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194-028
Wallace, Chris D (CED) From: Wallace, Chris D (CED) Sent: Friday, August 14, 2020 9:28 AM To: Travis Smith - (C) Cc: Torin Roschinger; Oliver Sternicki; Aras Worthington; Alaska NS - PB - Field Well Integrity Subject: RE: PBU 09-37 (PTD# 194-028) Injection Under Evaluation Travis, Plan as below including up to 45 days injection for monitoring and diagnostics is approved. Regards, Chris -------- Original message -------- From: "Travis Smith - (C)" <Travis.Smith@hilcorp.com> Date: 08/14/2020 8:57 AM (GMT -09:00) To: "Wallace, Chris D (CED)" <chris.wallace@alaska.gov> Cc: Torin Roschinger <Torin.Roschinger@hilcorp.com>, Oliver Sternicki <Oliver.Sternicki@hilcorp.com>, Aras Worthington <Aras.Worthington@hilcorp.com>, Alaska NS - PB - Field Well Integrity <PBField We I I Integrity@hilcorp.com> Subject: PBU 09-37 (PTD# 194-028) Injection Under Evaluation Chris: Hilcorp would like to place well 09-37 on injection under evaluation for 45 days. This under evaluation period will be in support of an application for Administrative Approval of injection. Well 09-37 was shut-in in 2017 due to rapid IA re -pressurization. The source of the re -pressurization is believed to be a low -rate leak near surface in jewelry within the coiled tubing completion. The well was secured with a tubing tail plug in 2017. On August 13, 2020 Hilcorp performed a (non -Witnessed) passing MITIA to 2200 psi. The proposed plan forward is as follows: 1. Pull the tubing tail plug. 2. Place well on injection for a 45 day Under Evaluation period. 3. Once on stabilized injection, perform AOGCC-witnessed MITIA. 4. Submit a proposal for an Administrative Approval for water injection with known IA re -pressurization. Please let me know if you have any concerns or need further information. Travis The information contained in this email message is confidential and may be legally privileged and is intended only for the use of the individual or entity named above. If you are not an intended recipient or if you have received this message in error, you are hereby notified that any dissemination, distribution, or copy of this email is strictly prohibited. If you have received this email in error, please immediately nolity us by return email or telephone if the sender's phone number is listed above, then promptly and permanently delete this message. MEMORANDUM TO: Jim Regg Qtr l I Zed P.I. Supervisor FROM: Austin McLeod Petroleum Inspector ' Well Name PRUDHOE BAY UNIT 09-37 IRSp Num: mitSAM201118151417 Rel Insp Num: NON -CONFIDENTIAL State of Alaska Alaska Oil and Gas Conservation Commission DATE: Thursday, November 19, 2020 SUBJECT: Mechanical Integrity Tests Hilcorp North Slope, LLC 09-37 PRUDHOE BAY UNIT 09-37 Src: Inspector Reviewed By: P.I. Supry� Comm API Well Number 50-029-22451-00-00 Inspector Name: Austin McLeod Permit Number: 194-028-0 Inspection Date: 11/18/2020 Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min Well o9-37 Type Inj ��' 'TVD 7627 - Tubing 1253 - 1255 - 1257 - 1260 - 1256 - 1254 - PTD 1940280 Type Test SPT Test psi 1907 IA 1221 2410 - 2366 - 2337 2312 2288 ' BBL Pumped: 0.6 BBL Returned: 0.6 OA 193 244 - 232 229 — 226 _L 223 Interval y — OTHER IP/F F MIT -IA for an AA application due to TxIA communication on Water. In temps stable. Notes: PP � J P Thursday, November 19, 2020 Page 1 of 1 Wallace, Chris D (CED) From: Alaska NS - PB - Field Well Integrity <PBFieldWelllntegrity@hilcorp.com> Sent: Wednesday, November 18, 2020 4:53 PM To: Wallace, Chris D (CED) Cc: Regg, James B (CED); Aras Worthington; Oliver Sternicki; Alaska IMS User; Alaska NS - PB - Field Well Integrity Subject: NOT OPERABLE: Injector 09-37 (PTD #1940280) failed AOGCC MIT -IA Mr. Wallace, Injector 09-37 (PTD #1940280) failed an AOGCC witnessed MIT -IA on 11/18/20. The well will now be classified as NOT OPERABLE. It will be shut-in and freeze protected when operationally feasible. The Operations Engineer will evaluate for repair options. Please respond with any questions. Andy Ogg Hilcorp Alaska LLC Field Well Integrity/ Compliance andrew.ogg@hilcorp.com P: (907) 659-5102 M: (307)399-3816 From: Alaska NS - PB - Field Well Integrity <PBFieldWelllntegrity@hilcorp.com> Sent: Sunday, November 8, 2020 6:36 AM To: chris.wallace@alaska.gov Cc: Regg, James B (CED) <jim.regg@alaska.gov>; Bo York <byork@hilcorp.com>; Aras Worthington <Aras.Worthington@hilcorp.com>; Oliver Sternicki <Oliver.Sternicki@hilcorp.com>; Alaska IMS User <akimsuser@hilcorp.com> Subject: UNDER EVALUATION: Injector 09-37 (PTD #1940280) Anomalous IA Pressure Trend Mr. Wallace, Injector 09-37 (PTD # 1940280) passed an MIT -IA on 08/20/20 which verifies two competent well barriers. The well is now classified asunder Evaluation to monitor for anomalous re -pressurization for up to 45 day (see attached). Plan Forward: 1. Operations: Put on injection 2. DHD: Perform AOGCC Witnessed MIT -IA once thermally stable 3. Well Integrity: Monitor for re -pressurization / apply for AA Please reply with any questions or concerns. Ryan Holt Hilcorp Alaska LLC Field Well Integrity/ Compliance Ryan.Holt@Hilcorp.com Wallace, Chris D (CED) From: Alaska NS - PB - Field Well Integrity <PBFieldWelllntegrity@hilcorp.com> Sent: Sunday, November 8, 2020 6:36 AM To: Wallace, Chris D (CED) Cc: Regg, James B (CED); Bo York; Aras Worthington; Oliver Sternicki; Alaska IMS User Subject: UNDER EVALUATION: Injector 09-37 (PTD #1940280) Anomalous IA Pressure Trend Attachments: RE: [EXTERNAL] RE: PBU 09-37 (PTD# 194-028) Injection Under Evaluation Mr. Wallace, Injector 09-37 (PTD # 1940280) passed an MIT -IA on 08/20/20 which verifies two competent well barriers. The well is now classified as Under Evaluation to monitor for anomalous re -pressurization for up to 45 day (see attached). Plan Forward: 1. Operations: Put on injection 2. DHD: Perform AOGCC Witnessed MIT -IA once thermally stable 3. Well Integrity: Monitor for re -pressurization /apply for AA Please reply with any questions or concerns. Ryan Holt Hilcorp Alaska LLC Field Well Integrity/Compliance Rva n. HoItCe1 Hilcorp.com P:(907)659-5102 M:(907)232-1005 TqQ.m: AK, GWO Well Integrity Engineer Sent: day, October 8, 2017 2:24 PM To: AK, Gompletions Well Integrity <AKDCWLCompletionsSupt@bp.com>; AK, GWO SUPT Well Integrity <AKDCWelllntegri oordinator@bp.com>; AK, OPS FS2 OSM <AKOPSFS2OSM1@bp.com>; AK, OPS FS2 DS Ops Lead <AKOPSF52DSOpsLea .com>; AK, OPS FS2 Facility OTL <AKOPSFS2FacilityOTL@bp.com>; AK, OPS FS2 Field OTL <AKOPSFS2Fie IdOTL@bp.com>, OpsProdEOCTL <AKOPSPCCEOCTL@bp.com>; AK, GWO SUPT Slickline <akdcWirelineoperationssuperinten bp.com>; AK, GWO SUPT Special Projects <akdcWellservicesoperationssuperintendent com>; Cismoski, Doug A <CismosDA@BP.com>; Daniel, Ryan <Ryan.Daniel@bp.com>; AK, RES GPB East Wells Op r <AKRESGPBEastWellsOptEngr@bp.com>; AK, OPS EOC Specialists <AKOPSEOCSpecialists@bp.com>; AK, OPS PCC Lead <AKOPSPCCOpsLead@bp.com>; AK, RES GPB West Wells Opt Engr <AKRESGPBWestWellsOpt@BP.com>; G GPB FS2 bri4lltls <ggpbfs2drillsites@BP.com>; 'Regg, James B (DOA) Qim.regg@alaska.gov)'<jim.regg@alaska.gov>;'chris.wallace@a.gov' <chris.wallace@alaska.gov>; Stechauner, Bernhard <Bernhard.Stechauner@bp.com> Cc: AK, GWO DHD Well Integrity <AKD&CDHDWelllntegri@bp.com>; AK, GWO SUP II Integrity <AKDCWellintegrityCoordinator@bp.com>; AKIMS App User <akimsuser.service@bp.com , empsey, David G <David.Dem pseyl@bp.com>; Hibbert, Michael <Michael.Hibbert@BP.com>; Janowski, Carrie <Carrie.Janowski@bp.com>; Montgomery, Travis <Travis.Montgomery@bp.com>; Munk,( .0reY unk,Corey <Corey.Munk@bp.com>; Obrigewitch, Beau <BEAU.OBRIGEWITCH@bp.com>; Sternicki, Oliver R <Oliver.Sternicki@bp.com>; Worthington, Aras 1 <Aras.Worthington@bp.com> Subject: NOT OPERABLE: Injector 09-37 (PTD #1940280) Anomalous IA Pressure Trend All, Wallace, Chris D (CED) From: Travis Smith - (C) <Travis.Smith@hilcorp.com> Sent: Friday, August 14, 2020 8:58 AM To: Wallace, Chris D (CED) Cc: Torin Roschinger; Oliver Sternicki; Aras Worthington; Alaska NS - PB - Field Well Integrity Subject: PBU 09-37 (PTD# 194-028) Injection Under Evaluation Chris Hilcorp would like to place well 09-37 on injection under evaluation for 45 days. This under evaluation period will be in support of an application for Administrative Approval of injection. Well 09-37 was shut-in in 2017 due to rapid IA re -pressurization. The source of the re -pressurization is believed to be a low -rate leak near surface in jewelry within the coiled tubing completion. The well was secured with a tubing tail plug in 2017. On August 13, 2020 Hilcorp performed a (non -Witnessed) passing MITIA to 2200 psi. The proposed plan forward is as follows: 1. Pull the tubing tail plug. 2. Place well on injection for a 45 day Under Evaluation period. 3. Once on stabilized injection, perform AOGCC-witnessed MITIA. 4. Submit a proposal for an Administrative Approval for water injection with known IA re -pressurization. Please let me know if you have any concerns or need further information. Travis The information contained in this email message is confidential and may be legally privileged and is intended only for the use of the individual or entity named above. If you are not an intended recipient or if you have received this message in error, you are hereby notified that any dissemination, distribution, or copy of this email is strictly prohibited. If you have received this email in error, please immediately notify us by return email or telephone if the sender's phone number is listed above, then promptly and permanently delete this message. While all reasonable care has been taken to avoid the transmission of viruses, it is the responsibility of the recipient to ensure that the onward transmission, opening, or use of this message and any attachments will not adversely affect its systems or data. No responsibility is accepted by the company in this regard and the recipient should carry out such virus and other checks as it considers appropriate. • Wallace, Chris D (DOA) From: AK, GWO Well Integrity Engineer <AKGWOWellSiteEnginee@bp.com> Sent: Sunday, December 24, 2017 3:28 PM To: AK, GWO Well Integrity Engineer;AK, OPS EOC Specialists;AK, OPS FS2 DS Ops Lead; AK, OPS FS2 Facility OTL;AK, OPS FS2 Field OTL;AK, OPS FS2 OSM;AK, RES GPB East Wells Opt Engr;AK, RES GPB West Wells Opt Engr;AKOpsProdEOCTL;Chamansingh, Ann Marie;G GPB FS2 Drillsites; Nottingham, Derek; Stechauner, Bernhard;Wallace, Chris D (DOA) Cc: AK, GWO Completions Well Integrity;AK, GWO DHD Well Integrity;AK, GWO Projects Well Integrity;AK, GWO SUPT Well Integrity;AK, OPS FF Well Ops Comp Rep;AKIMS App User; Cismoski, Doug A; Daniel, Ryan; Dempsey, David G; Hibbert, Michael; Janowski, Carrie; Montgomery,Travis J; Munk, Corey; Obrigewitch, Beau;O'connor, Katherine;Sternicki, Oliver R;Tempel,Joshua;Worthington,Aras J; Regg,James B (DOA); AK, GWO Well Integrity Well Information Subject: NOT OPERABLE: Injector 09-37 (PTD#1940280) Leak detection log complete,well secured All, Injector 09-37 (PTD#1940280)was made under evaluation on 12/3/17 to facilitate diagnostic work for TxIA communication. The planned leak detection log is now complete and the well was secured with a tubing tail plug on 12/22/2017. At this time the well is reclassified as Not Operable and will remain shut in. The production engineer will evaluate for a plan forward. Please respond with any questions, Joshua Stephens Well Integrity Engineer Office: 907-659-8110 Cell: 907-341-9068 WO SCANNED F • • 4,K GWO Well Integrity Engineer Sent: Sunday, :- -•. •er 03, 2017 10:21 AM To: AK, OPS EOC Specialis s, • , •• FS2 DS Ops Lead; AK, OPS FS2 Facility OTL; AK, OPS FS2 Field OTL; AK, OPS FS2 OSM; AK, RES GPB East Wells Opt Engr; ' ', • PB West Wells Opt Engr; AKOpsProdEOCTL; Chamansingh, Ann Marie; G GPB FS2 Drillsites; Nottingham, Derek; Stechauner, :- -•- d• 'chris.wallace@alaska.gov' Cc: AK, GWO Completions Well Integrity; AK, GWO DHD Well Inte. .- • •K, GWO Projects Well Integrity; AK, GWO SUPT Well Integrity; AK, GWO Well Integrity Well Information; AK, OPS FF Well •• . Rep; AKIMS App User; Cismoski, Doug A; Daniel, Ryan; Dempsey, David G; Hibbert, Michael; Janowski, Carrie; Montgo • Travis 3; Munk, Corey; Obrigewitch, Beau; O'connor, Katherine; Sternicki, Oliver R; Tempel, Joshua; Worthington, Ara ; '•egg, James B (DOA) 1 k°►24.02A 410 2-701‘15-t WELL LOG TRANSMITTAL#904349592 To: Alaska Oil and Gas Conservation Comm. November 7, 2017 Attn.: Makana Bender RECEIVED 333 West 7th Avenue, Suite 100 DATA LOGGED /111/2015 Anchorage, Alaska 99501 DEC 2 2 2017 M. K. BENDER RE: Leak Detect Log w/ACX: 09-37 AOGCC Run Date: 10/5/2017 The technical data listed below is being submitted herewith. Please address any problems or concerns to the attention of: Chris Gullett, Halliburton Wireline &Perforating, 6900 Arctic Blvd., Anchorage, AK 99518 09-37 Digital Log Image files 1 CD Rom 50-029-22451-00 Leak Detection Log SO* L5 1 Color Log 50-029-22451-00 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Halliburton Wireline & Perforating Attn: Chris Gullett 6900 Arctic Blvd. Anchorage, Alaska 99518 Office: 907-273-3527 FRS_ANC@halliburton.com Date: Signed: 72 Z L 13....eAeat • • Wallace, Chris D (DOA) From: AK, GWO Well Integrity Engineer <AKGWOWellSiteEnginee@bp.com> Sent: Sunday, December 3, 2017 10:21 AM To: AK, OPS EOC Specialists;AK, OPS FS2 DS Ops Lead;AK, OPS FS2 Facility OTL;AK, OPS FS2 Field OIL;AK, OPS FS2 OSM;AK, RES GPB East Wells Opt Engr;AK, RES GPB West Wells Opt Engr;AKOpsProdEOCTL; Chamansingh,Ann Marie;G GPB FS2 Drillsites; Nottingham, Derek; Stechauner, Bernhard;Wallace, Chris D (DOA) Cc: AK, GWO Completions Well Integrity;AK, GWO DHD Well Integrity;AK, GWO Projects Well Integrity;AK, GWO SUPT Well Integrity;AK, GWO Well Integrity Well Information; AK, OPS FF Well Ops Comp Rep;AKIMS App User;Cismoski, Doug A; Daniel, Ryan; Dempsey, David G; Hibbert, Michael;Janowski, Carrie; Montgomery, Travis J; Munk, Corey;Obrigewitch, Beau;O'connor, Katherine;Sternicki, Oliver R;Tempel,Joshua; Worthington,Aras J; Regg,James B (DOA) Subject: UNDER EVALUATION: Injector 09-37 (PTD#1940280) put on injection to perform leak detect log All, Produced water injector 09-37 (PTD#1940280)was made Not Operable on 10/08/2017 due to rapid IA repressurization while online. On 10/06/17 Eline ran a leak detect log but could not locate the source of the leak.The well will placed Under Evaluation and put on injection so another leak detect log can be performed with a different leak detect tool. Plan forward: 1. Operations: Put on Injection 2. E-line: Leak Detect Log 3. Slickline:Set tubing tail plug for secure Please respond if in conflict with plan. Andrew Ogg Well Integrity Engineer BP Global Wells Organization-Alaska Office:907-659-8110 SCANNED . Cell:307-399-3816 1 • • Wallace, Chris D (DOA) From: AK, GWO Well Integrity Engineer <AKGWOWellSiteEnginee@bp.com> Sent: Sunday, October 8, 2017 2:24 PM To: AK, GWO Completions Well Integrity;AK, GWO SUPT Well Integrity;AK, OPS FS2 OSM; AK, OPS FS2 DS Ops Lead;AK, OPS FS2 Facility OTL;AK, OPS FS2 Field OTL; AKOpsProdEOCTL;AK, GWO SUPT Slickline;AK, GWO SUPT Special Projects; Cismoski, Doug A; Daniel, Ryan;AK, RES GPB East Wells Opt Engr;AK, OPS EOC Specialists;AK, OPS PCC Ops Lead;AK, RES GPB West Wells Opt Engr; G GPB FS2 Drillsites; Regg,James B (DOA);Wallace, Chris D (DOA); Stechauner, Bernhard Cc: AK, GWO DHD Well Integrity;AK, GWO SUPT Well Integrity;AKIMS App User; Dempsey, David G; Hibbert, Michael;Janowski, Carrie; Montgomery, Travis J; Munk, Corey; Obrigewitch, Beau; Sternicki, Oliver R;Worthington, Aras J Subject: NOT OPERABLE: Injector 09-37 (PTD#1940280)Anomalous IA Pressure Trend All, Eline has finished running a leak detect log on Injector 09-37 (PTD#1940280). This round of diagnostics is complete. The well will now be re-classified as NOT OPERABLE as