 E .01 .00 454 454.00 300.00 554 554.00 400.00 654 654.00 500.00 755 754.00 600.00 857 854.00 700.00 2.57 N 1.63 E .02 .01 5.80 N .72 E .08 .06 13.24 N 3.76 W .48 .40 24.08 N 11.43 W 1.37 .89 39.41 N 22.33 W 3.13 1.76 959 954.00 800.00 1062 1054.00 900.00 1166 1154.00 1000.00 1272 1254.00 1100.00 1380 1354.00 1200.00 57.04 N 34.58 W 5.41 2.28 77.11 N 48.42 W 8.35 2.94 101.52 N 65.20 W 12.66 4.31 130.32 N 85.68 W 18.73 6.08 163.31 N 109.71 W 26.75 8.02 1491 1454.00 1300.00 1606 1554.00 1400.00 1728 1654.00 1500.00 1859 1754.00 1600.00 1992 1854.00 1700.00 202.02 N 138.42 W 37.78 11.03 246.16 N 173.46 W 52.59 14.81 299.40 N 218.51 W 74.64 22.05 363.59 N 272.73 W 105.26 30.62 429.81 N 329.60 W 138.05 32.79 2132 1954.00 1800.00 2280 2054.00 1900.00 2437 2154.00 2000.00 2594 2254.00 2100.00 2748 2354.00 2200.00 503.79 N 395.19 W 178.68 40.63 586.25 N 466.88 W 226.81 48.14 675.55 N 547.28 W 283.19 56.38 765.46 N 629.53 W 340.84 57.65 852.04 N 707.76 W 394.51 53.67 2900 2454.00 2300.00 3050 2554.00 2400.00 3197 2654.00 2500.00 33.41 2754.00 2600.00 3490 2854.00 2700.00 938.02 N 783.85 W 446.76 52.26 1022.56 N 857.41 W 496.97 50.20 1104.38 N 927.49 W 543.96 46.99 1183.29 N 994.01 W 587.67 43.71 1260.05 N 1072.34 W 636.20 48.53 3641 2954.00 2800.00 3789 3054.00 2900.00 3937 3154.00 3000.00 4088 3254.00 3100.00 4240 3354.00 3200.00 1335.33 N 1156.84 W 687.22 51.02 1405.35 N 1241.34 W 735.70 48.48 1473.55 N 1326.53 W 783.72 48.02 1547.34 N 1411.12 W 834.07 50.35 1624.96 N 1496.48 W 886.75 52.68 SPERRY-SUN DRILLING SERVICES ANCHORAGE ALASKA PAGE 6 ARCO ALASKA, INC. 2K-3 KUPARUK ALASKA COMPUTATION DATE: 7/19/89 DATE OF SURVEY: 07-17-89 JOB NUMBER: AK-BO-90067 KELLY BUSHING ELEV. = 154.00 FT. OPERATOR: T. MCGUIRE INTERPOLATED VALUES FOR EVEN 100 FEET OF SUB-SEA DEPTH TRUE SUB-SEA MEASD VERTICAL VERTICAL DEPTH DEPTH DEPTH TOTAL RECTANGULAR COORDINATES MD-TVD VERTICAL NORTH/SOUTH EAST/WEST DIFFERENCE CORRECTION 4393 3454.00 3300.00 4545 3554.00 3400.00 4698 3654.00 3500.00 4849 3754.00 3600.00 5001 3854.00 3700.00 1702.13 N 1582.04 W 939.31 52.57 1779.04 N 1667.96 W 991.95 52.64 1855.14 N 1753.64 W 1044.04 52.09 1930.90 N 1839.18 W 1095.89 51.85 2006.13 N 1924.80 W 1147.51 51.62 5151 3954.00 3800.00 5300 4054.00 3900.00 5450 4154.00 4000.00 5601 4254.00 4100.00 5751 4354.00 4200.00 2079.25 N 2009.24 W 1197.44 49.93 2152.08 N 2091.92 W 1246.25 48.81 2230.23 N 2172.18 W 1296.43 50.18 2309.52 N 2252.48 W 1347.21 50.78 2387.78 N 2332.72 W 1397.42 50.21 5904 4454.00 4300.00 6060 4554.00 4400.00 6216 4654.00 4500.00 6371 4754.00 4600.00 6526 4854.00 4700.00 2468.67 N 2416.19 W 1450.76 53.35 2552.35 N 2501.93 W 1506.83 56.06 2635.28 N 2588.06 W 1562.69 55.87 2717.00 N 2673.79 W 1617.70 55.01 2797.74 N 2759.17 W 1672.01 54.30 6679 4954.00 4800.00 6832 5054.00 4900.00 6983 5154.00 5000.00 7131 5254.00 5100.00 7280 5354.00 5200.00 2877.05 N 2844.98 W 1725.80 53.80 2954.25 N 2931.40 W 1778.87 53.07 3027.25 N 3016.59 W 1829.17 50.29 3095.26 N 3101.95 W 1877.20 48.03 3165.36 N 3187.35 W 1926.23 49.03 7431 5454.00 5300.00 7582 5554.00 5400.00 7734 5654.00 5500.00 7885 5754.00 5600.00 8035 5854.00 5700.00 3239.09 N 3273.09 W 1977.19 50.96 3312.59 N 3360.47 W 2028.97 51.78 3385.06 N 3448.40 W 2080.57 51.60 3455.72 N 3536.11 W 2131.20 50.62 3524.36 N 3624.42 W 2181.23 50.03 8184 5954.00 5800.00 8333 6054.00 5900.00 8482 6154.00 6000.00 8629 6254.00 6100.00 8775 6354.00 6200.00 3590.91 N 3712.98 W 2230.47 49.24 3656.00 N 3802.69 W 2279.75 49.28 3719.94 N 3892.93 W 2328.85 49.10 3781.51 N 3980.87 W 2375.57 46.72 3842.59 N 4068.09 W 2421.65 46.08 8861 6412.43 6258.43 3878.28 N 4119.06 W 2448.57 26.92 THE CALCULATION PROCEDURES USE A LINEAR INTERPOLATION BETWEEN THE NEAREST 20 FOOT MD (FROM RADIUS OF CURVATURE) POINTS SPERRY-SUN DRILLING SERVICES ANCHORAGE ALASKA PAGE 7 ARCO ALASKA, INC. 2K-3 KUPARUK ALASKA COMPUTATION DATE: 7/19/89 DATE OF SURVEY: 07-17-89 JOB NUMBER: AK-BO-90067 KELLY BUSHING ELEV. = 154.00 FT. OPERATOR: T. MCGUIRE INTERPOLATED VALUES FOR SPECIAL SURVEY POINTS TRUE SUB-SEA TOTAL MEASURED VERTICAL VERTICAL RECTANGULAR COORDINATES DEPTH DEPTH DEPTH NORTH/SOUTH EAST/WEST MARKER 3598 2925.30 2771.30 1313.88 N 8408 6103.69 5949.69 3688.01 N 8413 6107.03 5953.03 3690.17 N 8431 6119.05 5965.05 3697.91 N 8614 6243.34 6089.34 3775.01 N 1132.66 W CSG 3847.62 W TOP KUPARUK C 3850.66 W BASE KUPARUK C 3861.60 W TOP KUPARUK A 3971.58 W BASE KUPARUK A 8700 6302.22 6148.22 3810.96 N 8750 6336.44 6182.44 3831.87 N 8830 6391.21 6237.21 3865.31 N 8861 6412.43 6258.43 3878.28 N 4022.92 W SURVEY DEPTH 4052.78 W PBTD 4100.55 W CSG 4119.06 W TD mmmmmmmmm--mmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmm. ARCO ALASKA, INC. 2K-3 STRATIGRAPHIC SUMMARY mmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmm~, MEASURED ....... ~ ...... m DEPTH ........ TVD BKB BKB SUB-SEA COORDINATES WITH REF. TO WELLHEAD ORIGIN: 246FSL 94FEL SEC 02 T10N R08E CSG 3598 2925.30 2771.30 1313.88N 1132.66W TOP KUPARUK C 8408 6103.69 5949.69 3688.01N 3847.62W BASE KUPARUK C 8413 6107.03 5953.03 3690.17N 3850.66W TOP KUPARUK A 8431 6119.05 5965.05 3697.91N 3861.60W BASE KUPARUK A 8614 6243.34 6089.34 3775.01N 3971.58W PBTD 8750 6336.44 6182.44 3831.87N 4052.78W CSG 8830 6391.21 6237.21 3865.31N 4100.55W TD 8861 6412.43 6258.43 3878.28N 4119.06W mmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmm COMPUTER PROGRAM - SPERRY-SUN THREE DIMENSION RADIUS OF CURVATURE mmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmm DATE OF SURVEY: 07-17-89 COMPUTATION DATE: 7/19/89 JOB N UMBER:.AK-BO-90067 KELLY BUSHING ELEV. ~ 154.00 FT. ~ ,, · ,, · ii ! ii ill¶l ii i i .... ii im i ii ...... SPERR" -SUN DRLG. SVCS. 2K-3 KUPARUK ALASKA 07-17-89 HORZZONTAL PROJECT'TON START TVD = 0 FINZSH TVD = 6412.43 SCALE IS 1000 FEET/IN .eooo e- 6000 ~obo .bo oobo zobo ~obo 6 DEPARTURE .SO00 4000 3000 ,2000 1000 SPERR5 -SUN 2K-3 KUPARUK ALASKA 07-17-89 VERTICAL DRLG. SVCS. PROJECTION START TVD ,,, 0 FINISH TVD - 6412.43 SCALE IS 1000 FEET/IN 1000 2000 0000 4000 5000 O000 700O 5657.53 10bO 2oho VFRTTC. AI oobo ,soho RFCT~ON soho soho ARCO Alaska, Inc. Date: January 5, 1990 Transmittal #: 7640 RETURN TO: ARCO Alaska, Inc. Attn: Jenny Gamage Kuparuk Operations File Clerk ATO-1119 P.O. Box 100360 Anchorage, AK 99510-0360 Transmitted herewith are the following items. Please acknowledge receipt and return one signed copy of this transmittal. 2 K - 03 Acoustic Cement Bond Log 9 - 2 6 - 8 9 6 8 94 - 8 74 2 2 K - 04 Acoustic Cement Bond Log 1 1 - 0 4 - 8 9 9 0 0 0 - 1 0 703 2 K - 1 4 Acoustic Cement Bond Log 1 1 - 0 5 - 8 9 5 01 9 - 8 04 2 2K-1 7 CBT 1 2-25-89 7245-901 8 2K-20 CBT 1 2-24-89 7889-9698 2K-22 CBT 1 2-24-89 7923-9708 Receipt Acknowledged: DiSTRiBUTION: NSK Drilling State of Alaska(+sepia) RECEIVED JAN 1 2 Alaska 0il ~ Gas Cons. C0mmissl0_r Anchorage ARCO Alaska, Inc. Date- NoVember 13, 1989 Transmittal #: 7602 RETURN TO: ARCO Alaska, Inc. Attn: Jenny Gamage Kuparuk Operations File Clerk ATO-1119 P.O. Box 100360 Anchorage, AK 99510-0360 Transmitted herewith are the following items. Please acknowledge receipt and return one signed copy of this transmittal. 2K-03 PET Log 7-1 6-89 5700-8746 2K-04 PET Log 7- 1 6-89 1 00-4600 Receipt Acknowledged: ............................. Date: DISTRIBUTION: Drilling NSK State of Alaska (+sepia) STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION ~ APPLICATION FOR SUNDRY APPROVALS 161NAI. 1. Type of Request: Abandon __ Suspend __ Alter casing __ Repair well __ Change approved program __ Operation shutdown ~ Re-enter suspended well __ Plugging __ Time extension __ Stimulate __ Pull tubing m Variance ~ Perforate __ Other __ 2. Name of Operator ARCO Alaska, Inc, 3. Address P. 0. Box 100360, Anchorage, AK 99510-0360 4. Location of well at surface 246' FSL, 94'FEL, Sec. 2, TION, R8E, UM At top of productive interval 1320'FNL, 1200'FEL, Sec. 2, TION, RSE, UM (Approx) At effective depth 1227' FNL, 1056' FEL, Sec. 2, TION, RSE, UM (Approx) At total depth 1155'FNL~ 1020'FEL~ Sec. 2~ TION~ R8E~ UM (Approx) 12. Present well condition summary Total depth: measured 8861 ' MD feet true vertical 6412' TVD feet Effective depth: measured 8750' MD feet true vertical 6336' TVD feet 5. Type of Well: Development Exploratory Stratigraphic Service 6. Datum elevation (DF or KB) RKB 154' 7. Unit or Property name Kuparuk River Unit 8. Well number 2K-3 9. Permit number 88-120 10. APl number 50-- 103-20100 11. Field/Pool Kuparuk River Oil Pool Plugs (measured) None Junk (measured) No ne feet Casing Length Size Structural Conductor 80 ' 16" Sudace 3559 ' 9-5/8" Intermediate Production 8798 ' 7" Liner Perforation depth: measured None true vertical Cemented Measured depth True vertical depth 179 sx Arctic Set II 115' MD 700 sx Arctic Set Ill, 3598' MD 500 sx Class G 115' TVD 2924' TVD 200 sx Class G 8830' MD 6391' TVD RECEIVED Tubing (size, grade, and measured depth) None Packers and SSSV (type and measured depth) None & Gas Cons. Commissior~ Anchorage 13. Attachments Description summary of proposal __ Detailed operations program L BOP sketch __ 14. Estimated date for commencing operation I (:;~,,n'l',~mhpr I qRq 16. If proposal was verbally approved Oil 2~- Gas __ Name of approver N/A Date approved Service 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Si gned~;:2~,~Z~,~ ~ ~,,~.,,~z Title Area Dr il li n g E ngi neet ~ ~ t -- ,FCRCOMMISSION USEONLY Conditions of approval(~lotify Commission so repres~fl"tative may witness Plug integrity __ BOP Test ~ Location clearance __ /-¢'0 ~7 Mechanical Integrity Test ~ Subsequent form required 10- 15. Status of well classification as: Suspended__ Date (SRE) SA1/5 ! Approval No. uommlssloner Date '" ORIGINAL SIGNED BY Approved by order of the Commission LONNIE C. SMITH Form 10-403 Rev 06/15188 SUBMIT IN TRIPLICATE ARCO Oil and Gas Company O Well History - Initial Report - Daily Instructions: Prepare and submit the "llllti~'l Report" on the first Wednesday after a well is spudded or workover operations are started, Daily work prior to spudding should be summarized on the form giving inclusive dates only. District ARCO ALASKA INC, Field KUPARUK RIVER UNIT Auth. or W.O. ~K3587 LOPE ~~_se or Un~:)L: 25588 DRILLING Irate 2K-3 IWell no. Operator ARCO API: 50-103-20102 IHour IPrior status if a W.O. 15 ,, 00 Spudded or W.Os~n 05/27/89 Date and depth as of 8:00 a.m. 05/28/89 ( TD: 2053'( SUPV:CD 05/29/89 ( TD: 3618'( SUPV:CD 05/30/89 ( TD: 3618'( SUPV:CD 05/31/89 ( TD: 6460'( 2 SUPV:CD 06/01/89 ( TD: 8725'( 2; SUPV:CD O6/02/89 ( TD: 8861'( SUPV:CD 06/03/89 ( TD: 8861'( SUPV:ZR ~Plet ..... r~O~6~h f~ reported ~053) 565) 3) 0) 42) ) 65) 136) 7 o) DRILLING SURFACE HOLE MW: 8.9 VIS: 61 MOVE RIG FROM 2K-1 TO 2K-3, SET CONVEYOR, NU DIVERTER, ACCEPT RIG 1000, 5-27-89, PO BHA, FUNCTION TEST DIVERTER, FIX LEAK, SPUD WELL 1500 5-27-89, DRILL TO KOP AT 467', KICK OFF AND DRILL TO 2053'. DAILY:SS0,425 CUM:$80,425 ETD:S80,425 EFC:$1,384,000 REAM TIGHT HOLE MW: 9.2 VIS: 67 DRILL TO CSG POINT, 2053-3618, CBU, SHORT TRIP,TOH, TIGHT HOLE, 1914-1597, TOH, PICK UP 12-1/4" HOLE OPENER, TIH, REAM TIGHT HOLE SECTIONS. DAILY:S49,998 CUM:$130,423 ETD:S130,423 EFC:$1,384,000 TRIP IN TO DRILL OUT 9-5/8"~ 3598' MW: 0.0 VIS: TIH, REAM TIGHT SECTIONS, CBU, TOH LD BHA, RU AND RUN 9-5/8", 93 JTS SET AT 3598, RU AND CEMENT W/ 80 BBLS WATER, 700 SX AS III, 500 SX CLASS G, FULL RETURNS,BUMP PLUG, FLOATS HELD, NO CEMENT TO SURFACE,ND DIVERTER, DO TOP JOB, NU BRADENHEAD AND BOP STACK, TEST SAME, INSTALL WEAR BUSHING, PU BHA AND TRIP IN TO DRILL OUT. DAILY:S202,216 CUM:$332,639 ETD:S332,639 EFC:$1,384,000 DRILLING 8-1/2" HOLE 9-5/8"~ 3598' MW: 9.2 VIS: 34 CUT DRILLING LINE, CUNT TIH,TAG FC AT 3518,TEST CSG TO 2000 PSI,DRILL FLOATS AND 10' NEW HOLE,DISPLACE TO POLYMER MUD, DO LEAK OFF TEST TO 12.0 PPG EMW, DRILL 3628 TO 6460. DAILY:S71,130 CUM:$403,769 ETD:S403,769 EFC:$1,384,000 DRILLING 9-5/8"@ 3598' MW:10.3 VIS: 42 DRILL 6460-8451,TOH FOR WASHOUT 5-1/3 STANDS OUT, DRILL 8451-8725. DAILY:S54,724 CUM:$458,493 ETD:S458,493 EFC:$1,384,000 TOH FOR LOGS 9-5/8"@ 3598' MW:10.3 VIS: 48 DRILL 8725-8861,MWD SURVEY, CBU, PUMP PILL, SHORT TRIP TO SHOE,HOLE TOOK 45 BBLS MUD, TIGHT AT 8350, KELLY UP,HOLE PACKED OFF, REAM OUT, REGAIN CIRC,HIGH DRAG IN CAP ABOVE KUP AND SHALE BELOW, REAM TO BOTTOM, CIRC HOLE CLEAN, DROP SINGLE SHOT, SPOT DIESEL PILL, TOH FOR LOGS. DAILY:S50,684 CUM:$509,177 ETD:S509,177 EFC:$1,384,000 TTOH, LAY DOWN DP 9-5/8"@ 3598' MW:10.3 VIS: 46 TOH, RU SCHLUMBERGER, RUN TRIPLE COMBO LOGS,RD LOGGERS,MAKE CLEAN OUT TRIP,CIRC AND CONDITION HOLE, SPOT DIESEL PILL, TOH LAYING DOWN DRILL PIPE. DAILY:S48,997 CUM:$558,174 ETD:S558,174 EFC:$1,384,000 The above J,s correct ........... - ~ . T~tle ~ see Procedures an Drilling, Pages · [Number all daily well history forms consecutively iPage no. AR3B-459-1-D ARCO Oil and Gas Compar{y Daily Well History-Final Report Instructions: Prepare and submit 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 Lease or ~I~T~ Title ~DL: IAccounting cost center code State Field ~a~D, CO ALASKA INC. Auth. or W,O. KSJPARUK RIVER UNIT DRILLING ~ JWell no. 2K-3 Operator Spudded or W~j~D~l~un Date and deptl~POD as of 8:00 a.m. 06/04/89 ( TD= 8750'( SUPV:ZR AR.Co. W.I. rTotal number of wells (active or inactive) on this Icost center prior to plugging and ] labandonment of this well Date API= .~(]-lO~-;ZO1Tour ]l~r.~l&l~lf a W.O. Complete record for each day reported O~/Z I/tS~ 15 = IJO o) DOYON 14 RIG RELEASED, 2400 }iRS 7"@ 8831' MW: 0.0 VIS= CONTINUE TOH LDDP,PULL WEAR RING, RU AND RUN 7" CSG, LOST RETURNS ON JOINT 960, CBU,REGAINED FULL RETURNS,LOST AGAIN FOR GOOD ON ~113, ATTEMPT TO CIRC ON BOTTOM, NO RETURNS,MIX AND PUMP 200 SX CLASS G W/ ADDITIVES,DISPLACE W/ BRINE, BUMP PLUG, FLOATS HELD,TEST CSG TO 3500 PSI,SET SLIPS,ND BOP STACK, NU TREE AND TEST SAME,RELEASE RIG 2400 HRS, 6-3-89. DAILY:S154,936 CUM:$713,110 ETD:S713,110 EFC:$1,384,000 Old TD New TD PB Depth Released rig Date Kind of rig Classifications (oil, gas, etc.) Type completion (single, dual, etc.) Producing method Official reservoir name(s) 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 size T.P. C.P. Water % GOR Gravity Allowable Effective date corrected The abov~.s.,co rrect = Sign at~=.~.~ ~ Date / Title ~'~ Drilling, Pages 86 and 87. Number all daily well history forms consecutively t Page no. e, as they are prepared for each well. I AR3B-459-3-C Dlvl,~on of AtlsntlcRIchfl®ldCompa~ly ARCO Alaska, Inc. Date: June 16, 1989 Transmittal #: 7492 RETURN TO: ARCO Alaska, Inc. Attn: Brenda K. Miernyk Kuparuk Records Clerk ATO-1119 P.O. Box 100360 Anchorage, AK 99510-0360 Transmitted herewith are the following items. Please acknowledge receipt and return one signed copy of this transmittal. 2 K - 0 3 OH EDIT Tape and Listing 6 - 0 8 - 8 9 # 7 3 3 6 0 2 K - 01 OH EDIT Tape and Listing 6 - 0 3 - 8 9 # 7 3 3 5 0 Receipt Acknowledged' DISTRIBUTION' ........... Dat .~: Nas~p-it & Gas ConS. Commissl0r~ ............... ~ ~l~s~ P: ..... Afi:r,0rage Lynn Goettinger State of Alaska ARCO Alaska, Inc. Date: June 9, 1989 Transmittal #: 7489 RETURN TO: ARCO Alaska, Inc. Attn: Brenda K. Miernyk Kuparuk Records Clerk ATO-1119 P.O. Box 100360 Anchorage, AK 99510-0360 Transmitted herewith are the following items. Please acknowledge receipt and return one signed copy of this transmittal. 2K-03 2"& 5" Porosity FDC 6-02-89 7926-8796 2K-03 2" & 5" Raw FDC 6-02-89 7926-8796 2K-03 2" Dual Induction - SFL 6-02-89 900-8822 2K-03 5" Dual Induction - SFL 6-02-89 900-8822 2K-03 Cyberlook 6-02-89 81 50-8775 Receipt Acknowledged: Alaska Oil & Gas Cons. Co~1~i88i01~ Anchorage ........................... Date: ............ DISTRIBUTION: NSK Franzen State of Alaska(+sepia) D&M Drilling L. Johnston(vendor package) STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 1. Type of Request: Abandon __ Suspend __ Alter casing __ Repair well __ Change approved program ~ Operation shutdown __ Re-enter suspended well __ Plugging __ Time extension __ Stimulate __ Pull tubing __ Variance __ Perforate __ Other __ 2. Name of Operator ARCO Alaska, Inc. 3. Address P. O. Box 100360, Anchorage, AK 99510-0360 5. Type of Well: Development Exploratory Stratigraphic Service 6. Datum elevation (DF or KB) RKB 154' 7. Unit or Property name Kuparuk River Unit 4. Location of well at surface 246' FSL, 94'FEL, Sec. At top of productive interval 1320'FNL, 1200'FWL, Sec. At effective depth At total depth 1171'FNL, 1040'F~L, Sec. 2, TION, R8E, UM 2, TION, R8E, UM 2, TION, R8E, UM 12. Present well condition summary Total depth: measured true vertical feet Plugs (measured) feet 8. Well number 2K-3 9. Permit number 88-120 10. APl number 50-- 103-20100 11. Field/Pool Kuparuk River Oi] Pool RECEIVED Effective depth: measured true vertical Casing Length Structural Conductor Surface 3576 ' Intermediate Production 8819' Liner Perforation depth: measured Size 9-5/8" 7" feet Junk (measured) feet Cemented To surface MAY 1_ 6 ]989 Measure~laoSe~th0i[ a Gas Cons. C0rmr, issiorl Anch0[~[3~e vertical depth 3612'MD 2927'TVD 500' above 8854'MD 6421'TVD Kuparuk true vertical This sundry request revises the target for subject well Tubing (size, grade, and measured depth) Packers and SSSV (type and measured depth) resulting in revised casing setting depths and directional plan. 13. A~achments Description summary ofproposal Revised Directional Plan Detailed operations program __ BOP sketch __ 14. Estimated date for commencing operation Hay 25, 1989 16. If proposal was verbally approved Name of approver Date approved 15. Status of well classification as: Oil __ Gas __ Suspended __ Service 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed ~) ~ ¢.X~c~ Title Area Drilling Engineer FOR COMMISSION USE ONLY (TWM) 5A1/3 Date Conditions of approval: Notify Commission so representative may witness Plug integrity ~ BOP Test __ Location clearance __ Mechanical Integrity Test ~ Subsequent form required 10- ~ ~ Approved by order of the Commission ¢¢tJGINAL SIGNED ~Y LONNIE C. SMITH Approved Copy Returned Commissioner IApproval No. ¢-. Date 5'"-:--~,~-- SU BM IT IN TRIP L, rCATE feet Form 10-403 Rev 06/15/88 ARCO ALASKA, ]:no, Pad 2K, Wel I No: :3 Revteed Pr'opoeel Kupar'uk Fteld, North Slope, Alaeke 0 . RI(B ELEVATEON' 154' 1000_ 2000 _ 3000_ 4000_ 5000_ 6000 _ 7000 _ KOP TVD=500 TMD=500 DEP=O 3 BUILD 3 DE~ g PER I00 FT 21 27 B/ PERHAFROST TVD=1424 THD-1464 DEP-238 33 T/ UONU SNDS 'TVD-1543 TMD-1603 DEP-310 39 4S EOC TVD-1924 THD=2107 DEP=637 T/ W SAK SNDS TVD-2152 THD-2449 DEP-892 B/ W SAK SNDS TVD=2727 THD=3312 DEP=1535 9 5/8' CS13 PT TVD=2927 TMD=3612 DEP=I?Sg K-lO TVD=3162 THD=3964 DEP=2022 AVERAGE ANGLE 48 DEG 12 i'II N K-5 TVD=4502 TMD=S975 DEP=3520 RECE!¥EE ' T/ ZONE C TVD=6130 THD=8417 DEP-5341 T/ ZONE A TVD=6164 THD=8468 DEP=5379 TARGT CENTR TVD-6226 THD=8561 DEP=5448 B/ KUP SNDS TVD=6288 THD=8654 DEP=5517 TD (LOG PT) TVD=6421 TPID=8854 DEP=5667 I I I I ! 000 2000 3000 4000 VER'I' [ C^L SECT[ON '/ i 5000 6000 HOR I ~'~']NTAL PROJECTION SCALE 1 IN. = 1000 FEET ARCO ALASKA, !~,e. Pad 2K, Well No~ :3 Kuparuk Field, North Revised Proposal Slope, Alas a z c3 .4000 3000 2000 1000 _ i 1000._ 5000 4000 TARGET CENTER TVD=6226 TMD=8.561 DEP=5448 NORTH 3714 gEST 3986 TARGET LOCATION' 1320' FNL, 1200' FN1. SEC. 2, TION, R8E 3000 I WEST-EAST 2000 1000 i I TO LOCATION' 1171' FNL, 1040' FWL SEC. 2, T1ON, R8E 1 000 I SURFACE SURFACE LOCATION 2'1.6' FSL. 94' FEL SEC- 2. TI ON, RSE N 47 DEO 1 MI N W 5448' (TO TARGET) ARCO Alaska, Inc. Post Office Box i00360 Anchorage, Alaska 99510..-0360 Telephone 907 276 1215 December 12, 1988 Mr. C. V. Chatterton Commissioner State of Alaska Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Subject: Conductor As-Built Location Plat - 2K Pad (Wells 1 - 24) Dear Mr. Chatteron: Enclosed is an as-built location plat for the subject wells. any questions, please call me at 263-4618. Sincerely, If you have D. Martin Engineering Aide DM:hf Enclosure RECEIVED DEC ! 1988 Alaska Oil & Gas Cons. Commissim~ Anchorage GRU13/010 ARCO Alaska, Inc. is a Subsidiary of Alh3nlicRichfieldCompany --J WELLS 1-12 ARE' LOCATED IN SECTION 2 T. !0 N., R. 8 E., ss 3e ~ WELLS 13'24 ARE I. DCATED IN [' N., I N.T S. I ~TH IS ' , ,~URVEY !i SECTION, .CT,O., A...F' [] O.S. 2K ./- i i ,, I , ,, , it, : ~- VICINIITY MAP I"= I~ I PROTRACTED Notes: ! I~/,~ o~ SECTION CORNER ! ~ 14,~ I COORDINATES ARE A.S.P. ZONE 4. !SECTION II $e:t9 SECTION fa 2. ALL DISTANCES SHOWN ARE TRUE. · ~:2~1 i 3. ELEVATIONS ARE B.P.M.S.L. " : IVED 4. O.G. ELEVATIONS FROM CED-RIXX-33, I,r,,4. l , MONUMENTS PER LOUNSBURY ~ A:~OClATES. / DEC I 3 1988 ~'58,59,REFERENCE65 B 66.FIELD BOOK; L 88-40, p~s. 55,56, ~ Well ASp's , , AlaSYa Ull & ?,..:~ rjui,s, CT.,, , , ' ...... ~"" DiSt. I Dist. O.G. Pad No. Y X L~l~t;~tdl~J~ LONGITUDE F.S.L. F.E.L. Elev. Elev. I 5,938,600.18 498,310.17 70614'36.519" 150°00'49.133" 296' 94' 114.0 118.5 2 5,9,58,575.14 498,310.28 70° 14' `56.273" 150°00'49.1`50'' 271' ~ 11:3.9 `5 5,9,58,550.30 498,`510.35 70° 14' 36.029" 150°00'49.128'' :~46' I I 1`5.8 i 4 5,9,58,525.46 498,310.06 70014' 35.784" 150°00'49.136'' 22~' 6 ~ 5,938,475.14 ~ 498,310.~ 70°1 ~5.289" 150°00'49.1~8'' 17 113.8 ~ 4' ,, 14 6' i I 7 i 5,938,450.36 498,310.36 Y0°14,~5.046 150°00'49.1~7'' 8 I 5,938,425.30 498,~10.18 70°t ~4.799" 150 ° 00' 49.132'' 121' 113.8 9 5,938,400.30 498,309.98 ' 70°14'34.55~'' 150°00*49.13T'' 96' 113.8 I0 5,9~8,375.19 498,310.14 70° 14' ~4.~06'' 150°00'49.13~'' ~ 71' 113.9 I I 5,938,350.22 498,310.14 70°14'34.061 " 150 ° 00' 49.133'* ~ 46' 113.9 12 5,938,325.20 498,~10.17 70°14'33.815" 150 °00' 49. 131'' El' 94' 113.9 118.5 F. N.L. 13 5,938,235.31 498,310.37 70°14'32.9~0" ~ 150°00'49.1E5'' 69' 94' 113.7 118.5 14 5,938,210.14 498,310.16 ~ 70°14'3~.683'' 150° 00' 49.131'' 94' 113.7 15 5,938,185.12 498,310.16 ~ 70°14'32.4~'' 150°00'49.1~1'' 119' '16 5,938,160.11 . 498,310.20 70°14' 3~. 191'' 150° 00' 49. 130'' 144' : 113.8 4' 31.946" 150°00' 49.130'' 169' ~ 113.9 17 5,9~8, I ~5.21 498,310.18 70014, ,, , 0.OO:o, '19 5,938,085.~0 498,310.27 . 70~1 31 454" 150°0 49.12T" 21 114.0 . , . 30.962" 150°00'49.1~0'' 269' '~ 114.0 ' 21 5,938,035.16 498 310 16 ~ 70°14' ] 24 5~937~960.29 498,310.08 j 70°14'30.225" 150°00'49.13 $44' 95' I 113.9 j 118.5 ~ I HEREBY CERTIFY THAT I AM ~% ,. ' ,.'T.~ & TO PRACTICE LAND SURVEYING IN THE "~."mnT.~ '%'~ $. oTATE OF ALASKA AND THAT THIS · ,, BY ME OR UNDER MY DIRECT SUPER- ~. p~. ~.~ DRILL SITE 2.K vISION AND THAT ALL DIMENSIONS ~' m~m ~ CONDUCTOR AS-BUILTS AND OTHER DETAILS ARE CORRECT ~[~"'. ~'5~ ,'"~'~ o, =o, ,.... Immmm I I II II ~ I I Ill II I I I I I I I I Well ASP's AlasYa u, & ¢'..~ Cui,;:~, [;°'"~'T';~':~:u:: Dist. Dist. O.G. Pod No. 'Y' 'X' L~t;l~Mli:~ LONGITUDE F.S.L. E E.L. Elev. Elev. , I 5,938,600.18 498,310.17 70° 14'36.519 " 150 ° 00'49.13`5" 296' 94' 114.0 118.5 2 5,9`58,575.14 498,310.28 70° 14' ,56.273" 150°00'49.1,50'' 271' 11:5.9 `5 5,9:58,550.30 498,`510.35 70° 14-' 36.029" 150°00'49.128'' 246' 113.8 4 5,9`58,525.46 498,310.06 70014' 35.784" 150°00'49.136'' 2:~' 113.8 5 5,938,500.19 49 8,`510.1Z 70°!4' 35.536" 150° 00'49.1`54'' 196' 113.8 6 5,938,475.14 498,310.33 70014' 35.289" 150°00'49.128" 171' 113.8 4' " 14 6' I 13.8 7 5,958,450.$6 i 498,310.36 70° 14, 35.046 150°00' 49.127'' 8 5,938,425.`50 498,$10.18 70°t `54. 799" 150°00'49.1,52'' 121' 113.8 9 5,938,400.;50 498,309.98 70o14. 34.553" 150°00'49.1`57" 96' 11,5.8 I0 5,958,,575.19 498,510.14. 70014'34.,506'' 150°00'49.133'' 71' 11,5.9 I I 5,938~350.22 498,310.14 70°14'34.061 " 150°00'49.153" 46' 11`5.9 12 5,938,325.20 498,`510.17 70°14' 33.815'' 150 °00' 49. 131'' 21' 94' 11`5.9 118.5 EN.L 1,5 5,938,235.$1 498,`510.37 70 ° 14' 32.950'' 150 °00'49.125'' 69' 94' I 1`5.7 118.5 14 5,938,210.14 498,310. 16 70°14' 3Z.683'' 150° 00' 49. 131'' 94' 113.7 15 5,938,185.1Z 498,310.16 70o14'32.437" 150° 00'49. 131" 119' 11`5.8 16 5,938, 160.11 . 498,$10.20 70°14' 32. 191'' 150° 00' 49. 130'' 144' : 115.8 17 5,9,58, 13,5.21 498,$10.18 70° 14' `51.946" 150°00' 49.130" I 69' i 113.9 19 5,9`58,085.P~0 498,310.27 70014' 31.454" 150o00' 49.12?" 219' 114.0 20 5,938,060.14 498,3,0.22 70° 14'31.207" ,50° 00'49. 128" 244' i ,',4. l , . 30.962" 150°00'49.130'' 269' 't 114.0 21 5,938,035.16 498 310 16 70o14' 2`5 5,9`57,985.32 498,3,0.,$ 70 °,4' $0.471'' ,50o 00'49. 130'' 3l 95' ,,4.0 ' 24 5 ~937~960.29 498,$10.08 70 °14' 30.2Z5'' 150° 00'49.13 344' 95' I 113.9 118.5 October i9, 1988 Telecopy No. (907) 276-7542 J B Kewin Regional Driltz g Engineer AkCO Alaska, Inc P O Box 100360 Anchorage, AK 99510-0360 Re: Kuparuk River Unit~ 2K-3 ARCO Alaska, Inc Permit ~ 88-120 Surf Loc 250'FSL, 90'FEL, Sec 2, T10N, RSE, UM Btmhoie Loc I174'FbV~, 647'FWL, Sec 2, T10N, RSE, UM Dear Mr Kewin~ Enclosed is the approved application for permit to drill the above referenced well. The permit to drill does not indamnify you from the probable need to obtain additional permits required by law from other govern- 'mental agencies prior to commencing operations at the well site. To aid us in scheduling field work, please notify this oflice 24 hours prior to commencing installation oi the blowout prevention equipment so that a representative of the Commission may be present to Witness testing of the equipment before the surface casing shoe is drilled. ~ere a diverter system is required, please also notify this office 24 hours prior to commencing equipment installation so that the Commission may witness testing before drilling below the shoe of the conductor pipe. Very truly y~s, Chairman Alaska Oil and Gas Conservation Co~ission BY O~ER OF THE COMMISSION jo Enclosure C: Department of Fish & Game, Habitat Section - w/o encl Department of Environmental Conservation - w/o encl STATE OF ALASKA ALASKA O,__ AND GAS CONSERVATION COI,,,,,,IlSSION PERMIT TO DRILL 20 AAC 25.005 la. Type of work Drill Re-Entry [] Deepen[]1 Service [] Developement Gas [] Single Zone;~ Multiple Zone 2. Name of Operator 5. Datum Elevation (DF or KB) 10. Field and Pool ARCO Alaska, Inc. RKB 136',PAD 101 'GL feet Kuparuk River Field 3. Address 6. Property Designation Kuparuk River Oi I Po P.O. Box 100360 Anchorage, AK 99510-0360 ADL 25588 ALK 2674 4. Location of well at surface 7. Unit or property Name 11. Type Bond Isee 20 AAC 25.025) 250'FSL, 90'FEL,Sec.2,TION,R8E,UM Kuparuk River Unit Statewide At top of productive interval (@ target) 8. Well nu.mber Number 1320'FNL, 820' FWL,Sec. 2,T10N,R8E,UM 2K-3 #8088-26-27 At total depth 9. Approximate spud date Amount 11 74' FNL,647 ' FWL,Sec. 2,T1 0N,R8E,UM 11/1 3/88 $500,000 12. Distance to nearest 13. Distance to nearest well 14. Number of acres in property 15. Proposed depth (MD and TVD) property line 2K-2 9060 ' HD 647' @ TD feet 25' ~ surface feet 2560 6399'TVD feet 16. To be completed for deviated wells 17. Anticipated pressure (see 20 AAC 25.035 (e)(2)) Kickoff depth 500 feet Maximum hole angle 500 Maximum surface 1 722 psig At total depth (TVD) 2919 psig 18. Casing program Setting Depth size Specifications Top Bottom Quantity of cement Hole Casing Weight Grade Coupling Length MD TVD MD TVD (include stage data) 2z~'' 16" 62.5# H-40 Weld 80 35 35' 115 115' +200 # cf lz-~/4 d-.b/U HF-ER~' ,~u sx u~ass u 8-1/2 7" 26.0# J-55 BTC 9026 34 34' 9060 6399' HF-ER~ 200 SX Class G tail 19. To be completed for Redrill, Re-entry, and Deepen Operations. Top of G 500' above Present well condition summary Kupa ruk Total depth: measured feet Plugs (measured) true vertical feet Effective depth: measured feet Junk (measured) true vertical feet Casing Length Size Cemented Measured depth True Vertical depth Structural Conductor Surface · Intermediate Production Liner Perforation depth: measured true vertical ': ' · .... i.~.ii 20. Attachments Filing fee Drilling fluid program 21. I hereby certif,~hat the foreg~o~d correct to the best of my knowledge // Signed (' ,/~'//,.,~,¢ Title Regi cna l Dri I 1 i ng Engineer Date,/~-~-~/~' Permit Number I APInumber IApprovaldate ISeec~erletter ~-/2_0 50--/03- 2o /00 10/'19/88 for other requirements Conditions of approval Samples required [] Yes No Mud Io re uired m H ~' g q _ _; Yes ~ No ydrogen sulfide measures .~ Yes ~ No I;)irectional survey required .~Yes [] No Required working pre~s~ure fo~BOP~E--~ ~2M; '~ 3M; [] 5M; [] 10M; [] 15M Other: /,~,~~//C~/~ ~/~~./ by order of Approved by ~_ _~' ,,~', ( ¢'~,'/~ Commissioner the commission Date I~,-,rrn tn_4nt ~,,-,w lO_1_..q~ GENERAL DRILLING PROCEDURE KUPARUK RIVER FIELD DEVELOPMENT WELLS 1) MIRU. 2) Install FMC diverter system. 3) Drill 12-1/4" hole to 9-5/8" surface casing point according to d i rect i onal pl an. 4) Run and cement 9-5/8" casing. 5) Install and test BOPE. Test casing to 2000 psig. 6) Drill out cement and 10' new hole. Perform leak off test. 7) Drill 8-1/2" hole to logging point according to directional plan. 8) Run open hole logs. 9) Continue drilling 8-1/2" hole to provide 100' between PBTD and bottom of Kuparuk sands. 10) Run and cement 7" casing, Pressure test to 3500 psig. 11) Downsqueeze Arctic pack'and cement in 7" x 9-5/8" annulus. 12) ND BOPE and install temporary Xmas tree. 13) Secure well and release rig. 14) Run cased hole logs. 15) Move in Workover rig. NU BOPE. 16) PU 7" casing scraper and tubing, TIH to PBTD. clean brine and TOH standing tubing back. 17) Perforate and run completion assembly, set and test packer. 18) ND BOPE and install Xmas tree. 19) Change over to diesel. 20) Flow well to tanks. Shut in. 21) Secure well and release rig. 22) Fracture stimulate. Circulate hole with OEGASSER ~ MUD CLEANER SHALE ST STIR STIR SHAKERS MUD CLEANER CENTRIFUGE TYPICAL MUD SYSTEM SCHEMATIC Density DRILLING FLUID PROGRAM Spud to Drill out 9-5/8" Surface Casing to Weisht 9.6-9.8 '8. ?-9.2 Weight Up to TD 10.3 PV 15-30 5-15 9-13 yp 20-40 8-12 8-12 Viscosity 50-100 35-40 35-45 Initial Gel 5-15 2-4 3-5 10 Minute Gel 15-30 4-8 · ' 5-12 Filtrate AP1 20 10-20 pH 9-10 9.5-10.5 9.5-10.5 % Solids 10± 4-7 9-12 Drtllin~ Fluid System: - Triple Tandem Shale Shaker - 2 Mud Cleaners - Centrtfuse - Desasser - Pit Level Indicator (Visual & Audio Alarm) - Trip Tank - Fluid Flow Sensor - Fluid Agitators Notes: ,,, Drilling fluid practices will be in accordance with the appropriate regulations stated in 20 AAC 25.033. Maximum anticipated surface pressure is calculated using a surface casing leak-off of 13.5 ppg EMW and a gas gradient of .11 psi/ft. This shows that formation breakdown would occur before a surface pressure of 3000 psi could be reached. Therefore, ARCO Alaska, Inc. will test our BOP equipment to 3000 psi. After 200' of departure, there are no well bores within 200' of this proposed well. In accordance with Area Injection Order No. 2, excess non-hazardous fluids developed from well operations and those fluids necessary to control the fluid level in reserve pits will be pumped down the surface/production casing annulus. The annulus will be left with a non-freezing fluid during any extended shutdown in disposal operations. The annulus will be sealed with 175 sx of cement followed by arctic pack upon completion of the fluid disposal. Ll~CS/ih 20' DIVERTER SCHEHATIC 2. FI'lC SLII)-ON ~ STARTINI HEAD 3. FI'lC OlV[RI'~II A.