we continue forward with plan: 1. Well Integrity Engineer: Reclassify Under Evaluation- Complete 2. Operations: Put on injection- Complete 3. DHD: Perform MIT-IA &obtain Liquid Leak Rate—Passed MIT-IA 4. E-Line &Fullbore: Perform leak detection log- Complete 5. DHD: Monitor IA stabilization 6. APE/WIC: Additional diagnostics, repair or AA for continued operation. Please reply if in conflict with proposed plan. Andrew Ogg Well Integrity Engineer BP Global Wells Organization—Alaska Office: 907-659-8110 SCANNED Cell: 307-399-3816 From: AK, GWO Well Inte• ty Engineer Sent: Thursday, October 05, 11:24 AM To: AK, GWO Completions Well Inte. ' ; AK, GWO SUPT Well Integrity; AK, OPS FS2 OSM; AK, OPS FS2 DS Ops Lead; AK, OPS FS2 Facility OTL; AK, OPS FS2 1- - OTL; AKOpsProdEOCTL; AK, GWO SUPT Slickline; AK, GWO SUPT Special Projects; Cismoski, Doug A; Daniel, Ryan; AK, • - GPB East Wells Opt Engr; AK, OPS EOC Specialists; AK, OPS PCC Ops Lead; AK, RES GPB West Wells Opt Engr; G GPB FS2 ''sites; 'Regg, James B (DOA) (jim.regg@alaska.gov)'; 'chris.wallace@alaska.gov'; Stechauner, Bernhard Cc: AK, GWO DHD Well Integrity; AK, GWO SUPT Well Integrity, KIMS App User; Dempsey, David G; Hibbert, Michael; Janowski, Carrie; Montgomery,Travis J; Munk, Corey; Obrigewitch, : •u; Sternicki, Oliver R; Worthington, Aras J Subject: UPDATE 10/05/17 - UNDER EVALUATION: Injector 09-37 (PTD 940280)Anomalous IA Pressure Trend All, 1 • • Wallace, Chris D (DOA) From: AK, GWO Well Integrity Engineer <AKGWOWellSiteEnginee@bp.com> Sent: Thursday, September 14, 2017 1:11 PM To: AK, GWO Completions Well Integrity;AK, GWO SUPT Well Integrity;AK, OPS FS2 OSM; AK, OPS FS2 DS Ops Lead;AK, OPS FS2 Facility OTL;AK, OPS FS2 Field OTL; AKOpsProdEOCTL;AK, GWO SUPT Slickline;AK, GWO SUPT Special Projects; Cismoski, Doug A; Daniel, Ryan;AK, RES GPB East Wells Opt Engr;AK, OPS EOC Specialists;AK, OPS PCC Ops Lead;AK, RES GPB West Wells Opt Engr;G GPB FS2 Drillsites; Regg,James B (DOA);Wallace, Chris D (DOA); Stechauner, Bernhard Cc: AK, GWO DHD Well Integrity;AK, GWO SUPT Well Integrity;AKIMS App User; Dempsey, David G; Hibbert, Michael;Janowski, Carrie; Montgomery,Travis J; Munk, Corey; Obrigewitch, Beau; Sternicki, Oliver R;Worthington,Aras J Subject: UNDER EVALUATION: Injector 09-37 (PTD#1940280)Anomalous IA Pressure Trend All; Injector 09-37 (PTD#1940280)passed a state witness MIT-IA on 09/12/17. The well has begun to exhibit slow IA repressurization indicating possible TxIA communication. The well will remain Under Evaluation for the remainder of the 28 day clock for diagnostics. Plan Forward: 1. Well Integrity Engineer: Reclassify Under Evaluation- Complete 2. Operations: Put on injection- Complete 3. DHD: Perform MIT-IA &obtain Liquid Leak Rate—Passed MIT-IA 4. E-Line& Fullbore: Perform leak detection log- Cancelled 5. DHD: Monitor IA stabilization 6. APE/WIC: Additional diagnostics, repair or AA for continued operation. Please reply if in conflict with proposed plan. Matt Ross (Alternate: Josh Stephens) Well Integrity Engineering Office 907-659-8110 }--E> • 9 201 Cell 907-980-0552 �`ANNEQ Harmony 4530 Fro : A , S Well Integrity Engineer Sent: Thursday, Se. - ser 07, 2017 12:50 PM To: AK, GWO Well Integrity •••--r• AK, GWO Completions Well Integrity; AK, GWO SUPT Well Integrity; AK, OPS FS2 OSM; AK, OPS FS2 DS Ops Lead; AK, 0• acility OTL; AK, OPS FS2 Field OTL; AKOpsProdEOCTL; AK, GWO SUPT Slickline; AK, GWO SUPT Special Projects; Cismoski, •.,• • Daniel, Ryan; AK, RES GPB East Wells Opt Engr; AK, OPS EOC Specialists; AK, OPS PCC Ops Lead; AK, RES GPB West '- •it Engr; G GPB FS2 Drillsites; 'Regg, James B (DOA) (jim.regg@alaska.gov)'; 'chris.wallace@alaska.gov'; Stechauner, Bern . Cc: AK, GWO DHD Well Integrity; AK, GWO SUPT Well Integrity; AKIMS App s- • Dempsey, David G; Hibbert, Michael; Janowski, Carrie; Montgomery,Travis J; Munk, Corey; Obrigewitch, Beau; Sternicki, 0 i •• Worthington, Aras J Subject: UNDER EVALUATION: Injector 09-37 (PTD #1940280) Place on Injection for leak de og All, 1 • • MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission DATE: Wednesday,September 13,2017 TO: Jim Regg \1 .Supervisor 61 ? zz(17 SUBJECT: Mechanical Integrity Tests BP EXPLORATION(ALASKA)INC. • 09-37 FROM: Jeff Jones PRUDHOE BAY UNIT 09-37 Petroleum Inspector Src: Inspector Reviewed By).— P.I. y.-P.I.Supry NON-CONFIDENTIAL Comm Well Name PRUDHOE BAY UNIT 09-37 API Well Number 50-029-22451-00-00 Inspector Name: Jeff Jones Permit Number: 194-028-0 Inspection Date: 9/12/2017 Insp Num: mitJJ170912195313 Rel Insp Num: Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min Well I 09-37 Type Inj W ' TVD 7627 - Tubing 914 913 - 905 - 917 - PTD { 1940280 - Type Test SPT Test psi 1907 - IA 917 2295 ' 2225 - 2207 - BBL Pumped: 1 - 'BBL Returned: 0.5 - OA 229 - 296 289 _ 284 Interval 4YRTST P/F P ✓ Notes: 1 well inspected,no exceptions noted. SCANNED I3 Lij Wednesday,September 13,2017 Page 1 of 1 • • Wallace, Chris D (DOA) From: AK, GWO Well Integrity Engineer <AKGWOWellSiteEnginee@bp.com> Sent: Thursday, September 7, 2017 12:50 PM To: AK, GWO Well Integrity Engineer;AK, GWO Completions Well Integrity;AK, GWO SUPT Well Integrity;AK, OPS FS2 OSM;AK, OPS FS2 DS Ops Lead;AK, OPS FS2 Facility OTL; AK, OPS FS2 Field OTL;AKOpsProdEOCTL;AK, GWO SUPT Slickline;AK, GWO SUPT Special Projects; Cismoski, Doug A; Daniel, Ryan;AK, RES GPB East Wells Opt Engr;AK, OPS EOC Specialists;AK, OPS PCC Ops Lead;AK, RES GPB West Wells Opt Engr; G GPB FS2 Drillsites; Regg,James B (DOA);Wallace, Chris D (DOA); Stechauner, Bernhard Cc: AK, GWO DHD Well Integrity;AK, GWO SUPT Well Integrity;AKIMS App User; Dempsey, David G; Hibbert, Michael;Janowski, Carrie; Montgomery,Travis J; Munk, Corey; Obrigewitch, Beau; Sternicki, Oliver R;Worthington,Aras J Subject: UNDER EVALUATION: Injector 09-37 (PTD#1940280) Place on Injection for leak detect log All, Injector 09-37 (PTD#1940280) was made not operable after failing a MIT-IA. The AOGCC has granted permission to place the well on injection up to 7 days for integrity diagnostics. At this time the well is classified as Under Evaluation and is approved to be on injection for 7 days. Plan Forward: 1. Well Integrity Engineer: Reclassify Under Evaluation 2. Operations: Put on injection 3. DHD: Perform MIT-IA &obtain Liquid Leak Rate 4. E-Line&Fullbore: Perform leak detection log 5. Well Integrity Engineer: Reclassify Not Operable 6. Slickline& Fullbore: Secure well after completion of all above steps Please reply if in conflict with proposed plan. Matt Ross (Alternate: Josh Stephens) Well Integrity Engineering ® 1, Office 907-659-8110 SCORED Cell 907-980-0552 Harmony 4530 1 . • Wallace, Chris D (DOA) From: Wallace, Chris D (DOA) ( q 4 Sent: Friday,August 18, 2017 7:45 AM To: AK, GWO Well Integrity Engineer Cc: AK, GWO SUPT Well Integrity Subject: RE: Request to place well 09-37 under evaluation for integrity diagnostics Matt, Thank you for the call and email. The plan as detailed below is approved. Thanks and Regards, Chris Wallace,Sr.Petroleum Engineer,Alaska Oil and Gas Conservation Commission,333 West 7th Avenue,Anchorage,AK 99501,(907)793-1250 (phone),(907)276-7542(fax),chris.wallacePalaska.Rov CONFIDENTIALITY NOTICE:This e-mail message,including any attachments,contains information from the Alaska Oil and Gas Conservation Commission (AOGCC),State of Alaska and is for the sole use of the intended recipient(s). It may contain confidential and/or privileged information.The unauthorized review, use or disclosure of such information may violate state or federal law. If you are an unintended recipient of this e-mail, please delete it,without first saving or forwarding it, and,so that the AOGCC is aware of the mistake in sending it to you, contact Chris Wallace at 907-793-1250 or chris.wallace@alaska.gov. From:AK,GWO Well Integrity Engineer [mailto:AKGWOWellSiteEnginee@bp.com] Sent:Thursday,August 17, 2017 4:14 PM To:Wallace, Chris D(DOA)<chris.wallace@alaska.gov> Cc:AK,GWO SUPT Well Integrity<AKDCWelllntegrityCoordinator@bp.com> Subject: Request to place well 09-37 under evaluation for integrity diagnostics Chris; As discussed today, BP would like to make well 09-37 under evaluation and placed on produced water injection for 7 days to perform a leak detect log. Here's the recent history on this well; on June 3rd,we performed a passing MIT- IA prior to the state witnessed test. On June 5th the well failed a witnessed MIT-IA. We have since tested the pack offs on the tubing,which passed. Today,we performed another MIT-IA,which did pass. However, it took l lbbls to fill up indicating a down hole issue. Please see the attached well service reports and well bore schematic. SCANNED AUG 2 1 i7 1 • • MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: Jim Regg DATE: Thursday,July 27,2017 P.I.Supervisor 7 '7 SUBJECT:Mechanical Integrity Tests / �'I 1 7 BP EXPLORATION(ALASKA)INC. 09-37 FROM: Chuck Scheve PRUDHOE BAY UNIT 09-37 Petroleum Inspector Src: Inspector Reviewed By: P.I.Supry 131— NON-CONFIDENTIAL Comm Well Name PRUDHOE BAY UNIT 09-37 API Well Number 50-029-22451-00-00 Inspector Name: Chuck Scheve Permit Number: 194-028-0 Inspection Date: 6/5/2017 Insp Num: mitCS170727105801 Rel Insp Num: Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min Well 09-37 Type Inj W' TVD 7627 Tubing 1460 1460 ` 1460 - PTD 1940280 ' Type Test SPT Test psi 1907 IA 2124 2294 2221, BBL Pumped: 0.2 BBL Returned: 1.4 OA 556 565 - 560 Interval OTHER P/F F /, Notes: A third attempt to test IA was aborted after 15 min due to matching results from second test. In total just over 2 bbl was pumped and 1.4 bbls returned. scow® sEP 2 2 ,?rl ly: Thursday,July 27,2017 Page 1 of 1 • • MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission DATE: Thursday,July 27,2017 TO: Jim Regg 7127'/"I P.I.Supervisor /� SUBJECT: Mechanical Integrity Tests l BP EXPLORATION(ALASKA)INC. 09-37 FROM: Chuck Scheve PRUDHOE BAY UNIT 09-37 Petroleum Inspector Src: Inspector Reviewed By: P.I.Supry T-6/2— NON-CONFIDENTIAL Comm Well Name PRUDHOE BAY UNIT 09-37 API Well Number 50-029-22451-00-00 Inspector Name: Chuck Scheve Permit Number: 194-028-0 Inspection Date: 6/5/2017 Insp Num: mitCS170606125351 Rel Insp Num: Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min Well 09-37 Type Inj W- TVD 7627 Tubing 1457 1454 . 1461 1460 . PTD 1940280 Type Test SPT Test psi 1907 IA 1957 2269 2196- 2124. BBL Pumped: 0,5 BBL Returned: 1.4 OA 559 566 - 561 556 Interval OTHER P/F F ✓ Notes: Second attempt,well was repressured with same results. WAKED SEP 2 2 .-- Thursday,July 27,2017 Page 1 of 1 • • Nit 0q-37 Prot14z Regg, James B (DOA) From: Regg,James B (DOA) Sent: Wednesday, July 5, 2017 3:18 PM -'7l —7/141-7 To: AK, GWO Well Integrity Well Information; AK, GWO Projects Well Integrity;Wallace, Chris D (DOA); Brooks, Phoebe L (DOA) Cc: AK, GWO SUPT Well Integrity; AK, GWO Well Integrity Engineer; Bixby, Brian D (DOA) Subject: RE:June 2017 MIT Forms Attachments: MIT PBU 09-37 6-5-17 revised.xlsx; MIT PBU R-13 6-22-17 reivsed.xlsx; MIT PBU WGI-08 6-10-17 revised.xlsx ✓PBU 09-37 (PTD 1940280): all 3 attempts are failed tests PBU R-13 (PTD ): deleted "Chuck Scheve waved witness" (AOGCC rep) PBU WGI-08 (PTD 1900490): Increasing pressure on tested annulus does not equate to stabilization(failed test per our requirements, inconclusive at best); should have monitored pressure for additional 15-30 minutes. Revised reports attached. Jim Regg Supervisor, Inspections AOGCC NED `' F' 333 W.7th Ave,Suite 100 SCAN w ?`' Anchorage,AK 99501 907-793-1236 CONFIDENTIALITY NOTICE:This e-mail message,including any attachments,contains information from the Alaska Oil and Gas Conservation Commission(AOGCC),State of Alaska and is for the sole use of the intended recipient(s).It may contain confidential and/or privileged information. The unauthorized review,use or disclosure of such information may violate state or federal law.If you are an unintended recipient of this e-mail, please delete it,without first saving or forwarding it,and,so that the AOGCC is aware of the mistake in sending it to you,contact Jim Regg at 907- 793-1236 or iim.regg@alaska.gov. From:AK, GWO Well Integrity Well Information [mailto:akgwowellintegritywe@bp.com] Sent:Sunday,July 2, 2017 5:58 AM To:AK, GWO Projects Well Integrity<AKDCProjectsWelllntegrityEngineer@bp.com>; Regg,James B (DOA) <jim.regg@alaska.gov>; Wallace, Chris D (DOA) <chris.wallace@alaska.gov>; Brooks, Phoebe L(DOA) <phoebe.brooks@alaska.gov> Cc:AK, GWO SUPT Well Integrity<AKDCWelllntegrityCoordinator@bp.com>; AK, GWO Well Integrity Engineer <AKGWOWellSiteEnginee@bp.com> Subject:June 2017 MIT Forms All, Attached are the filled out AOGCC MIT forms for tests performed by BP in June of 2017. Well: PTD: Notes: DS09-37 1940280 AA 04E.000 Well Failed an AOGCC MIT-IA on 06/05/17 and was made not operable DS13-06 1972180 AA 4F.004 for shallow packer depth.: Passed MIT-IA on 6/19/2017 DS13-24 2042430 AA 4E.037 for TxIA communication: Passed MIT-IA on 6/5/17 A-08 1740040 AA 3.019 for slow TxIA communication: Passed MIT-IA on 6/10/2017 R-13 1830440 MIT-IA passed on 6/22/2017 1 • • • • STATE OF ALASKA • ALASKA OIL AND GAS CONSERVATION COMMISSION • Mechanical Integrity Test Submit to: jim.regq(cDalaska.aov' AOGCC.Inspectors(6alaska.00v phoebe.brooksalalaska.clov c7ri�s.w�l allace(Btalaska.aov OPERATOR: BP Exploration(Alaska),Inc. • l 1/51(7 FIELD!UNIT!PAD: Prudhoe Bay/PBU/DS09 DATE: 06/05/17 OPERATOR REP: Mike Zimmer AOGCC REP: Well 09-37 Pressures: Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. • PTD 1940280 Type Inj W ' Tubing 1453 - 1456 ' 1464- 1467W 1457' Type Test P Packer TVD 7627 ' BBL Pump 1.5 ". IA 328 • 2290 - 2158 " 2058• 1957 ' Interval 0 :/- Test Test psi 1907 " BBL Return OA 477• 582 - 574 • 566 ' 558' Result F Notes: Pre AA application test. Well 09-37 Pressures: Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. PTD 1940280 Type Inj W • Tubing 1457 • 1454" 1461 • 1460 ' Type Test 1 Packer TVD 7627 BBL Pump 0.5 . IA 1957 2269 2196 2124 Interval 0 v Test psi 1907 BBL Return OA 558 566 561 556 Result f ...- Notes:Notes: Well 09-37 Pressures: Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. PTD 1940280 Type Inj W Tubing 1460- 1460' 1460- Type Test 'F Packer TVD 7627 BBL Pump 0.2 IA 2124 • 2294, 2221 Interval 0 Test psi 1907 BBL Return 1.4 - OA 556 565 560 Result 1: Notes: Well Pressures: Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. PTD Type Inj Tubing Type Test Packer TVD BBL Pump IA Interval Test psi BBL Return OA Result Notes: Well Pressures: Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. PTD Type Inj Tubing Type Test Packer TVD BBL Pump IA Interval Test psi BBL Return OA Result Notes: Well Pressures: Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. PTD Type In) Tubing Type Test Packer TVD BBL Pump IA Interval • Test psi BBL Return OA Result • Notes: • Well Pressures: Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. PTD Type Inj Tubing Type Test Packer TVD BBL Pump IA Interval Test psi BBL Return_ OA Result . Notes: Well Pressures: Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. PTD Type Inj Tubing Type Test Packer TVD BBL Pump IA Interval Test psi BBL Return OA Result Notes: TYPE INJ Codes TYPE TEST Codes INTERVAL Codes Result Codes W=Water P=Pressure Test I=Initial Test P=Pass G=Gas 0=Other(describe in Notes) 4=Four Year Cycle F=Fail S=Slurry V=Required by Variance I=Inconclusive I=Industrial Wastewater 0=Other(describe in notes) N=Not Injecting Form 10-426(Revised 01/2017) MIT PBU 09-37 6-5-2017 • • MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: Jim Regg DATE: Thursday,June 15,2017 I P.I.Supervisor Co( SUBJECT: Mechanical Integrity Tests BP EXPLORATION(ALASKA)INC. 09-37 FROM: Chuck Scheve PRUDHOE BAY UNIT 09-37 Petroleum Inspector Src: Inspector Reviewed By: P.I.Supry NON-CONFIDENTIAL Comm Well Name PRUDHOE BAY UNIT 09-37 API Well Number 50-029-22451-00-00 Inspector Name: Chuck Scheve Permit Number: 194-028-0 Inspection Date: 6/5/2017 Insp Num: mitCS170606125351 Rel Insp Num: Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min Well 09-37 - Type Inj W TVD 7627 - Tubing 1457 1454 - 1461 - 1460 - PTD 1940280 - Type Test SPT Test psi 1907 " IA 1957 2269 . 2196 _ 2124 - BBL Pumped: 0.5BBL Returned: 1.4 OA 559 566 561 556 Interval OTHER P/F F Notes: Second pt, Well was repressured with same results. A third attempt to test IA was aborted after 15 mm due to matching results from second test. In total just over 2 bbl was pumped and 1.4 bbls returned SCAt'iHED AUG 3 0 2017 Thursday,June 15,2017 Page I of 1 • • MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: Jim Regg DATE: Thursday,June 15,2017 P.I.Supervisor le 7-0( 1 7 SUBJECT: Mechanical Integrity Tests BP EXPLORATION(ALASKA)INC. 09-37 FROM: Chuck Scheve PRUDHOE BAY UNIT 09-37 Petroleum Inspector Src: Inspector Reviewed By: P.I.Supry NON-CONFIDENTIAL Comm Well Name PRUDHOE BAY UNIT 09-37 API Well Number 50-029-22451-00-00 Inspector Name: Chuck Scheve Permit Number: 194-028-0 Inspection Date: 6/5/2017 Insp Num: mitCS170606124716 Rel Insp Num: Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min Well 09-37 (Type Inj W" TVD 7627 • Tubing 1453 1456 1464 - 1467 - 1457 PTD 1940280 Type Test SPT Test psi 1907 - IA1 328 2290 -1 2158 2058 - 1957 BBL Pumped: 1.5 /BBL Returned: j OA 477 582 574 - 566- 559 _ Interval OTHER P/F F Notes: Pre AA application ,i rQyl' I ,, z-- SCANNED i\UG 3 0 2017, Thursday,June 15,2017 Page 1 of 1 • S Wallace, Chris D (DOA) From: AK, GWO Well Integrity Engineer <AKGWOWellSiteEnginee@bp.com> Sent: Friday,June 9, 2017 3:28 PM To: AK, GWO Completions Well Integrity;AK, GWO SUPT Well Integrity;AK, OPS FS2 OSM; AK, OPS FS2 DS Ops Lead;AK, OPS FS2 Facility OTL;AK, OPS FS2 Field OTL; AKOpsProdEOCTL;AK, GWO SUPT Slickline;AK, GWO SUPT Special Projects;Cismoski, Doug A; Daniel, Ryan;AK, RES GPB East Wells Opt Engr;AK, OPS EOC Specialists;AK, OPS PCC Ops Lead;AK, RES GPB West Wells Opt Engr;G GPB FS2 Drillsites; Regg,James B (DOA);Wallace, Chris D (DOA); Stechauner, Bernhard Cc: AK, GWO DHD Well Integrity;AK, GWO SUPT Well Integrity;AK, GWO Well Integrity Well Information;AKIMS App User; Dempsey, David G; Hibbert, Michael;Janowski, Carrie; Montgomery,Travis J; Munk, Corey; Obrigewitch, Beau; Sternicki, Oliver R; Worthington,Aras J Subject: NOT OPERABLE:: Injector 09-37 (PTD#1940280)AOGCC MIT-IA Failed Attachments: 09-37.pdf All, Injector 09-37 (PTD#1940280)was made under evaluation on 05/28/17 to assess a remedial cement packer squeeze. A subsequent AOGCC witnessed MIT-IA failed on 06/05/17 indicating a lack of two competent wellbore barriers. At this time the well is classified as Not Operable and must be shut in as soon as operationally possible. Plan Forward: 1. Wellhead: PPPOT-T—Passed 06/08/17 2. Slickline: Secure well with TTP 3. Fullbore: FP TBG, MIT-T, CMIT-TxIA 4. Production Engineer: Develop plan forward Please reply with any questions, Joshua Stephens SCANNED UN I 20!.', Well Integrity Engineer Office: 907-659-8110 Cell: 907-341-9068 WO rear%MO.r.rrw..ae. 1 TREE 4'RAC • 09-37 SA�NOTES: WRLHEAD= CNV ACTUATOR= BAKER C KB.a.EV= 46.7 J /if .I 28' –10-3/4"X 9-5/8"XO,D=8.835" BF.LEl/ KOP= 4057' CONDUCTOR, –{ ? Max Angle= 50"@ 5734' _It, 2981' –{3-1/2 CAM DS SSSV NP,D=2.812" Datum ND= 10444' ID= Datum TVD= 8800'SS 10-3/4"CSG,45.5#,L80 BTC,ID=9.953" –1 28' 9-5/8"CSG,40#,L80 BTC,D=8.835' H 3630' Minimum ID =225" @ 9020' 2-7/8" OTIS 'XN' NIPPLE 1 r—I 7999' 5-1/2"PARKER SWS NP,D=4.562" (MOD TBG) ESTIMATED TOP OF CBNB IT(06/22/10) -- --8850 1 8970'-8973' HTBG PUNCH(08/05/09) 8985' –I3-1/2"OTIS XN NP,D=2.75' 8992' --15-112"OTIS XN NW,D=4.46"(8ENNO TBG) 3-1/2'TBG-CT,7#,QT800,.0093 bpf,D=3.094" --I 8992' 8993' H3-1/2"X 2-7/8"XO,D=2.375" 8993' –I2-718"LOC SEAL UNIT,EST.TOP OF CEMENT N 2-7/8"TBG(06/22/10) –{ 8992' D=2.375' 8993' 5-1/2"SBR MN LOCK,D=3.00" MILLED SHEATH,ID=2.36"(07/06/15) H 8992'-9010' k 8994' –13-1/2"SBR EXTENSION,D=3.00' 9004' –13-1/2"NDEXNG MULESHOE,D=2.375' • 9010' –2-7/8"QUICKDRL.L RUG(08/03/09) 9020' –2-7/8"OTIS XN NP,D=2.25 2-7/8'TBG,6.5#,L-80,.0058 bpf,D=2.441" – 9028' 1—/ I 9026' –12-7/8"MULESHOE WLEG,I D=2.441' -1 B-ND-TT-NOT LOGGED PERFORATION SUMMARY REF LOG:SWS CM-G ON 08/21/94 ANGLE AT TOP PBRF:22"@ 10436' Pbte:Refer to Production DB for historical pert data SIZE SPF NTBRVAL Opn/Sqz SHOT SQZ 2" 6 +10436.10442 0 10/16/06 2" 6 10474-10480 0 10/16/06 2" 6 10490 10504 0 10/16/06 2" 6 10530-10544 0 10/16/06 10502' –15-112*MARKER DONT 3-3/8' 6 10597-10637 0 09/02/94 ? H FISH:2-7/8"QU1 KDRLL COL MLLE)(07/)6/15) PBTD H 10709' 44444444 44444444 444444444444 44444444 5-1/2"CSG,17#,L80 LTC/NSCC, --I 10804' --4444444 .0232 bpf,D=4.892' DATE REV BY COMMENTS DATE REV BY COM ENTS PRUDHOE BAY UNIT 08/17/94 0-16 ORIGINAL COM PLETION 06/25/10 I-UW/PJC CEMENT(06/22/10) WELL: 09-37 09/15/94 CTD RECOM PLETE 01/11/12 TMyJM)ADDED HRS SAFETY NOTE PBRMT No: 1940280 05/16/01 RN/TP CORRECTIONS 06/03/15 PJC TBG/LNR CORRECTIONS AR No: 50-029-22451-00 10/16/06 THJTLH PEWS ADDED 07/29/15 TITR/JM)MLLED SHEATWSET FISH SEC 1,T10N,R15E,201'FSL&318'FEL 09/09/09 MV/lLH PLUG SET&TBG PUNCH(08/05/09) 10/05/09 JAF/SV DRAWING COTTONS BP Bcploration(Alaska) • • Wallace, Chris D (DOA) From: AK, GWO Well Integrity Engineer <AKGWOWellSiteEnginee@bp.com> Sent: Sunday, May 28, 2017 4:41 AM To: AK, GWO Well Integrity Engineer;AK, GWO Completions Well Integrity;AK, GWO SUPT Well Integrity;AK, OPS FS2 OSM;AK, OPS FS2 DS Ops Lead;AK, OPS FS2 Facility OTL; AK, OPS FS2 Field OTL;AKOpsProdEOCTL;AK, GWO SUPT Slickline;AK, GWO SUPT Special Projects; Cismoski, Doug A; Daniel, Ryan;AK, RES GPB East Wells Opt Engr;AK, OPS EOC Specialists;AK, OPS PCC Ops Lead;AK, RES GPB West Wells Opt Engr; G GPB FS2 Drillsites; Regg,James B (DOA);Wallace, Chris D (DOA); Stechauner, Bernhard Cc: AK, GWO DHD Well Integrity;AK, GWO Projects Well Integrity;AK, OPS FF Well Ops Comp Rep; Sternicki, Oliver R;Worthington,Jessica; Dickerman, Eric; Munk, Corey; Pettus,Whitney;AKIMS App User Subject: UNDER EVALUATION: Injector 09-37 (PTD#1940280) Place on Injection for Warm Up Prior to MIT-IA All, Produced water injector 09-37 (PTD#1940280)was classified as Not Operable due to a packer leak found on 04/23/2009. A remedial cement packer squeeze was performed on 05/22/2010. A subsequent MITIA failed on 06/25/2010 just 3 days after cementing. A SCMT was run on 06/01/2015 to determine quality of cement squeeze and results indicated good cement. Another MITIA was performed on 06/01/2015 and passed. Results from the SCMT and the second MITIA indicate the original MITIA failed due to green cement. Surface kit issues that had delayed progression towards making this well operable have been repaired. The AOGCC has granted permission for water injection as under evaluation for 28. The AOGCC have granted permission to place the well back on water injection only days to determine the success of a packer squeeze. Once the injection rate is stable,a witnessed MIT-IA will be performed. The well has been reclassified as Under Evaluation. Be mindful of low volume,fluid packed annuli,specifically the inner annulus which has been cemented to 8850ft. Plan Forward: 1. WIE: Reclassify the well as UNDER EVAL 2. OPS: POP w/DHD assist(Plan to POI:05/28/2017) 3. DHD: Pre-AOGCC MIT-IA(After two week injection period) 4. DHD(P): AOGCC Witnessed MIT-IA SCANNED MN: 0 a!t,�. 5. ENG:Apply for AA 6. WIE (P): Reclassify as OPERABLE and return well to service Please reply if in conflict with proposed plan. Matt Ross (Alternate: Josh Stephens) Well Integrity Engineering Office 907-659-8110 Cell 907-980-0552 Harmony 4530 1 " ` , . STATE OF ALASKA •ALASKA OIL AND GAS CONSERVATION COMMI N REPORT OF SUNDRY WELL OPERATIONS 1. Operations Performed Abandon 0 Plug Perforations 0 Fracture Stimulate 0 Pull Tubing 0 Operations shutdown 0 Suspend 0 Perforate 0 Other Stimulate 0 Alter Casing 0 Change Approved Program 0 Plug for Redrill 0 Perforate New Pool 0 Repair Well 0 Re-enter Susp Well 0 Other:Mill Plug Q 2. Operator Name: BP Exploration(Alaska),Inc 4. Well Class Before Work 5. Permit to Drill Number 194-028 3. Address: P.O.Box 196612 Anchorage, Development 0 Exploratory 0 AK 99519-6612 Stratigraphic 0 Service Q 6. API Number: 50-029-22451-00-00 7. Property Designation(Lease Number): ADL 0028327 8. Well Name and Number: PBU 09-37 9. Logs(List logs and submit electronic and printed data per 20AAC25.071): 10. Field/Pools: PRUDHOE BAY,PRUDHOE OIL 11.Present Well Condition Summary: RECEIVED Total Depth: measured 10810 feet Plugs measured None feet true vertical 9189 feet Junk measured 10709 feet AUG 11 2015 Effective Depth: measured 10709 feet Packer measured None feet true vertical 9094 feet Packer true vertical feet AOGCC Casing: Length: Size: MD: TVD: Burst: Collapse: Conductor 80 20"91.5#H-40 28-108 28-108 1490 470 Surface 2 10-3/4"45.5#L-80 27-30 27-30 5210 2480 Surface 3502 9-5/8"40#L-80 30-3531 30-3531 5750 3090 Intermediate 10783 5-1/2"17#L-80 25-10808 25-9187 7740 6280 Perforation Depth: Measured depth: 10436-10442 feet 10474-10480 feet 10490-10504 feet 10530-10544 feet 10597-10637 feet True vertical depth: 8839-8845 feet 8874-8880 feet 8889-8902 feet 8927-8940 feet 8989-9027 feet Tubing(size,grade,measured and true vertical depth) See Attachment See Attachment See Attachment Packers and SSSV(type,measured and None true vertical depth) None 12.Stimulation or cement squeeze summary: Intervals treated(measured): Treatment descriptions including volumes used and final pressure: SCANNEL NOV 1 6 2015 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation: 0 0 0 0 0 Subsequent to operation: 0 0 0 0 0 14.Attachments:(required per 20 AAC 25.070.25.071,&25.283) 15.Well Class after work: Daily Report of Well Operations 0 Exploratory ❑ Development 0 Service 0 Stratigraphic ❑ Copies of Logs and Surveys Run 0 16.Well Status after work: Oil 0 Gas ❑ WDSPL 0 Printed and Electronic Fracture Stimulation Data 0 GSTOR ❑ WINJ IIJ WAG 0 GINJ 0 SUSP 0 SPLUG 0 17.I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if r O.Exempt: 31 53 Contact Summerhays,Nita M(WIPRO Technologies) Email Nita.Summerhays@bp.com Printed Name Summerhays,Nita IPRO Technologies) Title Petrotechnical Data Manager Signat ��_/���� �� Phone +1 907 564-4035 Date 08/11/2015 Form 10-404 Revised 5/2015 k 7 q,2y/ RBDMS--- AUG 1 4 201�ubmit Original Only 0 0 _ 22 ± -0 � \ \ 0 = ni om c 9 _ =5 ._ 0) $ / E / Cr 2 E »2 0 0- co E \ ° E / k » --••••. \ C / ) meg i'..) 4- ® _ _ £ / ° ) n /\ / \ , ƒ § § o = © = C = w 9- _ H 5 U) ƒ \ ' , % O \ ^ y c\ / 0_I \ q CO o = ± o ® o co ƒ \ kms / a2 ®_ / o▪ ƒ 0 U 7 \ < \ a) • < E 0▪ 3 < 2 E oco / » A_ o E o 0 ® / / © $ & \ s f Cl) % R ¥ = e2 I / � 92 ;:t: ■ R N. i � U 7p . o_D / 0 _ r c2 & _ m < 5 � o / .- / R / < 0 < + E s / 7 0c / O - q \ – O 't $ * / / / E \ G / % 0 Ca G 9\ 2 t / w w H / o a) co c ƒ / # E t k " O re / t 0_ ._, » Im O 0 il ® G ® / 7 7 E \ < / / h / ii / C - \ E 2 z ® _ 0 a)E w E '- 2 2 \ 0 - 2 E Z 0 O o • . \ 0 • 0 ± I I I : < O O m w Q ® O E ® U = 2 2 z 2 = Q I G &) U O 2 G k ± - _ n9 x 3 ¥ & O I \ U I L > \ 0 m ® 3 � 2EO – gjN guJ m > Y • $ / ¢ k \ % E / / \ 5 0 / \ -1 > - > 0 L / :/ / / :/ 0)46 / f uj> OIfZ0OO \ / \ / � H = – - R = – g a / G 2 / $ E \ < % / 7 > > 0 6 @ 2 U O t G O a w c I t E G + m t Amb m r o R L I- < r r r e o \ / \ \ \ 03 ® \ 5 / $ () NN NN 2 ® � � � / ® \ « N. < III/1 • CD o000 0 00 12 o N 0 o O g up up up cV- U N o 0 0 0 01 QD 0 0 0 0 rn c- 1.0 ,r m m up V' N Is Ns00 up up 0 O O O r r ,r co d' O M 00 O O) c- N M 1.0 M N O) O CO CO (0 M O) N M is Ns Ns CI i I i i I— Is Y- V O 00 Ns O 1.11 M QD O7 — N M N N M N N N O) O CO (0 N M N- Ns iJ a � 0 co000 2O M g CO O) r- 00 O M r M 1.0 O N O) O O) O O M c- N M CO O) O) V p C i I i i i i I i i a th 00 r- O M CO CD 0 c-0Ch 0 cm 0) N N co N N N O) O O) O) MM� N M a0 00 W CI. o I- H- ON a) 00 00 0 0 0 7 0 7 0 0 J N N J _ J00 0 00 O 00 00 U U N N V # Cq 00 N 00 N LO 0 00 O) 00 d7 O U - 000 0 N N d N d W M r r r N p O) c j �# M 4t Ch N N- N r r 0/ CV N aD N C co0N OL N Ch c c- M J CO N L[) Ct 0)O O = U w U OOLLLLOZZZZZZ Z W W O m m m 00m 00 ODDCCDDDDDD 0 0) CL l— I— F- I— I— TRE = 4'RC • . AlIf . E-lhau-EAC CIW 09-37 NOTES: ACTUA TOW BAKER C KB.ELEV= 46.7' L.,L"' ....1[11 211' —10-3/4"X 9-5/8"X0,ID=8.835" BF.ELEV KOP= 405T "CONDUCTOR, — 7 Max Angle= 50*@ 5734 ___#, , 29814 —3-1/2'CAM DS SSSV NP,13=2.812' Datum M3= 10444' 113-= " 410 Datum TV17. 8800'SS 10-3/4"CSG,45.5#,L80 BTC,ID=9.953' 28' 9-5/8'CSG,40#,L80 BTC,ID=8.835' H 3530' Minimum ID =2.25" @ 9020' 2-718" OTIS 'XN' NIPPLE I 1---i 7999' —5-1/2"PARKER SWS NP,ID=4.562' (BMW TBG) ESTIMATED TOP OF NENT(06/22/10) — —8850 i V 8970-8973 —TBG PUNCH(08/05/09) *. •p• 4 . 8985' —3-1/2'OTIS XN NP,ID=2.75" I kit _ I if 8997 —5-1/2'OT1S XN NIP,ID=4.46"(BOHM TBG) TBG-CT,7*, 3-1/2' ' -i.. { 8993' —3-1/2"X 2-7/8'XO,ID=2.375' 01800,.0093 bpf,C 3.094"s= —I 8992 ii r '' - .p . ...,,,,,.....„,. UNIT, = EST.TOP OF CEMT EN14 2-7/8'TBG(06/22/10) -{ 8997 i , ' 8993' —2-7/8'LOC SEAL ID 2.375' . N- , 8993' —5-1/2'SBR W/XN LOCK,ID=3.00' MILLED SI-EATH,ID=2.36'(07/06/15) J— 8992'-9010' Av ,,:. N. r.c 8994 I—3-1/2"SBR EXTENSION,Co=3,00' ----------__, 9804' I—3-1/2'MEKING MULESHOE,ID=2.375' 9010' —12-7/8"QUICKDRLL PLUG(08/03/09) I 1 9020' H2-7/8"OTIS XN?A),13=2.25 2-7/8'TBG,6.5#,L-80,.0058 bpf,ID=2.441" — 9026' j---• • 9026' H2-7/8'IVIULESHOE VVLEG,I D=2.441- H ELMO-TT-NOT LOGGED PERFORATION StAAVARY REEF LOG:SWS CMG ON 08/21/94 ANGLE AT TOP P&P:22. ,., 10436' Note:Refer to Production 0E3 for historical perf data SIZE SW MERVAL Opn/Sqz SHOT SOZ ., I 2' 6 10436-10442 0 10/16/06 2' 6 10474-10480 0 10/16/06 2' 6 10490-10504 0 10/16/06 101802' H5-117 MARKER Jorir 2' 6 10530-10544 0 10/16/06 3-3/8' 6 10597-10637 0 09/02/94 I I Ilk ? —FISI-t.2-7/8'OUICKCRLL COL PALLED(07/06/15) PBTD —{ 10709' ........ ........1 ........ ........I Ne........14 5-1/2"CSG, 17*,L80 LTC/NSCC, — 10804' 1 "6444444 .0232 bpf,0=4.892" DA TE RB/BY CO64NTS DATE REV BY COMA:NTS PRUD-OE BAY LINT 08/17/94 D-16 ORIGINAL COM PLET1ON 06125/10 WW/PJC CEMENT(06(22/10) MAIL 09-37 09/15/94 CTD RECOMPLETE 01/11/12-111,4*.116 ADIDED H2S SAFETY NOTE FERIAT No: 1940280 05/16/01 RN/IP CORRECTIONS 06/03/15 PJC TBG/LAR CORRECTIONS AR No: 50-029-22451-00 10/16/06 TEUTU-i PaRFS ADDED 07/29/15 TTP/JM) la.LED SI-EAT1ISET FISH SEC 1,TION,R15E,201'FSL&318'Fa 09/09/09 WiTLH'RUG SET&TBG PUNCH(08/05109) 10/05/09 JAF/SV DRAVVNG CORRECTIONS I3P Exploration(Alaska)k a) - . r o sCU cv 1 CO O yQ . U L pp N 0 NI- OQOQr f' X f� LQ" L�Ca N O OC 0 .5 tZ I- Q dO Pli Y o 0 _ a C O O c O c Q: f6 C no T Q Q It ra 9 w N In u) u) N N N � uu t(') N N u) ns O a1 E L m !- :f C >+ '7 7 > �. T C Y a.) p y ay' to O. a >C C O C O C 0) C C c. 0) na C C O 'n L C C a3 4 c ( L. ° r c )n - C Z CII > 4/ K r. Q) > L = ay F- C a1 ✓ f0 O 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 ,,,- MI Cl.) U s 6 J J J J J J J J J J J J J J J cQ O W W W W W W WWWWWWWWW np ra 4 LL LL LL LL LL LL L.L. LL LL LL LL u. LL LL LL vi a) E "' Q J J J J J J J J J J J J J J J a O ° a/ C4 k F- Q Q Q Q Q Q Q Q Q Q Q Q Q Q Q N C C C) ZZZZZZ ZZZZZZZZZ ^ u O �" LL LL LL LL LL I.L. LL U. LL LL LL LL LL LL LL a) L ._ U v > ., w N E a a) p - O tT . z a v p U . 7 � � � � c O °(a a a) % w r 0 o. 0 0 0 0 0 0 Q F`- c c0 .� ( P. U v 1- 0 0 0 0 0 0 o z 1- Q Q) L U > 6j ro .. 'n v, Z z Z Z Z Z Q LL 2 u) (7 LL LL a. o pD00000 O0Q > > O w 4LI w a CO CO CO CO m m Ce w d d c' w do w 1- i- t- I- r- I- — Q cn V 0COozzzzzz00N ' a N J i z2wwwww wO 2 2 a0 WWWWWW V > J) 0 0 0 0 0 0 ay PI W W O o g C 02 CO N a - U.1 O >^ ),- ).- >- >- >- >.- ›.- ›- '+1 c > a J 0 0 0 0 0 0 0 0 0 J J J J J J 8 C", 5-`ti) VI' ".5 At---pcp 0 1 al 6.1E >- w < < < < < z Q Q Q Q Q Q Q Q Q Z g m m m m m CO CO m CO CO CO m CO m m 4 00 0 00z000 0000000 losol 0 2 2 2 = _ = 2 2 2 2 = _ _ _ _ w 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 a) gi 1 w• > > > > > > 00 = > > > D > > :.