~'II,Y ~1111'1~ ~ 2000 I~18AU, VN,VIt 4. 20- 2000 F41 ~ tP(~ W/lO' ~l/l?.rrl $. I0' HCR 8AU, VAI,VII~IMIO° ~ A $11eekE VAI,Vl ~ MITaI'~TICALLY I~y C~ 6. 20' 20CO I~1 Atlll.~ t~iVlNt~I~ 4 AK0 ALA:~,A. INC.. I~~T~ APegOV~ OF THIS OlVEATIA $Y~T~ ).,I A VARIAI~ F;O~ 20AAC2"J.035~) I"!AI NTENANCE & OP£~TION 3 UPON INITIAL INSTALLATI(W, CLOM, I:~EVENTER vERIFY THAT VALVE 0PEN~ 2. CLOSE ANNULAR IH~rV~g'r~:~ AND ~l,01dlf AIR TI'~G DIVERT'ER LINES EVERY CLOSE J~NNULAR PREVENTER IN TH~ EVEN? THAT .~ INFLUX OF WELL~::X~ FLUII~ (~ {~$ I$ DETECTED OPE:N APPI~OPI=.IAI'[ VALVE TO ACNIEVE ~~: DIVERSION. DO NOT SHUT IN WELL UNDER ANY CIRCLIHSTANCES · · i iii i 7 , 6 I_ DIAGRN~ el 1~-5/8' 5(3(30 PSI ~ BOP STAO( 4. 1:~-5/8' - KILL 6, 1~5/'8" - 5000 PSI 7. ~8~ - ~~I ACO. M,L~TOR CAPACITY TEST I. 0-~ ~ FlU. /ICQ, M/.ATCR RESERVOIR TO ~ LEVEL WITH HYOIULLIC FLUID. ~ ~ T~T ~~ ~ IS ~~I ~ I~ ~I ~ ~ T~ ~~T~. 3. ~ TI~ T~~ ~ ~ SIXThlY 4. ~~~~ ~T. T~ ~~ L~ LI~T IS 45 ~~ ~I~ TI~ ~ I~ ~I ~I~ 13-5/8' BOP STAll<; TEST 4 I. FILL ~ STAO( AN30.CKE blt~J/FCLD WITH ARCTIC DIESEL. 2. O.E~ TI-~T ALL LO0( ~ ~ IN PELLI-F. AD ARE FILLY I~TEACTED, SEAT TEST PLUG IN V~LLI~:J~ ...... WITH RU~IIN3 JT AI~ RLN IN L~ LI~E VALVES ADJACE~ TO BCP STAOC ALL OTI-ER' VALVES AJ~) (]-II(E~ SHOLLD BE ~ 4. P~ESSL;~ UP TO 250 PSI ~ HCLD FCR I0 ~ C~EASE PRE~LRE TO ~:X33 PSI ~ H~.D FCR I0 MIN. BLEED PRESSL;~ TO 0 PSI. 5, CPEN ~ PREVENTER A~ kW,AL Kill LIllE VALVES. O. CEE TCP PIPE RA~ ~ HCR VALVES . CN Kill ~ O-CKE LI~ES. ~, TEST TO 2~0 PS! ~r) ~ PS! AS IN S'mP 4. ?. 03~I~g Tggr!m ALL V~.VES, L!~'~S, ~ WITH A ~50 PSI LOW AM) ~ m! HIGH. TEST AS IN s'rEP 4. ~ 2 I i I I0. O.O~E BLIM) P. Ak6 AN) TEST TO 250 PSI A,"d) f ,,. ~n~ mu~ ~e ~,~ ~mmv~ TeST euJr,. a.u~D. S~T ALL V~ ~ m~m ~TI~ ~ ~I. F~ SI~ ~ ~ TO ~ILLI~ ~VI~. ~Y ~~ ~I~Y ~~E ~ ~ILY. ARCO ALASKA, !ne. Ped 2K. Well No, :3 Pr'.opoeed Kuperuk Field. North Slope. Aleeke 0 _ RKB £LEVAT[ON~ 136' 1000. 2000 _ m 3000_ m o 4O00 _ rrl 5000. 6000 _ ?000 KOP TVD=500 TMD=500 DEP=O BUILD 3 DEe 9 PER I00 FT 15 2? B/ PERMAFROST TVDml 406 TMD=1444 DEP=229 33 T/ UGNU SNDS TVD=1525 THD=1582 DEP=298 39 EOC TVD=1962 TMD=2165 DEP=681 T/ 14 SAK SNDS TVD-213;4 THD=2432 DEP-886 K-12 TVD=2709 TMD=3326 DEP=1570 9 5/8' CSG PT TVD=2gog TMD=3637 DEP=1808 K-lO TVD=3144 THD=4002 DEP=2087 K-5 TVD=4484 THD=6085 DEP=3681 AVERAGE ANGLE 49 DE(; 57 HI N T/ ZONE C TVD=6112 TMD=8615 DEP=5618 T/ ZONE A TVD=6146 THD=8668 DEP=5659 TARGET CNTR TVD=6208 TMD=8764 DEP=5732 B/ KUP SNDS TVD-6270 TMD=8860 DEP-5806 TD (LOG PT) TVD-6399 TMD=9060 DEP-5959 I I I I 1 000 2000 3000 4000 VERTICAL SECTION I 5000 6000 HOR ! ZONT AL PROJECT I ON SCALE I IN. - 1000 FEET 4OOO TD LOCATION, 1173' FNL. 647' FWL SEC. 2. TlOfl. RSE ;5000 TARGET LOCATION, 1320' FNL. 820' Fk'l. SEC. 2. TION. RSE 2000 1 000 0 ARCO ALASKA. Ina. Pad 2K. Well No. :3 Propo.ed Kuperuk Fl·Id. North SI ope. Al,,ka 6000 5000 4000 WEST-EAST 3000 2000 TARGET CENTER TVD-6208 THD-8764 SEP-5732 NORTH 3710 I, EST 437'0 N 49 DEG 40 MI N 14 5732' (TO TARGET) 1000 0 1000 ACE L(X~AT[ON' I 280' FSL. 90' FEL ~ b-'lie. 2. TI ON. RILE: 250 200 1 50 1 O0 50 0 50 ,1 ~ I I I ~1 I 55o.I ....... - - -- ~'~']' ' \ ~ ~soo b4oo ~ I 500 _ _ J ,~00 /,?00 J 4so_ I / I 1200 iI ,,,, ,' oo ~ ~oo ~ ~oo~__ I ~ ~0 ~00 ~ x ~l r~O ~ ' - ~ ~oo ~kooo ~z~ i~oo I I ~ ~ ~. ~800 I , , ~ ~oo ~o ~ ~o~ I I ~ +~o~' ~ ~ ~oo UO0 '~~ol I 25~ 250. j ~.~ ooo~%~ ~o ' - I /~~oo 150 . I I i i i I I I 55~ 50!. 45~ 40( 35C 3Or, I .20( I I J _ 15( 250 200 1 50 1 O0 50 0 50 CHECK LEST FOR NEW WELL PERMITS ITEM APPROVE 'DATE Loc (7. thr~ 8) (3) Admin ~ /~.,/f f 9. 13') -' 10. (10 and 13) 12. 13. (4) Casg _._.~..'~.<//,/. '~'<¥'$~ (14 ~h~ 22) (23 thru 28) (6) O~ 14. 15. (6) Add: Ge. lo gy: · 16. 17. 18. 19. 20. 21. '22. 23. 24. 25. 26. 27. 28. For £?c 29. (29 thru 31) 30. 31. Company /,-cO ~//'~.i-~o~ ' -~-,~J'_~,, Lease ~ Well No. ~ YES NO Is :he pe~= fee a==ached ' ~ . 2. Is well to be located in a defined pool ............................. ~ 3. Is well located proper distance from property line .................. ~- 4. Is well located proper distance from other wells .................... ~ 5. Is sufficient undedicated acreage available in this pool ............ 6. Is well to be deviated and is wellbore plat included., .............. ~ 7. Is operator the only affected party .................... ~ ............ ~ 8. Can permit be approved before fifteen-day-wait ...................... ~ ~S Does operator have a bond in force .................................. ~ Is a conservation order needed ...................................... ,, , Is administrative approval needed ................................... Is the lease number appropriate ..................................... ~ Does the well have a unique name and number ........................ ~ iA Engineering: LCS ~//~ BEW / Is conductor string provided ........................................ Will surface casing protect all zones reasonably expected to serve as an underground source of drinking water ..................... 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 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 wellbore separation proposed eeo. eeoeeoe.eeeeeeeoeee~oeo rev: 08/11/88 {.01I Is a diverter system required ....................................... Is the drilling fluid program schematic and list of equipment adequate/~o_. Are necessary diagrams and descriptions of diverter and BOPE attached. Does BOPE have sufficient pressure rating - Test to ~O~o psig .. Does the choke manifold comply w/API RP-53 (May 84) .... ' ............. Is the presence of H2S gas probable ................................. eXPloratory and Stratigraphic wells: Are data presented on potential overpressure zones? · oeoeoeeeooooeeeee Are seismic analysis data presented on shallow gas zones ............ If an offshore loc., are survey results of seabed conditions presented Additional requirements ............................................. POOL Additional Remdrks: INITIAL GEO. -UNIT ON/OFF CLASS STATUS 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'effort has been made to chronologically ' -: · ,. organize this category of information. RECEIVED , o4 1998 Anchorage * ALASKA COMPUTING CENTER * ....... SCHLUMBERGER ....... COMPANY NAME : BP EXPLORATION WELL NAME : F- 2 6 FIELD NAME : PRUDHOE BAY BOROUGH : NORTH SLOPE STATE : ALASKA API NUMBER : 500292198700 REFERENCE NO : 98337 LIS Tape Verification Listing Schlumberger Alaska Computing Center 14-JUL-1998 09:31 PA GE: **** REEL HEADER **** SERVICE NAME : EDIT DATE : 98/07/13 ORIGIN : FLIC REEL NAME : 98337 CONTINUATION # : PREVIOUS REEL : COGENT · BP EXPLORATION, PRUDHOE BAY, F-26, API #50-029-21987-00 **** TAPE HEADER **** SERVICE NAME : EDIT DATE : 98/07/13 ORIGIN · FLIC TAPE NAME : 98337 CONTINUATION # : 1 PREVIOUS TAPE : COF~qENT : BP EXPLORATION, PRUDHOE BAY, F-26, API #50-029-21987-00 TAPE HEADER PRUDHOE BAY CASED HOLE WIRELINE LOGS WELL NAME: F- 26 API NUMBER: 500292198700 OPERATOR: BP EXPLORATION LOGGING COMPANY: SCHLUMBERGER WELL SERVICES TAPE CREATION DATE: 13-JUL-98 JOB NUMBER: 98337 LOGGING ENGINEER: SHARPLES OPERATOR WITNESS: J. RATHERT SURFACE LOCATION SECTION .. 2 TOWNSHIP: 1 iN RANGE: 13 E FNL: 3138 FSL: FEL: 2197 FWL : ELEVATION (FT FROM MSL O) KELLY BUSHING: 68. O0 DERRICK FLOOR: 67. O0 GROUND LEVEL: 36.46 WELL CASING RECORD OPEN HOLE CASING DRILLERS CASING BIT SIZE (IN) SIZE (IN) DEPTH (FT) WEIGHT (LB/FT) 1ST STRING 8.500 5.500 10567.0 2ND STRING 3RD STRING PRODUCTION STRING CURVE SHIFT DATA - ALL PASSES TO STANDARD(MEASURED DEPTH) LIS Tape Verification Listing Schlumberger Alaska Computing Center 14-JUL-1998 09:31 BASELINE CURVE FOR SHIFTS LDWG TOOL CODE: LDWG CURVE CODE: RUN NUMBER: PASS NUMBER: DATE LOGGED: LOGGING COMPANY: BASELINE DEPTH 88888.0 10337.0 10284.5 10240.0 10196.0 10176.0 10175.5 10174.0 10172.0 10170.5 10168.0 10161.5 10159.0 10154.5 10144 5 10142 5 10132 0 10110 5 10108 5 10093 0 10092.5 10086.5 10070.5 10068.5 10051.0 10014.5 10013.5 10009.0 10008.5 9979.5 9959.0 9955.0 9950.5 9941.0 9936.5 9930.0 9926.0 9922.0 9915.0 9910.5 9903.0 9896.5 9879.5 9879.0 9862.0 .......... EQUIVALENT UNSHIFTED DEPTH .......... GR CH CNTD 88890.5 88890.5 10339.5 10339.5 10286.5 10286.5 10241.5 10241.5 10197.0 10197.0 10176.5 10173.5 10170.0 10161.5 10154.5 10145.0 10111.0 10093.5 10087.5 10071.0 10052.0 10015.0 10010.0 10176.5 10173.5 10170.0 10161.5 10145.0 10134.0 10111.0 10093.5 10087.5 10071.0 10052.0 10015.0 10010.0 9981.0 9981.0 9960.5 9960.5 9956.5 9956.5 9952.0 9952.0 9941.5 9941.5 9938.5 9938.5 9931.5 9931.5 9926.5 9926.5 9922.5 9922.5 9915.0 9915.0 9911.0 9911.0 9903.5 9903.5 9896.5 9896.5 9879.0 9861.5 9879.0 PAGE: LIS Tape Verification Listing Schlumberger Alaska Computing Center 14-JUL-1998 09:31 9860.5 9861.5 9846.5 9848.0 9821.5 9822.0 9822.0 9815.5 9815.0 9815.0 100.0 99.5 99.5 REMARKS: CONTAINED HEREIN IS THE CNTD DATA ACQUIRED ON BP EXPLORATION WELL F-26 ON Il-MAR-98. THE DEPTH SHIFTS SHOWN ABOVE REFLECT CNTD PASS #1 GRCH TO THE BASELINE GAi~MA RAY PROVIDED BY THE CLIENT; AND CNTD PASS #1 NPHI TO THE BASELINE GAIV~A RAY. ALL OTHER CNTD CURVES WERE CARRIED WITH THE NPHI SHIFT. $ $ PAGE: **** FILE HEADER **** FILE NAME : EDIT .001 SERVICE : FLIC VERSION : O01CO1 DATE : 98/07/13 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : FILE HEADER FILE A~JMBER: 1 EDITED CURVES Depth shifted and clipped curves for each pass in separate files. PASS NL~IBER: 1 DEPTH INCREMENT: 0.5000 FILE SUMMARY LDWG TOOL CODE START DEPTH STOP DEPTH GRCH 10358.0 9794.0 CNTD 10382.0 9794.0 $ CURVE SHIFT DATA - PASS TO PASS (MEASURED DEPTH) BASELINE CURVE FOR SHIFTS LDWG CURVE CODE: PASS NUMBER: BASELINE DEPTH $ .......... EQUIVALENT UNSHIFTED DEPTH .......... GRCH CNTD REMARKS: THIS FILE CONTAINS THE CLIPPED AND DEPTH CORRECTED DATA FOR CNTD PASS #1. NO PASS TO PASS SHIFTS WERE APPLIED TO THIS DATA. $ LIS Tape Verification Listing Schlumberger Alaska Computing Center 14-JUL-1998 09:31 PAGE: LIS FORMAT DATA ** DATA FORMAT SPECIFICATION RECORD ** ** SET TYPE - 64EB ** TYPE REPR CODE VALUE 1 66 0 2 66 0 3 73 44 4 66 1 5 66 6 73 7 65 8 68 0.5 9 65 FT 11 66 23 12 68 13 66 0 14 65 FT 15 66 68 16 66 I 0 66 0 ** SET TYPE - CHAN ** NAME SERV UNIT SERVICE API API API API FILE NUMB NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUMB SAMP ELEM CODE (HEX) O0 000 O0 0 1 1 1 4 68 0000000000 DEPT FT 1244483 NPHI CNTD PU-S 1244483 O0 000 O0 0 1 1 1 4 68 0000000000 NRAT CNTD 1244483 O0 000 O0 0 1 1 1 4 68 0000000000 CRAT CNTD 1244483 O0 000 O0 0 1 1 1 4 68 0000000000 NCNT CNTD CPS 1244483 O0 000 O0 0 1 1 1 4 68 0000000000 FCNT CNTD CPS 1244483 O0 000 O0 0 1 1 1 4 68 0000000000 CFTC CNTD CPS 1244483 O0 000 O0 0 1 1 1 4 68 0000000000 CNTC CNTD CPS 1244483 O0 000 O0 0 1 1 1 4 68 0000000000 GRCH CNTD GAPI 1244483 O0 000 O0 0 1 1 1 4 68 0000000000 TENS CNTD LB 1244483 O0 000 O0 0 1 1 1 4 68 0000000000 CCL CNTD V 1244483 O0 000 O0 0 1 1 1 4 68 0000000000 ** DATA ** DEPT. 10384.500 NPHI. CNTD 17.881 NRAT. CNTD 3.338 CRAT. CNTD NCNT. CNTD 5602. 036 FCNT. CNTD 1678. 208 CFTC. CNTD 1539.184 CNTC. CNTD GRCH. CNTD - 999. 250 TENS. CNTD 1614. 000 CCL. CNTD O. 000 3. 468 4964. 595 LIS Tape Verification Listing Schlumberger Alaska Computing Center 14-JUL-1998 09:31 PAGE: DEPT. 9793.500 NPHI.CNTD 48.105 NRAT. CNTD NCNT. CNTD 1857.858 FCNT. CNTD 260.693 CFTC. CNTD GRCH. CNTD 88.422 TENS. CNTD 1498.000 CCL.CNTD 7.127 239.096 0.000 CRAT. CNTD CNTC. CNTD 7.107 1888.415 ** END OF DATA ** **** FILE TRAILER **** FILE NAME : EDIT .001 SERVICE : FLIC VERSION : O01CO1 DATE : 98/07/13 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : **** FILE HEADER **** FILE NAME : EDIT .002 SERVICE : FLIC VERSION : O01CO1 DATE : 98/07/13 MAX REC SIZE : 1024 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: 0.5000 FILE SUMMARY LDWG TOOL CODE START DEPTH STOP DEPTH GRCH 10372.0 9790.0 CNTD 10396.0 9790.0 $ CURVE SHIFT DATA - PASS TO PASS (MEASURED DEPTH) BASELINE CURVE FOR SHIFTS LDWG CURVE CODE: GRCH PASS NUMBER: 1 BASELINE DEPTH .............. 88888.0 .......... EQUIVALENT UNSHIFTED DEPTH .......... GR CH CNTD 88889.0 88890.5 LIS Tape Verification Listing Schlumberger Alaska Computing Cen~er 14-JUL-1998 09:31 PAGE: 10380.0 10374.5 10363.0 10358.0 10342.5 10341.5 10339.5 10331.5 10329.5 10323.0 10319.5 10300.0 10280.0 10271 5 10264 0 10263 0 10243 5 10240 0 10237 0 10234.0 10219.5 10215.0 10211.5 10209.0 10206.5 10196.0 10194.0 10175.5 10175.0 10167.0 10160.5 10158.0 10155.0 10143.5 10141.0 10131.5 10122.5 10113.5 10110.0 10108.0 10100.5 10099.0 10092.5 10074.0 10071.5 10070.0 10068.5 10050.0 10049.5 10030.0 10024.5 10022.5 10014.0 10013.5 10009.0 10342.5 10340.5 10325.0 10264.5 10235.5 10215.5 10198.0 10176.0 10161.0 10155.0 10145.5 10125.0 10111.0 10101.0 10093.5 10071.5 10052.0 10026.0 10015.5 10010.5 10382.5 10377.5 10366.0 10360.5 10345.5 10335.0 10332.5 10323.0 10302.0 10283.0 10272.0 10265.0 10245.0 10242.0 10236.5 10221.0 10213.5 10210.5 10208.5 10196.0 10177.0 10170.0 10161.5 10144. 0 10134.0 10117. 0 10111. 0 10101.0 10094.5 10077.0 10074.5 10071.5 10051.5 10032.5 10025.5 10015.5 LIS Tape Verification Listing Schlumberger Alaska Computing Center 14-JUL-1998 09:31 PAGE: 10001.5 10003.5 9991.5 9992.5 9990.5 9992.5 9975.0 9975.5 9972.0 9974.5 9959.0 9961.0 9954.5 9956.5 9950.5 9952.5 9952.5 9944.0 9945.0 9938.5 9940.0 9930.0 9932.0 9929.5 9931.5 9926.0 9927.0 9922.0 9923.0 9923.0 9914.5 9915.0 9914.5 9901.0 9902.0 9897.0 9897.5 9896.0 9897.0 9891.0 9890.5 9888.0 9886.5 9887.0 9887.5 9879.5 9879.0 9871 . 5 9871.0 9865.0 9866.0 9861.5 9861.5 9857.0 9858.5 9844.5 9846.0 9844.0 9845.5 9829.0 9830.0 9822.5 9823.0 9821.0 9822.0 9815.5 9815.5 9813.0 9813.0 9809.5 9809.0 9806.0 9806.5 9802.0 9800.5 9797.0 9795.5 100.0 100.0 98.5 $ REd. ARKS: THIS FILE CONTAINS THE CLIPPED ANDDEPTH CORRECTED DATA FOR CNTD PASS #2. THE DEPTH SHIFTS SHOWN ABOVE REFLECT CNTD PASS #2 GRCH TO CNTD PASS #1GRCH; AND CNTD PASS #2 NPHI TO CNTD PASS #1NPHI. ALL OTHER CNTD CURVES WERE CARRIED WITH THE NPHI SHIFT. $ LIS FORMAT DATA LIS Tape Verification Listing Schlumberger Alaska Computing Center 14-JUL-1998 09:31 PAGE: ** DATA FORMAT SPECIFICATION RECORD ** ** SET TYPE - 64EB ** TYPE REPR CODE VALUE 1 66 0 2 66 0 3 73 44 4 66 1 5 66 6 73 7 65 8 68 0.5 9 65 FT 11 66 23 12 68 13 66 0 14 65 FT 15 66 68 16 66 1 0 66 1 ** SET TYPE - CHAN ** NAME SERV UNIT SERVICE API API API API FILE NUMB NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUMB SAMP ELEM CODE (HEX) DEPT FT 1244483 O0 000 O0 0 2 1 1 4 68 0000000000 NPHI CNTD PU-S 1244483 O0 000 O0 0 2 1 1 4 68 0000000000 NRAT CNTD 1244483 O0 000 O0 0 2 1 1 4 68 0000000000 CRAT CNTD 1244483 O0 000 O0 0 2 1 1 4 68 0000000000 NCNT CNTD CPS 1244483 O0 000 O0 0 2 1 1 4 68 0000000000 FCNT CNTD CPS 1244483 O0 000 O0 0 2 1 1 4 68 0000000000 CFTC CNTD CPS 1244483 O0 000 O0 0 2 1 1 4 68 0000000000 CNTC CNTD CPS 1244483 O0 000 O0 0 2 1 1 4 68 0000000000 GRCH CNTD GAPI 1244483 O0 000 O0 0 2 1 1 4 68 0000000000 TENS CNTD LB 1244483 O0 000 O0 0 2 1 1 4 68 0000000000 CCL CNTD V 1244483 O0 000 O0 0 2 1 1 4 68 0000000000 ** DATA ** DEPT. 10398.500 NPHI. CNTD 16.536 NRAT. CNTD 3.261 CRAT. CNTD NCNT. CNTD 4268.839 FCNT. CNTD 1309.166 CFTC. CNTD 1200.714 CNTC. CNTD GRCH. CNTD -999.250 TENS. CNTD 1624.000 CCL.CNTD 0.000 DEPT. 9788.500 NPHI. CNTD 45.221 NRAT. CNTD 6.828 CRAT. CNTD NCNT. CNTD 1922. 607 FCNT. CNTD 281 . 573 CFTC. CNTD 258. 248 CNTC. CNTD GRCH. CNTD -999.250 TENS. CNTD 1470. 000 CCL. CNTD O. 000 3.286 4363. 625 6. 777 1927. 