= aaaaaa aaaaaaaaa 74„ X n CO M N V in O O co CO LO 0 u) O u) O_ N O O) 00 00 l0 00 00 N c0 N N 00 a o0 0 O 0 0 0 0 O O O O O O p O O O OLn eta) -J0 0 0 0 0 0 0 O O O O O O O 0 0 _ Ql I M m 14.1 -� U co N 40 u) cn co cn N co U m -) m LL' 'C eu >• > > > x > x > r m N m a' r o Cr x > m a 0 S .- in O O e- 1- 1- O 0 0 1- 0 0 CO lD O O O O O O O O O O O O O O O L C O C N LC) c0 CO0t0 V CO 8 C) t0 Q1 O �' Q T O O in Cr Cr et CO O In M M N u) 00 m O M V N u) (0 V V 0 in in an O) N f9 -O N 0 N 0 O M N M M N 0 O4.4 > N N N N N N N N N N N N N N N N m 1, O) O) O) T T O T (3) O) 0) O co (3) O Q) E C F N N N N N N N N N N NNN N N 0) O 0 0 0 0 0 0 0 0 0 0 0 0 0 0 C OO O O O O O O O O O O O O O r C inN u) u) N u) uN uu) 7 ) u) u) u) u) u) N G. Y m Com W C a 'O w Q1 Lu g E .. u 0.0 c E o r— z . O cn se v ,,, Q8Q' mQN N Q Q Q Q Q a le Na Eal .' M M ON Vcc Z O M M N O N O O 4-, r',1E al D A J aH C7 -� a N a) -o U w o o tn.� 3 c co a V L v o , OF T� �w\1/j��sv THE STATE Alaska Oil and Gas E ' a��jA of T i\ SIKi\ Conservation Commission ___ _ A t _„,__, `• 1- .. _,_, 333 West Seventh Avenue 4' GOVERNOR BILL WALKER Anchorage, Alaska 99501-3572 *�' Main: 907.279.1433 O4'ALAS" Fax: 907.276.7542 www.aogcc alaska gov Aras Worthington SCANNED JUL 0 7 2015. _ o �g Wells Engineer q BP Exploration(Alaska), Inc. I P.O. Box 196612 Anchorage, AK 99519-6612 Re: Prudhoe Bay Field, Prudhoe Bay Oil Pool, PBU 09-37 Sundry Number: 315-403 Dear Mr. Worthington: Enclosed is the approved application for sundry approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the AOGCC grants for good cause shown, a person affected by it may file with the AOGCC an application for reconsideration. A request for reconsideration is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. Sincerely, Cathy Pi Foerster ���.. Chair DATED this 3U' day of June, 2015 Encl. % STATE OF ALASKA .'L E D ALASKA OIL AND GAS CONSERVATION COMMISSION GI-3113 APPLICATION FOR SUNDRY APPROVALS JUN 2 5 2U i;; 20 MC 25.280 1. Type of Request: Abandon 0 Plug Perforations ❑ Fracture Stimulate 0 Pull Tubing ❑ "� C rNi}tdown 0 ' Suspend ElPerforate ❑ Other Stimulate 0 Alter Casing 0 Change Approved Program 0 Plug for Redrill ❑ Perforate New Pool 0 Repair Well 0 Re-enter Susp Well 0 Other Mill Cement/Plug IZI• 2. Operator Name: BP Exploration(Alaska),Inc 4. Current Well Class: 5. Permit to Drill Number 194-028 - 3. Address: P O.Box 196612 Anchorage,AK Exploratory 0 Development 0 99519-6612Stratigraphic ❑ Service a 6. API Number: 50-029-22451-00-00 • 7. If perforating: 8. Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool'? Will planned perforations require a spacing exception? Yes 0 No I l PBU 09-37 9. Property Designation(Lease Number): 10. Field/Pools' ADL 0028327 - PRUDHOE BAY,PRUDHOE OIL • 11. PRESENT WELL CONDITION SUMMARY Total Depth MD(ft): Total Depth TVD(ft): Effective Depth MD(ft): Effective Depth TVD(ft): Plugs(measured): Junk(measured): 10810 • 9189 • 8992 7626 See Attachment Casing Length Size MD TVD Burst Collapse Structural Conductor 80 20"91 5#H-40 28-108 28-108 1490 470 Surface See Attachment See Attachment See Attachment See Attachment See Attachment See Attachment Intermediate Production 10783 5-1/2"17#L-80 25-10808 25-9187 7740 6280 Liner I Perforation Depth MD(ft): Perforation Depth TVD(ft)• Tubing Size: Tubing Grade' Tubing MD(ft): See Attachment See Attachment See Attachment See Attachment See Attachment Packers and SSSV Type No Packer Packers and SSSV MD(ft)and TVD(ft): No Packer No SSSV Installed No SSSV Installed 12.Attachments: Description Summary of Proposal 0 13.Well Class after proposed work BOP Sketch 0 Detailed Operations Program 0 Exploratory 0 Stratigraphic 0 Development 0 Service ®• 14 Estimated Date for Commencing Operations1 81` 15. Well Status after proposed work: Oil ❑J , Gas 0 WDSPL 0 Suspended 0 16.Verbal Approval: Date: WINJ LdrL3'(� GINJ ❑ WAG 0 Abandoned 0 Commission Representative: Op Shutdown 0 GSTOR 0 SPLUG 0 17.I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Worthington,Aras J Email Aras.Worthington@bp com Printed Name Worthington,Aras J Title Wells Engineer Signature / �� i/9-.</915'Phone +1 907 564 4102 Date COMMISSION USE ONLY Conditions of approval:Notify Commission so that a representative may witness Sundry Number I (-10.3 Plug Integrity 0 BOP Test 0 Mechanical Integrity Test Ig- Location Clearance 0 Other: ( l t / I . -.71--",_/ ,,, Y1 Yl f S s't GI/ /lA t T - /A r-t li i r( of a- F/ C v . -�-Q L-i L r 5�d i Jj f'r c /L i 0'1'1 Spacing Exception Required? Yes 0 No Er Subsequent Form Required: /0 _4-0 4 } APPROVED BYTHE Approved by: COMMISSIONER COMMISSION Date:/_3�)—f S VTL to/3 ///9/5 !O ORIGINAL A .�v.s— Submit Form and Form 10-403 Revised 5/2015 Approved application is valid for 12 months from the date of approval Attach nts in Duplicate RBDMS<kc JUL - 1 201$ 09-37 194-028 Plugs Attachement SW Name Date MD Description 09-37 06/23/2010 8992 Cement Plug 09-37 08/05/2009 9010 2-7/8" Composite Plug d Co O O CA CO LC) LO Lf) - co N co O co co O r r r r N o 0 0 o co o co o 0) Ln cO co co N f� LU L 0 0 O co N- co V co O CO co co N O) Ln LO M CO O N CO 0) CO CO CI) I- CO I- N N- H CD OO O LO N O) CO N— CO CO N CO N N CO O) N CD N O N- N CO I— ++ O CO — CO N- O a) M O 0 0 CO CO 0) M a) MCOON0) O) O CO CD 0) M CO N O) a V coCU CO O I� LO CO O M '— CO 0) Q 03 N CO N N O) O N O N 0) Co N CO CO �O •_ d, a» F— CD F- 0 0 CO 0 0 0 0a o co J CO CO COCO �_ N CO = J J O O N Ln p N-N N N •� CI) 'Cr• VO O O (0 ( O U rn vNNNNF- Hio OLn M O 0 f� A N O Ln M M M 4 N N N M M CON CI)O O a) V ti N- CO C CO in N N 0) O) M G) M LO N J Z • HO • w w U R0oo000000O U o u_ u_ p Z Z Z Z Z Z Z CLCtO m COm m m C0 O » CC » » » Ucnu) Cl- F- E- I- HHH d Cl) • Cfl O CO t— N Q V O N O Cfl y V 0o O CO (N ❑ CO 00 O) O) O 0 CO CO CO CO 07 H a W C. 0 LU > Q Y I� Ln CO J Q U L O V CO CO N J W J J O. C v O7 CO am Q ct Q < W 1 0Z d co N- 00 N CO J a J O U J 11 D 0 0 (0 (0 (00) 0) Z W Z W Z U ) a -J ❑ W ❑ co co co co co Q H Q H < = o W w > ~ JaJ O W cn W Z 0 O J u O L O W a — _J a < -J w 2 ( 2N 2 O :nU O co u) cr a) ca f6 • N O 'gf "i• 00 O LI; M 0 0 0 0 a N ai a1 cn co cc J = H O d J (� 2 O co co co co co a3 Q N a O p _ 0 c cov0N p_ M I— 0) Co 0) o 0 0 CJ 0 0 a L a) o 2 a) a a o W U J D W ❑ F- • (n Cn (n (n (n d H J a. a s a. a. O C7 O Q CO m CO CO CO L J J Z LL Z a < W W 0 Q W W J W W y Z o_ C7 C) U W W ti W a < ° gg o CQIY -1 -1 O C0 w W CO CO E E cn co a cC a) x000000 ❑ c O O O C) O p N N N N N • • N N N N N N N N N CN o. co co co co co a cn 0 LU N CQ LU O CO Q m m O _ O O a EY m E co Z r N- r r r 5 CO M M CO co d7 0 0) 0 0 O O CO 0 O TL= 4"FMC 09 37 VVH_LHE4D= Clw � SAFETY NOTES: ACTUATOR= BAKER C KB.BEV= 46.T1.."- BF.ELEV= ` J 28' -i 10-314'X 9-5/8"XO,D=8.835" KOP= 4057' —"CONDUCTOR, -f ? Max Angle= 50°@ 5734' —#' I 2981' -{3-1/2"CAM DS SSSV NP,D=2.812" OM Datum MD= 10444' ID= " Datum1V13= 8800'SS 10-3/4"CSG,45.5#,L80 BTC,ID=9.953" I 28' 11 4 . 9-5/8"CSG,40#,L80 BTC,D=8.835" H 3530' Minimum ID =2.25" a@ 9020' 2-7/8" OTIS 'XN' NIPPLE ' 7999' 15-1/2"PARKER SWS NP,D=4.562' �(BBIIND TBG) �TIMATED TOP OF CEMENT(06/22/10) --I -8850 I—>' 4, 3. 8970'-8973' --I TBG PUNCH(08/05/09) r it: 8985' H 3-1/2-OTIS XN MP,D=2.75' y 8992' H5-112"01IS XN NP,D=4.46"(BEHIND TBG) 8993' H3-1/2"X 2-7/8"XO,D=2.375" 3-1/2"TBG-CT,7#,QT800,.0093 bpf,D=3.094" --1 8992' '`4:::' 1 EST.TOP OF CEMENT N 2-7/8"TBG(06/22/10) -8992' *++� 8993' -12-7/8"LOC SEAL UNIT,D=2.375" 8993' -1 5-1/2"SBR W/XN LOCK,D=3.00" .t.4 .4 '!4� +.w. 8994' H3-1/2"SBR EXTENSION,D=3.00" :*''::4 n _\ .4 9004" I3-1/2'NOD(NG AAULESt i0�D=2.375" 9010' -12-7/8"QUACKDRLL PLUG(08/03/09) I I 9020' --I2-7/8"OTIS XN NP,D=2.25 2-7/8"TBG,6.5#,L-80,.0058 bpf,D=2.441" -{ 9026' I—' • —I 9026' -I2-718"MULESHOE WLEG,I D=2.441' H ELMD-TT-NOT LOGGED PERFORATION SUMMARY REF LOG:SWS CM-G ON 08/21/94 ANGLE AT TOP PERF:22"@ 10436' Note:Refer to Production DB for historical perf data SIZE SPF INTERVAL Opn/Sqz SHOT SQZ 2" 6 10436-10442 C 10/16/06 2" 6 10474-10480 C 10/16/06 2" 6 10490-10504 C 10/16/06 2' 6 10530-10544 C 10/16/06 10502' H5-1/2"MARKER JOINT 3-3/8" 6 10597-10637 C 09/02/94 PBTD -1 10709' .......8 5-1/2"CSG,17#,L80 LTC/NSCC, - 10804' iv4���!!�• .0232 bpf,ID=4.892" DATE REV BY COMMENTS DATE REV BY COK?ENTS PRUDHOE BAY UNIT 08/17/94 D-16 ORIGINAL COMPLETION 06/25/10 HJW/PJC CEMENT(06/22/10) WELL 'b9-37 09/15/94 CTD RECOMPLETE 01/11/12 TMWJMD)ADDED H2S SAFETY NOTE FERMI-ND:'1940280 05/16/01 RN/TP CORRECTIONS 06/03/15 PJC TBG/LNR CORRECTIONS API No: 50-029-22451-00 10/16/06 TEUTLH PERES ADDED SEC 1,T1 ON,R15E,201'FSL 8 318'Fa 09/09/09 MV/TLH PLUG SET&TBG PUNCH(08/05/09) 10/05/09 JAF/SV DRAVITIG CORRECTONS BP Exploration(Alaska) bP 0 09-37 Post packer squeeze milling Intervention Engineer Aras Worthington (907) 564-4102 Production Engineer Mark Drotar (907) 564-5367 History In June, 2010, a packer squeeze was attempted on the well after a failing MIT-IA and LDL. After the packer squeeze, an MIT-IA was performed on the well, and the MIT-IA failed. The tubing pressure climbed rapidly and tracked IA pressure for the duration of the test. The well was SI and labeled "Not-Operable" and no further surveillance or testing was done to diagnose the failure. In June 2015, an MIT-IA was pumped on the well and the well passed. It is believed that the cement may not have fully set-up prior to pumping the original MIT-IA so that is why the repressurization was seen. Well will be deemed "Under Evaluation" until a state witnessed MIT-IA is passed. Before the witnessed MIT-IA the cement and bridge plug must be milled out of the tubing tail to have the well POI. Objective Mill cement and bridge plug out of tubing tail. Procedural steps Coiled Tubing 1. Mill cement and bridge plug and push remnants out of tubing tail. Slickline 2. D&T to TD. SBHPS. Operations 3. Put well on injection under evaluation. I Fullbore 4. Perform AOGCC witnessed MITIA to 2500 psi. [FIE= 4'F�,iC 09-37 SAFETY NOTES; VOR L1pCF :M' IAC1UA.TOF� BAKER TKR PF'.V- 46.7 �'L. nor 28' H103.W"x .-Sd-xo c 0E25I i BF.ELEU KCP= 4057 "C�ON1Dl1CTOR, H .' 1 Mat Angie- 50"IT5/34 -4 _ I 9a11.1' 1.--1,3-'I t",*r_A it as s.s.sv P42 11-91112' Dolun lU- 14444' _ Datum'tlD= 6800x'SSI 10-3M`CSG:45 54 L&(}BTC O 9 953 f-. .a 26'.. _ 0. 9.5/8CSG,404,U30 BTC,ID=8.835- - 3630' Minimum ID =225" •, 9020' 2-718"OT1SI'XN'NIPPLE ' 7O' 1`e-1rrRAWER SWSNIP,V=4.sex �_ (BEHIND num A 1 I-13 F OP DI-CHAN(t I•:Ei 72t 1 G} J� -,..8850 J ."'°.'.•••,. ""..""..."'",.•"".• 8970°-8873'H[1fl Rruai(p1Axu04) 4.`yy y 8986 I-�3 11 DM XN.4P,D.2 75' I 9997 I I•• r::"r}lt'.XN 1.1+' 67-4 46-19-944140 TINS) I • 098?' -.F 1.;-,K /..o-at}.U 2'97. 3-1 2'TBG CT,74,47Ei06,.4003 bpi.D=3 091' 8442' i,yr,�` I f r, r[x.s w 11./1,u _i1 ' T.TOP OF CEMENT IN 2-118'TBG(06122'10) --i $497 I >�993' ' - 8993' --I5-1,2'SBR".5A)G1 LCCK O-3.00' I ..l \�4a 8994' H3-1f:'58R EJ(T3451004,ID-3.00' hy+ 1 9004' -3-1(7 J t-X V Gil,F-SHIX-,11=2:i'5' 1/41,0 9010' 127,rOLCKDR 1 PLUG(06,03/09} ' 9020' H2-r1F3'ons xNUP,ID=7751 2-78'THG,6.50f,L-80..0058 bpi,D=2.441'1 f 9028. i---' I YQia4i' I a res-FMrsHvc wxrr,r v-2 aar I i 1-.3.IU0-TT-NDTLOGGED I ra-ro-iitat IL I IMWtftr REF LOG:1 18O'+$-G ON 09121!94 ANSI FATTCPPFRF 22.@ 10436' Roue Refer to Production COW Insiolcal poll data SIDE.SPI- MEM/AL i Op'JSgz 51131 5OZ..__ 7 6 10436-10442 C 10,16/36 2- 6 10474-10480 C 10116/06 7 6 10490-10504 C 10116'913 I 10602' '-•s 1t2'MA RKERJOfdT' 7 6 10030-100044 C 10W16/36 3 3l8' 6 10597 10637 C 09x132194 I P1113 H 10709' I ti`-44 .4 5-10-t.�`.X`i.17#,t 8CI t TO ANS(?., � 10804' I . +11114116;( 0r2;>2 bp! D-4 697 MTF I RFV BY (X) 415 DATE NO/BY. ONVIVENIn. P Iflk3F BAY tM 06/17114 D-16 ORDINAL COMPLETION 06120110 F17OPJCICD.(NT106'22/10} VM1L. IDS 37 09115114CTU RECO6IPLETE 01111!12 TMIr,1MDAUDED I-125 SAI-E1Y NOTE liiMM!No_'1940280 'a5,16,G1' (8JrlP [xlFB.11{:tX7hl5 06'3:i11h i-JO 'TDCr LN2CXNbYi'l1DAeu ARM:. 50 02922451 OD 44L'16+06rTH/1tH F — SMILD ' SEC 1,TM.RIe 201'1S(.&318'Fa ;t»x3CAv9 Will II PLG SET TOG PUND1(08/05419} 10P0.5(09 .140-1,5V DRAIN) G CS C110 _ BP Exploration(Alaska) 2 '. XHVZE Pages NOT Scanned in this Well History File This page identifies those items that were not scanned during the initial scanning project. They are available in the original file and viewable by direct inspection. /q'r~' 0 2 ~ Fi~e Number of Well History File PAGES TO DELETE RESCAN Complete Color items. Pages: Grayscale, halftones, pictures, graphs, charts- Pages: Poor Quality Original- Pages: n Other- Pages: DIGITAL DATA [] Diskettes, No. [] Other, No/Type OVERSIZED [] Logs of various kinds [] Other scanned bY:~Dianna'Vincent Nathan Lowell V TO RE-SCAN Notes: Re-Scanned by: Bevedy Dianna Vincent Nathan Lowell Date: /si q,tiFa+aaTl!A'SM!W RwnP'Fs mwF . . S'e+ °w wnAMw?N?gA cmpmw • • by BP Exploration (Alaska) Inc. Attn: Well Integrity Coordinator, PRB -20 Post Office Box 196612 Anchorage, Alaska 99519 -6612 December 30, 2011 Mr. Tom Maunder Alaska Oil and Gas Conservation Commission /L."^ 0 g3i 333 West 7 Avenue ( "'�i Anchorage, Alaska 99501 o1 Subject: Corrosion Inhibitor Treatments of DS -09 Dear Mr. Maunder, Enclosed please find multiple copies of a spreadsheet with a list of wells from DS -09 that were treated with corrosion inhibitor in the surface casing by conductor annulus. The corrosion inhibitor is engineered to prevent water from entering the annular space and causing external corrosion that could result in a surface casing leak to atmosphere. The attached spreadsheet represents the well name, API and PTD numbers, top of cement depth prior to filling and volumes of corrosion inhibitor used in each conductor. As per previous agreement with the AOGCC, this letter and spreadsheet serve as notification that the treatments took place and meet the requirements of form 10 -404, Report of Sundry Operations. If you require any additional information, please contact me or my alternate, Gerald Murphy, at 659 -5102. Sincerely, Mehreen Vazir BPXA, Well Integrity Coordinator • w BP Exploration (Alaska) Inc. Surface Casing by Conductor Annulus Cement, Corrosion inhibitor, Sealant Top-off Report of Sundry Operations (10 -404) DS-09 10/20/11 Corrosion Initial top of Vol. of cement Final top of Cement top off Corrosion inhibitor/ Well Name PTD # API # cement pumped cement date inhibitor sealant date ft bbls ft gal 09 -01 1750760 50029201880000 Sealed conductor NA NA NA NA NA 09 -02 1760160 50029201980000 Sealed conductor NA NA NA NA NA 09-03 1760350 50029202090000 Sealed conductor NA NA NA NA NA 09-04A 1930240 50029202120100 Sealed conductor NA NA NA NA NA 09-05A 1930260 50029202150100 Sealed conductor NA NA NA NA NA 09-06 1760480 50029202160000 Sealed conductor NA NA NA NA NA 09-07A 1990220 50029202230100 Sealed conductor NA NA NA NA NA 09-08 1760700 50029202300000 Sealed conductor NA NA NA NA NA 09.09 1760760 50029202320000 Sealed conductor NA NA NA NA NA 09 -10 1760820 50029202350000 Sealed conductor NA NA NA NA NA 09-11 1760840 50029202360000 0.7 NA 0.7 NA 3.4 7/17/2010 09 -12 1770070 50029202390000 Sealed conductor NA NA NA NA NA 09-13 1770080 50029202400000 Sealed conductor NA NA NA NA NA 09 -14 1770250 50029202490000 Sealed conductor NA NA NA NA NA 09-15A 2070220 50029202560100 Sealed conductor NA NA NA NA NA 09 -16 1770370 50029202570000 Sealed conductor NA NA NA NA NA 09-17 1770380 50029202580000 Sealed conductor NA NA NA NA NA 09-18 1770390 50029202590000 Tanko conductor NA NA NA NA NA 09 -19 1770400 50029202600000 Sealed conductor NA NA NA NA NA 09 -20 1770410 50029202610000 Sealed conductor NA NA NA NA NA 09 -21 1831600 50029210360000 2.5 NA 2.5 NA 25.5 7/17/2010 09 -22 1831730 50029210490000 6.7 NA 6.7 NA 42.5 7/8/2010 09 -23 1980440 50029210667100 2.2 NA 2.2 NA 15.3 7/8/2010 09-24 1852020 50029214280000 Dust Cover NA NA NA 9.4 10/20/2011 09-25 1840280 50029210830000 3.2 NA 32 NA 23.0 7/8/2010 09-26 1840370 50029210910000 0.3 NA 0.3 NA 1.7 7/8/2010 09-27 1850280 50029212910000 Dust Cover NA NA NA 6.8 10/20/2011 09-28A 1930430 50029212920100 Dust Cover NA NA NA NA NA 09-29 1850960 50029214220000 13.5 3.0 0.5 7/13/2011 11.9 10/20/2011 09-30 , 1851840 50029214117000 Dust Cover NA NA NA 8.5 10/20/2011 09-31C 1960640 50029213960300 0.2 NA 0.2 NA 1.7 7/27/2010 09-32 1851180 50029213710000 Sealed conductor NA NA NA N/A NA 09-33A 2081560 50029213650100 9.3 NA 9.3 NA 66.3 7/18/2010 09 -34A 1932010 50029213290100 Sealed conductor NA NA NA N/A NA 09-35A 1930310 50029213140100 2.0 NA 2 NA 17.0 7/27/2010 09-36C 1951140 50029214290300 Dust Cover NA NA NA 9.4 10/20/2011 - -} 09-37 1940280 50029224510000 Open Flutes NA 0 NA 3.4 10/20/2011 09-38 1890210 50029219190000 0.1 NA 0.1 NA 6.8 10/20/2011 09-39 1910120 50029221330000 1.2 NA 12 NA 11.9 7/17/2010 09-40 1901690 50029221180000 1.3 NA 1.3 NA 10.2 7/17/2010 09-41 1900740 50029220540000 Dust Cover NA NA NA N/A NA 09-42A 1990070 500292205901 SC Leak 09-43 1901070 50029220780000 11.3 6.0 1.0 7/13/2011 8.5 7/18/2011 09-44A 2091570 50029220870100 1.5 NA 1.5 NA 10.2 9/1612010 09-45 1901150 50029220830000 0.2 NA 0.2 NA 3.4 10/20/2011 09-46 1901330 50029220920000 1.5 NA 1.5 NA 10.2 7/182010 09-47 1901460 50029220980000 1.3 NA 1.3 NA 6.8 7/18/2010 09-48 1910040 50029221280000 1.3 NA 1.3 NA 6.8 7/18/2010 09-49 1921340 50029223170000 0.7 NA 0.7 NA 2.6 10/20/2011 09-50 1921490 50029223250000 Dust Cover NA NA NA 4.3 10/202011 09-51 _ 1921410 50029223200000 Dust Cover NA NA NA 3.4 10/20/2011 ~J • Steve Rossberg Wells Manager BP Exploration (Alaska) Inc. P.O. Box 196612 Anchorage, AK 99519-6612 ' ~' " .l ~.