060 LIS Tape Verification Listing Schlumberger Alaska Computing Center 14-JUL-1998 09:31 PAGE: ** END OF DATA ** **** FILE TRAILER **** FILE NAME : EDIT .002 SERVICE · FLIC VERSION : 0 O1 CO1 DATE : 98/07/13 MAX REC SIZE : 1024 FILE TYPE .. LO LAST FILE : **** FILE HEADER **** FILE NAME : EDIT .003 SERVICE : FLIC VERSION : 001 CO1 DATE : 98/07/13 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : FILE HEADER FILE NUMBER: 3 EDITED CURVES Depth shifted and clipped curves for each pass in separate files. PASS NUMBER: 3 DEPTH INCREMENT: O. 5000 FILE SUMMARY LDWG TOOL CODE START DEPTH STOP DEPTH GRCH 10372.0 9794.0 CNTD 10396.0 9794.0 $ 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 CNTD 88888.0 88888.5 88890.0 10375.5 10377.5 10370.0 10372.0 10364.5 10366.5 10358.5 10360.5 LIS Tape Verification Listing Schlumberger Alaska Computing Center 14-JUL-1998 09:31 PAGE: 10 10350 5 10342 0 10338 0 10331 0 10323 5 10300 5 10285 0 10272 5 10269.0 10240.5 10233.5 10227.5 10219.5 10215.0 10202.5 10199.0 10175.5 10167.5 10161.0 10159.0 10144.5 10142.0 10132.0 10110.5 10108.5 10099.5 10096.5 10093.0 10092.0 10088.0 10076.5 10075.0 10070.5 10069.0 10051.0 10050.5 10016.5 10014.5 10013.5 10009 5 10009 0 9991 5 9979 0 9974 0 9959 5 9959 0 9955 0 9951 0 9950 5 9939.0 993 6.5 993 O. 0 9927.5 9926.0 9922.5 10342.5 10286.0 10273.5 10235.0 10202.0 10161.0 10145.5 10111.0 10093.5 10077.0 10071.5 10052.0 10015.0 10010.0 9981.5 9961.0 9956.5 9952.5 9938.5 9932.0 9927.0 10352.0 10341.0 10332.5 10326.0 10302.5 10286.5 10270.5 10242.0 10228.5 10221.5 10216.5 10200.5 10177.0 10170.0 10161.5 10144.0 10133.5 10111.0 10101.0 10098.0 10094.5 10089.5 10077.0 10071.5 10051.5 10019.0 10015.0 10011.0 9992.5 9975.0 9961.0 9953.0 9940.5 9929.0 9923.0 LIS Tape Verification Listing Schlumberger Alaska Computing Center 14-JUL-1998 09:31 PAGE: 11 9922.0 9923.0 9914.5 9914.5 9911.0 9910.5 9904.0 9906.5 9903.5 9904.0 9896.5 9897.5 9896.0 9896.5 9889.0 9889.0 9884.5 9885.5 9878.5 9879.0 9878.5 9864.5 9866.0 9862.0 9861.5 9860.0 9862.0 9857.5 9859.0 9846.0 9848.0 9842.0 9843.5 9833.0 9833.0 9821.5 9822.0 9816.5 9817.0 9815.5 9815.5 9812.0 9813.0 9810.0 9809.0 9807.0 9806.5 100.0 100.0 99.5 $ REMARKS: THIS FILE CONTAINS THE CLIPPED ANDDEPTH CORRECTED DATA FOR CNTD PASS #3. THE DEPTH SHIFTS SHOWN ABOVE REFLECT CNTD PASS #3 GRCH TO CNTD PASS #1 GRCH; AND CNTD PASS #3 NPHI TO CNTD PASS #1 NPHI. ALL OTHER CNTD CURVES WERE CARRIED WITH THE NPHI SHIFT. $ LIS FORMAT DATA ** DATA FORMAT SPECIFICATION RECORD ** * * SET TYPE - 64EB ** TYPE REPR CODE VALUE 1 66 0 2 66 0 3 73 44 4 66 1 5 66 6 73 7 65 8 68 0.5 9 65 FT 11 66 23 12 68 LIS Tape Verification Listing Schlumberger Alaska Computing Center 14-JUL-1998 09:31 PAGE: 12 TYPE REPR CODE VALUE 13 66 0 14 65 FT 15 66 68 16 66 1 0 66 1 ** SET TYPE - CHAN ** NAME SERV UNIT SERVICE API API API API FILE NUMB NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUMB SAMP ELEM CODE (HEX) DEPT FT 1244483 O0 000 O0 0 3 1 1 4 68 0000000000 NPHI CNTD PU-S 1244483 O0 000 O0 0 3 1 1 4 68 0000000000 NRAT CNTD 1244483 O0 000 O0 0 3 1 1 4 68 0000000000 CRAT CNTD 1244483 O0 000 O0 0 3 1 1 4 68 0000000000 NCNT CNTD CPS 1244483 O0 000 O0 0 3 1 1 4 68 0000000000 FCNT CNTD CPS 1244483 O0 000 O0 0 3 1 1 4 68 0000000000 CFTC CNTD CPS 1244483 O0 000 O0 0 3 1 1 4 68 0000000000 CNTC CNTD CPS 1244483 O0 000 O0 0 3 1 1 4 68 0000000000 GRCH CNTD GAPI 1244483 O0 000 O0 0 3 1 1 4 68 0000000000 TENS CNTD LB 1244483 O0 000 O0 0 3 1 1 4 68 0000000000 CCL CNTD V 1244483 O0 000 O0 0 3 1 1 4 68 0000000000 ** DATA ** DEPT. 10398.000 NPHI. CNTD 16.256 NRAT. CNTD 3.286 CRAT. CNTD NCNT. CNTD 4320. 000 FCNT. CNTD 1314. 629 CFTC. CNTD 1205. 724 CNTC. CNTD GRCH. CNTD -999.250 TENS. CNTD 1596. 000 CCL. CNTD O. 000 DEPT. 9793.500 NPHI.CNTD 48.113 NRAT. CNTD 6.758 CRAT. CNTD NCNT. CNTD 1824.847 FCNT. CNTD 270.042 CFTC. CNTD 247.672 CNTC. CNTD GRCH. CNTD -999.250 TENSoCNTD 1420.000 CCL.CNTD 0.000 3.248 4380.492 7.108 1873.539 ** END OF DATA ** **** FILE TRAILER **** FILE NAME : EDIT .003 SERVICE : FLIC VERSION : O01CO1 DATE : 98/07/13 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : LIS Tape Verification Listing Schlumberger Alaska Computing Center 14~JUL-1998 09:31 PAGE: 13 **** FILE HEADER **** FILE NAME : EDIT .004 SERVICE : FLIC VERSION : O01CO1 DATE : 98/07/13 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : FILE HEADER FILE NUMBER: 4 EDITED CURVES Depth shifted and clipped curves for each pass in separate files. PASS NUMBER: 4 DEPTH INCREMENT: 0.5000 FILE SUMMARY LDWG TOOL CODE START DEPTH STOP DEPTH GRCH 10372.0 9796.0 CNTD 10396.0 9796.0 $ 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 CNTD 88888.0 88888.0 88891.0 10360.0 10363.0 10358.0 10360.5 10329.5 10332.5 10319.5 10323.0 10317.5 10317.5 10300.0 10302.5 10284.0 10286.5 10263.5 10265.5 10240.5 10242.0 10234.0 10236.5 10226.5 10228.5 10219.5 10222.0 10211.5 10213.5 10208.5 10210.0 10203.0 10204.5 10196.5 10198.0 10193.5 10196.0 10175.5 10176.5 10174.5 10177.0 10167.0 10169.5 LIS Tape Verification Listing Schlumberger Alaska Computing Center 14-JUL-1998 09:31 PAGE: 14 10160 5 10158 5 10143 5 10140 5 10131 5 10110 0 10107 0 10099 5 10096.0 10092.0 10091.5 10086.0 10079.0 10075.5 10074.5 10071.5 10069.5 10068.5 10059.0 10058.0 10050.0 10038.0 10030.0 10029.5 10025.0 10016.5 10014.0 10013.5 10008.5 10004.5 10004.0 9990.0 9979.0 9976.5 9971.0 9959.0 9958.0 9954.5 9951.0 9938.5 993 O. 0 9929.0 9926.0 9922.0 9914.0 9907.0 9904.0 9901.5 9897.0 9896.0 9887.0 9884.5 9878.5 9877.5 9861.5 10161.0 10145.0 10111.5 10101.0 10093.5 10088.0 10077.0 10071.0 10061.0 10051.5 10031.5 10026.0 10015.5 10010.5 10005.0 9981.0 9979.0 9961.0 9956.5 9953.0 9932.0 9927.0 9923.5 9914.5 9908.5 9905.5 9902.5 9897.0 9879.0 9862.0 10161.5 10143.5 10134.0 10111.0 10098.0 10094.5 10082.0 10077.0 10074.0 10071.5 10060.5 10051.5 10040.0 10032.0 10019.0 10015.5 10006.5 9992.5 9973.0 9960.5 9952.5 9940.5 9931.5 9923.0 9898.0 9887.5 9886.0 9878.5 LIS Tape Verification Listing Schlumberger Alaska Computing Center 14-JUL-1998 09:31 PAGE: 15 9857.5 9851.0 9839.5 9835.5 9831.5 9829.5 9825.5 9821.0 9816.0 9815.0 9809.0 98O5.0 100.0 $ 9830.0 9822.0 9815.5 100.5 9859.0 9854.0 9840.5 9837.0 9833.0 9826.0 9817.0 9809.0 9804.5 99.5 REFIARKS: THIS FILE CONTAINS THE CLIPPED AND DEPTH CORRECTED DATA FOR CNTD PASS #4. THE DEPTH SHIFTS SHOWN ABOVE REFLECT CNTD PASS #4 GRCH TO CNTD PASS #1 GRCH; AND CNTD PASS #4 NPHI TO CNTD PASS #1 NPHI. ALL OTHER CNTD CURVES WERE CARRIED WITH THE NPHI SHIFT. $ LIS FORMAT DATA ** DATA FORMAT SPECIFICATION RECORD ** ** SET TYPE - 64EB ** .............................. TYPE REPR CODE VALUE .............................. 1 66 0 2 66 0 3 73 44 4 66 1 5 66 6 73 7 65 8 68 0.5 9 65 FT 11 66 23 12 68 13 66 0 14 65 FT 15 66 68 16 66 1 0 66 1 LIS Tape Verification Listing Schlumberger Alaska Computing Center 14-JUL-1998 09:31 PAGE: 16 ** 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 1244483 O0 000 O0 0 4 1 1 4 68 0000000000 NPHI CNTD PU-S 1244483 O0 000 O0 0 4 1 1 4 68 0000000000 NRAT CNTD 1244483 O0 000 O0 0 4 1 1 4 68 0000000000 CRAT CNTD 1244483 O0 000 O0 0 4 1 1 4 68 0000000000 NCNT CNTD CPS 1244483 O0 000 O0 0 4 1 1 4 68 0000000000 FCNT CNTD CPS 1244483 O0 000 O0 0 4 1 1 4 68 0000000000 CFTC CNTD CPS 1244483 O0 000 O0 0 4 1 1 4 68 0000000000 CNTC CNTD CPS 1244483 O0 000 O0 0 4 1 1 4 68 0000000000 GRCH CNTD GAPI 1244483 O0 000 O0 0 4 1 1 4 68 0000000000 TENS CNTD LB 1244483 O0 000 O0 0 4 1 1 4 68 0000000000 CCL CNTD V 1244483 O0 000 O0 0 4 1 1 4 68 0000000000 ** DATA ** DEPT. 10399.000 NPHI.CNTD 16.163 NRAT. CNTD 3.172 CRAT. CNTD NCNT. CNTD 4203 . 666 FCNT. CNTD 1325. 052 CFTC. CNTD 1215. 283 CNTC. CNTD GRCH. CNTD -999. 250 TENS. CNTD 1559. 000 CCL. CNTD O. 000 DEPT. 9795.500 NPHI.CNTD 51.673 NRAT. CNTD 6.935 CRAT. CNTD NCNT. CNTD 1888.098 FCNT. CNTD 272.272 CFTC. CNTD 249.717 CNTC. CNTD GRCH. CNTD -999.250 TENS. CNTD 1437.000 CCL.CNTD 0.000 3.235 4358.968 7.516 1906.711 ** END OF DATA ** **** FILE TRAILER **** FILE NAME : EDIT .004 SERVICE : FLIC VERSION · O01CO1 DATE : 98/07/13 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : **** FILE HEADER **** FILE NAME : EDIT .005 SERVICE : FLIC VERSION : O01CO1 DATE : 98/07/13 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : LIS Tape Verification Listing Schlumberger Alaska Computing Center 14-JUL-1998 09:31 PAGE: 17 FILE HEADER FILE NUMBER: 5 AVERAGED CURVES Compensated Neutron: Arithmetic average of edited passes for all curves. DEPTH INCREMENT O . 5000 PASSES INCLUDED IN AVERAGE LDWG TOOL CODE PASS NUMBERS 1, 2, 3, 4, CNTD $ REMARKS: THE ARITHMETIC AVERAGE WAS CALCULATED AFTER CLIPPING AND DEPTH CORRECTIONS WERE APPLIED. $ LIS FORMAT DATA ** DATA FORMAT SPECIFICATION RECORD ** ** SET TYPE - 64EB * * TYPE REPR CODE VALUE 1 66 0 2 66 0 3 73 40 4 66 1 5 66 6 73 7 65 8 68 0.5 9 65 FT 11 66 25 12 68 13 66 0 14 65 FT 15 66 68 16 66 1 0 66 1 ** SET TYPE - CHAN ** NAME SERV UNIT SERVICE API API API API FILE NUMB NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUMB SAMP ELEM CODE (HEX) DEPT FT 1244483 O0 000 O0 0 5 1 1 4 68 0000000000 NPHI CNAV PU-S 1244483 O0 000 O0 0 5 1 1 4 68 0000000000 NRAT CNAV 1244483 O0 000 O0 0 5 1 1 4 68 0000000000 CRAT CNAV 1244483 O0 000 O0 0 5 1 1 4 68 0000000000 NCNT CNAV CPS 1244483 O0 000 O0 0 5 1 1 4 68 0000000000 FCNT CNAV CPS 1244483 O0 000 O0 0 5 1 1 4 68 0000000000 LIS Tape Verification Listing Schlumberger Alaska Computing Center 14-JUL-1998 09:31 PAGE: 18 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) CFTC CNAV CPS 1244483 O0 000 O0 0 5 1 1 4 68 0000000000 CNTC CNAV CPS 1244483 O0 000 O0 0 5 1 1 4 68 0000000000 GRCH CNTD GAPI 1244483 O0 000 O0 0 5 1 1 4 68 0000000000 TENS CNTD LB 1244483 O0 000 O0 0 5 1 1 4 68 0000000000 ** DATA ** DEPT. 10398.000 NPHI.CNAV -999.250 NRAT. CNAV -999.250 CRAT. CNAV NCNT. CNAV -999.250 FCNT. CNAV -999.250 CFTC. CNAV -999.250 CNTC. CNAV GRCH. CNTD -999.250 TENS.CNTD -999.250 DEPT. 9793.500 NPHI.CNAV -999.250 NRAT. CNAV -999.250 CRAT. CNAV NCNT. CNAV -999.250 FCNT. CNAV -999.250 CFTC. CNAV -999.250 CNTC. CNAV GRCH. CNTD 88'.422 TENS. CNTD 1498.000 -999.250 -999.250 -999.250 -999.250 ** END OF DATA ** * * * * FILE TRAILER * * * * FILE NAME : EDIT .005 SERVICE : FLIC VERSION : 001 CO1 DATE : 98/07/13 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : **** FILE HEADER **** FILE NAME : EDIT .006 SERVICE : FLIC VERSION · O01CO1 DATE : 98/07/13 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : FILE HEADER FILE ArUMBER 6 RAW CURVES Curves and log header data for each pass in separate files; raw background pass in last file PASS NUMBER: 1 DEPTH INCREMENT: 0.5000 LIS Tape Verification Listing Schlumberger Alaska Computing Center 14-JUL-1998 09:31 PAGE: 19 FILE SU~9~RY VENDOR TOOL CODE START DEPTH CNTD 10395.0 $ LOG HEADER DATA DATE LOGGED: SOFTWARE VERSION: TIME LOGGER ON BOTTOM: TD DRILLER (FT) : TD LOGGER (FT) : TOP LOG INTERVAL (FT) : BOTTOM LOG INTERVAL (FT) : LOGGING SPEED (FPHR) : DEPTH CONTROL USED (YES/NO): TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE GR GA~A RAY CNTD COMP. NEUTRON $ 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 STOP DEPTH .......... 9791.5 Il-MAR-98 8C0-609 1311 il-MAR-98 10402.0 10401.0 9800.0 10397.0 1800.0 NO TOOL NUMBER CGRS-A CNT-D 8.500 10567.0 SEA WATER TOOL TYPE (EPITHERMAL OR THERMAL): MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): THERMAL SANDSTONE 2.65 BLUELINE COUNT RATE NORMALIZATION IN OIL ZONE TOP NORMALIZING WINDOW (FT) : BASE NORMALIZING WINDOW (FT) : BLUELINE COUNT RATE SCALES SET BY FIELD ENGINEER FAR COUNT RATE LOW SCALE (CPS): 0 FAR COUNT RATE HIGH SCALE (CPS): 4000 NEAR COUNT RATE LOW SCALE (CPS): 0 LIS Tape Verification Listing Schlumberger Alaska Computing Center 14-JUL-1998 09:31 PAGE: 2O NEAR COUNT RATE HIGH SCALE (CPS): TOOL STANDOFF (IN): 20000 REMARKS: CORRELATED TO ATLAS BHCS DATED 08-DEC-1989. PUMPED 315 BBL SEAWATER, 10 BBL METHANOL, AND 21 BBL DIESEL. THIS FILE CONTAINS THE RAW CNTD DATA FOR PASS #1. $ LIS FORMAT DATA ** DATA FORMAT SPECIFICATION RECORD ** ** SET TYPE - 64EB ** TYPE REPR CODE VALUE 1 66 0 2 66 0 3 73 44 4 66 1 5 66 6 73 7 65 8 68 0.5 9 65 FT 11 66 23 12 '68 13 66 0 14 65 FT 15 66 68 16 66 1 0 66 1 ** SET TYPE - CHAN ** NAME SERV UNIT SERVICE API API API API FILE NUMB NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUMB SAMP ELEM CODE (HEX) DEPT FT 1244483 O0 000 O0 0 6 1 1 4 68 0000000000 NPHI PS1 PU 1244483 O0 000 O0 0 6 1 1 4 68 0000000000 RTNR PS1 1244483 O0 000 O0 0 6 1 1 4 68 0000000000 TNRA PS1 1244483 O0 000 O0 0 6 1 1 4 68 0000000000 RCNT PS1 CPS 1244483 O0 000 O0 0 6 1 1 4 68 0000000000 RCFT PS1 CPS 1244483 O0 000 O0 0 6 1 1 4 68 0000000000 CNTC PS1 CPS 1244483 O0 000 O0 0 6 1 1 4 68 0000000000 CFTC PS1 CPS 1244483 O0 000 O0 0 6 1 1 4 68 0000000000 GR PS1 GAPI 1244483 O0 000 O0 0 6 1 1 4 68 0000000000 TENS PS1 LB 1244483 O0 000 O0 0 6 1 1 4 68 0000000000 CCL PS1 V 1244483 O0 000 O0 0 6 1 1 4 68 0000000000 LIS Tape Verification Listing Schlumberger Alaska Computing Center 14-JUL-1998 09:31 PAGE: 21 ** DATA ** DEPT. 10395.000 NPHI.PS1 7.326 RTNR.PS1 2.000 TNRA.PS1 RCNT. PS1 3878.788 RCFT. PS1 1939.394 CNTC. PS1 3888.587 CFTC. PSI GR.PS1 27.121 TENS.PSi 778.000 CCL.PS1 -0.010 DEPT. 9791.500 NPHI.PS1 47.825 RTNR.PS1 7.260 TNRA.PS1 RCNT. PS1 2018.018 RCFT. PS1 277.977 CNTC. PS1 1992.205 CFTC. PSI GR.PS1 99.460 TENS.PSI 1444.000 CCL.PS1 -999.250 2.024 1778.733 7.075 254.949 ** END OF DATA ** **** FILE TRAILER **** FILE NAME : EDIT .006 SERVICE : FLIC VERSION · O01CO1 DATE · 98/07/13 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : **** FILE HEADER **** FILE NAME : EDIT .007 SERVICE : FLIC VERSION : O01CO1 DATE : 98/07/13 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 last file PASS NUMBER: 2 DEPTH INCREMENT: O. 5000 FILE SUN, VARY VENDOR TOOL CODE START DEPTH STOP DEPTH CNTD 10419.5 9788.5 $ LOG HEADER DATA DATE LOGGED: 11 -MAR - 98 LIS Tape Verification Listing Schlumberger Alaska Computing Center 14-JUL-1998 09:31 PAGE: 22 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): 8C0-609 1311 il-MAR-98 10402.0 10401.0 9800.0 10397.0 1800.0 NO TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE GR GA~k~A RAY CNTD COMP. NEUTRON $ TOOL NUMBER CGRS-A CNT-D BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLERS CASING DEPTH (FT) : LOGGERS CASING DEPTH (FT) : 8.500 10567.0 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) : SEA WATER NEUTRON TOOL TOOL TYPE (EPITHERMAL OR THERMAL) MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): THERMAL SANDSTONE 2.65 BLUELINE COUNT RATE NORMALIZATION IN OIL ZONE TOP NORMALIZING WINDOW (FT): BASE NORMALIZING WINDOW (FT) : BLUELINE COUNT RATE SCALES SET BY FIELD ENGINEER FAR COUNT RATE LOW SCALE (CPS): 0 FAR COUNT RATE HIGH SCALE (CPS): 4000 NEAR COUNT RATE LOW SCALE (CPS): 0 NEAR COUNT RATE HIGH SCALE (CPS): 20000 TOOL STANDOFF (IN): REMARKS: CORRELATED TO ATLAS BHCS DATED 08-DEC-1989. PUMPED 315 BBL SEAWATER, 10 BBL METHANOL, AND 21BBL DIESEL. THIS FILE CONTAINS THE RAW CNTD DATA FOR PASS #2. $ LIS Tape Verification Listing Schlumberger Alaska Computing Center 14-JUL-1998 09:31 PAGE: 23 LIS FORMAT DATA ** DATA FORMAT SPECIFICATION RECORD ** ** SET TYPE - 64EB * * TYPE REPR CODE VALUE 1 66 0 2 66 0 3 73 44 4 66 1 5 66 6 73 7 65 8 68 0.5 9 65 FT 11 66 23 12 68 13 66 0 14 65 FT 15 66 68 16 66 1 0 66 1 ** SET TYPE - CHAN ** NAME SERV UNIT SERVICE API API API API FILE NUMB NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUMB SAMP ELE~ CODE (HEX) DEPT FT 1244483 O0 000 O0 0 7 1 1 4 68 0000000000 NPHI PS2 PU 1244483 O0 000 O0 0 7 1 1 4 68 0000000000 RTNR PS2 1244483 O0 000 O0 0 7 1 1 4 68 0000000000 TNRA PS2 1244483 O0 000 O0 0 7 1 1 4 68 0000000000 RCNT PS2 CPS 1244483 O0 000 O0 0 7 1 1 4 68 0000000000 RCFT PS2 CPS 1244483 O0 000 O0 0 7 1 1 4 68 0000000000 CNTC PS2 CPS 1244483 O0 000 O0 0 7 1 1 4 68 0000000000 CFTC PS2 CPS 1244483 O0 000 O0 0 7 1 1 4 68 0000000000 GR PS2 GAPI 1244483 O0 000 O0 0 7 1 1 4 68 0000000000 TENS PS2 LB 1244483 O0 000 O0 0 7 1 1 4 68 0000000000 CCL PS2 V 1244483 O0 000 O0 0 7 1 1 4 68 0000000000 ** DATA DEPT. 10419.500 NPHI.PS2 7.326 RTNR.PS2 2.000 TNRA.PS2 RCNT. PS2 3878.788 RCFT. PS2 1939.394 CNTC. PS2 3888.587 CFTC.PS2 GR.PS2 81.364 TENS.PS2 1025.000 CCL.PS2 -0.019 2.024 1778.733 LIS Tape Verification Listing Schlumberger Alaska Computing Center 14-JUL-1998 09:31 PAGE: 24 DEPT. 9788.500 NPHI.PS2 RCNT. PS2 1987.578 RCFT. PS2 GR.PS2 80.045 TENS.PS2 49.961 RTNR.PS2 260.693 CNTC. PS2 1446.000 CCL.PS2 7. 624 1927. 020 -999.250 TNRA.PS2 CFTC. PS2 7.320 239.096 ** END OF DATA ** **** FILE TRAILER **** FILE NAME : EDIT .007 SERVICE : FLIC VERSION : O01CO1 DATE : 98/07/13 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : **** FILE HEADER **** FILE NAME : EDIT .008 SERVICE : FLIC VERSION : O01CO1 DATE : 98/07/13 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : FILE HEADER FILE NUMBER 8 RAW CURVES Curves and log header data for each pass in separate files; raw background pass in last file PASS NUMBER: 3 DEPTH INCREMENT: O. 5000 FILE SUF~IARY VENDOR TOOL CODE START DEPTH CNTD 10416.5 $ 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): STOP DEPTH 9792.0 11 -MAR-98 8C0 - 609 1311 11 -MAR-98 10402.0 10401.0 9800.0 10397.0 1800.0 NO LIS Tape Verification Listing Schlumberger Alaska Computing Center 14-JUL-1998 09:31 PAGE: 25 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE GR GAM~iA RAY CNTD COMP. NEUTRON $ TOOL NUMBER CGRS-A CNT-D BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLERS CASING DEPTH (FT) : LOGGERS CASING DEPTH (FT) : 8.500 10567.0 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) : SEA WATER NEUTRON TOOL TOOL TYPE (EPITHERMAL OR THERMAL) : MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): THERMAL SANDSTONE 2.65 BLUELINE COUNT RATE NORMALIZATION IN OIL ZONE TOP NORMALIZING WINDOW (FT): BASE NORMALIZING WINDOW (FT) : BLUELINE COUNT RATE SCALES SET BY FIELD ENGINEER FAR COUNT RATE LOW SCALE (CPS): 0 FAR COUNT RATE HIGH SCALE (CPS): 4000 NEAR COUNT RATE LOW SCALE (CPS): 0 NEAR COUNT RATE HIGH SCALE (CPS): 20000 TOOL STANDOFF (IN): REMARKS: CORRELATED TO ATLAS BHCS DATED 08~DEC-1989. PUMPED 315 BBL SEAWATER, 10 BBL METHANOL, AND 21 BBL DIESEL. THIS FILE CONTAINS THE RAW CNTD DATA FOR PASS #3. $ LIS FORMAT DATA LIS Tape Verification Listing Schlumberger Alaska Computing Center 14-JUL-1998 09:31 PAGE: 26 ** DATA FORMAT SPECIFICATION RECORD ** ** SET TYPE - 64EB ** TYPE REPR CODE VALUE 1 66 0 2 66 0 3 73 44 4 66 1 5 66 6 73 7 65 8 68 0.5 9 65 FT 11 66 23 12 68 13 66 0 14 65 FT 15 66 68 16 66 1 0 66 1 ** SET TYPE - CHAN ** NAME SERV UNIT SERVICE API API API API FILE NUMB NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUMB SAMP ELE~ CODE (HEX) DEPT FT 1244483 O0 000 O0 0 8 1 1 4 68 0000000000 NPHI PS3 PU 1244483 O0 000 O0 0 8 1 1 4 68 0000000000 RTNR PS3 1244483 O0 000 O0 0 8 1 1 4 68 0000000000 TNRA PS3 1244483 O0 000 O0 0 8 1 1 4 68 0000000000 RCNT PS3 CPS 1244483 O0 000 O0 0 8 1 1 4 68 0000000000 RCFT PS3 CPS 1244483 O0 000 O0 0 8 1 1 4 68 0000000000 CNTC PS3 CPS 1244483 O0 000 O0 0 8 1 1 4 68 0000000000 CFTC PS3 CPS 1244483 O0 000 O0 0 8 1 1 4 68 0000000000 GR PS3 GAPI 1244483 O0 000 O0 0 8 1 1 4 68 0000000000 TENS PS3 LB 1244483 O0 000 O0 0 8 1 1 4 68 0000000000 CCL PS3 V 1244483 O0 000 O0 0 8 1 1 4 68 0000000000 ** DATA ** DEPT. 10416.500 NPHI.PS3 7.326 RTNR.PS3 2.000 TNRA.PS3 RCNT. PS3 4000.000 RCFT. PS3 2000.000 CNTC. PS3 4010.106 CFTC. PS3 GR.PS3 167.813 TENS.PS3 923.000 CCL.PS3 -0.010 DEPT. 9792.000 NPHI.PS3 49.242 RTNR.PS3 6.520 TNRA.PS3 RCNT. PS3 2053.831 RCFT. PS3 315.026 CNTC. PS3 1960.389 CFTC. PS3 GR.PS3 125.057 TENS.PS3 1422.000 CCL.PS3 -999.250 2.024 1834.318 7.237 288. 929 LIS Tape Verification Listing Schlumberger Alaska Computing Center 14-JUL-1998 09:31 PAGE: 27 ** END OF DATA ** **** FILE TRAILER **** FILE NAME : EDIT .008 SERVICE : FLIC VERSION : O01CO1 DATE : 98/07/13 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : **** FILE HEADER **** FILE NAME : EDIT .009 SERVICE : FLIC VERSION : O01CO1 DATE : 98/07/13 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : FILE HEAIgER FILE ATUMBER 9 RAW CURVES Curves and log header data for each pass in separate files; raw background pass in last file PASS NUMBER: 4 DEPTH INCREMENT: 0.5000 FILE SUREVZARY VENDOR TOOL CODE START DEPTH STOP DEPTH 10421.0 9794.0 CNTD $ 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 il-MAR-98 8C0-609 1311 il-MAR-98 10402.0 10401.0 9800.0 10397.0 1800.0 NO TOOL NUMBER LIS Tape Verification Listing Schlumberger Alaska Computing Center 14-JUL-1998 09:31 PAGE: 28 GR GAMMA RAY CNTD COMP. NEUTRON $ BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLERS CASING DEPTH (FT) : LOGGERS CASING DEPTH (FT) : BOREHOLE CONDITIONS FLUID TYPE: FLUID DENSITY (LB/G): SURFACE TEMPERATURE (DEGF) : BOTTOM HOLE TEMPERATURE (DEGF) : FLUID SALINITY (PPM) '. FLUID LEVEL (FT) : FLUID RATE AT WELLHEAD (BPM) : WATER CUTS (PCT) : GAS~OIL RATIO: CHOKE (DEG) : CGRS-A CNT- D 8.500 10567.0 SEA WATER NEUTRON TOOL TOOL TYPE (EPITHERMAL OR THERMAL): MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): THERMAL SANDSTONE 2.65 BLUELINE COUNT RATE NORMALIZATION IN OIL ZONE TOP NORMALIZING WINDOW (FT): BASE NORMALIZING WINDOW (FT) : BLUELINE COUNT RATE SCALES SET BY FIELD ENGINEER FAR COUNT RATE LOW SCALE (CPS): 0 FAR COUNT RATE HIGH SCALE (CPS): 4000 NEAR COUNT RATE LOW SCALE (CPS): 0 NEAR COUNT RATE HIGH SCALE (CPS): 20000 TOOL STANDOFF (IN): R~W_ARKS: CORRELATED TO ATLAS BHCS DATED 08-DEC-1989. PUMPED 315 BBL SEAWATER, 10 BBL METHANOL, AND 21 BBL DIESEL. THIS FILE CONTAINS THE RAW CNTD DATA FOR PASS #4. $ LIS FORMAT DATA LIS Tape Verification Listing Schlumberger Alaska Computing Center 14-JUL-1998 09:31 PAGE: 29 ** DATA FORMAT SPECIFICATION RECORD ** ** SET TYPE - 64EB ** TYPE REPR CODE VALUE 1 66 0 2 66 0 3 73 44 4 66 1 5 66 6 73 7 65 8 68 0.5 9 65 FT 11 66 23 12 68 13 66 0 14 65 FT 15 66 68 16 66 1 0 66 1 ** SET TYPE - CHAN ** NAME SERV UNIT SERVICE API API API API FILE NOWB NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUMB SAMP ELEM CODE (HEX) DEPT FT 1244483 O0 000 O0 0 9 1 1 4 68 0000000000 NPHI PS4 PU 1244483 O0 000 O0 0 9 1 1 4 68 0000000000 RTNR PS4 1244483 O0 000 O0 0 9 1 1 4 68 0000000000 TNRA PS4 1244483 O0 000 O0 0 9 1 1 4 68 0000000000 RCNT PS4 CPS 1244483 O0 000 O0 0 9 1 1 4 68 0000000000 RCFT PS4 CPS 1244483 O0 000 O0 0 9 1 1 4 68 0000000000 CNTC PS4 CPS 1244483 O0 000 O0 0 9 1 1 4 68 0000000000 CFTC PS4 CPS 1244483 O0 000 O0 0 9 1 1 4 68 0000000000 GR PS4 GAPI 1244483 O0 000 O0 0 9 1 1 4 68 0000000000 TENS PS4 LB 1244483 O0 000 O0 0 9 1 1 4 68 0000000000 CCL PS4 V 1244483 O0 000 O0 0 9 1 1 4 68 0000000000 ** DATA ** DEPT. 10421.000 NPHI.PS4 22.192 RTNR.PS4 4.000 TNRA.PS4 RCNT. PS4 3555.556 RCFT. PS4 888.889 CNTC. PS4 3564.539 CFTC. PS4 GR.PS4 124.306 TENS.PS4 1009.000 CCL.PS4 -0.019 DEPT. 9794.000 NPHI.PS4 43.737 RTNR.PS4 6.353 TNRA.PS4 RCNT. PS4 1759.674 RCFT. PS4 276.986 CNTC. PS4 1828.777 CFTC. PS4 GR.PS4 62.656 TENS.PS4 1449.000 CCL.PS4 -999.250 4. 048 815. 253 6.607 254.040 LIS Tape Verification Listing Schlumberger Alaska Computing Center 14-JUL-1998 09:31 PAGE: 3O ** END OF DATA ** **** FILE TRAILER **** FILE NAME : EDIT .009 SERVICE : FLIC VERSION : O01CO1 DATE : 98/07/13 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : **** TAPE TRAILER **** SERVICE NAME : EDIT DATE : 98/07/13 ORIGIN : FLIC TAPE NAME : 98337 CONTINUATION # : 1 PREVIOUS TAPE : COMMENT : BP EXPLORATION, PRUDHOE BAY, F-26, API #50-029-21987-00 **** REEL TRAILER **** SERVICE NAME : EDIT DATE : 98/07/13 ORIGIN : FLIC REEL NAME : 98337 CONTINUATION # : PREVIOUS REEL : CO~IENT : BP EXPLORATION, PRUDHOE BAY, F-26, API #50-029-21987-00 ALASKA COMPUTING CENTER ~- SCMLUMBERGER ~ COMPANY NAME : ARCO ALASKA, INC. WELL N:AME : 2K-3 FIELD NAME : KUPA~UK 00ROUGH : NORTH SLOPE STATE : AL~S~.A API NUMBEP : 50-103-20100 REFERENCE NO : 73360 l OF! MED IS TAPE VERIFICATION LISTING CHLUMBERGER ALASK,~ COMPJTING CENTER 8-JUN-1989 16:6,2 **** REEL HEADER ~ SERVICE NAME : EDIT DATE : 99/06/ 8 ORIGIN : FLIC REEL NAHE : 73360 CONTINUATION ,~ : PREVIOUS REEL : COMMENT : ~RCg ALASKA, INC., KUPARUK, 2K-3, API ~50-103-201C0 · -*** TAPE H E ~D.,: R. -~-'*-~..~ ~... SERVICE NAME : EDIT D~TE : ~g/06/ 8 ORIGIN : FL!C T~PE NAME : 73360 CONTINUATION ~ : 1 PREVIOUS T~PE : COMMENT : ~RC~ ALASKA, INC., KUPARUK, 2K-~ &PI ~50-I0~-20100 -~=# FILE HEADER -~¢~ FILE NAME : EDIT .001 SERVICE : FLIC VERSION : 001A02 DATE : 89706/ 8 MAX REC .SIZE : 1096 FILE TYPE : LO LAST FILE : PAGE'. SCHLUMBERGER WELL SERVICES COMPANY NAME: ARCO ALASKA, INC. WELL: 2K-3 FIELD: KUPARUK BOROUGH: N~RTH SLOPE STATE: .AL ASKA API NUMBER: 50-103-20100 LOCATION: 25gj FSL & go' FEL SECTION: 02 TOWNSHIP: ~ANGE: 8E PERMANENT D~TUM: MSL ELEVATION: 0 IS TAPE VERIFICATION LISTING CHLUMBERGER ALASK,~ COMPUTING ,CENTER B-JUN-lO89 16:42 PAGE: LOG MEASURED FRO~ RKB 154 ABOVE PERMANENT D{TUM ELEVATIONS KB: 154 153 GL: 113 RUN NUMBER: ONE TS DRILLER: B861 TO LOGGER: 8828.5 CASING: 9 5/8" LB ] DRILLER DEPTH gF 3598 &NO LOGGER DEPTH OF 3598 BIT SIZ=: 8 112" TYPE FLUID IN HOLE: LSND POLYMER DENSITY: 10.3 VISCOSITY: 4B PH: g FLUIO LOSS: 3.8 MUD RESISTIVITY: FILTRATE RESISTIVITY: MUD CAKE RESISTIVITY: 3.74 @ 72 3.9 @ 69 3.25 @ 72 TINE CIRCULATION ENDEO: 04:00 02-JUN TIME LOGGER ON BOTTOM: 12:19 02-JUN MAXIMUM TEMP RECORDED: 148 LOGGING DISTRICT: LOGGING ENGINEER: WI'TNESS: PRUDHOE BAY FRITZKE KINNEVAN/GOLDEN/RUNJE TOGL NUMBERS: IEM 1347 SGC 2626 CNC 1238 DIC 1303 NLM 1 378 PGS 508 tIS 1457 FIELD REMARKS: 2" STANDOFFS ,AND A CAULIFLOWER BULLNOSE WERE USED ON 'THE OIT MATRIX DENSITY = 2~65 G/CC,HoL~,CORRECTIoNFLUIO DENSITY~ 1~ G/CC. NEUTRON MATRIX : SAND, = CA IP. ~AXIMUM DEVIATION = 50.~ DE~GREES @ 599?'. SP ZERO SHIFT AT 64'97'. POOR SP RESPONSE AT THE BOTTO~ OF THE HOLE. TENSION SCALE CHANGED AT 6998'. PAD ELEVATION = 118 FT. D,ATE JOB STARTEg: 08-JUN-89 JOB REFERENCE NO: 73360 LDP/ANA: J. KOHRING FILE - EDIT.O01 .IS TAOE VERIFICATION LISTZNG ;CHLUNBERGER ALASK~ COMPUTING CENTER 8-JUN-lO89 16:42 ARCO ALASKA, KUPARUK 2K-3 50-103-20100 INC o DATA SAMPLED EVERY -.5000 FEET D,~TA ZNCLUD~D - TOOL EXTENSION TOOL TYPE USED NAME IT-D .OIL DUAL INDUCTION SFL 8821' 'TO 3598' DC .FDC FORMATION DENSITY 8794' TO 7925' NT-A/D/H .CNL COMPENS,(kTED NEUTRON 8781' TO 7925' R .CSG GAMMA R,~Y 3690' TO 894' TABLE TYPE · TUN! CN FN WN APIN FL SECT TOWN RANG CDUN STAT NATI ENGI WITN SON PDAT EP~ FT LMF APO FT EKB FT EOF FT EGL FT TOD FT BLI FT TLI FT TCS TLAB CONS V~LU ,~RCO ~LASKA, INC. KUPARUK 2 K-3 50-103-20100 250' FSL & 90' FEL 02 1ON 8E NORTH SLOPE ALASK~ US~. FRITZKE KINNEVAN/GDLDEN/RUN JE 5483 !5 7 ~SL RKB 154. 154. 153. I13. 8~61. 8'821. 900o 04:00 02-JUN 12:19 02-JUN DEFI COMPANY NAME :FIELD NAME WELL NAME API SERIAL NUMBER FIELD LOCA'TION SECTIaN 'TOWNSHIP RANGE C~UNT¥ STATE OR PROVINC~ NATION ENGINEER"S NAME WI'TNESSmS NAME SERVICE ORDER NUMBER PERMANENT DATUM LOG ME~SURED FROM BOTTOM LOG INTERVAL TOP LOG INTERVAL 'TIME CIRCULATION STOPPEO 'TIME LOGGER AT !BOTTOM · IS TAPE VERIFICATION LISTING ;CHLUMBERGER ALASKA COMPUTZNG CENTER 8-JUN-19B9 18:42 PAGE: TABLE TYPE : CURV DEPT ILO ILM SFLU SP GR TENS DPHI RHOB DRHO FFDC NFDC CALI GR TENS NPHI TNPH TNRA NPOR DEFI DEPTH CHANNEL NAME IL-DEEP ~ESISTIVITY IL-MEDIUM RESISTIVITY SFL UN.~,V ER AGED SPONTANEOUS POTENTIAL GAMMa RAY TENSION DENSITY POROSITY BULK DENSITY DELTA RHO FAR FDC COUNT RATE NEAR FDC COUNT R~,T"E: CALI PE,q GAMMA RAY TENSION NEUTRON POROSITY THERMAL NEUTRON POROSITY CALIBRATED THERMAL NEUTRON RATIO NEUTRON POROSITY OUTPUT FROM AN ~PPLICATION PROGRAM RCNT RCFT CNTC C FTC GR TENS GR TENS RAW CORRECTED NEAR THERMAL COUNTS RAW CORRECTED FAR THERMAL COUNTS CORRECTED NEAR THERMAL COUNTS CORRECTED FlOR THERMAL COUNTS GAMMA RAY CALIPER TENSION GAMMA RAY TENSION DATA FORMAT SPECIFICATION RECORD ~ *~X: SET TYPE - 64EB -'~ TYPE REPR CODE V,~LUE ! 66 O 2 66 0 ] 73 .112 4 66 .1 5 66 6 73 7 65 8 68 0.5 11 66 9 12 68 1] 66 0 ,IS TAPE VERIFICATION LISTING ;CHLUMBERGER ALASKA COMPUTING CENTER 8-JUN-1989 16:42 TY,~E REPR 14 65 15 66 16 66 0 66 CODE V AL UE 68 1 ~X-' SET TYPE - CH~N ~ NAME SERV UNIT SERVICE API API API &PI ,=ILE NUMB NUMB ID OR,qER ~ LOG TYP=_ CLASS MOD NUMB SAMP ELEM OEPT ILO OIL ILM OIL SFLU OIL SP OIL GR OIL TENS OIL DPHI FDC RHOB FDC ORHO FOC FFDC ,=DC NFDC FDC CALI FDC GR FOC TENS FBC NPHI CNL TNPH CNL TNRA CNL NPi]R CNL RCNT CNL RCFT CNL CNTC CNL CFTC CNL GR CNL CALI CNL TENS CNL GR CSG TENS CSG FT 548357 O0 000 CHMM 548357 07 120 OHMM 548357 07 120 CHMM 548357 07 220 MV 548357 07 010 G~PI 548357 07 310 LB 548357 07 635 PU 548357 0'7 635 G/C3 548357 07 350 G/C3 548357 07 35,6 CPS 548357 07 354 CPS 548357 07 35,4 IN 548357 07 280 GAPI 548357 07 3!0 Lr5 548357 07 635 PU 548357 07 890 PU 54:8357 07 890 548357 07 420 PU 548357 07 890 CPS 548357 07 420 CPS 1548357 07 '420 CPS 5483157 07 420 CPS 54:8357 0'7 420 G~PZ 548357 0'7 310 IN 548357 07 280 ~LB 5483!57 07 635 GAPI 548357 07 310 LB 548357 07 635 SIZE REPR CODE O0 0 1 1 1 4 6B 46 0 1 1 1 4 68 44 0 1 1 1 4 68 O1 0 1 1 1 4 68 O1 0 1 1 1 4 68 O1 0 1 1 1 4 68 21 0 1 1 I 4 68 21 0 1 1 1 4 68 02 0 1 1 1 4 68 O1 0 1 1 1 4 68 02 0 1 1 1 4 68 O1 0 1 1 1 4 68 O1 0 1 1 1 4 68 O1 0 1 1 1 ,4 68 21 0 i 1 1 4 68 O0 0 1 1 1 4 68 00 0 1 1 1 4 68 O1 0 1 1 I 4 68 O0 0 1 1 I 4 68 O1 0 1 1 I 4 68 O1 0 1 1 1 4 68 01 0 1 1 I 4 68 O1 0 1 1 1 4 68 01 0 I I I 4 68 O1 0 1 1 1 4 68 21 0 1 1 1 4 68 01 0 1 1 1 4 68 21 0 1 1 1 4 68 PROCESS CHEX) 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 DO00000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000,000 O0000000OO 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 DEPT. 8830.500 ILO.OIL 2.772 ILM.DIL SP.DIL -20.500 GR.DIL 97.938 TENS.OIL RHOB.FDC 1.423 DRHO.FDC -0.038 FFDC.FDC CALI.FDC 8.500 GR.FDC 97.938 TENS.FDC TNPH.CNL 44.228 TNRA.CNL 3.654 NPOR.CNL RCFT.CNL 462.759 CNTC.CNL !858.845 CFTC.CNL CALI.CNL 8.500 TENS.CNL 4928.000 GR.CSG 2.878 4928.000 5224.000 492 8. 000 44.228 517.666 -999.Z50 SFLUoDIL DPHI.FDC NFDC.FDC NPHI.CNL RCNT.CNL GR.CNL TENS.CSG 2.845 74.353 1003.500 1825.931 97.938 -999.250 IS TAPE YERIFIC~TTON LISTING CHLUMBERGER ~LASK~ Cg-~PUTING CENTER DEPT. 8800.000 ILD.DIL SP.DIL -22.750 GR.DIL RHOB.FDC 1.405 DRHO.FDC CALI.,mDC 4.]01 GR.FDC TNPH. CNL 44.228 TN RA. CNL RCFT.CNL 462.?59 CNTC.CNL CALI.CNL 4.301 TENS.CNL DEPT. 8700.000 ILO.OIL SP.DIL -21.266 GR.DIL RHOB. FDC 2.419 DRHO.FDC CALI.FDC 9.180 GR.FDC TNPH.CNL 37.972 TNRA.CNL RCFT.CNL 4~6.071 CNTC.CNL CALI.CNL 9.180 TENS.CNL DEPT. 8600. 000 ILO. OIL SP.OIL -32.313 GR.DIL RHOB.FDC 2.445 DRHO.FDC CALI.FDC 8.570 GR.FDC TNPH.CNL 30.4?4 TNRA.CNL RCFT.CNL 786. 665 CNTC.CNL CALI.CNL 8.570 TENS.CNL DEPT. 8500. 000 ILO.OIL SP.DIL -32.281 GR.DIL RHDB. FDC Z. 404 DRHD. FDC CALI.FOC 8.742 GR.FDC TNPH.CNL 30.0,44 TNRAoCNL RCFT.CNL 755.676 CNTC.CNL CALI.CNL 8.742 TENS.CNL DEPT. 8400.000 ILO.OIL SP.DIL -24.563 GR.DII RHOB.FDC 2.313 ORHO.FDC CALI.FDC 8.805 GR.FDC TNPH.CNL 42.985 TNRA.CNL RCFT.CNL 429.090 CNTC.CNL CALI.CNL B.8D5 TENS.CNL DEPT. 8300.000 ILO.OIL SP.DIL -34.531 GR.DIL RHOB.FDC 2.685 DRHO.FDC CALI.FDC 8.914 GR.FDC TNPH.CNL 33.278 TNRA.CNL RCFT.CNL 780.266 CNTC.CNL CALI.CNL 8.914 TENS.CNL DEPT. 8200.000 ILO.OIL SP.DIL -39.781 GR.DIL RHDB. FDC 2.345 DRHD.FDC CALI.FDC 8.797 GR.FOC TNPH.CNL 47.279 TNRA.CNL RCFT.CNL 412.823 CNTC.CNL 8-JUN-1989 16:42 2.