~ ~ 1, - ~, ±-.. RE: Cancellation of Administrative Approval AIO 4E.019 PBU 09-37 (PTD 194-028) Prudhoe Bay Oil Pool Dear Mr. Rossberg: Pursuant to BP Exploration (Alaska) Inc. (BPXA)'s request dated August 11, 2010 the Alaska Oil and Gas Conservation Commission (AOGCC) hereby cancels Administrative Approval AIO 4E.019, which allows continued water injection in Prudhoe Bay Unit (PBU) well 09-37. This well exhibited slow tubing x inner annulus (TxIA) communication and BPXA did not at the time propose repairing the well to eliminate the problem. The Commission determined that water injection could safely continue in the well, but subject to a number of restrictive conditions set out in the administrative approval. BPXA recently attempted to repair the communication, but was not successful and the well failed a MITIA. BPXA has determined to shut-in the well and evaluate further repair options. Consequently, Administrative Approval AIO 4E.019 no longer applies to operation of this well. Instead, PBU 09-37 will be governed by provision of the underlying AIO No. 4E. _: ~. DONE at Anchorage, Alaska and dates ~-~ Daniel T. Seam t, Jr. Commission •, Chair AIO 4E.019 cancel • • September 2, 2010 Page 2 of 2 cc: Torin Roschinger/Gerald Murphy BPXA Well Integrity Coordinator, PRB-20 P.O. Box 196612 Anchorage, AK 99519-6612 TION AND APPEAL NOTICE As provided in AS 31.05.080(a), within 20 days after written notice of the entry of this order or decision, or such further time as the Commission grants for good cause shown, a person affected by it may file with the Commission an application for reconsideration of the matter determined by it. If the notice was mailed, then the period of time shall be 23 days. An application for reconsideration must set out the respect in which the order or decision is believed to be erroneous. The Commission shall grant or refuse the application for reconsideration in whole or in part within 10 days after it is filed. Failure to act on it within 10-days is a denial of reconsideration. If the Commission denies reconsideration, upon denial, this order or decision and the denial of reconsideration are FINAL and may be appealed to superior court. The appeal MUST be filed within 33 days after the date on which the Commission mails, OR 30 days if the Commission otherwise distributes, the order or decision denying reconsideration, UNLESS the denial is by inaction, in which case the appeal MUST be filed within 40 days after the date on which the application for reconsideration was filed. If the Commission grants an application for reconsideration, this order or decision does not become final. Rather, the order or decision on reconsideration will be the FINAL order or decision of the Commission, and it may be appealed to superior court. That appeal MUST be filed within 33 days after the date on which the Commission mails, OR 30 days if the Commission otherwise distributes, the order or decision on reconsideration. As provided in AS 31.05.080(6), "[t]he questions reviewed on appeal are limited to the questions presented to the Commission by the application for reconsideration." ~, In computing a period of time above, the date of the event or default after which the designated period begins to run is not included in the period; the last day of the period is included, unless it falls on a weekend or state holiday, in which event the period runs until 5:00 p.m. on the next day that does not fall on a weekend or state holiday. • BP Exploration (Alaska) Inc. Attn: Well Integrity Coordinator, PRB-20 Post Office Box 196612 Anchorage, Alaska 99519-6612 August 11, 2010 • ~ ~~ `, ~. ~`~ ~'~ o. Mr. Daniel Seamount, Chairman Alaska Oil and Gas Conservation Commission 333 West 7th Avenue Anchorage, Alaska 99501 Subject: Prudhoe Bay Unit Well 09-37 (PTD #1940280) Application for Cancellation of Administrative Approval 4E.019 Dear Mr. Seamount, BP Exploration (Alaska) Inc. requests cancellation of Administrative Approval number 4E.019 dated March 13, 2007. The administrative approval was for continued water injection into well 09-37 with slow T x IA communication. This well failed an MITIA on June 20, 2010 post packer squeeze. The first attempt at repairing the leaking packer with cement was unsuccessful. The well remains shut-in while it is being evaluated for further remedial options. Therefore it is requested to cancel the Administrative Approval for continued operations. A plot of wellhead pressures has been included for reference. If you require any additional- information, please contact me at 564-5637 or Torin Roschinger /Gerald Murphy at 659-5102. Sincerely, R. Steven Rossberg Well Operations Manager, BP • • Attachments: TIO Plot Cc: Bixby/Liddelow Murphy/Roschinger East Onshore Site Manager Kaity Longden Harry Engel 09-37 (PTD #1940280) TIO ~t W~.: o~~ a,nc;~ ~,~ t ten f a zoos -~- ~+ oon -o- noon - o~ ;.c~;o _._ __ _ _, STATE OF ALASKA ALASKA AND GAS CONSERVATION COMMISS~ REPORT OF SUNDRY WELL OPERATIONS 1. Operations Abandon ^ Repair Well ^ Plug Perforations ^ Stimulate^ Other Q PACKER Performed: Alter Casing ^ Pull Tubing ^ Perforate New Pool ^ Waiver^ Time Extension ^ Change Approved Program ^ Operat. Shutdown ^ Perforate ^ Re-enter uspended Well ^ FAILED 2. Operator BP Exploration (Alaska), Inc. 4. Well Class Before Work: .Permit to Drill Number: Name: Development ^ Exploratory ^ 194-0280 3. Address: P.O. Box 196612 Stratigraphic^ Service ^Q .API Number: Anchorage, AK 99519-6612 50-029-22451-00-00 8. Property Designation (Lease Number) : 9. Well Name and Number\ 7 ` ADLO-028327 PBU 09-3 10. Field/Pool(s): PRUDHO E BAY FIELD /PRUDHOE BAY POOL 11. Present Well Condition Summary: Total Depth measured 10810 feet Plugs (measured) 8983 feet true vertical 9189.3 feet Junk (measured) None feet Effective Depth measured 10709 feet Packer (measured) true vertical 9094 feet (true vertical) Casing Length Size MD TVD Burst Collapse Structural Conductor 80 20"91.5# H-40 32 - 112 32 - 112 1490 470 Surface 2 10-3/4" 45.5# L-80 26 - 28 26 - 28 5210 2480 Surface 3502 9-5/8" 40# L-80 28 - 3530 28 - 3530 5750 3090 Production 10783 5-1 /2" 17# L-80 21 - 10804 21 - 9184 7740 6280 Liner Liner Perforation depth: Measured depth: SEE ATTACHED - _ _ _ _ True Vertical depth: Tubing: (size, grade, measured and true vertical depth) 2-7/8" 6.5# LL-80 8992 - 9026 7626 - 7951 3-1/2" 7# QT800 SURFACE-8992 SURFACE-7626 Packers and SSSV (type, measured and true vertical depth) G'CGr s ~ ~°- ~ - ~ - n ~ ~~s~, ~~ r~ ~ ~'~~~ R~ . 12. Stimulation or cement squeeze summary: - Intervals treated (measured): p `:. t~ ~ r) r ' '" ' t r yy ~ @`, Q ~+~ (~I~' {~ ~ry~ ~y ~ ~'~~ F~ 6A~lvra~ €n1*t~lYe 4A~111l1 ~~~~~!a~ ' , : i ( ( ~ ! . ) }} pp,,~~Yi y~~~~ ~dllt ~, Treatment descriptions including volumes used and final pressure: ~i1C~11~f;l~~ 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing pressure Prior to well operation: Subsequent to operation: 14. Attachments: .Well Class after work: Copies of Logs and Surveys Run Exploratory^ Development ^ Service ^~ Daily Report of Well Operations X .Well Status after work: Oil Gas WDSPL GSTOR ^ WAG ^ GINJ ^ WINJ ^~ SPLUG ^ 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt: 309-242 Contact Gary Preble Printed Name Gary Pr le Title Data Management Engineer Signature Phone 564-4944 Date 7/8/2010 ~,ounn~ JUL u y ~ 'LL,,7/~0 _ 7 °r-~~ 09-37 194-028 PERF OTTO[_HMFNT Sw Name Operation Date Pert Operation Code Meas Depth Top Meas Depth Base Tvd Depth Top Tvd Depth Base 09-37 9/2/94 PER 10,597. 10,637. 8,989.23 9,026.71 09-37 10/15/06 APF 10,474. 10,480. 8,874.44 8,880.03 09-37 10/15/06 APF 10,490. 10,504. 8,889.35 8,902.39 09-37 10/15/06 APF 10,530. 10,544. 8,926.64 8,939.71 09-37 10/16/06 APF 10,436. 10,442. 8,839.07 8,844.65 09-37 8/3/09 BPS 9,010. 10,436. 7,639.3 8,839.07 09-37 8/4/09 PER 8,970. 8,973. 7,610.47 7,612.62 09-37 6/21/10 SQZ 8,890. 9,010. 7,553.52 7,639.3 09-37 6/22/10 BPS 8,983. 9,010. 7,619.81 7,639.3 AB ABANDONED PER PERF APF ADD PERF RPF REPERF BPP BRIDGE PLUG P ULLED SL SLOTTED LINER BPS BRIDGE PLUG SET SPR SAND PLUG REMOVED FCO FILL CLEAN OUT SPS SAND PLUG SET FIL FILL SQF SQUEEZE FAILED MIR MECHANICAL ISOLATED REMOVED SQZ SQUEEZE MIS MECHANICAL ISOLATED STC STRADDLE PACK, CLOSED MLK MECHANICAL LEAK STO STRADDLE PACK, OPEN OH OPEN HOLE • • 09-37 DESCRIPTION OF WORK COMPLETED NRWO OPERATIONS EVENT SUMMARY ACTIVITYDATE SUMMARY 6/20/2010 CTU 8 , 1.75" CT ,Job Scope: Packer Squeeze / Cleanout Move from DS 13 to DS 09. Arrive DS-09. BEGIN MIRU.""JOB CONTINUED ON , 06/21 /10** 6/21/2010 CTU 8, 1.75" CT, Job Scope Packer Squeeze w/ CO. MIRU on DS 09-37. Make up cementing BHA and RIH to quickdrill plug at 9010 ft. Displace CT, tubing and IA to diesel. Pump 3 bbls of cement and leave balanced plug across tubing perfs 8970-8973'. POOH. MU milling assy. WOC. Cement at 1000psi at 8pm. RIH w/ BOT 2.70" 3 bladed junk mill. Mill down to 8940, **Job Continued on 6/22*" 6/22/2010 _m ®._ ___ ,__... .~....._ CTU 8, 1.75" CT: Job Scope: Packer squeeze, mill to 3 1/2" x 2 7/8" cross over. ~ ~ ~ I ~ Mill from 8890ft to 8983 ft CTM. Slight motor work noticed ,milling at 1 fpm with no ' ~ stalls from cement. Motor stall at 8983 CT measurement (3 1 /2" x 2 7/8" x/o) ; i POOH. Conduct drill. RDMO. ""Job Complete** 6/25/2010i T/I/0= 0/0/0 Temp= S/I MIT-IA FAILED to 4000 psi (Post Cement squeeze) Pressured up Tbg to 1000 psi prior to MIT-IA with 1 bbl meth.Pressured up IA with j 2.2 bbls meth. Tbg pressure increased to 2840 while pressuring up IA to 4000 psi. ~ In the 1st 15 mins IA lost 380 psi and Tbg gained 660 psi. In the 2nd 15 mins IA j 3 lost 130 psi and Tbg lost 20 psi.Bled pressures back from Tbg and IA, bled - 2.5 ~ bbls meth. Final WHPs 0/0/0 ~.r. _._...-- WV,SV,SSV= Shut MV,IA,OA= Open ~ ~_ --~ ~_~ _ ~~ FLUIDS PUMPED BBLS 75.5 MEOH 364 1 % XS KCL 39 diesel 478.5 Total TREE= 4" FMC WELLHEAD= CMJ ACTUATOR= BAKER C KB. ELEV = 46' BF. ELEV = KOP = 4057' Max Angle = 50 @ 5921' Datum MD = 10444' Datum TV D= 8800' SS SAFETY N 09-37 2$' 10-314" X 9-5/8" XO ' I-13-112" CAM DS SSSV NIP, ID = 2.812" 10-3/4" CSG, 45.5#, L80, ID = 9.953" ~-I 28, 9-518" CSG, 40#, L80, ID = 8.835" 3530' Minimum ID = 2.25" @ 9020' 2-7i8" OTIS'XN' NIPPLE 3-1/2" TBG-CT, 7#, OT800, .0093 bpf, ID = 3.094" I--I $992' 2-7/8" TBG, 6.5#, L-80, .0058 bpf, ID = 2.441" (-I 9026' 'j~ 999' I- (5-1/2" PARKERSWS NIP, ID=4.562" ~$$50 ESTIMATED TOC IN IA (06/22/10) 8970'-8973' TBG PUNCH (08/05109) $985' 3-1/2" OTIS XN NIP, ID = 2.75 $992' S-1/2" OTIS XN NIP, ID = 4.455", $992' 3-1/2" X 2-7/8" XO, ID = 2.375", $992' ESTIMATED TOC IN 2-718" (06/22/10) $ggg' 2-7/8" LOC SEAL UNIT, ID = 2.375" 8993' 5-112" SBR W/XN LOCK, ID = 3.00" $994' 3-112" SBR EXTENSION, ID = 3.00" 9004' 3-1/2" INDIXING MULESHOE, ID = 2.375" 9010' 2-7/8" QUICKDRILL PLUG (08/03!09) 9020' 2-7/8" OTIS XN NIP, ID = 2.25 9026' --~2-718" MULESHOE WLEG ELMD-TT -NOT LOGGED PERFORATION SUMMARY REF LOG: SWS CNI-G ON 08/21(94 ANGLE AT TOP PERF: ??? @ 10436' Note: Refer to Reduction DB for historical pert data SIZE SPF INTERVAL Opn/Sqz DATE 2" 6 10436 - 10442 C 10116/06 2" 6 10474 - 10480 C 10/16/06 2" 6 10490 - 10504 C 10/16/06 2" 6 10530 - 10544 C 10/16/06 3-3l8" 6 10597 - 10637 C 09/02/94 PBTDI~ 10709' 5-1/2" CSG, 17#, L80, .0232 bpf, ID = 4.892" I-~ 10$04' DATE REV BY COMMENTS DATE REV BY COMMENTS 08!18/94 ORIGINAL COMPLETION 06!25/10 HJW/PJC CEMENT (06!22/10) 09/15!94 LAST WORKOVER 05/16/01 RNlTP CORRECTIONS 10/16/06 TEL/TLH PERFS ADDED 09/09/09 MV/TLH PLUG SET &TBG PUNCH (08!05!09} 10/05109 JAF/SV DRAWING CORRECT~NS PRUDHOE BAY UNff WELL: x'09-37 PERMIT No: 1940280 API No: 50-029-22451-00 SEC 1, T10N, R15E, 1204.02' FEL & 3110.1' FNL BP Exploration (Alaska) AOGCC MITIA Forms for 03-36760600), 03-12 (1790580), 03-37 (20990), 04-10 (... Page 1 of 1 Maunder, Thomas E (DOA) From: AK, D&C Well Integrity Coordinator [AKDCWeIIlntegrityCoordinator@bp.com] Sent: Thursday, July 01, 2010 5:06 PM To: AK, D&C Well Integrity Coordinator Cc: Regg, James B (DOA); Maunder, Thomas E (DOA); Brooks, Phoebe L (DOA); AK, D&C Well Integrity Coordinator Subject: AOGCC MITIA Forms for 03-36 (1760600), 03-12 (1790580), 03-37 (2091390), 04-10 (1760420), 04-43 (1940130),04-44 (1940100),09-16 (1770370),09-19 (1770400), 09-31C (1960640), 09-36C (1951140), 09-37 (1940280) Attachments: June 2010 MIT Forms GPB part 1.zip Jim, Tom and Phoebe, Please find the attached AOGCC MITIA forms for the following wells: 03-06 (PTD #1760600) 03-12 (PTD #1790580) -enclosed are 2 tests; original test from 6/12 /2010 and retest on 6/29/2010. 