$10 ILM.DIL 97.938 TENS.DIL -0.056 FFDC.FgC 97.938 TENS.FDC 3.655 NPOR.CNL 1)58.~45 CFTC.CNL 5972.000 GR.CSG 3.756 ILM.DIL 89.500 TENS.DIL 0.058 FFDC.FDC 89.500 TENS.FDC 3.476 NPOR.CNL 1791.591 CFTC.CNL 5980.000 GR-CSG 6.755 ILM.DIL 74.813 TENS.DIL 0.025 FFDC.FDC 74.813 TENS.FDC 2.770 NPOR.CNL 2369.163 CFTC. CNL 5948.000 GR.CSG 14.655 ILM.DIL 66.563 TENS.DIL 0.063 FFOC.FDC 66.563 TENS.FDC 12.839 NPOR.CNL 2283.613 CF'TC.CNL 5908.000 GR.CSG 2.724 ILM.DIL 97.188 TENS.OIL 0.049 FFOCoFDC 97.188 TENS.FgC 3.499 NPOR.CNL 1684.127 CFTC.CNL 6064°000 GR.CSG 7.189 ILM.DIL 105.375 TENS.OIL 0.173 FFOC.FDC 105.375 TENS.FDC 2.71I NPDR.CNL 2491.759 CFTC.:CNL 5584.000 GR.CSG 3.408 ILM. OIL 137.750 TENS.OIL 0.020 FFDC.FDC 137.750 TENS.FDC 3.908 NPOR.CNL 1785.210 CFTC.CNL 2.677 5972.000 5228.000 5972.000 44.228 517.668 -999.250 3.813 5980.000 570.000 5980.000 37.104 .554..505 -999.250 7.227 5948.000 494.000 5948.000 30.631 869. 914 -999.250 14.249 5908.000 598.500 5908.000 29.538 844.657 -999.250 2.910 6064.000 725. 000 6064.000 40.566 477.464 -999.250 6.92,3 5584.000 393.750 5584.000 33.10'7 853.201 -999.250 3.420 5528.000 623.5:00 5628.000 47.233 470.929 SmLU.DIL DPHI.FDC NFOC.FDC NPHI.CNL RCNT.CNL GR.CNL TE~S.CSG SFLU.DIL DPHI.FDC NFDC.FDC NPHI.CNL RCNT.CNL GR.CNL TENS.CSG SFLU.DIL DPHI.FDC NFDC.FDC NPHI.CNL RCNT.CNL GR.CNL TENS.CSG SFLU.DIL DPHI.FDC NFDC.FDC NPHI.CNL RCNT.CNL GR.CNL TENS.CSG SFLU.gIL DPHI.FDC NFOC.FOC NPHI.CNL RCNT.CNL GR.CNL TENS.CSG SFLU.DIL DPHI.FDC NFDC.FDC NPHI.CNL RCNT.CNL GR.CNL TENS.CSG SFLU.DIL DPHI.FDC NFDC.FDC NPHI.CNL RCNT.CNL GR.CNL PAGE: 2.854 75.444 953.000 50.941 1825.931 97.938 -999.250 3.742 13.985 651.500 41.749 1794.953 89.500 -999.250 8.983 12.419 596.500 30.369 2317.676 74.813 -999.250 :14.0'94 14.882 665.000 31.193 2273.589 66.563 -999.250 2.634 2'0.430 691.000 42.739 1740.872 97.188 -999.250 38.124 -2.133 661.000 29.067 2458.027 105-375 -999.250 3.456 18.506 633.000 50.228 1755.162 137.750 IS TAPE VERIFICATION LISTING CHLUMBERGER ALASKA COMPUTING CENTER CALI.CNL 8.797 TENS.CNL DEPT. 8100.000 ILD.DIL SP.DIL -43.344 GR.DIL RHOB.FDC 2.448 DRHD.FDC CALI.FDC 8.742 GR.FDC TNPH.CNL 42.262 TNRA.CNL RCFT.CNL 449.002 CNTC.CNL CALI.CNL 8.742 TENS.CNL DEPT. 8000.000 ILO.OIL SP.DIL -38.344 GR.DIL RHOB.FDC 2.356 DRHO.FDC CALI.FDC 8.828 GR.FDC TNPH.CNL 50.426 TNRA.CNL RCFT.CNL 411.357 CNTC.CNL CALI.CNL 8.828 TENS.CNL DEPT. 7900.000 ILO.OIL SP.DIL -53.531 GR.DIL RHOB.FDC -999.250 ORHG.FDC CALI.FDC -999.250 GR.FDC TNPH.CNL -999.250 TNRA.CNL RCFT.CNL -999.250 CNTC.CNL CALI.CNL -999.250 TENS.CNL DEPT. 7800.0 O0 ILO. D IL SP.DIL -41.750 GR. OIL RHO6.FDC -999.250 ORHO.FgC CALl. FOC -9'99. Z 50 GR. FDC TNPH.CNL -999.250 TNRA.CNL RCFT.CNL -999.250 CNTC.CNL CALI.CNL -999.250 'TENS.CNL DEFT. 7700.000 ILO.OIL SP.DIL -61.813 GR.DIL RHOE.FDC -999.250 DRHD.FDC CALI.FDC -999.250 GR.FOC TNPH.CNL -999.250 TNRA.CNL RCF'T.CNL -999.250 CNTC.CNL CALI.CNL -999.250 TENS.CNL OEP'T. '?600.000 ILD.DIL SP.DIL -57.~031 GR.DIL RHDB.FDC -999.250 DRHD.FDC CALI.FDC -999.250 GR.FDC TNPH.CNL -999.250 TNR~.CNL RCFT.CNL -999.250 CNTC.CNL CALI.CNL -999.250 TENS.CNL DEPT. 7500.000 ILD.DIL SP.DIL -49.291 GR.DIL RHOS.FDC -999.250 ORHO.FOC C~LI.FDC -999.250 GR.FDC TNPH.CNL -999.250 TNR~.CNL 8-JUN-1989 16:42 5628.000 GR.CSG 2.815 ILM.DIL 244.750 TENS.DIL 0.038 FFDC.FDC 244.750 TENS.FDC 3.554 NPOR.CNL 1876.222 CFTC.CNL 5664.000 GR.CSG 3.653 ILM.DIL 257.750 TENS.DIL 0.039 FFDC.FDC 257.750 TENS.FDC 3.990 NPOR.CNL 1689.113 CFTC.CNL 5372.000 GR.CSG 4.092 ILM.DIL 156.3T5 TENS.DIL -999.250 FFDC.FDC -999.250 TENS.FDC -999.250 NPDR.CNL -999.250 CFTC.CNL -999.250 GR.CSG 3.~03 ILM.DIL 105.500 TENS.DIL -999.250 FFOC.FDC -999.250 TENS.FDC -999.250 NPOR.CNL -999.250 CFTC.CNL -999.250 GR.CSG 4.659 ILM.DIL 100.625 TENS.DIL -999.250 FFDC.FDC -999.250 TENS.FDC -999.250 NPOR.CNL -999.250 CFTC.CNL -999.259 ~R.CSG 5.445 ILM.DIL 118.813 TENS.DIL -999.250 FFDC.FDC -999.253 TENS.FDC -999.250 NPOR.CNL -999.250 CFTCoCNL -999.250 GR.CSG 3.505 ILM.DIL 131.625 TENS.OIL -999.Z50 FFDC.FOC -999.250 TENS.FOC -999.250 NPOR.CNL -999..250 TENS.CSG 2.854 SFLU.DIL 5664.000 gPHI.FDC 505.500 NFDC.FDC 5664.000 NPHI.CNL 43.160 RCNT.CNL 539.210 GR.CNL -999.250 TENS.CSG 3.700 SFLU.DIL 5372.000 DPHI.FDC 635.500 NFDC.FDC 5372.000 NPHI.CNL 51.799 RCNT.CNL 424.084 GR.CNL -999.250 TENS.CSG 4.151 SFLU.DIL 5328.000 DPHI.FDC -999.250 NFDC.FDC -999.250 NPHI.CNL -999.250 RCNT.CNL -999.250 GR.CNL -999.250 TENS.CSG 3.771 SFLU.DIL 5840.000 DPh!.FD~C -999.250 NFCC.FDC -999.250 NPHI.CNL -999.250 RCNT.'CNL -999.250 GR.CNL -999.250 TENS.CSG 4.64.2 , SFLU.DIL 5404.000 DPHI.FDC -999.250 NFDC.FDC '-999.250 NPHI.CNL -999.250 RCNT.CNL -999.250 GR.CNL -999.250 TENS.CSG 5.501 SFLU.QIL 5524.000 DPHI.FDC -999.250 NFDC.FDC -999.250 NPHI.CNL -999.250 RCNT.CNL -999.250 GR.CNL -999.250 TENS.CSG 3.413 SFLU.DIL 5368.000 DPHI.FDC -999.250 NFDC.FDC -'999.250 NPHI.CNL -999.250 RCNT.CNL PAGE: -999.250 3.130 1Z.2ZZ 612.000 43.837 1808.994 244.750 -999.250 4.728 17.810 655.500 51.694 1618.378 257.750 -999.250 4.524 -999.250 -9 99.250 -999.250 -999. 250 -999.250 -9!)9.250 4.480 -999.2 :i!. 0 -999.250 -999.250 -999.250 -999.2:50 -999.250 4.552 -999.250 -999.250 -999. 2150 -999.250 '-999.250 -999.250 7.188 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 2.8'74 -999.250 -999.250 -999.250 -999.250 .IS 'TAPE VERIFICATION LISTING ;CHLUMBERGER ~L~SK~ COMPUTING CENTER RCFT.CNL -999,750 CNTC.CNL CALI,CNL -999.250 TENS.CNL DEPT. 7400.000 ILD.DIL SP.DIL -57.531 GR.DIL RHOB.FDC -999.250 DRHO.FOC CALI. FDC -999.250 GR. FDC TNPH. CNL -9 99.250 TN R.~.CNL RCFT.CNL -999.250 CNTC.CNL CALI.CNL -999.250 TENS.CNL D_:PT. 7300.000 ILO.OIL SP.OIL -52.313 GR.DIL RHOB. FDC -9 99.2 50 DR HO. FDC CALI.FDC -999.2 50 GR. FOC TNPH.CNL -999.250 TNRA.CNL RCFT.CNL -999.250 CNTC.CNL CALI.CNL -999.250 TENS.CNL DEPT, T2OO,OOO ILO,OIL SP,DIL -61,750 GR,DIL RHOB,FDC -999,250 DRHO,FDC CALI,FDC -999,250 GR,FDC TNPH.CNL -999,250 TNRA,CNL RCFT.CNL -999.250 CNTC.CNL CALI.CNL -999.250 TENS,CNL DEPT. TlO0.O00 ILD.DIL SP.DIL -63.500 GR.DIL RHOB.FDC -999.250 DRHO.FDC CALI.FDC '-999.250 GR.FOC TNPH,CNL -999.250 TNRA,CNL RCFT.CNL -999.250 CNTC.CNL CALI,CNL -999.250 TENS,CNL B-JUN-lgB9 16:42 -9q9.250 CFTC.CNL -999.250 GR.CSG ¢.268 ILM.DIL 128.625 TENS.OIL -999.250 FFDC.FDC -999. 250 TENS. FDC -999.250 NPOR.CNL -999.250 CFTC.CNL -999.250 GR.CSG 2.480 ILM.DIL 115.688 TENS.OIL -999.250 FFDC.FDC -999.250 TENS.FDC -999.250 NPOR,CNL -999.250 CFTC.CNL -999.250 GR.CSG 2.986 ILM.DZL 115.81) TENS.OIL -999.250 FFDC.FgC -999.250 TENS.FDC -999,250 NPOR,CNL -999,250 CFTC,CNL -999.250 GR.CSG 3.884 ILM.DIL 111.,438 TENS.OIL -999.250 FFDC.FDC -'999.250 TENS.FDC -999.250 NPOR.CNL -999.250 CFTC.CNL -999.250 GR,CSG DEPT. 7000.000 ILO.OIL 3. SP.DIL -62.031 GR.DIL 104. RHDB.FDC -999.250 DRHO.FDC -999. CAL!,FDC -999,250 GR,FDC -999, TNPHoiCNL -999,250 TNRA,CNL -999. RCFT,CNL -999,250 CNTC,CNL -999, CALI.CNL -999.250 TENS.CNL -999, DEPT, 6900,000 ILO.OIL SP,DIL -60.281 GR,DIL RHCB,FDC -999,250 DRHO.FDC CALI,FDC -999,250 GR.FDC TNPH.CNL -999.250 TNRA.CNL RCFT.CNL '-999,250 CNTC,CNL CALI.CNL -999.250 TENS.CNL 165 ILM.DIL 563 TENS.OIL 250 FFDC.FDC 250 TENS.FDC 250 NPOR.CNL 250 CFTC.CNL 250 GR,CSG 13.375 ILM.DIL 95.313 TENS.DIL -999.250 FFDC.FDC -999.250 TENS.FDC -999.250 NPOR.CNL -999.250 CFTC.CNL -999.250 GR.CSG DEPT, 6800.000 ILO.OIL 3, SP,OIL -73.250 GRoDIL 84. RHD~,~DC -999,250 gRHD,FDC -999. C~LI.FDC -999.250 GR.FOC .-999. 495 ILM.DIL 688 TENS.OIL 250 FFDC.FDC 1250 TENS.FOC -999.250 -999.250 4.291 5512.000 -999.250 -999. 250 -999.250 -999.25D -999.250 2.499 5240.000 -999.250 -999.250 -999.250 -999.250 -999.250 2.986 5064.00D -999.250 -999.250 -999.250 -99 9.250 -999.250 3. 922 5100.000 -999. 250 -999.250 -999.250 - 99'9. 250 -999.250 3,142 5188,000 --999,250 -999.250 -999,250 -999.250 -999.250 3.338 4888.000 -999.250 -999.250 -999.250 -999.250 -999.250 3.51! 5052.000 -99'9.250 -999.250 GR.CNL TENS.CSG SmLU.DIL DPHI. FDC NFOC.FDC NPHI.CNL RCNT.CNL GR,CNL TENS.CSG SFLU.OIL DPHI.FDC NmOC.FDC NPHI.CNL RCNT.CNL GR.CNL TENS.CSG SFLU.DIL DPHi. FDC NFSC.FDC NPHI.CNL RCNT.CNL G~,CNL TENS.CSG SFLU.DIL DPHI,FDC NFDC,FDC NPHI,CNL RCNT,CNL GR,CNL TENS,CSG SFLU.DIL DPHI.FOC NFDC.FDC NPHI.CNL RCNT.CNL GR.CNL TENS.CSG SFLU.DIL DPHI.FDC NFDC.FDC NPHI.CNL RCNT.CNL GR.CNL TENS.CSG SFLU.DIL DPHI.FDC NFDC.FDC NPHI..CNL P~GE ' -999.250 -999.250 4.315 -999,250 -999.250 -999.250 -999.250 -999.250 -999.250 2.179 -999.250 -999.250 -999.250 -999.250 -999.250 -9~9.250 3.058 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 3.639 -999.250 -999.250 '-999.250 -999.250 -999.250 -999.Z~0 2,517 -999,250 -999,250 -999.250 -999. 250 -999.250 -999.25 0 3.482 -999.250 -999,250 -999,250 -999,250 -999,250 -999,250 3,840 -999,250 -999,250 -999,250 ,IS TAPE VERIFICATION LISTIN~ iCHLUM~ERGER ~L~SK.~ COMPUTING CENTER TNPH.CNL -999.250 TERA.CNL RCFT.CNL -999.250 CNTC.CNL C~LI.CNL -999.250 TENS.CNL DEPT. 67D0.000 ILO.OIL SP.DIL -59.063 GR.D!L RHOB.FDC -999.250 gRHO.FDC CALI.FDC -999.250 GR.FDC TNPH.CNL -999.250 TNR~.CNL RCFT.CNL -999.250 CNTC.CNL CALI.CNL -999.250 TENS.CNL DEPT. 6600.000 ILD.DIL SP.OIL -79.813 GR.DIL RHDB.FOC -999.250 DRHO.FDC CALI.FDC -999.250 GR.FDC TNPH.CNL -999.250 TNRA.CNL RCFT.CNL -999.250 CNTC.CNL CALI.CNL -999.250 TENS.CNL DEPT. 6500.000 ILO.OIL SP.DIL -68.500 GR.DIL RHOB.FDC -999.250 QRHO.FDC CALI.FDC -999.250 GR.FDC TNPH.CNL -999.250 TNRA.CNL RCFT.CNL -999.250 CNTC.CNL C~LI.CNL -999.250 TENS.CNL DEPOT. 6400.0 O0 ILD.DIL SP.OIL -2.268 GR.DIL RHOB.FOC -999.250 ORHO.FOC CALI. FDC -999. Z 50 GR. FDC TNPH.CNL -999.250 TNRA.CNL RCFT.CNL -999.250 CNTC.CNL CALI.CNL -999.250 TENS.CNL DEPT. 6300.000 ILO.OIL SP.DIL -27.000 GR.DIL RHD~.FDC -999.250 DRHO.FDC CALl. FDC -999. Z 50 GR. FDC TNPH.CNL -999.250 TNRA.CNL RCFT.CNL -999.250 CNTC.CNL C,~LI.CNL -999.250 TENS.CNL DEPT. $200-000 ILO.OIL SP.DIL -10.242 GR.DIL RHDB.FDC -999.250 ORHO.FDC CALI.FDC -999.250 GR.FDC TNPH.CNL -999.250 TNRA.CNL RCFT.CNL -999.250 CNTC.CNL CALI.CNL -999.250 TENS.CNL 8-JUN-1989 16:.42 -999.250 NPDR.CNL -999.250 CFTC.CNL -999.250 GR.CSG 4.584 ILM.DIL 94.813 TENS.OIL -999.250 FFgC.FDC -999.250 TENS.FDC -999. 250 NPDR.CNL -999.250 CFTC.CNL -999.250 GR.CSG 3.739 ILM.DIL 116.063 TENS.OIL -999.250 FFDC.FDC -999.250 TENS.FDC -999.250 NPDR.CNL -999.250 CFTC.CNL -999.250 GR.CSG 3.914 ILM.DIL 126.250 TENS.DIL -999.250 FFDC.FDC -999.250 TENS.FDC -999.250 NPDR.CNL -999.250 CFTC.CNL -999.250 OR.CSG 2.956 ILM.DIL 142.000 TENS.DIL -999.250 FFDC.FOC -999.250 TENS.FDC -999.25D NPOR.CNL -999.250 CFTC.CNL -999.250 GR.CSG 4.835 ILM.DIL 132.875 TENS.OIL -999.25D FFDC.FDC -999.250 'TENS.FDC -999.250 NPDR.CNL -99'9.250 CFITC.CNL -999.250 GR.CSG 1.679 ILM.DIL 116.438 'TENS.OIL -999.250 FFDC.FDC -999.250 TENS.FDC -999.250 NPOR.CNL -999.250 CFTC.CNL -999.250 GR..CSG -999.250 -999.250 -999.250 4.363 4804.000 -999.250 -999.25D -999.250 -999.250 -999.250 3.692 4588.000 --999.250 -999.250 -999.250 -999. 250 -999.250 3.825 4544.000 -999. 250 -999.250 -999.25D -999.250 -999.250 2. 895: 4544.000 -999.250 -999. 250 -999.250 -999.250 -999.250 4. 726 4408.000 -999.250 -999.250 -999. 250 -999.250 -999.250 1.661 4324.000 -999.250 -999.250 -99 9.250 -9'99.2 50 -999.250 RCNT.CNL GR .CNL TENS.CSG SFLU.DIL DPHI.FDC NFDC.FDC NPHI.CNL RCNT.CNL GR.CNL TENS.CSG S~tU. DIL DPHI.FDC NFDC.FDC NPHI.CNL RCNT.CNL GR.CNL TENS.CSG SFLU.DIL DPHI.FDC NFDC.FDC NPHI.CNL RCET.CNL GR.CNL TENS.CSG SFLU.DIL DPHI.FDC NFDC.FDC NPHI .CNL RCNT.CNL GR.CNL TENS .CSG SFLU.OZL DPHI.FDC NFDC.FDC NPHI .CNL RCNT.CNL GiR.CNL TENS.CSG SFLU.DIL DPHI.FDC NFDC.FDC NPHI.CNL RCNT.CNL GR.CNL TENS.CSG PAGE: -999.250 -999.250 -999.250 4.714 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 3.494 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 3.652 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 2.789 -999.250 -999.250 -999.250 -999.250 -999.2.50 -999.250 4.260 -999.250 -999.250 -999.250 -999.250 -'999.250 -999.250 1.435 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 ,IS TAPE VERIFIC~T'ZON LISTING CHLUM,~E~GER ~LASK~ COMPUTT. NG CENT'.-=R DEPT. 6100.000 ILD.CIL SP.DIL 0.751 OR.OIL RHOB.,:DC -999.250 DRHC.FDC CALI. FDC -9 99.250 GR. FDC TNPH.CNL -999.250 TNRA.CNL RCET.CNL -999.250 CNTC.CNL CALI.CNL -999.250 TENS.CNL DEPT. 6000.000 ILD.DIL SP.DIL -4.250 GR.DIL RHOB. FDC -999.2 50 DR HO. FDC CALI. FDC -999.2 50 GR. FDC TNPH.CNL -999.250 TNRA.CNL RCFT.CNL -999.250 CNTC.CNL CALI.CNL -999.250 TENS.CNL DEPT. 5900.000 ILD.:IL SP.DIL -7.730 GR.DIL RHOB.FDC -999.250 ORHD.FDC CALI. FDC -999.2 50 GR.FDC TNPH.CNL -999.250 TNRA.CNL RCFT.CNL -999.250 CNTC.CNL CALI.CNL -999.250 TENS.CNL DEPT. 5800.000 ILD.DIL SP.DIL -0. 245 GR. OIL RHO~).FDC -999.250 ORHO.FDC CALI. FDC -999.250 GR. FOC TNPH.CNL -999.250 TNR~.CNL RCFT.CNL -999.250 CNTC.CNL CALI.CNL -999.250 TENS.CNL B-JUN-1989 16:42 2.276 ILM.DIL 117.813 TENS.~IL -999.250 FFDC.FDC -999.250 TENS.FDC -999.250 NPOR.CNL -999.250 CFTC.CNL -999.250 §R.CSG 2.958 !LM.DIL 123.500 TENS.OIL -999.250 FFDC.FDC -999.250 TENS.FDC -999.250 NPOR.CNL -999. 250 CFTC.CNL -999.250 GR.CSG 3.469 ILM.DIL 85.000 TENS.OIL -999.250 FFDC.FDC -999.250 TENS.FDC -999.250 NPOR.CNL -999.,250 CFTC.CNL -999.250 GR.CSG 3.300 ILM.DIL 101.000 TENS.DIL -999.250 FFDC. FDC -999.250 TENS.FDC -"~99. 250 NPgR.CNL '-999.250 CFTC.CNL -999.250 GR.CSG DEPT. 5700.000 ILO.OIL 3. SP.DIL -13.000 GR.DIL 79. RHOB. ~FD~C -999.250 DRHO.FDC -999. CALI. FDC -999. Z 50 GR. FDC - 999. TNPH.CNL -999.250 TNRA.CNL -999. RCFT.CNL -999.250 CNTC.CNL -999. CALI.CNL -999.250 TENS.CNL -999. DEPT. 5600. 000 ILO.OIL 3. S~.OlL -17.454 GR.DIL 109. RHDS.FDC -999.250 DRHD.FDC -999. CALI. FOC -999. 250 GR. FDC - 999. TNPH.CNL -999.250 TNR~.CNL -999. RCFT.CNL -999.250 CNTC.CNL -999. CALI .CNL -999. 250 TENS. CNL .-999. DEPT. 5500. 000 ILO.OIL .3. SP. DIL -15.4 61 G~.DIL 1125. RHt3B.FDC -999.250 DRHD.FOC -999. C,&LI . FDC -999' 250 GR . FDC -999. TNPH.CNL -999.250 TNRA.CNL -999. RCFT.CNL -999.2 50 CNTC. CNL - 999. CALI.CNL -9'99.250 'TENS.CNL -999. 693 ILM.D!L 125 TENS.DIL 250 FFSC. FDC 250 TENS. FOC 250 NPDR.CNL 250 CFTC.CNL 250 GR.CSG 944 I LM. D IL 1313 TENS.DIL 250 FFOC.FDC 250 TENS. FDC 250 NPOR.CNL 250 CFTC.CNL 250 GR.CSG 055 ILM.DIL 625 TENS.OIL 250 FFDC.FDC 250 TENS. FDC 250 NPOR.CNL 250 CFTC.CNL 250 GR.CSG 2.248 4312.000 -999.250 -999. 250 -999.250 -999.250 -999.250 2.944 4260.000 -999.250 -999.250 -999.250 -999.250 -999.250 3.296 4220.000 -999.250 -999.250 -999.250 -99 9.250 -999.250 3.294 4228.000 -999.250 -999.250 -999.250 - !)9 9. 250 -999.250 3. 530 4160. 000 -999.250 -999.250 -999.2 50 -999.250 -999.250 3.904 4108.000 -999.250 -999.250 -999.25!0 -999.250 -99'9.250 3.053 4024.000 -999.2.50 -999.250 -999. 250 -999.250 -999.250 SFLU.DIL DPHI.FDC N~=DC.FDC NPHI.CNL RCNT.CNL GR.CNL TENS .CSG SFLU.DIL DPHI.FDC NFDC.FDC NPHI.CNL RCNT.CNL GR.CNL TENS.CSG SFLU.~IL DPHI.FDC NFDC.FDC NPHI.CNL RCNT.CNL GR.CNL TE~S.CSG SFLU.DIL DPHI.FDC NFDC.FDC NPHI.CNL RCNT.CNL GR.CNL TENS.CSG SFLU.DIL DPHI.FDC NFDC.FDC NPHI.CNL RCNT.CNL GR.CNL TENS.CSG SFLU.gIL DPHI. FDC NFDC.FDC NPHI.CNL RCN'T. CNL GR.CNL TENS.CSG SFLU.DIL D PH ii. F DC N FDC. FDC NPHI.CNL RCNT.CNL GR. CNL TENS.CSG PAGE: 2.150 -999.250 -999.250 -999.250 -999 -999.250 -999.250 2.711 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 3.484 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 3.089 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 3.3'74 -999.250 -999.250 -999.250 -999. 250 -999.250 -999.250 3.840 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 2.561 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 10 · IS TAPE VERIFICATION LISTING ;CHLU~BERGER ALASKA COMPUTIN,~ CENTER DEPT, 5400.000 ILD.DIL SP,DIL -10.500 GR.DIL RHOB,FDC -999,250 ~RHO,FDC CALI.FDC -999.250 GR,FDC TNPH.CNL -999,250 TNRA.CNL RCFT.CNL -999.250 CNTC,CNL C~LI.CNL -999.250 TENS.CNL DEPT. 5300.000 !LD.DZL SP.DIL -19.984 GR.DIL RHCB.FDC -999.250 DRHO.FOC C~LI. :DC -9 g9.250 GR. FDC TNPH.CNL -999.250 TNRA.CNL RCFT.CNL -999.2 50 CNTC.CNL C.ALI.CNL -999.250 TENS.CNL . 1!1. -999. -)99. -999. -999. -999. . 107, -999. -999. -999. -999. -999. DEPT, 5200,000 ILO.OIL 3. SP,DIL -23,734 GR,DIL 118. RHOB,FDC -999.250 gRHO.FDC -999. CALI,FDC -999.250 GR,FDC -999, TNPHoCNL -999.250 TNRA.CNL -999, RCFT.CNL -999.250 CNTC.CNL .-999. CALI.CNL -999.250 TENS.CNL -999. DEPT, 5100,000 ILO. OIL SP,DIL -25.484 GR.DIL RHOB,FDC -999.250 ORHO,FDC C~LI. FDC -999. Z 50 GR. FDC TNPHoCNL -999.250 TNRA.CNL RCFT,CNL -999. 250 CNTC.CNL CALI,CNL -999,250 TENS,£NL DEPT, 5000,000 ILO,OIL SP,DIL -26,500 GR,DIL RHO~.~DC -999.250 DRHO.FDC CALI,FDC -999,250 GR.FDC TNPH,CNL -999,2~0 TNRA,CNL RCFT,CNL -999,250 CNTC.CNL CALI,CNL -999.250 TENS,CNL 8-JUN-1989 16:42 DEPT, 4900,000 ILD,DIL SP, OIL -22. 734 GR, OIL RHOB,FDC -999,250 DRHO.FDC CALI, FDC -999.250 GR, FDC TNPH.CNL -999. 250 TNRA.CNL RCFT,CNL -999,250 CNTC.CNL CALI,CNL -999.250 TENS.CNL . ?3. -999. -999. -'999. -999. -999. . 104. -999. -999. - 99 9. -999. -999. . -999. -999. -999. -999. -999. DEPT, ¢$00,~000 ILD,DIL 4, SP,DIL -26,734 GR,DIL 85. RHOB.FDC -999.Z50 ORHO.FDC -999, CALI.FDC -999.250 GR.FDC -999. TNPH,CNL -999,250 TNRA,CNL -999, RCFT,CNL -999,250 CNTC,CNL -999, 191 ILM.DIL 3.085 313 TENS.OIL 3990.000 250 FFDC.FDC -999.250 250 TENS.FDC -999.Z50 250 NPQR.CNL -999.250 250 CFTC.CNL -999.250 250 GR.CSG -999.250 152 !LM.DIL 3.034 375 TENS.DIL 3730.000 250 FFDC.FDC -999.250 250 TENS.FDC -999.250 250 NPOR.CNL -999.250 250 CFTC.CNL -999.250 250 GR.CSG -999.250 206 ILM.DIL 3.126 375 TENS.OIL 3764.000 250 FFDC.FDC -999.250 250 TENS.FDC -999.250 250 NPDR.CNL -999.250 250 CFTC.CNL -999.Z50 250 GR,CSG -999.250 393 ILM.DIL 4.593 563 TENS.DIL 3764.000 250 FFDC.FDC -999.250 250 TENS.FDC -999.250 250 NPDR.CNL -999.250 250 CFTC.CNL -999.250 250 GR.CSG -999.250 611 ILM.DIL 3.436 250 TENS.OIL 3490.000 250 FFDC.FDC -999.250 250 'TENS. FDC -999.250 .250 NPOR,CNL -999.250 250 CFTC.CNL ,-999.250 250 GR,CSG -999,250 607 ILM.DIL 3.446 125 TENS.DIL 3580.000 ZSO FFDC.FDC -999.250 ZSO TENS.FDC -999.Z50 250 NPOR.CNL -999.250 250 CFTC.CNL -999.Z50 IS0 GR.CSG -999.250 450 ILM.DIL 750 TENS.OIL 250 FFDC.FDC 250 TENS.FDC 250 NPOR.CNL ZSO CFTC.CNL 4.209 3450.000 -'999.250 -999.250 -999.250 -999.250 SFLU.OIL DPHI.FDC NFDC.FDC NPHI.CNL RCNT.CNL GR.CNL TENS.CSG SFLU.DIL DPHI.FDC NFDC.FDC NPHI.CNL RCNT.CNL GR.CNL TENS.CSG SFLU.DIL DPHI.FDC NFDC.FDC NPHI.CNL RCNT.CNL GR.CNL TENS.CSG SFLU.DIL DPHI.FDC NFDC,FDC NPHI,CNL RCNT,CNL GR,CNL TENS.CSG SFLU.OIL DPHI.FDC NFDC.FDC NPHI.CNL RCNT. CNL GR.CNL TENS.CSG SmLU.DIL DPHI.FDC NFDC.FDC NPHI.CNL RCNT.CNL GR,CNL T~NS,CSG SFLU.DIL DPHI.FDC NFDC.FDC NPHI.CNL RCNT.CNL GR.CNL PAGE: 11 2.871 -999.250 -999,250 -999,250 -999.250 -999.250 -999.250 2.667 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 3.034 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 4.253 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 3.186 -999.250 -999,250 -999,250 -999.250 -999.250 -9~99.250 2,764 -999,250 -999,250 -999,250 -999,250 -999,2.50 -999,250 4.820 -999.250 -999.250 -999.250 ,-999.2.50 -999.250 · IS TAPE YERIFICAT'ION LISTING iCHLUMBERGER ALASKA COMPUTING CENTER 8-.JUN-1989 16:42 C~Li. CNL -999.250 TENS.CNL -999.250 GR.CSG -999.250 DEPT. 4700.000 ILO.OIL SP.DIL -24,500 GR.~IL RHOB.FDC -999.250 DRHG.EDC CALI. FDC -999.250 GR. FDC TNPH.CNL -999.250 TNR~.CNL RCFT.CNL -999,250 CNTC.CNL CALT.CNL -999,250 TENS.CNL 3. 971 ILM.DIL 96.625 TENS.DZL -999.250 FFDC.FDC -999,!50 TENS.FDC -999.250 NPDR.CNL -999.25g CFTC.CNL -999.250 GR.CSG 3.710 3280.000 -999.250 -999.250 -999.250 -'999.250 -999. 250 DEPT. 4600,000 ILD.DIL 3.358 !LM.DIL 3.124 SP.DIL -32.000 GR.DIL 103,688 TENS,DIL 3290,000 RHDB.FDC -999.250 DRHD.FDC -999.250 .:FDC. FDC -999,250 CALI.FDC -999.250 GR.FDC -999,250 TENS.FDC -999,250 TNPH.CNL -999.250 TNRA.CNL -999.250 NPDR.CNL -999.250 RCFT,CNL -999,250 CNTC.CNL -999.250 CFTC.CNL -999,250 CALI.CNL -999.250 TENS.CNL -999.25D GR.CSG -999.250 DEPT, .4500,0D0 ILO.OIL 3,947 ILM,DIL 3.702 SP.DIL -33,750 GR,DZL 93,063 TENS,DIL 32T0,000 RHDB.FDC -999.250 DRHg. FDC -999.250 FFDC.FDC -999.250 CALI.FDC -999.250 GR.FOC -999.250 TENS.FDC -999.250 TNPH.CNL -999.250 TNRA.CNL -999.250 NPOR.CNL -999.250 RCFT.CNL -999.250 CNTC.CNL -999.250 CFTC.CNL -999.250 CALI.CNL -999.250 TENS.CNL -999.250 GR.CSG -999.250 DEPT. 4400,000 ILO.OIL 3,781 ILM,DIL 3,593 SP,DIL -29,938 GR.DIL 100,625 TENS,DIL 3110,000 RHOS.FDC -999.250 DRHD.FDC -999.250 FFDC.FgC -999.250 CALI,FDC -999.250 GR,FDC -999,250 TENS.FDC -999,.250 TNPH.CNL -999.250 TNRA.CNL -999.250 NPDR.CNL -999.250 RCFT.CNL -999.250 CNTC.CNL -999.250 CFTC.CNL -999.250 CALI.CNL -999.250 TENS.CNL -999.250 GR.CSG -999.250 DEPT. 4300. 000 ILO.OIL 4.926 ILM.DIL 4.702 SP.DIL -32.250 GR.OIL t10.813 TENS.OIL 3210.000 RHOS.FDC -999.250 ORHO.FOC -999,250 FFOC. FDC -999.250 CALI.FDC -999,250 GR,FDC -999,25D TENS,FDC -999.250 TNPH.CNL -999.250 TNRA.CNL -99'9.250 NPOR.CNL -999.250 RCFT.CNL -999.250 CNTC.CNL -999.250 CFTC.CNL -999.250 CALI.CNL -9'99.250 TENS.CNL -999.250 GR.CSG --999.250 DEPT. 4200.000 ILO.OIL 3.420 ILM.DIL 3.147 SP.DIL -32.500 GR.DIL I03.063 TENS.OIL 2960.000 RHOO,FD<C '-999.250 ORHO,FOC -999o250 FFOC,FDC -999,250 CALI.FDC -999.250 GR.FOC -999.250 TENS.FDC -999.250 ~NPH.CNL -999.250 TNRA.CNL -999.250 NPQR.CNL -999.250 RCFT.CNL -999.250 CNTC.CNL -999.250 CFTC.CNL -999.250 CALI.CNL -999.250 TENS.CNL -999.250 GR.CSG -999.250 5.BOZ ILM,DIL B3.1B8 TENS,OIL · -999.250 FFDC.FDC -999.250 TENS.FDC -999.250 NPOR.CNL DEPT. 4100.000 ILD.DIL SP.DIL -39.719 GR.OIL RHOB.FDC -999.250 gRHD.FgC CALI.FDC -999.250 GR.FDC TNPH.CNL -999.250 TNR~.CNL 5.343 2844.000 -999.250 -999.250 -999.250 TENS.CSG SFLU.DIL DPHI.FDC NFDC.:DC NPHI.CNL RCNT.CNL GR.CNL TENS.CSG SFLU.DIL DPHI,FDC NFDC,FDC NPHI .CNL RCNT .CNL GR,CNL TENS,CSG SFLU,OIL DPHI.FDC NFDC,FDC NPHI.CNL RCNT.CNL GR.CNL TENS,CSG SFLU.OIL DPHI.FDC NFDC.FDC NPHI.CNL RCNT.CNL GR.CNL TENS.CSG S:LU.DIL D~HI.FDC NFDC.FDC NPHI.CNL RCNToCNL GR.CNL TENS.CSG SFLU.DIL DPHI.FDC NFCC,FDC NPHI.CNL RCNT.CNL GR.CNL TENS.CSG SFLU.DIL DPHI.FDC NFDC.FDC NPHI.CNL RCNT.CNL PAGE: 12 -999,250 3,480 -999,250 -999,250 -999,250 -999,250 -999,250 -999,250 2,738 -999,250 -999,250 -999,250 -999,250 -999,250 -999.250 3.290 -999.250 -999.250 -999.250 -999.2 50 -999.250 -999.250 3,355 -999,250 -999,250 -999,250 -999,250 -999,250 -999.250 4.500 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 3,040 -999,250 -999,250 -999,250 -999,250 -999,250 -999.250 4,597 -999,250 .-999,250 -999,250 -999.250 IS TAPE VERIFIC.~T!ON LISTING CHLUMBERGER ALASK:~ COMPUTING CENTER RCFT.CNL -999.250 CNTC.CNL CALI.CNL -999.250 TENS.CNL DEPT. 4000.000 iLO.OIL SP.gIL -37.250 GR.DIL RHOB. FDC -999.250 ORHO. FDC CALI. mDC -999.250 GR. Fgc TNPH,CNL -999,250 TNR~.CNL RCFT,CNL -999,250 CN'TC ,CNL CALI,CNL -999,250 TENS,CNL DEPT. 3900.000 ILD.DIL SP.DIL -41.500 GR.DIL RHOB.FDC -999.250 DRHD.FOC C AL I,FDC -999,250 GR. FDC TNPH,CNL -999,250 TNRA,CNL RCFT.CNL -999. 250 CNTC.CNL C~LI,CNL -999.250 TENS,CNL DEPT. 3800.000 ILO.OIL SP.DIL -45.250 GR.DIL RHOB.FDC -999.250 ORHO.FOC CALI.FDC -999.250 GR.FDC TNPH. CNL -999.250 TNRA.CNL RCFT.CNL -999.250 CNTC.CNL CALI,CNL -999,250 TENS,CNL DEPT. 3700.000 ILO.OIL SP.DIL -44.969 GR.DIL RHOB.FDC -999.250 DRHD.FDC CALI,FDC -999,250 GR,FgC TNPH,CNL -999,250 TNRA,CNL RCFT,CNL -999,250 CNTC,CNL C~LI,CNL -999,250 TENS,CNL DEPT. 3600. 000 ILD. OIL SP.DIL -43.219 GR.OIL RHOB.FDC -999.250 DRHO.FDC CALI, FDC -999,2 50 GR, FDC TNPH,CNL -999,250 TNRA,CNL RCFT.CNL -999.250 CN'TC. CNL C/~LI.CNL -999.2!5:0 TENS.CNL DEPT. 3500.000 ILO.OIL SP. OIL 3. 0135 GR. OIL RHO~.FDC -999.250 ORHO.FDC CALI. FDC -999.250 GR. FDC TNPH.CNL -999.250 TNRA.CNL RCFT,CNL -999,250 CNTC,CNL CALI.CNL -999.250 TENS.CNL DEPT. 3400.000 ILD.DIL SP.DIL -999.250 GR.DIL RHOB.FDC -999.250 DRHO.FDC C~LI.FOC -999.250 GR.FDC 8-JUN-1989 16:42 -999. -999. 98. -999. -999. -999. -999. - 999. . 90. -999. -999. -999. -999. - 999. 92. -999. -999. -999. -999. -999. . 94. -999. -999. -999. -999. -999. 2000. 68. -999. -999. -999. -999. -'999. 250 CFTC.CNL -999.250 250 GR,CSG -999.250 751 ILM,DIL 3.603 750 TENS,DIL 2750,000 250 FFDC.FOC -999.250 250 TENS.FDC -999.250 250 NPDR.CNL -999.250 !50 CFTC,CNL -999,250 250 GR,CSG -999,250 782 ILM,DIL 4,44T 938 TENS,DIL 2734,000 250 FFDC,FOC -999,250 250 TENS,FDC -999,250 250 NPDR,CNL -999,250 250 CFTC,CNL -999,250 250 GR,CSG -999.250 264 ILM.DIL 3.323 438 TENS.DIL 2610.000 250 FFDC.FDC -999.250 250 TENS.FDC -999.250 250 NPOR.CNL -999,250 250 CFTC,CNL -999.250 250 GR,CSG -999.250 136 ILM.DIL 375 TENS,DIL 250 FFDC.FDC 250 TENS,FDC 250 NPOR,CNL 250 CFTC.CNL 250 GR,CSG 3.695 2614.000 -999.250 -999.250 -999.250 -999. 250 97.188 000 ILM.DIL 2000.000 313 TENS.DIL 2570.000 250 FFDC.FgC -999.250 250 TENS.FDC -999.250 250 NPOR.CNL -999.250 250 CFTC,CNL -999.250 250 GR.CSG 45.469 15.799 50.000 -999.250 -99'9. 250 - 999. 250 -999.250 -999.250 25O 250 250 250 ILM.DIL TENS.OIL FFOC.FDC TENS.FDC NPOR.CNL CFTC.CNL ~R.CSG ILM.OIL TENS.DIL FFDC.FOC TENS.FDC -999. -999. -999. -999. 2000.000 2530.000 -999.250 -999.250 -999. 250 -999.250 55.313 -999.250 --999.25O -999.250 '-999.250 GR,CNL TENS,CSG SFLU.DIL DPHI.FDC NFgC.FDC NPHI.CNL RCNT.CNL GR.CNL TENS.CSG SFLU.DIL DPHI.FDC NFDC.FDC NPHI.CNL RCNT.CNL GR.CNL TENS,CSG SFLU.OIL DPHI.FDC NFDC.FDC NPHI.CNL RCNT.CNL GR.CNL TENS.CSG SFLU.DIL DPHI.FDC NFDCoFDC NPHI.CNL RCNT.CNL GR.CNL TENS.CSG SFLU.OIL DPHI.FOC NFDC.FDC NPHI.CNL RCNT.CNL GR.CNL TENS.CSG SFLU.DIL DPHI.FDC NFDC.FDC NPHI.CNL RCNT.CNL G~.CNL TENS.CSG SFLU.DIL DPHI.FDC NFDC.FDC NPHI.CNL PAGE: -999.250 -999.250 3.888 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 4.079 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 3.143 -9'99.250 -999.250 -999.250 -999.250 -999.250 -999.250 3.615 -999.250 -999.250 -999.250 -999.250 -999 o 250 2594,000 0.142 -999.250 -999.250 -999.250 -999.250 -999.250 2524.000 2000.000 -999.250 -999.250 -999.250 -999.250 -999.250 2460.080 -999.250 -999.250 -999.250 -999.250 13 IS 'TAPE VERIF'IC~.TION LISTINO CHLUMSERGER ~L~SK~4 ~COMPUTZNG CENTER TNPH.CNL -999.250 TNRA.CNL RCFT.CNL -999.250 CNTC.CNL CALI.CNL -999.250 TENS.CNL DEPT. 3300.000 ILO.OIL SP.DIL -999.250 GR.DIL RHOB.FDC -999.250 gRHO.FDC CALI. FDC -999.250 GR.FDC TNPH.CNL -999.250 TNRA.CNL RCFT.CNL -999.250 CNTC.CNL C~LI.CNL -999.250 TENS.CNL DEPT. 3200.000 ILO.OIL SP.DIL -999.250 gR.DIL RHOB.FDC -9)9.250 DRHO.FOC CALI, FDC -999,250 GR, FDC TNPH.CNL -999.250 TNRA.CNL RCFT.CNL -999.250 CNTC.CNL CALI.CNL -999.250 TENS.CNL DEPT. 3100.000 ILD.OIL SP.OIL -999.2 50 GR.DIL RHCB.FDC -999.250 DRHO.FDC C~LI. FDC -999,250 GR. FDC TNPH,CNL -999.250 TNRA,CNL RCFT.CNL -999.250 CNTC.CNL CALI.CNL -999.250 TENS.CNL DEP'T. ;3000.000 ILD.DIL SP.DIL -999.250 GR.DIL RHOB.FDC -999.250 DRHO.FDC CALIoFDC -999,250 GR.FDC TNPH.CNL -999.250 TNRA.CNL RCFToCNL -999,250 CNTC.CNL CALI.CNL -999.250 TENS.CNL DEPT. 2900.000 !LD.DZL SP.DIL -999.250 GR.DIL RHOB..FDC -999.250 DRHO.FOC CALI.FDC '-999.250 GR.FDC TNPH.CNL -999.250 TNRA.CNL RCFT.CNL -999.250 CNTC.CNL CALI.CNL -999.250 TENS.CNL DEPT. ZBO0.O00 ILO.OIL SP.OIL -999.250 GR.DIL RHOB-FD~C -999.250 DRHO.FDC CALI.FDC -999.250 GR.FDC TNPH.CNL -999.250 TNRA.CNL RCFT.CNL -999.250 CNTC.CNL CALI.CNL -999.250 TENS.CNL 8-JUN-1989 16:42 -999.250 NPOR.CNL -999.250 CFTC.CNL -999.250 GR.CSG -999,250 ILM.DIL -999,250 TENS.DIL -999,2.50 FFDC.FDC -999.250 TENS.FDC -999.250 NPDR.CNL -999,250 CFTC,CNL -999,250 GR.CSG -999.250 ILM.DIL -999.250 TENS.OIL -999.250 FFDC.FDC -999.250 TENS.FOC -999.250 NPOR.CNL -999.250 CFTC.CNL -999.250 GR.CSG -999,250 ILM.DIL -999,250 TENS.OIL -999,250 FFDC.FDC -999,250 TENS.FOC -999,250 NPOR.CNL -999,250 CFTC,CNL -999.250 GR,CSG -999.250 ILM, DIL -:999,250 TENS.OIL -999.250 FFDC,FDC -999,250 TENS.FDC -999.250 NPgR.CNL -999.250 CFTC.CNL -999,250 GR.CSG -999.250 ILM.DIL -999.250 TENS,OIL -999,250 FFDC.FDC -999.250 TENS.FDC -999.250 NPOR.CNL -999.250 CFTC.CNL -999. 250 ~aR. CSG -999.250 ILM.DIL -999. 250 TENS.DIL -999.250 FFDC.FDC -999.250 TENS.FDC -999. 250 NPOR.CNL -999.250 CFTC.CNL -999.250 GR,CSG -999.250 -999.250 51.781 -999.250 -999.250 -999.250 -999,250 -999.250 -999,250 45.000 -999.250 -999.250 -999,250 -999,250 -999,250 -999,250 53.219 -999,250 -999,250 -999,250 -999,250 -999.250 -999.250 53.031 -999,250 -999.250 -999,250 -999,250 -999,250 -999,250 54.313 -999.250 -999,250 -999,250 -999.250 -999.250 -999,250 43.844 -999,250 -999,250 -999,250 -999,250 -999,250 -999,250 44.656 RCNT.CNL GR.CNL TENS.CSG SFLU.DIL DPHI.FDC NFDC,FDC NPHI.CNL RCNT.CNL GR.CNL TENS.CSG SFLU.DIL DPHI.FDC NFDC.FDC NPHI.CNL RCNT.CNL GR.CNL TENS.CSG SFLU.DIL DPHI.FDC NFDC.FDC NPHI.CNL RCNT.CNL GR,CNL TENS,CSG SFLU,DIL DPHI,FDC NFDC,FDC NPHI,CNL RCNT,CNL GR.CNL TENS,=CSG SFiLU.DIL DPHI,FDC NFDC,FDC NPHI,CNL RCNT.CNL GR.CNL TENS.CSG SFLU.OIL DPHI,FDC NFDC, FDC NPHI ,CNL RCNT,CNL GR,CNL TiENS,CSG PAGE: 14 -999.250 -999.250 2390.000 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 2320,000 -999.250 -999.250 -999,250 -999,250 -999,250 -999.250 2270.000 -999.250 -999.250 -999.250 -999,250 -999.250 -999.250 2160.000 -999.250 -999,250 '-999,250 -999,250 -999,250 -999,250 2200.000 -999,250 -999.250 -999,250 -999.250 -999,250 -999.250 2160.000 -999,250 -999,250 -999,250 -999,250 -999,250 -999.250 1980,000 .IS TAPE VERIFICATION LISTING ;CHLUMBERGER ALASK:~ COMPUTING CENTER DEPT. 2700.000 ILO.OIL SP.DIL -999.250 GR.OIL RHOB. FDC -999.250 DRHO.FDC C ALI. FDC -999.2 50 GR . FDC TNPH.CNL -999.250 TNRA.CNL RCFT.CNL -999.250 CNTC.CNL C~LI.CNL -999.,250 TENS.CNL DEPT. 2600.000 ILD.DIL SP.DIL -999.250 GR.DIL RHCB.FDC -999.250 gRHO.FDC C~LI.PDC -999.250 GR.FOC TNPH.CNL -999.250 TNRA.CNL RCFT.CNL -999.250 CNTC.CNL CALI.CNL -999.250 TENS.CNL DEPT. 2500.000 ILD.DIL SP. DIL -999. 250 GR. DIL RHOB. FDC -999.2 50 gRHO. FOC C ALI. FDC -999.250 GR. FDC TNPH.CNL -999.250 TNRA.CNL RCFT.CNL -999.250 CNTC.CNL CALI.CNL -999.250 TENS.CNL DEPT. 2400. 000 ILO. OIL SP.DIL -ggg.zEO GR.DIL RHOB.FDC -999.250 DRHO.FDC CALI. FDC -999.250 GR .FDC TNPH.CNL -999. 250 'TNRA.CNL RCFT.CNL -9'99.250 CNTC.CNL CALI.CNL -999.250 TENS.CNL DEPT. 2300.000 ILD.DIL SP.OIL -999.250 GR.DIL RHOB.FOC -999.250 ORHO.FOC CALI.¢DC -999.250 GR.FDC TNPH.CNL -999.250 TNRA.CNL RCFT.CNL -99'9.250 CNTC.CNL CALI.CNL -999.250 TEN:S.CNL DEPT. 2200.000 ILO.OIL SP.DIL -999 250 GR.OIL RHOE.FDC -999Z250 DRHO.FDC CALI. FDC -999.250 GR. FDC TNPH.CNL -999.2150 TNRA.CNL RCFT. CNL -999.250 CNTC.CNL CALI.CNL '-999.250 TENS.CNL DEPT. 2100.000 ILO.OIL SP.DIL -'999.250 GR.DIL RHDE.FDC -999.250 DRHO.FDC CALI.FDC -999.250 GR.FDC TNPH.CNL -999.250 TNRA.CNL RCFT.CNL -999.250 CNTC.CNL CALI.CNL '-999.250 TENS.CNL B-JUN-1989 16:42 -999.250 ILM.D'IL -999.250 -999.250 TENS.DIL -999.250 -999.250 FFDC.FDC -999.250 -999.250 TENS.FDC -999.250 -999.250 NPOR.CNL -999.250 -999.250 CFTC.CNL -999.250 -999.250 GR.CSG 48.438 -999.250 ILM.DIL -999.250 -999.250 TENS.OIL -999.250 -999.250 FFDC.FDC -999.250 -999.250 TENS.FDC -999.250 -999.Z50 NPOR.CNL -999.250 -999.250 CFTC.CNL -999.Z50 -999.250 GR.CSG 5B..~3B -999.250 ILM.DIL -999.250 -999.250 TENS.DIL -999.250 -999.Z50 FFDC.FDC -999.250 -999.250 TENS.FDC -999.250 -999.250 NPOR.CNL -999.250 -999.Z50 CFTC.CNL -999.Z50 -ggg. ZEO GR.CSG 43.