03-37 (PTD #2091390) 04-10 (PTD #1760420) 04-43 (PTD #1940130) 04-44 (PTD #1940100) 09-16 (PTD #1770370) 09-19 (PTD #1770400) 09-31 C (PTD #1960640) 09-36C (PTD #1951140) 09-37 ~_ (PTD #1940280) «June 2010 MIT Forms GPB part 1.zip» Thank you, Gerald Murphy (alt. Torin Roschinger) Well Integrity Coordinator Office (907) 659-5102 Cell (907) 752-0755 Pager (907) 659-5100 Ext. 1154 ~~ _ 7/2/2010 • • STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION Mechanical Integrity Test Email to:jim.regg@alaska.gov; phoebe.brooks@alaska.gov; tom.maunder@alaska.gov; doa.aogcc.prudhoe.bay@alaska.gov OPERATOR: BP Exploration (Alaska), Inc. FIELD /UNIT /PAD: Prudhoe Bay /PBU / DS-09 DATE: 06/25/10 OPERATOR REP: Torin Roschinger AOGCC REP: Packer Depth Pretest Initial 15 Min. 30 Min. Well 09-37 Type Inj. N TVD 7,627' Tubing 0 2,840 3,300 3,480 Interval O P.T.D. 1940280 Type test P Test psi 1906.75 Casing 0 4,000 3,600 3,490 P/F F Notes: MIT-IA post packer squeeze OA 0 60 60 60 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 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 TYPE INJ Codes D =Drilling Waste G =Gas I =Industrial Wastewater N =Not Injecting W =Water TYPE TEST Codes M =Annulus Monitoring P =Standard Pressure Test R =Internal Radioactive Tracer Survey A =Temperature Anomaly Survey D =Differential Temperature Test ~~^ ~J INTERVAL Codes I =Initial Test 4 =Four Year Cycle V =Required by Variance T =Test during Workover O =Other (describe in notes) MIT Report Form BFL 11/27/07 MIT PBU 09-37 06-25-10.x1s NOT OPERABLE: Injector 09-37 (PTD #1940280) Failed MITIA post packer squeeze Page 1 of 3 Maunder, Thomas E (DOA) From: AK, D&C Well Integrity Coordinator [AKDCWetllntegrityCoordinator@bp.com] Sent: Monday, June 28, 2010 1:13 PM To: Regg, James B (DOA); Maunder, Thomas E (DOA); Brooks, Phoebe L (DOA); Schwartz, Guy L (DOA); Cismoski, Doug A; Engel, Harry R; AK, D&C Well Services Operations Team Lead; AK, D8~C Wireline Operations Team Lead; AK, OPS FS2 DS Ops Lead; AK, OPS FS2 Facility OTL; AK, OPS FS2 Ops Lead; AK, OPS FS2 OSM; AK, OPS FS2 OSS; AK, RES GPB East Production Optimization Engineer Cc: Longden, Kaity; AK, D&C Well Integrity Coordinator; Holt, Ryan P (ASRC); Janowski, Carrie Subject: NOT OPERABLE: Injector 09-37 (PTD #1940280) Failed MITIA post packer squeeze Attachments: MIT PBU 09-37 06-25-10.x1s; 09-37.pdf All, Injector 09-37 (PTD# 1940280) has an Administrative Approval for PWI only due to known TxIA communication. On 06/22/10, a packer squeeze was attempted to gain gas injection capability. However, the MITIA failed after the packer squeeze verifying the squeeze was unsuccessful. As a result, the AA for TxIA communication while on PWI will be cancelled. The well has been reclassified as Not Operable and will remain shut-in until repaired. The MIT form and wellbore schematic have been included for your reference. «MIT PBU 09-37 06-25-10.x1s» «09-37.pdf» Thank you, Toxin Roschinger (alt. Jerry Murphy) Well Integrity Coordinator Office (907) 659-5102 Harmony Radio x2376 Cell (406) 570-9630 Pager (907) 659-5100 Ext. 1154 NSU, ADW Well Integrity Engineer Sent: Sunc~y, October 05, 2008 12:45 PM To: 'Regg, James A)'; 'Maunder, Thomas E (DOA)'; GPB, Area Mgr East (FSl/2/COTU/Seawater); GPB, GC2 OTL; GPB, GC2 Wellpad Lead; Rossberg, R Steven; Engel, R; NSU, ADW Well Operations Supervisor; GPB, Wells Opt Eng; GPB, Optimization Engr; GPB, EOC Specialists Cc: Townsend, S. Eliot; NSU, ADW Well Inte]chS~Engineer; Phillips, Patti J Subject: OPERABLE: 09-37 (PTD #1940280) Passe ,remains compliant with AA for IA repressurization All, Well 09-37 (PTD# 1940280) has passed a MITIA to 2500 psi confirming tiers to liquid and compliance with AOGCC AA 4E.019. The well has been reclassified as Operable and may re on injection. A copy of the MITIA form has been included for reference. 7/2/2010 Email to:jim.regg@alaska.gov; phoebe.brooks@alaska.gov; tom.maunder@alaska.gov; doa.aogcc.prudhoe.bay@alask/a.gov OPERATOR: BP Exploration (Alaska), Inc. ~~ ~( z~l to FIELD /UNIT / PAD• P dh Ba /PBU / DS-09 / ru oe y DATE: 06/25/10 OPERATOR REP: Torin Roschinger AOGCC REP: STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION Mechanical Integrity Test Packer Depth Pretest Initial 15 Min. 30 Min. Well 09-37 / Type Inj. N TVD '`7,627' Tubing 0 2,840 3,300 3,480 Interval O P.T.D. 1940280 Type test P Test psi 1906.75 Casing 0 ''4,000 3,600 X3,490 P!F F Notes: MIT-IA post packer squeeze OA 0 60 60 60 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 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 TYPE INJ Codes D =Drilling Waste G =Gas I =Industrial Wastewater N =Not Injecting W =Water TYPE TEST Codes M =Annulus Monitoring P =Standard Pressure Test R =Internal Radioactive Tracer Survey A =Temperature Anomaly Survey D =Differential Temperature Test INTERVAL Codes I =Initial Test 4 =Four Year Cycle V =Required by Variance T =Test during Workover O =Other (describe in notes) ~,.~ perp.,{, ~ ; ^ j MIT Report Form BFL 11/27/07 MIT PBU 09-37 06-25-10.x1s . • F ~ _ E~- ~~ ~~ ~-s`~ ~ `, , ~~ ~ ~ ~ ~r , ~ ; ~~ ±~~ ~,~ ~~tp ,` F : , . ~ , H '~-~ . z ... _ <~-~' ".~ ~ b ~ ~ ~ ~,~~`~, ~~ ~G'~ ~~ p_''a ~~ SARAHPALfN, GOVERNOR ~ ~ ~ ~ ~` ~ ~AS~A 0~ ~~5 ~F 333 W. 7thAVENUE, SUITE 100 COI~SERVA~'IO1~T CODII-IISSIOt~T ~` ANCHORAGE,ALASKA 99501-3539 ps PHONE (907) 279-1433 ~ FAX (907) 276-7542 Ms. Patti Phillips Production Engineer BP Exploration (Alaska),Inc. P.O. Box 196612 .- ,; ~,~~.~~~F: ~~ ~~ 'tl ~ a ~ Ot~~ ~ ;~~,~ Anchorage, AK 99519-6612 .~ Q `~~ Re: Prudhoe Bay Field, Prudhoe Bay Pool, PBU 09-37 Sundry Number: 309-242 Dear Ms. Phillips: Enclosed is the approved Application for Sundry Approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. When providing notice for a representative of the Commission to witness any required test, contact the Commission's petroleum field inspector at (907) 659-3607 (pager). As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the Commission grants for good cause shown, a person affected by it may file with the Commission an application for rehearing. A request for rehearing is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. A person may not appeal a Commission decision to Superior Court unless rehearing has been requested. Sincerely, Daniel T. Seamount, Jr. 1 Chair ~ DATED this2 3 day of July, 2009 Encl. ~'~,~ ~ ~~~ ~ STATE OF ALASKA ~ ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVAL 20 AAC 25.280 ~~~~ivE~~ ,1UL I 6 2009 ~''~('~ <°~Ia~~~ ~6, ~ ~~s Cons. Commissior~ .Anch~rag~ 1. Type of Request: Abandon Suspend Operational shutdown Perforate Waiver Othe x Alter casing ~ Repair well Q_ Plug Perforations~ Stimulate ~ Time Extension ~ PACKER SQZE , Change approved program ~ Puii Tubing ~ Perforate New Pool^ Re-enter Suspended Well ~ 2. Operator Name: 4. Current Well Class: 5. Permit to Drill Number: BP Exploration (Alaska), Inc. Developmenl[] Exploratory ~ 194-0280 _ 3. Address: P.O. Box 196612 Stratigraphic[] Service ^~ _ 6. API Number: Anchorage, AK 99519-6612 50-029-22451-00-00- 7. If pertorating, closest approach in pool(s) opened by this operation to nearest 8. Well Name and Number: property line where ownership or landownership changes: PBU 09-37- Spacing Exception Required? Yes ^ No ^ 9. Property Designation: 10. KB Elevation (ft): 11. Field/Pools(s): _ ADLO-028327~ 46.7 KB ~ PRUDHOE BAY Fieid / PRUDHOE BAY Pool 11. PRESENT WELL CONDITION SUMMARY Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD (ft): Effective Depth ND (ft): Plugs (measured): Junk (measured): 10810 , 9189.3 - 10709 9094 NONE NONE Casing ~ength Size MD ND Burst Collapse CONOUCTOR 80 20" 91.5# H-40 32 112 32 112 1490 470 SURFACE 2 10-3/4" 45.5# L-80 26 28 26 28 5210 2480 SURFACE 3502 9-5/8" 40# L-80 28 3530 28 3530 5750 3090 PRODUCTION 10783 5-1/2" 17# L-80 21 10804 21 9184 7740 6280 Pertoration Depth MD (ft): Pertoration Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): SEE ATTACHMENT - - 2-7/8" 6.5# L-80 8992' - 9026' - - 3-1/2" 7# QT800 TBG-CT SURFACE - 8992' Packers and SSSV Type: 5-1/2" OTIS XN NIPPLE Packers and SSSV MD (ft): 8992' 5-1/2" SEALBORE RECEPT XN LOCK 8993' 3-1/2" CAMCO DS SSSV NIPPLE 2981' 12. Attachments: Descriptive Summary Proposal ~ 13. Well Class after proposed work: Detailed Operations Program ^ BOP Sketch ~ Exploratory ^ Development ~ Service ^~ ~ 14. Estimated Date for 15. Well Status after proposed work: Commencing Operations: 7/30/2009 OIL ~ GAS ~ PLUGGED ~ ABANDONED ~ 16. Verbal Approval: Date: WAG ^ GINJ ^ WINJ ^~ - WDSPL ^ Commission Representative: Prepared by Gary Preble 564-4944 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact PATTI PHILLIPS Printed Name PATTI PHILLIPS Tide PRODUCTION ENGINEER ~. Signatur ;, Phone 564-4578 Date 7/16/2009 COMMISSION USE ONLY i.1~ ~~~ ~~~ ~ SZ Conditions of approval: Notify Commission so that a representative may witness Sundry Number: ~- ~ Plug Integrity [] BOP Test ~ Mechanical Integrity Test ~ Location Clearance ~ Other: Subsequent Form Required: ~ o APPROVED BY ~] 7 ~ ~ q A d b C `-~ pprove y: OMMISSIONER THE COMMISSION Date: / I Form 10-403 Revised 06/2006 v r ORIGINAL Submit in Duplicate ~ra~ 09-37 194-028 PERF ATTACHMENT • Sw Name Operation Date Perf Operation Code Meas Depth Top Meas Depth Base Tvd Depth Top Tvd Depth Base 09-37 9/2/94 PER 10,597. 10,637. 8,989.23 9,026.71 09-37 10/15/06 APF 10,474. 10,480. 8,874.44 8,880.03 09-37 10/15/06 APF 10,490. 10,504. 8,889.35 8,902.39 09-37 10/15/06 APF 10,530. 10,544. 8,926.64 8,939.71 09-37 10/16/06 APF 10,436. 10,442. 8,839.07 8,844.65 AB ABANDONED PER PERF APF ADD PERF RPF REPERF BPP BRIDGE PLUG P ULLED SL SLOTTED LINER BPS BRIDGE PLUG SET SPR SAND PLUG REMOVED FCO FILL CLEAN OUT SPS SAND PLUG SET FIL FILL SQF SQUEEZE FAILED MIR MECHANICAL ISOLATED REMOVED SQZ SQUEEZE MIS MECHANICAL ISOLATED STC STRADDLE PACK, CLOSED MLK MECHANICAL LEAK STO STRADDLE PACK, OPEN OH OPEN HOLE • r, To: Jerry Bixby / Clark Olsen Date: July 9, 2009 Well Operations Team Leader From: Patti Phillips, Production Engineer AFE: PBD09WL37-M Brad Gathman, Well Design Engineer Subject: 09-37i Packer Squeeze Est. Cost: $400K IOR: 225 Please perform the following procedure(s): 1. S D&T 2. E Set composite, CMIT, punch tubing, Circulate dead crude 3. C Packer Squeeze, Mill cement 4. F MITIA to 4000 psi 5. C Mill composite bridge plug (WOC 3 days) Current Status: Operable Produced Water Injector Last Injection: 07/06/09: 4600 BWPD (meter off line), 1526 psi Max Deviation: 50° C~ 5921' MD Min ID: 2.25"C 9020' MD, 2-7/8" Otis XN NIPPLE Tubing : 3-1/2" Tbg - CT 7# QT-800 ID - 3.094" Last Tag: 04/21 /09:10560'+20' corrected 10580', 57' perfs covered Last Downhole Op: 04/23/09: TecWel LDL (Leak @ SBR 8992') Latest H2S Value: no data available (nearby producer 09-21 54 ppm 11/03/05) WILL NEED SUNDRY APPROVAL Obiective• The objective is to restore tubing integrity by repairing a packer (SBR) leak @ 8992'. A previous pressure/temperature/gradio/spinner LDL was inconclusive, but a TecWel LDL was run on 4/24/2009 and identified a leak C«~ 8992'. The plan forward will be to set a composite plug at 9,010', punch the tubing and pump cement into the IA. ~j, ~or~•c~.\ r~~v~-s~ ~v~~ ~~ ~~~ -~-c3 ~c,.~c.t~~ ~~c. A p.. ~'~/a7 ~ Once repaired, the well will be put back on injection and can be removed from AA, and put on MI injection. It currently has a very favourable MI ranking. Well Historv: Well 09-37i is a produced water injector with TxIA communication. The well was completed in August 1994 and worked over with coiled tubing. It has 3-1/2" CT and 2- 7/8" L-80 tubing. A caliper log run on 7/4/2002 showed isolated pitting at 3202' MD (53%) and 5587' MD (41 %). Because the tubing string is a continuous length of coil tubing, the caliper results were divided into 50' sections. A Leak Detect Log run on ~ • 9/17/2002 found anomalies at 1670' -1680', 2077', 3202', and 5587'. An MIT-IA to 2500 psi failed on 11/24/2002 and a LLR on the IA was 0.33 gpm. Subsequent LLRs on the IA were found on 11/03/2003 at 0.31 gpm @ 2500 psi, on 10/30/04 at 0.06 gpm @ 2500 psi, and on 8/14/2005 at 0.05 gpm @ 2500 psi. A CMIT-TxIA was done on 09/08/06 and the tubing failed (the tubing would not pressure up) but the IA passed to 2500 psi. A 40 arm caliper was run 04/21/09 from 10580' SLM. (Refer to the attached PDS report dated April 21, 2009). A TecWel LDL was run on 4/23/2009 and found a leak at the SBR packer @ 8992'. Please contact the following personnel regarding any questions; Patti Phillips at W: 564-4578, work, 346-1755 home, 240-3742 (cell) Brad Gathman: 564-5778 (work), 907-242-2034 (cell) Risk Discussion: This well has a history of schmoo and may require a brush and flush prior to the job. The surrounding coil tubing is in very good condition. Slickline: MIRU 1. Drift and tag for composite bridge plug. 2. RDMO E-line: MIRU Set Baker 2-7/8" Quick Drill Composite Bridge Plug @ 9010' ELMD. (This is in the 10' pup joint between the WLEG and the x-over from the SBE and 2- 7/8" tubing). • Tie-In Log: Perforating Record 2" HSD, PJ 2006 HMX w/ GR/CCL. Dated 16- October, 2006. 2. Conduct a CMIT to 3000 psi to confirm plug is set. • If the CMIT fails; contact APE about proceeding with procedure 3. Punch 3-1/2" coil tubing at 8970' ELMD using SLB 20ES Puncher, RDX. Load tubing puncher with 4 spf and a 2' gun. (Wall thickness = 0.2 inches). • Tie-In Log: Perforating Record 2" HSD, PJ 2006 HMX w/ GR/CCL. Dated 16- October, 2006. 4. Confirm circulation through punches. Liquid pack tubing and IA by circulating 190 bbls of dead crude down tubing and up the IA through a choke skid at surface. Ensure all gas is removed from the tubing and IA. • Tubing Volume = 0.0093 x 8993' = 83.7 bbls • IA volume = 0.01135 x 8993' = 102 bbls CT: ~ 1. MIRU 1.75" CT unit. • 2. MU Pig Shear Nozzle, connector and no check valves. RIH and tag plug @ 9010'. Pick-up until full string weight is observed. PUH 10'. Flag CT. 3. Batch mix 2.1 pumpable bbls of 15.8 ppg Unislurry cement which will give 500 psi compressive strength in 5-7 hours and ~ 2000 psi ultimate compressive strength. BHT at packer depth of 8993' is 136 deg F. • Catch a sample of the cement for QC testing. (This needs to go to the lab to determine when the blend reaches 500 psi compressive strength. Lab must be notified prior to the job 659-2423.) Once the blend is approved, conduct Job Scope meeting to ensure that participants know the upcoming job sequence. 4. RIH to flag. Pump following down the coil: • 5 bbl water spacer • 2.1 bbls 15.8 ppg Cement • 5 bbl water spacer • MEOH for FP of CT Pump as follows, taking returns up CT x T annulus: a. Pump 5 bbl water spacer. Shut in reel valve. b. Displace surface lines through manifold near reel valve until good 15.8 ppg cement is achieved. Close manifold valve. c. Load coil with soft expanded foam pig. Open the manifold to the reel and pump the cement into the reel. Pump 2.1 bbls of cement and shut in reel valve. d. Displace the surface lines to fresh water via the manifold near the reel. Close manifold valve. e. Load the coil with the second foam pig followed by the ball. Open the reel valve and pump 5 bbls of freshwater behind the balL 5. Displace the cement to the nozzle at 1 to 2 bpm. Slowly reduce the pump rate to 0.5 bpm when cement is 2 bbls from the nozzle. 6. Pump ~/2 bbl cement up around coiled tubing and then POOH while laying in 1:1 returns. Continue to pump until the ball seats. Do not shear nozzle. Shut down pumps. 7. Slowly pull coil to 8600' MD. WCTOC is 8784' if no cement is placed in the annulus. Wait 5 minutes for the cement to settle. 8. Shear open the nozzfe. 9. Shut in CT x T annulus and open IA. • • 10. Circulate 1.1 bbls of cement through the tubing punches at 8970' and up the IA. Monitor returns at su ace to 40 bbl tank. Close in IA once 1.1 bbl fluid has returned to surface. 11. POOH while replacing voidage. WOC until 500 psi compressive strength has been reached (about 5 hours). 12. MU motor and 2.72" mill & jars and RIH. Mill through green cement to 8992' MD (3-1/2" x 2-7/8" x-over). Do not run a smaller mill and mill up composite bridge plug at this time. 13. POOH and RDMO. Fullbore: WOC 3 days before proceeding with MITIA 1. MIT-IA to 4000 psi • If the MIT-IA passes; proceed with milling composite plug • If the MIT-IA fails, contact APE and discuss a re-squeeze 2. RDMO CTU: Mill Pluq 1. MIRU 1.75 CTU 2. MU BHA with 2.20" mill 3. RIH and mill the remaining cement and upper part of the composite plug until slips release. Push plug body out of the Tubing Tail, but Do Not chase to bottom (There is a chance the plug body could get hung up beside the BHA in 5-1/2" casing). • Composite plug body is 2.11", so this will pass through the 2.25" XN nipple at 9020' MD. 4. Freeze protect top 2500' of wellbore 5. RDMO 6. Contact DSO to put well back on PWI. ~ ~. a~ t~c w~ ~ ~.~. ray acruar~_. _ _ eaK~ _ ___ ~ ~ ~ ~ ~ es. ~rr • ~c ~ a~s t,~me a~ ~ ~n ~ ~zt oaium~« s~u ~~~~ ~ar • ~ ~ ~ ~ s~~E7v ~r~9: ~ Min~num 1D = 2.25" ~ 30?Q' 2 7J8" OfilS'XN' NIPRLE ~•~ z.~~a s x~ ~rs r~. cr~ m• a~ar . Leak @ 8,992' MD 2-am~ ~, e.ss, vao. ~ 4M. ~• zu~- 1!t]F131 ~ciRARY R~ LOG' ~Af3 C7~G R3~i 08d211~4 AN[IEAT TqP P~ T77 ~ 1D13B tiMa_ ~ler ta ?a~aduaLrrt t7B far I~aor~~ per! dats ~ 3F~ ~ff~1fl4L [~ATE 2 B tQ~38. tQ9~2 1m18l08 2 8 tU#TA. t0i/84 O tU/i8~06 ? 8 tfA~O. tOFiQ~1 41 1diB106 2 8 tfTSiO= 105i4 O 1m4Bd06 3-3~' B t€Ri~37 ~ 70&37 O ~02194 ~ 5.id2' C,.9G, 1TA. L88, A232 6pf, ~* i_892' ~ i~~~~~ ~z~ i Tf« i]A'fE fl@V 61f ~0~175 [~Al'E RtV 6Y COi~~i'FS 0&1&B4 09~CiRMt (~OA~PLETX~ff t~~08 G~VTLtM CAT3T VLV ~T 0$d15~19i LA$F W~n)5S SN0~~8 K581i1M TST i1R.V RA1~3i ~5d4&'49 i~rUl'P tO~t~OB T8.7i1!# P~SAD~ oz.~ .