~38 -999.250 ILM.DIL -999.250 -999.250 TENS.DIL -999.250 -999.Z50 FFDC.FDC -999.250 -999.250 TENS.FDC -999.Z50 -999.250 NPOR.CNL -999.250 -999.250 CFTC.CNL -999.250 -999.250 GR.CSG 32.063 -999.Z50 ILM.DIL -999.250 -999.250 TENS.DIL -999.250 -999.Z50 FFDC.FDC -999.250 -999.250 TENS.FDC -999.250 -999.250 NPOR.CNL -999.250 -999.250 CFTC.CNL -999.250 -999.250 GR.CSG 45.813 -999.250 ILM.DIL -999.250 -999.250 'TENS.DIL -999.250 -999.250 ~FDC.FDC -999.Z50 -999.250 TENS.FOC -999.250 -999.250 NPOR.CNL -999.250 -999.250 CFTC.CNL -999.250 -999.250 GR.CSG 21.73~ -999.Z50 ILM.DIL '-999.25D -999.250 TENS.DIL '-999.250 -999.Z50 FFDC.FDC -999.Z50 -999. Z50 TENS.FDC -999.Z50 -'999.250 NPOR.CNL -999.250 -999.250 CF'TC.CNL -999.250 -999.250 GR.CSG 31.609 SFLU.OIL DPHI.FDC NFDC.FDC NPHI.CNL RCNT.CNL GR.CNL TENS.CSG SmLU.DIL DPHI.FDC NFDC.FDC NPHI .CNL RCNT.CNL GR.CNL TENS.CSG SFLU.DIL DPHI.FDC NFDC.FDC NPHI.CNL RCNT.CNL GR.CNL TENS.CSG SFLU.OIL DPHI.FDC NFDC.FDC NPHI.CNL RCNT.CNL GR.CNL TENS.CSG SFLU.DIL DPHI. FDC NFEC.FDC N PH I. CNL RCNT. CNL GR.CNL TENS.CSG SFLU.DIL DPHI.FDC NFDC.FDC NPHI.CNL RCNT.CNL GR.CNL TENS.CSG SFLU.DIL DPHI.FDC NFOC.FDC NPHI.CNL RCNT.CNL GR.CNL TENS.CSG PAGE: -999.250 -999.Z50 -999.250 -999.250 -999.250 -999.250 1975.000 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 1880.000 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 1875.000 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 1765.000 -999.250 -999.250 -999.250 -999.250 -999'250 -999.Z50 1880.000 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 1660.000 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 1790.000 15 ,IS TAPE VERIFIC.~TION LISTING iCHLUMSE~GER ~LASK~ COMPUTING CENTER DEPT. 20,00. 000 ILD.DIL SP.DIL -999.250 GR.DIL RHOS.~DC -999.250 DRHO.FDC CALI. ~DC -9 99.2 50 GR. FDC TNPH.CNL -999.250 TNRA.CNL RCFT.CNL -999.250 CNTC.CNL CALI. CNL -999. 250 TENS.CNL DEPT. 1900.000 ILD.DIL SP.DIL -999.250 OR.OIL RHOB.FDC -999.250 DRHO.FDC C&LI. FDC -999. 250 GR. FDC TNPH.CNL -999. 250 TNR~.CNL RCFT.CNL -999.250 CNTC.CNL CALI.CNL -999.250 TENS.CNL DEPT. 1800.0 O0 ILO. OIL SP. DIL -999. 250 GR. OIL RHOB.FDC -999.250 DRHO.FDC CALI. FDC -999. 250 GR.FDC TNPH.CNL -999.250 'TNRA.CNL RCFT.CNL -999.250 CNTC.CNL CALI.CNL -999.250 TENS.CNL DEPT. 1700.000 ILD.DIL SP.OIL -999.250 GR.DIL RHOB.FDC -999.250 ~RHO.FDC CALI.FDC -999.250 GR.'FOC TNPH.CNL -999.250 TNRA.CNL RCFT.CNL -999.250 CNTC.CNL CALI.CNL -999.250 TENS.CNL DEPT. 1600.000 ILO.OIL SP.DIL -9'99.2 50 GR.DIL RHOB.FDC -999.250 DRHO.FOC C~lI. FDC -999.250 GR. FDC TNPH.CNL -999.250 TNRA.CNL RCFT.CNL -999.250 CNTC.CNL CALI.CNL -999.250 'TENS.CNL DEPT. 1500.000 ILO.OIL SP.DIL -999.250 OR.OIL RHOB.FDC -999.250 ORHO.FOC CALI.FDC -999.250 GR.FDC TNPH.CNL -999.250 TNRA.CNL RCFT.CNL -999.250 CNTC.CNL CALI.CNL -999.250 TENS.CNL DEPT. 1400.000 ILD.DIL SP.DIL -999.250 ~GR.DIL RHOB.FDC -999.250 DRHO.FDC CALI.FDC -999.250 GR.FDC TNPH.CNL -999.250 TNR~.CNL RCFToCNL -999.250 CNTC.CNL $-JUN-1989 16:42 -999. -999. -999. -999. -999. - 999. -gg9. -999. -999. -999. -999. -999. -999. -999. 250 ILM.OIL -999.250 250 TENS.DIL -999.250 250 FFDC. FDC -999.250 250 TENS.FDC -999.250 250 NPOR.CNL -999.250 250 CFTC.CNL -999.250 250 ~R.CSG 46.906 250 ILM.DIL -999.250 250 TENS.DIL -999.250 250 FFDC.FDC -999.250 250 TENS.FDC -999.250 250 NPOR.CNL -999.250 250 CFTC.CNL -999.250 250 GR.CSG 47.375 -999.250 ItM.DIt -999.250 TENS.OIL -999.250 FFDC.FDC -999.250 TENS.FDC -999.250 NPOR.CNL -999.250 CFTC.CNL -999.250 GR.CSG -999.250 ILM.DIL -999.250 TENS.DIL -9:99.250 FFDC.FDC -999.250 TENS.FDC -999.250 NPOR.CNL -999.250 CFTC.CNL -999.250 GR.CSG -999.250 ILM.DIL -999.250 TENS.DIL -999.250 FFDC.FDC -999.250 TENS.FDC -999.250 NPOR.CNL -999.250 CFTC.CNL -999.250 GR.CSG -999.250 ILM. DIL -999.250 TENS.OIL -999.250 FFDC.FDC -999.250 TENS.FOC -999.250 NPORoCNL '-999.250 CFTC.CNL -999.250 GR.CSG -999.250 tLM.DIL -999.250 TENS.OIL -999.250 FFD:C.FDC -999.250 TENS.FDC -999.2510 NPOR.CNL -999.250 CFTC.CNL -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 25.375 -999.250 -999.250 --999.250 -999.250 -999.250 -999.250 45.000 -999.250 -999.250 -999.250 -999.250 -'999.250 -999. 250 21. '92.2 -999.250 -'999.250 -999.250 -999.250 -999.250 -999.250 31.35'9 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 SFLU.DIL DPHI.FDC NFEC.FDC NPHI.CNL RCNT.CNL GR.CNL TENS.CSG SFLU.DIL DPHI.FDC NFDC.FDC NPHI.CNL RCNT.CNL GR.CNL TENS.CSG SFLU.OIL DPHI.FDC NFOC.FDC NPHI.CNL RCNT.CNL GR.CNL TENS.CSG SFLU.DIL DPHI.FDC NFOC.FD£ NPHI.CNL RCNT.CNL GR.CNL TENS.CSG SFLU.OIL DPHI.FDC NFDC.FDC NPHI.CNL RCNT.CNL GR.CNL TENS.CSG SFLU.DIL DPHI.FDC NFDC.FDC NPHI.CNL RCNT.CNL GR.CNL TENS.CSG SFLU.DIL DPHI.FDC NFDC.FDC NPHI.CNL RCNT.CNL GR.CNL PAGE: -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 1700.000 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 1705.000 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 1575.000 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 1500.000 --999.250 -999.250 -999.250 -999.250 -999.250 -999.250 1505.000 -999.250 -999.250 -999.250 -999.250 -999. 250 -999.250 1430.000 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 16 IS TAPE VERIFICAT'IDN LISTING CHLUPSERGER ~LASKA COMPUTING CENTER CALI.CNL -999.250 TENS.CNL DEPT. 1300.000 ILO.OIL SP.DIL -999.250 GR.DIL RHOB.FDC -999.250 DRHO.FDC C~EI.FDC -999.250 GR.FDC TNPH.CNL -999.250 TNRA.CNL RCFT.CNL -999.250 CNTC.CNt C&LI.CNL -999.250 TENS.CNL DEPT. 1200.000 ILO.DIE Sm. OIL -999.250 GR.DIL RHDB.FDC -999.250 DRHg. FOC CALI.FDC -999.250 GR.FDC TNPH.CNL -999.250 TNRA.CNL RCFT.CNL -999.250 CNTC.CNL CALI.CNL -999.250 TENS.CNL DEPT. 1100.000 ILO.DIE SP.DIL -999.250 GR.DIL RHOB.~DC -999.250 ORHO.FgC CALI.FDC -999.250 GR.FDC TNPH.CNL -999.250 TNRA.CNL RCFT.CNL -999.250 £NTC.CNL C~LI.CNE -999.250 TENS.CNL DEPT. 1000.000 ILO.DIE SP.DIL -999.250 GR.DIL RHGB..FDC -999.250 DRHO.FOC C ALI. FDC -999.2 !50 GR. FOC TNPH.CNL -999.250 TNRA.CNL RCFT.CNL -999.250 CN'TC.CNL C~LI.CNL -999.250 TENS.CNL DEPT. 900.000 II~.~II SP.OIL -999.250 GR.DIL RH~.FDC -999.250 DRHO.F~C CALI.FDC -999.250 GR.FDC TNPH.CNL -999.250 TNRA.CNL RCFT.CNL -999.250 CNTC.CNL CALI.CNL -999.250 TENS.CNL DEPT. 893.000 ILD.DIL SP.OIL -999.250 GR.OIL RHOB.FDC -999.250 DRHO.FDC C~LI.FDC -999.250 GR.FDC TNPH.CNL -999.250 TNRA.C:NL RCFT.CNL -999.250 CNTC.CNL CAEI.CNL -999.250 TENS.CNL END OF DATA 3-JUN-lO89 16:42 -999.250 GR.CSG -999.250 ILM.DIL -999.250 TENS.OIL -999.250 FFDC.FDC -999.250 TENS.FOC -999.250 NPOR.CNL -999.250 CFTC.CNL -999.250 GR.CSG -999.250 ILM.DIL -999.250 TENS.OIL -999.250 FFDC.FDC -999.250 'TENS.FDC -999.250 NPOR.CNL -999.250 CFTC.CNE -999.250 GR.CSG -999.250 ILM.DIL -999.~50 TENS.DIE -999.250 FFOC.FDC -999.250 TENS.FDC -999.250 NPOR.CNL -999.250 CFTC.CNL -999.250 GR.CSG -999.250 ILM.OIE -999.250 TENS.DIE -999.250 FFDC.FDC -999.250 TENS.FDC -999.250 NPOR.CNL -999.250 CFTC.CNL -999.250 GR.CSG -999.250 ILM.DII -999.250 'TENS.OIL -999.250 FFDC.FDC -999.250 TENS.F~C -999.250 NPOR.CNL -999.250 CFTC.CNL -999.250 GR.CSG -999.250 ILM.OIL -999.250 TENS.DIE -999.250 FFDC.FDC -999.250 TENS.FDC -999.250 NPDR.CNL -999.250 CFTC.CNL -999.250 GR.CSG 26.84~ -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 24.531 -999.25~ -999.250 -999.250 -999.250 -999.250 -999.250 27.625 -99~.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999. 250 -999.250 -999.250 -999.250 -999.250 42.938 -999.250 -999.250 -999.~50 -999.250 -999.250 -999.250 30.000 -999.250 -999.250 -999.250 -999.250 -999.~50 -999.250 34.281 TENS.CSG SFLU.~IL DPHI.FDC NFDC.FDC NPHI.CNL RCNT.CNL GR.CNL TENS.CSG SFLU.DIL DPHI.FDC NFDC.FDC NPHI.CNL RCNT.CNL GR.CNL TENS.CSG SFLU.DIL DPHI.FDC NFaC.FDC NPHI.CNL RCNT.CNL GR .CNL TENS .CSG SFLU.DIL DPHI.FDC NFDC.FDC NPHI.CNL RCNT.CNL GR.CNL TENS.CSG SFLU.DIL DPHI.FDC NFDC.FDC NPHI.CNL RCNT.CNL GR.CNL TENS.CSG SFLU.DIL DPHI.FDC NFDC.FDC NPHI.CNL RCNT.CNL G~.CNL TENS.CSG PASE: 17 1370.000 -999.250 -999,250 -999.250 -999.250 -999.250 -999.250 1300.000 -999.250 -999.2~0 -999.250 -999.250 -999.250 -999.2S0 1250.000 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 1150.000 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 1125.000 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 1075.000 -999.250 -999.250 -999.250 -999.250 -999.Z50 -999.250 1070.000 .IS TAPE VERIFICATION LISTING ;CHLUM~ERGER 8LASKA COMPUTING CENTER 8-JUN-1989 16:42 PAGE: 18 · =~ FILE TRAILER ~'~'~',-,,,~- FILE NAME : EDIT .001 SERVICE : =LIC VERSION : 001.~02 DATE : 89/06/ 8 MAX REC SIZE : 1096 FILE TYPE : LO LAST FILE : · ~ FILE HEADER ~ FILE NAME : EDIT .002 SERVICE : mLZC VERSION : 001A02 DATE : 89/06/ ~ MAX REC SIZE : 1096 FILE TYPE : LO LAST ~ILE : FILE- EDIT.O02 ARCO ALASKA~, INC. KUPARUK 2K-3 50-103- 20100 1.2" HIGH RESOLUTION FDC/CNL DATA SAMPLED EVERY -.1000 FEET DA'TA INCLUDED - TOOL EXTENSION TOOL TYPE USED NAME FOC .FOH FORMATION OENSITY 87g~' TO 8083' CNT-A/~,/H .CNH COMPENSATED NEUTRON 8781' TO 8083" IS TAPE VERIFICATION LISTING CHLU~BERG~R ALASKA COMPUTING CENTER TABLE TYPE : CONS TUNI CN FN WN APIN FL SECT TOWN RANG COUN STAT N&TI ENGI WITN SON POAT EPD FT LMF APl] FT EKE FT EOF EGL FT TDD FT TABLE TYPE : CURV DEFI OEPT DPHI RHOB DRHO FFDC NFDC CALI GR TENS NPHI TNPH TNRA NPO~ RCNT RCFT CNTC CFTC GR CALI TENS B-JUN-1989 16:42 V~LU PAGE: 19 ARCO ALASKA, INC. KUPARUK 2K-3 50-103-20100 250' FSL & 90' FEL O2 1ON 8E NORTH SLOPE ALASKA USA FRITZKE KINNEVAN/GOLDEN/RUNJE 54835T M S L O. RKB 154. 154. 153. 113. 8861. DEFI DEPTH CHANNEL NAME DENSITY POROSITY SULK DENSITY DELTA RHO FAR FOC COUNT ~TE NEAR FDC COUNT RATE CALIPER GAMMA RAY TENSZON NEUTRON PORD~SITY 'THERMAL NEUTRON POROSITY CALIBR.~TED THERMAL NEUTRON RATIO NEUTRON POROSITY OUTPUT FROM AN APPLICATION PROGRAM RAW CORRECTED NEAR THERMAL COUNTS RAW CORRECTED ~AR THERMAL COUNTS CORRECTED NEaR THERMAL COUN'TS CORRECTED F~R 'THERMAL COUNTS GAMMA RAY CALI~ER TENSION COMPANY NAME FIELD NAME WELL NAME API SERIAL NUMBER FIELD LOCATION SECTION TOWNSHIP RANGE COUNTY STATE OR PROVINCE NATION ENGINEER'S NAME WITNESS'S NAME SERVICE ORDER NUMBER PERMANENT DATUM LOG MEASURED FROM IS TAPE VERIFICAT'IDN LISTING CHLUMBERGER ALASKA CDMPUTING CENTER 8-JUN-19B9 16:42 PAGE'. 20 ~-~ DATA FORMAT SPECIFICATION_ RECOOD., SET TYPE - 64E8 "-'"-,--,- TYPE REPR CODE V~LUE ! 66 0 2 66 0 3 73 80 4 66 1 5 66 6 T3 7 65 8 58 0.099 9 65 FT 11 66 12 68 13 66 O !~ 65 FT 15 66 68 16 66 1 0 66 ~ SYT TYPE - CHAN -,-'~'~- NAME SERV UNIT SERVIC:,_ API ,~P'I API ~PI =ILE~ NUMB NUMB SIZE REPR ID ORDER ~ LOG TYPE CLASS MOD NUMB S~MP ELEM CODE DEPT FT 548357 O0 DPHI FDH PU !548357 07 RHOB FDH G/C3 548,357 07 DRHO FDH G/C3 548357 07 FFDC ~DH C~S 548357 07 NFDC FDH CPS 548357 07 CALI FDH IN 548357 07 GR FDH G~PI 5481357 07 TENS FDH L~ 548357 07 NPHI CNH PU 54'8357 07 TNPH CNH PU 548357 07 TNRA CNH 548357 07 NPOR CNH PU 548357 07 RCNT CNH CPS :548357 07 RCFT CNH CPS 548357 07 CNTC CNH CPS 548357 07 CFTC CNH CPS 548357 0'7 GR CNH GAPI 548357 07 CALI CNH IN :548357 07 TENS CNH LB 548357 07 P~OCESS ( H E X ) 000 O0 0 2 I 1 4 68 53 5 21 0 2 1 1 4 68 350 02 0 2 1 1 4 68 356 O1 0 2 1 1 4 68 354 0 2 O 2 1 1 4. 68 1354 O1 0 2 1 1 4 68 Z80 O1 0 2 1 1 4 68 310 01 0 2 1 1 4 6 8 635 21 0 2 ! I 4 68 890 O0 0 2 1 1 4 68 890 DO 0 2 1 I 4 68 420 01 0 2 1 1 4 68 890 00 0 2 1 1 4 68 42 O 01 0 2 1 1 4 68 420 O1 0 2 1 1 4 68 420 O1 0 2 1 1 4 68 420 01 0 2 1 1 4 68 310 01 0 2 1 I 4 6 8 280 O1 0 2 I 1 4 68 635 21 0 2 I 1 4 68 OOOO000000 O00000000O O0000000DO 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 O0000000OO O00000'O000 0000000000 0000000000 0000000000 000000000'0 0000000000 0000000000 OODO000000 O0000000DO IS TAPE VERIFICATION LISTING CHLUMBERGER ~LASKA COMPUTING CENTER DATA DEPT. $842.400 DPHI.FOH FFDC.FDH 3466.000 NFOC.FDH TENS.FDH 4094.000 NPHZ.CNH NPOR.CNH 40.327 RCNT.CNH CFTC.CNH 475.102 GR.CNH DEPT. B~O0.O00 gPHI.FOH FFDC.FgH 3454.000 NFDC.PDH TENS.FDH 5848.000 NPHI.CNH NPOR.CNH 40.304 RCNT.CNH CFTC.CNH 475.102 GR.CNH DEPT. 8700.000 DPHI.FDH FFDC.FDH 536.000 NFDC.FDH TENS.FDH 5748.000 NPHI.CNH NPDR.CNH 40.580 RCNT.CNH CFTC.CNH 535.509 GR.CNH DEPT. 8600.000 OPHI.FDH FFDC.FDH 521.000 NFOC.FDH TENS.FDH 5720.000 NPHI.CNH NPOR.CNH 31.239 RCNT.CNH CPTC.CNH 863.008 GR.CNH DEPT. 8500.000 DPHI.FDH FFDC.FDH 573.000 NFOCoFDH TENS.FDH 5712.000 NPHI.CNH NPCR.CNH 31.7.55 RCNT.CNH CFTC. CNH 819.083 GR. CNH DEPT. 8400.000 DPHI.FDH FFDC.FDH 756.500 NFDC.FDH TENS.FDH 5804.000 NPHI.CNH NPOR.CNH 43.244 RCNT.CNH CFTC.CNH 481.590 GR.CNH DEPT. 8300.000 DPHI.FDH FFDC.FDH 538.000 NFDC.FDH TENS.FDH 53.84.000 NPHI.CNH NPOR.CNH 55.560 RCNT.CNH CFTC. CNH 577.4,26 GR.CNH DEPT. 8200.000 OPHI.FOH FFDC.FDH 617.500 NFDC.FQH TENS.FDH 5380.000 NPHI.CNH NPOR.CNH 45.066 RCNT.CNH CFTC.CNH 474.121 GR.CNH DEPT. 8100.000 DPHI.FOH FFOC.FDH 482.750 NFDC.FDH TENS.FDH 5564.000 NPHI.CNH NPOR.CNH 41.4,46 RCNT.CNH CFTC.CNH 5,39. 605 GR.CNH 8.-JUN-19~9 18:42 62.777 RHOB.FOH 961.500 CALI.FDH 40.291 TNPH.CNH 1521.122 RCFT.CNH 77.875 CALI.CNH 62.826 RHOB.FDH 953.000 CALI.FDH 40.274 TNPH.CNH 1621.122 RCFT.CNH 77.875 CALI.CNH 10.689 RHOB.FDH 663.000 CALI.FDH 44.357 TNPH.CNH 1 714. 254 RCFT.CNH 92.625 CALI.CNH 13.978 RHOB.FDH 602.000 CALI.FDH 30.775 TNPH.CNH 2323.560 RCFT.CNH 72.313 C~LI.CNH 15.973 RHOB.FDH 624.500 CALI.FDH 30.701 TNPH.CNH 2367.532 RCFT.CNH 67.063 CALI.CNH 20.914 RHOB.FDH 708.500 CALI.FDH 44.507 TNPH.CNH 1780.215 RCFT.CNH 96.438 C~LI.CNH 5.655 RHOB.FDH 723.500 CALI.FOH 41.754 TNPH.CNH 1795.~48 RCF'T.CNH 106.313 CALI.CNH 15.262 RHOB.FOH 676.500 CALI.FgH 46.079 TNPH.CNH 714. 254 RCFT.CNH 1.31.500 CALI.CNH 10.510 RHOB.FDH 610.500 CALI.FDH 42.136 TNPH.CNH I815.768 RCFT.CNH 232.$75 CALI.CNH 1.514 11.477 40.327 424.710 11.477 1.613 11.516 40.304 424.710 11.516 2.474 9.242 40.315 468.044 9.242 2.419 8.:375 30.589 775.221 8.375 2.386 8.852 3 .Z. 199 710. :870 8.852 2.305 7.855 45.253 461.967 7.855 2.557 9.141 47.304 571.759 9.141 2.398 9.313 45.249 413.301 9.313 2.4'75 9.195 41.281 413.301 9.195 DRHO.FDH GR.FDH TNR~.CNH CNTC.CNH TENS.CNH DRHO.FDH GR.FDH TNRA.CNH CNTC.CNH T_:NS.CNH DRHO.FDH GR.FDH TNRA.CNH CNTC.CNH TENS.CNH DRHD.FDH GR.FDH TNRA.CNH CNTC.~CNH TENS.CNH DRHO.FDH GR.FDH TNRA.CNH CNTC.CNH TENS.CNH DRHD.FDH GR.FDH 'TNR~.CNH CNTC.CNH TENS.CNH DRH.O.FDH GR.FDH TNR~.CNH CNTC.CNH TENS.CNH DRHO.FDH GR.FDH TNRA.CNH CNTC.CNH TENS.CNH DRHO.FDH GR .FDH TNRA.CNH CNTC.CNH TENS.CNH PAGE: 21 -0.014 77.875 3.541 1650.344 4094.000 -0.016 77.875 3.541 1650.344 5848.000 0.087 92.625 3.623 1810.210 5748.000 0.021 72.313 2.781 2353.911 5720.000 0.027 67.063 2.815 2332.809 :5712.000 0.058 '96.4 ~38 3.516 1759.757 5804.000 0.172 1~06.313 3.473 2197.834 5384.000 0.069 131.500 3.723 1748.604 5380.000 0.046 232.875 3. 498 1855.458 5564.000 IS TAPE VERIFICATION LISTING CHLUMBERGER ~LASK~ COMPUTING CENTER 8-JUN-Ig~B9 16:4Z PAGE: 22 DEPT. 80 B 2.6 O0 DP HI. FDH FFDC. FDH 725 · 0 O0 NF DC · FOH TENS.FDH 5544.000 NPHI.CNH NPOR.CNH 43.8T5 RCNT.CNH C =TCo CNH 489.0 83 GR. CNH 19.264 RH3B.FDH 708.500 CALI.FDH 42.931 TNPH.CNH 1821.122 RCmT.CNH 242.500 CALI.CNH 2.332 DRHO.FDH 8.758 GR.~DH 43.434 TNRA.CNH 472.657 CNTC.CNH 8.754 TENS.CNH 0.068 242.500 3.508 1737.640 5544.000 END 0: DATA **** FILE TRAILER $$~m FILE NAME : EDIT .002 SERVICE : FLIC VERSION : 001~02 DATE : B9/05! 8 MAX REC SIZE : 1096 FILE TYPE : LO LAST FILE : ,~.~ TAPE TRAILER SERVICE NAME : EDIT DATE : B9/0.6! 8 ORIGIN : mLIC TAPE NAME : 73]360 CgNTINU&TION ~ : PREVIOUS T~PE : COMMENT : ARCO ALASKA, INC., KUP,~RUK., 2K-3, AP1 ~50-103-20100 **** REEL TRAILER SERVICE NAME : EDIT DATE : 89!06/ 8 ORIGIN : FLIC REEL NAME : 73360 CONTINUATION ~ : PREVIOUS REEL : COMMENT : ARCO ALASKA~ INCo, KUP,~RUK~ ZK-3,