~ac w~sa~n ~~ c~r~w ~~c wau~s~n ~~ onvr~ ss.sv ~ a9ate~ ~a,r~- wrw~sa~nr i€~aar~raa~ ~* ~ BAY i~+tF M/HL: ~3T 4~0; ~ 9~1028F3 AF91~tr: 546~2~151-~ ~ Hcpwra~on (1lasxs} • • PDS Report Overview ~ ~, ~~. Body Region Analysis 1~•1'ell: DS 09-37 Swvey Date: April 21, 2009 Field: Prudhoe Bay Tool Type: U11' MFC 24 No. 211390 Company: BP Exploration (Alaska~, Inc. Tool Size: 1.69 Country: USA No of Fingers: 2-~ Analvst: HY. Yan Tubing: Nom.OD 41~eight Grade & Thread Nom.ID Nom. Upset Upper len. Lo~ti~er len. Penetration and Metal Loss (3'o wall) ~ penetration body ~ metal loss body 150 100 50 ~ 0 to 1 to 10 to 20 to 40 to over t% 10°./0 20% 40% 85% 85% Number of joints analyse d Itotal = 1811 pene . 5-I 82 26 17 2 0 loss 116 65 0 0 0 0 Damage Configuration 1 body ) 20 I) 0 i;olated genera) line ring hole ~ po;s pitting conosion cono:ion corro~ion ible hole Number of ~oints dama ed Itotal = 111 I1 0 0 0 0 Damage Profile (°io wall) ~ penetration body ~ metal loss body 0 50 100 1 51 101 151 Bottom of Survey = 181 • • Final Job Report Manufacturer: TecWel AS Docum~nt no. : JN-WLD-2009-04-062 Revision 1 4 ~ppendices ~.1 Dynamic Log - Leak in Seal Assembly (~~~ 8,99~' ~'ID. ~ ~ ~ 14aerl c~ ~ . , ~ • ~Nm~y. or cwN~v~auvn ~M~asna~, ~~~c. Well: 9-37 ~- Input DLIS Files ~ FAULT PERFO 007LUP FN:6 PRODUCER 15-Oct-200613:32 1057t.0 FT 8900.5 FT I i Output DLIS Files FAULT PERFO 009PUP FN:8 PRODUCER 15Act-200614:18 10564.0 FT 8895.0 FT ; OP System Version: 14C0-302 ~ MCM i i A GUN SRPC-3193-Q3 2006 UPCT-A SRPC-3193-Q3_2006 ~ , Casin Collar Locator CCL ' ~ (---) 1 i ----------- Tension (TENS) ----------- ~ (LBF) 30a 8900 B Perforating Record HSD, PJ 2006 HMX w! ' Tubing Punch 8970' ELMD 51 /2" XO P 31/2' XN NI ' 31/2142 9UU0 - 2 7/8" XN N omposite Plug 9010' ELMD Tubing Tall ~ Well 09-37 3-'/z" coiled tubing Tubing Punch = 8! Leak = 899~ 2-7/8" tubing ta 5-'h" casing 5-'/2" x 3-'/2" annulus volume = 0.01135 bbl/ft 3-'h" coil volume = 0.0093 bbl/ft ~ 8893' MD - Desired Top of Cement SBR = 8993' MD Composite Plug = 9010' MD XN Nipple = 9020' MD (8993' - 8893') x 0.01135 bbl/ft = 1.1 bbls (8992' - 8893') x 0.0093 bbl/ft = 0.9 bbls 2-7/8" tubing volume - 0.0058 bbl/ft (9010' - 8992') x 0.0058 bbl/ft = 0.1 bbls Total Cement Volume = 2.1 bbls ~ ~ we~~ ~S ~S7 osra '3 rt 5I94 Prapwd BY: .a.c.enss 6CN ITEM OE9Cfi~qN 1~11xOD INCM FY~IIQ NCNEB LEMGTII FEE TOP FE ~ ~ ~ t 2 'IFXitUI~ER 91,Y'JSGT ~RI x3F~ k~Ox p~1P 7 3.5 ~ '.+ 1 e^.982 I 1 72 0.75 _ ~. .. $ I~T~A :7.5 9.•2G I ~_93 2_67 !' ~ I 4 3 L2 GOP.EDTUBINq 3~5 I 9.094 I 297~7 3.=2 ~ s ' ! 6 COILGXJ~~TOR a. ~ 3.t25 +~.89 29~1.t2 } -~- ~ - 6 FW~~YOOI.PUVQ- 4.S :~ a.:h .~~s.~i __ _ f~ I 7 C5lJCbD314PP.` 7.8 2.078 1.38 St98+7 • I 8 r -' ~ i;.. t- -•~ - b 4} FLO'~VOC?I,PI.NG COLCaFI~HJf17R 4.5 3 4.3 a.725 Fi.2y J.91 2961.~d Yun5,2T -1--~- -~-~ y ~ -j~-i -- ~- - ~4 ' 1 37~70011.E~TU~WCi C6I.CJf~Jf~TCA ^ 3.5 : :1.OBd 4.3 ~ 9_12S a89S J.98 PBll8.18 996e,13 I i i ~ ' 2 2.013 XFJ wPPI~ 4.3 2.75 1.21 0966.13 ~ ~ '3 34~7'AP~IIFt~PJY 9.5 ' :.4s1 8,13 8096. ~ _ i i - M1 3 1~'2 AH BQ7f X 2~~8 1:il6 FMIt a.3 2.975 J.58 83~2 5 ~ ~ :i LOCxTGFi86sLl~'IfT 3.4 2.~7R 1.11 BOB3.J~ . _ ~-_~ : ~;, ~ -8 ~ 9=,..dL9f'P.CERP.KF 2.95 7.375 5~~7 N074.1~ . j !. g - 7 SEAL L.~1R'UOlDEO A ` 2.~75 1 8000.?& 1 ~ "31 ~ 'a ~ SE1LLNIT;U0lDE0) 3 1 2.379 ?.49 e001.~8 - I ~ , I ' 9 NrDON(3t.11.lE8HCE 9 3.375 7,3a Aa02.:N. .~_ ~ ~ ~~ , _ ~:ar ~ ~~ ~~: ~- - ~ __: _~- 2D ~._..~.,_____ ~~~~~ACLE 5 ti7 XN LUCK d.515 ~ 3 ~,~,, ~.33 8oo~.sa Ha!+3 ~~ ~ j~ ~~p . 21 10r Sf ~' 30~ 3 7~ 1 1 A 5994.55 ! aa ~ ^ OYF.RFR!)MS?~X2it9R1~ 1.13 2.~1A U,Tt AO~A.3:~ -r--' ~' £3 18 X 2 7,'8 PUP JOIPfr 2.La19 2.Ad 15 900~.J4 ; a ~la xrv ryip '~~s~r 2.x- rio-DO 3, 64e 2.24 i. oa so2v. aa ~ ; i rP 1 26 ~ C ~ 7!9 PUP IN.LE~~pG 1YLCr' 2.985 3.8 S 2.44 z. a a a 0.87 Ba2t.l 2 S02b, l;t _~ . ~ _ i 8025,TS - ~ '-t- A - . ~ . ' : ~- ~ ~" 1 ' _' -t- . __ ~~ i ~ _ .' ~ ~.._. - ~_ ' ' 1 . ; _ ~.., ~ _ ~ f ~ ?j ~ . '_~_" ~ "'...~ _ _. ~~. .~ ~z. " ~. ,v, --; ,. -~- ~ --~~ ; - - ~za ._. -~ _.... ~~ . .. _ . _~.. , ~ . : ~ , -;?< ~ -- ~ 1 , ~, '25 t -- ~ ~ ~ ~- ~- ~ ~-- f ~~e~ caaa+~rrae ~ iue~ uNa~ au sea MARkEI!D~ I~l13PACCOLR IN NEIfT~AL~E9Y,iDA- P~. W7wA.9 nrMt.o~ - ~ t~~'.~ : '---"-' ~'( Q~ ~• Apq I"Q61AI. PIPB r"J LrUil THt~ IN HAlJl3EF 1' aHLPYE ~dlVNlqik $EAI.:ACATOR _ I~OF3f3AL31N3iR ----_-- - _ . -- --- . .. - -- ; ~ , - ~ I y; ~_ 1_ 1-- i ~ 1NNULU3 AVD TS1~IN[i FREE2E PRO'rF.G7ED `I'02GCa' W.+GIYi.? VR WFii. TlHB~ tFxSC~M 7~2~} GQFi1EC:f6Dt]~P7IISTQQNUPIIuOEP7M•:ACO~?TQC4~l~N3TH,l00V~w"°F'V} „--- . , I._ _ - ~ - ._~. ' Page 1 of ~ ~ • ~ Maund~r, TF~am~s E (DOA) From: Phillips, Pa#ti J [Patti.Philiips~bp.com] S~nt; Wednesday, July 22, 2Q09 11:46 RM To: Maunder, Thc~rr~~s E {DOA) Subj~Gt: FW: C?S Q9-37 (1~44-f?28} Packer Squeeze Hi Tom, See the reply be(ow. Let me know if you need more informatian. Thanks, Patti i~at~d ~~c~li~ Prz~tu~ra ~~~ir~~ C~~ 0~ ~»d i~ ~~~ ~ ~07~ ~5`~~ ~ PFe~se eorrsiCler the e~rtvircrnmer~t t~fcr~e printing this e~ritaif. I~rom; Prek~le, Gary B (SAIG) Sent: Wedne~day, July 22, ~049 1Q:3fl AM Tv: Philiips, Patti J Subject; FW: Da Q~-37 (194-028) Packer Squee~e ~'~; T~r~ ~~~ ~ qu f~~n c~r~ th~t 16?-~~~ ~~~ 0~~37 w~ ~ui~m" ~ri~~y. From; Maunder, ThQmas E (DQ~A} [maitto:tcam.maunc~r~aalaska.gau] sent: w~ane~~ay, ~~,~y z~, zc~o~ ~o: i~ A~ To. Prebie, Gary ~ ~SA~C) ~b~ect: f?S (}9-3~ (I9~4-028} Racker Squeeze Gary, Please fonaard #o Patti. Ratti, f am r~viewing th~ sundr~r appticatian for th~ prapased packee squeeze ta r~pair T x IA ~~mmunieafiion. Wi11 there b~ an attempt to squeeze cemen# ta piug the packer i,~ak or is th~ Li.R toc> smatl? The LLR = D.083 gpm and is too smal! to squeeze. Need to puncn the tubing to pump and circula#e cement into the IA. ~'he intent is to rQp~ir 1' x(,A communie.~tiQn how~v~r by circutating ~s ye~ta pEan in step 1Q cic~eSn't that insur~ there will be cc~mmunicatian via the punches at 89~70? Yes, but the tubing punches will be covered by cement fiom the packer up tfl ~8893', over the tubing punch~s at 897fl'. Is the intent t~ circ~late tF+e work ~il x cAmpletion tubing annutus? No, will wai# on cement for 3 days, get an M9T-3A, then mil9 up ths remain'sng cement and upper part of the composite plu~ ~n the tubing. ! look fa~nrard tQ your reply. . Tom Maunder, AE 7/22/2009 r~: ~o~cc Christine Mahnken 333 W. 7th Ave Suite 100 Anchorage> Alaska 99501 (907] 793-1225 RE : Cased Hole/Open Hole/Mechanicai Logs and/orTubing lnspectionjCaliper/ M1T) The technical data listed below is being submitted herewith. Please acknowledge receipt by returning a signed copy of this transmittal letter to the following : BP Exploration (Alaska], Inc. Petrotechnical Data Center Attn: Joe Lastuflca LR2-1 900 Benson Blvd. Anchorage, Alaska 99508 and Injection Profile q 22 Apr-09 09~7 ~n / ~' ~ ~ I I ~ 1S ~~-1 i~~2 ProActive Diagnostic Services, Inc. Attn: Robert A. Richey 130 West International Airport Road ~~~~~ a t~~ ~~y ~~~~ Suite C Anchorage, AK 99518 Fax: (907j 245-8952 1 j Leak Detection - WLD 22 Apr-09 09-37 Color Log / EDE 50-029-22451-00 2) Signed Print Name: ~~~ r9<t-oa~s Color Log / EDE 5Q-029 22451=00 Date : PROACTNE DIAGNOSTIC SERVICES, INC., 130 W. INTERNATIONAL AIRPORT RD SUITE C, ANCHORAGE, AK 99518 PHOtdE: (907)245-8951 FAx: (907)245-88952 E-M19AIL : :._ __._ ,.~ __._ ~ ---_, _ _ __ _ . _ _ _.._. WEBSITE ._ ___ _ ._ ._~__. C:~Documenrs and Setbngs\OavneflDestiKOp\Tru~smit BP,docx ~ ALA5SA OIL A1QD GAS COI~TSERQA'i`IO1~T COMI~IISSIOrIT Patti Phillips Production Engineer SARAH PALIN, GOVERNOR 333 W. 7th AVENUE, SUITE t00 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907)276-7542 BP Exploration Alaska Inc. PO Box 196612 Anchorage, AK 99519-6612 Re: Prudhoe Bay Field, Prudhoe Bay Oil Pool, PBU 09-37 Sundry Number: 308-434 Dear Ms. Phillips: Enclosed is the approved Application for Sundry Approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. When providing notice for a representative of the Conunission to witness any required test, contact the Commission's petroleum field inspector at (907) 659-3607 (pager). As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the Commission grants for good cause shown, a person affected by it may file with the Commission an application for rehearing. A request for rehearing is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. A person may not appeal a Commission decision to Superior Court unless rehearing has been requested. Sincerely, Daniel T. Seamount, Jr. Chair !~`-~ DATED this ~ day of December, 2008 Encl. • STATE OF ALASKA ~L~a~ `,~~'~j ALASKA OIL AND GAS CONSERVATION COMMISSION a- APPLICATION FOR SUNDRY APPROVAL ~n aac ~s ~s3n 1. Type of Request: Abandon Suspend Operational shutdown Pertorate Waiver Othe Alter casing ^ Repair well Q , Plug Pertorations^ Stimulate ^ Time Extension ^ TUBING PATCH _ Change approved program ^ Pull Tubing ^ Pertorate New Pool^ Re-enter Suspended Well ^ 2. Operator Name: 4. Current Well Class: 5. Permit to Drill Number: BP Exploration (Alaska), Inc. Development Exploratory ^ 194-0280 3. Address: P.O. Box 196612 Stratigraphic^ Service Q ~ 6. API Number: Anchorage, AK 99519-6612 50-029-22451-00-00 - 7. If perforating, Gosest approach in pool(s) opened by this operation to nearest 8. Well Name and Number: property line where ownership or landownership changes: PBU 09-37 . Spacing Exception Required? Yes ^ No ^ 9. Property Designation: 10. KB Elevation (ft): 11. Field/Pools(s): _ ©t ADLO-028327 ~ 46.7 KB ~ PRUDHOE BAY Field / PRUDHOE BAY Pool 11. PRESENT WELL CONDITION SUMMARY Total Depth MD (ft): Total Depth ND (ft): Effective Depth MD (ft): Effective Depth ND (ft): Plugs (measured): Junk (measured): 10810 ~ 9189.3 ~ 10709 9094 NONE NONE Casing Length Size MD ND Burst Collapse CONDUCTOR 80 20" 91.5# H-40 32 112 32 112 1490 470 SURFACE 2 10-3/4" 45.5# L-80 26 28 26 28 5210 2480 SURFACE 3502 9-5l8" 40# L-80 28 3530 28 3530 5750 3090 PRODUCTION 10783 5-1/2" 17# L-80 21 10804 21 9184 7740 6280 Perforation Depth MD (ft): Perforation Depth ND (ft): Tubing Size: Tubing Grade: Tubing MD {ft): SEE ATTACHMENT - - 2-7/8" 6.5# L-80 8992' - 9026' - - 3-1/2" 7# OT800 TBG-CT SURFACE - 8992' Packers and SSSV Type: 5-1/2" OTIS XN NIPPLE Packers and SSSV MD (ft): 8992' 5-1/2" SEALBORE RECEPT XN LOCK 8993' 3-1/2" CAMCO DS SSSV NIPPLE 2981' 12. Attachments: Descriptive Summary Proposal ~ 13. Well Class after proposed work: Detailed Operations Program ^ BOP Sketch ^ Exploratory ^ Development ^ Service Q 14. Estimated Date for 15. Well Status after proposed work: Commencing Operations: 12/15/2008 OIL ^ GAS ^ PLUGGED ^ ABANDONED ^ 16. Verbal Approval: Date: WAG ^ GINJ ^ WINJ- ^Q WDSPL ^ Commission~epresentative: Prepared by Gary Preble 564-4944 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact pATTI PHILLIPS Printed Name PATTI PHILLIP Title PRODUCTION ENGINEER Signature rjltfl~ v ~~ ~ Phone 564578 Date 12/1/2008 COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number: ,3p~- ~{3'f Plug Integrity ^ BOP Test ^ Mechanical Integrity Test ~ Location Clearance ^ Other: Subsequent Form Required: " VO I APPROVED BY Approved by: COMMISSIONER THE COMMISSION Date: Form 104173 Revi>ed 06/20 ~ g Submit in Duplicate ~, • To: Jerry Bixby /Clark Olsen Well Operations Team Leader From: Whitney King Production Engineer Subject: 09-37i TecWel LDL and Patch Please erform the followin rocedure s Date: November 24, 2008 AFE: PBD09WL37-M Est. Cost: $40M IOR: 200 1. S Drift w/ 3-1/2" Baker Dummy (pre-patch) 2. E TecWel LDL. If leak found, run 30' single set 3-1/2" Baker patch. 3. FP If patch run, MITIA to 2500 psi, LLR if it fails (post-patch) Current Status: Operable Produced Water Injector Last Injection: 11/16/08: 5648 BWPD, 1396 psi Max Deviation: 50° @ 5921' MD Min ID: 2.25"@ 9020' MD, 2-7/8" XN NIPPLE Last Tag: 10/05/06: 10591' SLM Last Downhole Op: 10/16/06: Adperfs Latest H2S Value: no data avialable (nearby producer 09-21 54 ppm 11./03/05) Job Objective: The objective of this job is to identify the slow TxIA communication by running a TecWel LDL. A previous pressure/temperature/gradio/spinner LDL was inconclusive but the TecWel tool is better equipped to find small leaks. Once the leak is located, it will be repaired by a patch so that the well can go back on injection. Once the well is repaired, it can be removed from AA and put on MI injection. It currently has a very favourable MI ranking. Well History: Well 09-37i is a produced water injector with TxIA communication. The well was completed in August 1994 and worked over with coiled tubing. It has 3-1 /2" CT and 2- 7/8" L-80 tubing. A caliper log run on 7/4/2002 showed isolated pitting at 3202' MD (53%) and 5587' MD (41 %). Because the tubing string is a continuous length of coil tubing, the calliper results were divided into 50' sections. A Leak Detect Log run on 9/17/2002 found anomalies at 1670' -1680', 2077', 3202', and 5587'. An MIT-IA to 2500 psi failed on 11/24/2002 and a LLR on the IA was 0.33 gpm. Subsequent LLRs on the IA were found on 11/03/2003 at 0.31 gpm @ 2500 psi, on 10/30/04 at 0.06 gpm @ 2500 psi, and on 8/14/2005 at 0.05 gpm @ 2500 psi. A CMIT-TxIA was done on 09/08!06 and the tubing failed (the tubing would not pressure up) but the IA passed to 2500 psi. • Please contact Jennifer Julian at W: 564-5663, C: 240-8037 or Patti Phillips at W: 564- 4578, H: 346-1755, C: 240-3742 with any questions or comments. Risk Discussion: Because this is a coil tubing completion with no collars, it will be difficult to tie-in. Plan on running a 30' patch if a single leak can be identified. The most likely hole depth is the 57% penetration in the tubing C~ 3202'. It is in the form of a single, small isolated pit. The surrounding coil tubing is in great condition. A gamma ray log can be run with the LDL to assist in tie-in. E-line can also be flagged after leak in found. Slickline Pre- LDL: 1. -Run a 3-1/2" Baker dummy to 3-1/2" x 2-7/8" XO at 8892' MD. _ E-line TecWell LDL 1. Shut in well prior to logging. Ensure a 30' 3-1/2 L-80 Baker patch is available. 2. MIRU E-line TecWel WLD/temp/CCUGR supplied by PDS (659-2307). RIH w/ tool string to tubing tail @ 9026' MD. _ 3, Pressure up the IA to 3000 psi and take returns to the formation. Well should 'be on a vacuum. Ensure constant pressure on the IA. Log a continuous pass with no stops or interruptions from tubing tail at 9026' MD to the surface at no faster than 30 fpm. • • Risk Discussion: Because this is a coil tubing completion with no collars, it will be difficult to tie-in. Plan on running a 30' patch if a single leak can be identified. The most likely hole depth is the 57% penetration in the tubing C~ 3202'. It is in the form of a single, small isolated pit. The surrounding coil tubing is in great condition. A gamma ray log can be run with the LDL to assist in tie-in. E-line can also be flagged after leak in found. Slickline Pre- LDL: 2. Run a 3-1/2" Baker dummy to 3-1/2" x 2-7/8" XO at 8892' MD. E-line TecWell LDL 4. Shut in well prior to logging. Ensure a 30' 3-1/2 L-80 Baker patch is available. 5. MIRU E-line TecWel WLD/temp/CCUGR supplied by PDS (659-2307). RIH w/ tool string to tubing tail C~ 9026' MD. 6. Pressure up the IA to 3000 psi and take returns to the formation. Well should be on a vacuum. Ensure constant pressure on the IA. 7. Log a continuous pass with no stops or interruptions from tubing tail at 9026' MD to the surface at no faster than 30 fpm. Note: Logging any faster than 30 fpm can result in a "blocky" leak signature. 8. Perform repeat passes and stop counts around anomalies as required. When a leak is located, the leak rate may be confirmed by placing the sensor of the tool at the leak point and bleeding off the IA. The signal should die off. Make sure that adequate stop counts are taken to identify the leak within 5' - 10`. The patch length is 30', so we need to be certain we can cover the leak. 9. Flag line at leak location and POOH. 10. RIH and set 3-1/2" L-80 single set Baker patch across the leak as per manufacturer recommendations. Note: L-80 is requested because chrome corrodes in injectors due to oxygen in the water. 11. Bleed of pressures to zero. RDMO. Fullbore Post Patch (if patch set) 1. MIT-IA to 3000 psi, LLR if it fails. 2. RDMO and return well to injection as per WIC. 1 Y • " TecWel LDL Presentation: 1. Present all full passes individually on 1"scale. 2. Anomaly passes should be on a 5" scale. 3. Overlay temp curves from the static baseline pass and the full dynamic passes on a 1"scale. 4. Clearly label all passes with: a. logging direction/speed b. pumping configuration/rate/direction/fluid type and temperature c. approximate bbls away at beginning of each pass ., 0 ~ ~ 09-37 '"~""°`° ..~ OY1TE l~11 HY GATE PTV BY Ob>YSEI~IT3 0811&94 p1I6lML CQIPLETIpiI 0~~(~ (:AT3T VLV StT dNt'3!®i LAST YIf~1~V t0~O5fOB G T VLV R~LEU 4SM8101 PlY1P 11d18t09 7EUiLH P9iF3AD~ 02A8IQ9 .~TqC WANBtSAPETY t~D$ U£~W Id31MIP.IC Al/9'tSF1Y K3TE !f Oi11Y1P S~V t~ 49118108 Fa.JAA WANEiiS0.FETY ~/~i4B) FRIDF~)EBkY tMT NBL: ~B-.YT P9i~f liD: X914289 API NY: 54tQ~22151-04 101 R15E. 12D/A2 Fal~S11D_t'FM. 8P Ekpbration {A4sxsj 09-37 194-028 PFRF OTTO[_HMFNT • Sw Name Operation Date Perf Operation Code Meas Depth Top Meas Depth Base Tvd Depth Top Tvd Depth Base 09-37 9/2/94 PER 10,597. 10,637. 8,989.23 9,026.71 09-37 10/15/06 APF 10,474. 10,480. 8,874.44 8,880.03 09-37 10/15/06 APF 10,490. 10,504. 8,889.35 8,902.39 09-37 10/15/06 APF 10,530. 10,544. 8,926.64 8,939.71 09-37 10/16/06 APF 10,436. 10,442. 8,839.07 8,844.65 AB ABANDONED PER PFRF APF ADD PERF RPF REPERF BPP BRIDGE PLUG P ULLED SL SLOTTED LINER BPS BRIDGE PLUG SET SPR SAND PLUG REMOVED FCO FILL CLEAN OUT SPS SAND PLUG SET FIL FILL SQF SQUEEZE FAILED MIR MECHANICAL ISOLATED REMOVED SQZ SQUEEZE MIS MECHANICAL ISOLATED STC STRADDLE PACK, CLOSED MLK MECHANICAL LEAK STO STRADDLE PACK, OPEN OH OPEN HOLE • OPERABLE: 09-37 (PTD #1940280) Passed MITIA, remains compliant with AA for IA ... Page 1 o£%3w • • Regg, James B (DOA) From: Sent: To: NSU, ADW Well Integrity Engineer [NSUADWWeIIlntegrityEngineer@BP.com] Sunday, October 05, 2008 12:45 PM Regg, James B (DOA); Maunder, Thomas E (DOA); GPB, Area Mgr East (FS1/2/COTU/Seawater); GPB, GC2 OTL; GPB, GC2 Wellpad Lead; Rossberg, R Steven; Engel, Harry R; NSU, ADW Well Operations Supervisor; GPB, Wells Opt Eng; GPB, Optimization Engr; GPB, EOC Specialists Cc: Townsend, S. Eliot; NSU, ADW Well~egrity Engineer; Phillips, Patti J Subject: OPERABLE: 09-37 (PTD #1940280) Passed MITIA, remains compliant with AA for IA repressurization Attachments: MIT PBU 09-37 10-04-08.x1s AI I, Wel! 09-37 (PTD# 1940280) has passed a MITIA to 2500 psi confirming barriers to liquid and compliance with AOGCC AA 4E.019. The well has been reclassified as Operable and may remain on injection. A copy ofi the MITIA form has been included for reference. «MIT PBU 09-37 10-04-08.x1s» Please let us know if you have any questions. Thank you, ,,~lnnrz ~u6e, ~'. E. Well integrity Coordinator GPE3 ells Group Phone: (907) 659-5102 Pager: (907) 659-5100 x1154 From: NSU, ADW Well Integrity Engineer Sent: Thursday, September 25, 2008 11:18 AM Y ~~~~ To: 'Regg, James B (DOA)'; 'Maunder, Thomas E (DOA)'; GPB, Area Mgr East (FSl/2/COTU/Seawater); GPB, GC2 OTL; GPB, GC2 Wellpad Lead; Rossberg, R Steven; Engel, Harry R; Daniel, Ryan; NSU, ADW Well Operations Supervisor; GPB, Wells Opt Eng; GPB, Optimization Engr; GPB, EOC Specialists; Phillips, Patti J Cc: Winslow, Jack L.; Holt, Ryan P (ASRC); NSU, ADW Well Integrity Engineer Subject: UNDER EVALUATION: 09-37 (PTD #1940280) IA Repressurization while on PWI -UPDATE Jim and Tom, In following with the evaluation plan stated below, an additional MIT-IA to 2,500 psi was conducted on 9f23f08 with passing results. However, there is some doubt as to whether or nat the minimum 1,000 psi TxIA differential was achieved, so the test will be repeated to ensure that the minimum required tubing integrity is verified. The well remains classified as Under Evaluation and on the original 28-day clack beginning 9119{08. The plan forward still remains: 1. F: MIT-IA to 2500 psi, LLR if fails. 2. WIC: Shut-in if fails, or eval for further diagnostics if passes. Please call with any questions or concerns. 10/7/2008 OPERABLE: 09-37 (PTD #1940280) Passed MITIA, remains compliant with AA for IA ... Page 2 of~ly • Thanks. On behalf of Anna Dube, ,~rxson ~. ~a alternate -Taylor Wellman by Alaska -Well Integrity Engineer office: 907-659-5098 cell: 713-299-2651 pager: 659-5100 x1446 harmony: 758-2418 From: NSU, ADW Well Integrity Engineer Sent: Friday, September 19, 2008 9:06 AM To: 'Regg, James B (DOA)'; 'Maunder, Thomas E (DOA)'; GPB, Area Mgr East (FSl/2/COTU/Seawater); GPB, GC2 OTL; GPB, GC2 Wellpad Lead; Rossberg, R Steven; Engel, Harry R; Daniel, Ryan; NSU, ADW Well Operations Supervisor; GPB, Wells Opt Eng; GPB, Optimization Engr; GPB, EOC Specialists; Phillips, Patti J Cc: NSU, ADW Well Integrity Engineer; Winslow, Jack L.; Holt, Ryan P (ASRC) Subject: UNDER EVALUATION: 09-37 (PTD #1940280) IA Repressurization while on PWI Jim and Tom, Well 09-37 (PTD #1940280) is an injector limited to PWI by AIO 4E.019 allowing continued injection with TxIA communication to MI injection. An AOGCC witnessed MIT-IA passed to 2,500 psi on 09/09/08. However, the IA has demonstrated repressurization while on PWI since. The IA has been bled three times since 09/12/08 with the IA building back to tubing pressure each time: 09/12/08: Bled IA from 1370 psi to 300 psi all fluids. 09/14/08: Bled IA from 1320 psi to 360 psi. 09/17/08: Bled IA from 1320 psi to 0 psi (fluid/gas) The initial evaluation of the well led us to conclude the first bleeds were due to thermal activity. However, as bleeding activities continued, it was determined that further diagnostics are needed. The well has been reclassified as Under Evaluation for continued diagnostics with the well on injection. The plan forward for the well is as follows: 1. F: MIT-IA to 2500 psi, LLR if fails 2. WIC: Shut-in if fails, or eval for further diagnostics if passes. A wellbore schematic, TIO plot and Injection plot have been included for reference. Please call with any questions or concerns. Thank you, Andrea Hughes Well Integrity Coordinator Office: (907) 659-5102 Pager: (907) 659-5100 x1154 10/7/2008 Email to:jim.regg@alaska.gov; tom.maunder@alaska.gov;bob.fleckenstein@alaska.gov;doa.aogcc.prudhoe.bay@alaska.gov OPERATOR: BP Exploration (Alaska), Inc. ' '~~ I~ ~~ (' FIELD /UNIT /PAD: Prudhoe Bay /PBU / DS 09 DATE: 10/04/08 OPERATOR REP: Anna Dube AOGCC REP: STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION Mechanical Integrity Test I~ ~ Packer Dep h Pretest Initial 15 Min. 30 Min. Well 09-37 Type Inj. W TVD 7 627' Tubing 1,280 1,280 1,280 1,280 Interval O P.T.D. 1940280 Type test P Test psi 1907 Casing 1,350 ,500 2,490 2,480 P/F P Notes: Repeat MITIA to establish 1000 psi differential and OA 380 380 380 380 to ensure compliance with AA 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 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 TYPE INJ Codes D =Drilling Waste G =Gas I =Industrial Wastewater N =Not Injecting W =Water TYPE TEST Codes M =Annulus Monitoring P =Standard Pressure Test R =Internal Radioactive Tracer Survey A =Temperature Anomaly Survey D =Differential Temperature Test INTERVAL Codes I =Initial Test 4 =Four Year Cycle V =Required by Variance T =Test during Workover O =Other (describe in notes) MIT Report Form BFL 11/27/07 MIT PBU 09-37 10-04-O8.xls MEMORANDUM To: Jim Regg q ~ P.I. Supervisor ~~ ~ ` ~~~v ~ FROM: Bob Noble Petroleum Inspector State of Alaska Alaska Oil and Gas Conservation Commission DATE: Wednesday, September 10, 2008 SUBJECT: Mechanical Integrity Tests BP EXPLORATION (ALASKA) INC 0937 PRUDHOE BAY UNIT 09-37 Src: Inspector NON-CONFIDENTIAL Reviewed By: P.I. Suprv `~~<-- Comm Well Name• PRUDHOE BAY UNIT 09-37 Insp Num• mitRCN080910064016 Rel Insp Num: API Well Number: 50-029-22451-00-00 permit Number 194-028-0 ~ Inspector Name: Bob Noble Inspection Date• 9/9/2008 Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. Well 09-37 Type Inj. ~' ' TVD ~ 76z6 IA ~ Izao zsoo zsoo zsoo p T. I9aozso TypeTest SPT Test psi zsoo pA s7o s9o i 590 590 i ' Interval oT~R P/F P ~ Tubing ~ tzso Izso tzso Izso Notes: 2 Year test cycle Wednesday, September 10, 2008 Page 1 of 1 09-37 (PTD #1940280) Internal Waiver Cancellation - Normal Well . . --'lto\01 All, An internal waiver was issued for TxlA communication on well 09-37 (PTD #1940280) on 03/08/06. The well passed an MITIA on 09/08/06 proving two comepentent barriers. Under the new WI System Policy set to take effect on June 1,2007, well 09-37 will be Operable. The Administrative Approval for TxlA communication will not be cancelled. The well is reclassified as a Normal well. Please remove all waivered well signs and the lamintaed copy of the waiver from the well house. Thank you - Jack L. Winslow (for Andrea Hughes) Well Integrity Engineer office - 659-5102 pager - 659-5100, 1154 SCANNED MAY 1 6 2007 1 of 1 5/10/200711:18 AM • • - _ _ SARaiF4 PALfAI, GOyERtVOR ~ ~ 333 W. 7[n AVENUE. SUITE 100 ~~++g~~1 I~~ ~-a ~~~s76L'I~~~JI~®~ ;~®~1~ 9~~~1~ ANCHORAGE, ALASKA 99501-3 53 9 ~ PHONE (907) 279-1433 FAX (907) 270"-7542 ADMINISTRATIVE APPROVAL AIO 4E.019 Mr. Steve Rossberg Wells Manager BP Exploration (Alaska) Inc. P.O. Box 196612 Anchorage, AK 99519-6612 ~'<.~' ,lAN ~ ~ 208 RE: PBU 09-37 (PTD I94-028) Request for Administrative Approval Dear Mr. Rossberg: In accordance with Rule 9 of Area Injection Order ("AIO") 04E.000, the Alaska Oil and Gas Conservation Commission ("AOGCC" or "Commission") hereby grants BP Exploration (Alaska) Inc. ("BPXA")'s request for administrative approval to continue water injection in the subject well. This administrative approval replaces the canceled sundry approval (301-3 ~ 1 }. PBU 09-37 exhibits slow tubing-casing annulus (inner annulus) repressurization. AOGCC finds that BPXA has elected to perform no corrective action at this time on PBU 09-37. The Commission further finds that, based upon reported results of BPXA's diagnostic procedures, PBU 09-37 exhibits two competent barriers to release of well pressure. Accordingly, the Commission believes that the well's condition does not compromise overall well integrity so as to threaten human safety or the environment. AOGCC's administrative approval to continue water injection in PBU 09-37 is conditioned upon the following: 1. BPXA shall record wellhead pressures and injection rate daily; 2. BPXA shall submit to the AOGCC a monthly report of well pressures and injection rates; 3. BPXA shall perform an MIT-IA every 2 years to 1.2 times the maximum anticipated well pressure; 4. BPx~, shall limit the well's IA pressure to 2,000 psi; AIO ~E.Oi9 March 13> 300 Pale 2 or 3 ~. BPXA shall immediately shut in the well and notit~ the AOGCC if there is any change in the weli's mechanical condition; 6. after well shut in due to a change in the well's mechanical condition, AOGCC appro~~al shall be required to restart injection, and 7. The MIT anniversary date is September 30, 2006. As provided in AS 31.0.080, within 20 days after written notice of this decision, or such further time as the Commission grants for good cause shown, a person affected by it may file with the Commission an application for rehearing. A request for rehearing is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. A person may not appeal a Commission decision to Superior Court unless rehearing has been requested. ld dated March 13, 2007. ~~ ~~~ Cathy/P. Foerster Commissioner RE: PBO 09-37 Admin Approval Request . . Jim, Bob and Tom, Please see the attached MIT form for the MITIA done on 09/08/06. Please call with any other questions. Thank you, Andrea Hughes Well Integrity Coordinator Office: (907) 659-5102 Pager: (907) 659-5100 xl154 Sì~ MAR (] 9 Z007 -----Original Message----- From: James Regg Ita: im .sLate.ak.us Sent: Tuesday, 3:40 PM To: NSU, ADW Well Integrity Engineer Subject: PBU 09-37 Admin Approval Request Received admin approval for this well; you reference an MITIA done on 9/8/2006; we do not have a record of that test but do have a CMIT TxIA (w/TTP) witnessed by the Commission on 9/30/2006 I'd appreciate a copy of the 9/8/2006 MIT for our files. Thank you. Jim Regg AOGCC Content-Description: MIT PBU 09-37 09-08-06.xls MIT PBU 09-37 09-08-06.xls Content-Type: applicationJvnd.ms-excel Content-Encoding: base64 1 of 1 3/9/2007 1 :31 PM . . Email to:Winton_Aubert@admin.state.ak.us;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: Notes: Well P.T.D. Notes: Well P.T.D. Notes: Well P.T.D. Notes: Well P.T.D. Notes: TYPE INJ Codes D = Drilling Waste G = Gas I = Industrial Wastewater N = Not Injecting W = Water MIT Report Form BFL 9/1/05 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION Mechanical Integrity Test BP Exploration (Alaska), Inc. Prudhoe Bay / PBU / OS 09 09/08/06 Andrea Hughes v P TYPE TEST Codes M = Annulus Monitoring P = Standard Pressure Test R = Intemal Radioactive Tracer Survey A = Temperature Anomaly Survey D = Differential Temperature Test INTERVAL Codes I = Initial Test 4 = Four Year Cycle V = Required by Variance T = Test during Workover o = Other (describe in notes) MIT PBU 09-37 09-08-06.xls 1. Operations Abandon 0 Repair Well 0 Plug Perforations 0 Stimulate 0 Uther ~ Cancel Sundry Performed: Alter Casing 0 Pull Tubing 0 Perforate New Pool 0 WaiverD Time Extension 0 #301-351 Change Approved Program 0 Operat. Shutdown 0 Perforate 0 Re-enter Suspended Well 0 2. Operator BP Exploration (Alaska), Inc. 4. Current Well Class: 5. Permit to Drill Number: Name: De\elopment Exploratory 194-0280 J 3. Address: P.O. Box 196612 Stratigraphic Sef'\.1ce 6. API Number: Anchorage, AK 99519-6612 I 50-029-22451-00-00 I 7. KB Elevation (ft): 9. Well Name and Number: 46.7 KB ¡ 09-37 J 8. Property Designation: 10. Field/Pool(s): ADL-028327 ' Prudhoe Bay Field/ Prudhoe Bay Oil Pool I 11. Present Well Condition Summary: Total Depth measured 10810 / feet Plugs (measured) None true vertical 9189.3 , feet Junk (measured) None Effective Depth measured 10718 - feet true vertical 9102.78 feet Casing Length Size MD TVD Burst Collapse Surface 2 10-3/4" 45.5# L-80 26 - 28 26 - 28 5210 2480 Conductor 80 20" 91.5# H-40 32 - 112 32 - 112 1490 470 Surface 3502 9-5/8" 40# L -80 28 - 3530 28 - 3529.82 5750 3090 Production 10783 5-1/2" 17# L -80 21 - 10804 21 - 9183.65 7740 6280 SCANNED MAR 02 2007 Perforation depth: Measured depth: 10597 - 10637 True Vertical depth: 8989.23 - 9026.71 Tubing: (size, grade, and measured depth) 3-1/2" 7# QT800 21 - 8992 2-7/8" 6.5# L-80 8992 - 9026 Packers and SSSV (type and measured depth) 12. Stimulation or cement squeeze summary: Intervals treated (measured): Treatment descriptions including volumes used and final pressure: 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing pressure Prior to well operation: Subsequent to operation: 14. Attachments: 15. Well Class after proposed work: Copies of Logs and Surveys Run Exploratory De\elopment Sef'\.1ce ~ Daily Report of Well Operations 16. Well Status after proposed work: ./ Oil Ir Gas r WAG r GINJ r WINJ r;¡ WDSPl 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. I~Undry Number or N/A if C.O. Exempt: 301-351 Contact Anna Dube / Andrea Hughes Printed Name Anna Dube, P.E. Title Well Integrity Coordinator d ~W Phone 907-659-5102 Date 2/21/2007 Signatur . (,~ ",... ,I .~ ~ I ,L-VL-I L-..... . STATE OF ALASKA J"~I MAR 0 1 Z007 ALA Oil AND GAS CONSERVATION COMM.&J"'/:> REPORT OF SUNDRY WELL OPERAi'rÕtJ§& Gas Cons. Commission Form 10-404 Revised 04/2004 0 RIG I N A L RBDMS BfL, MAR () 1 Z007 Submit Original Only STATE OF ALASKA ALASKA Oil AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERA TIQYS Oil & Gas Canso Commission . . RECEIVED I"'Jr'T ó} 4 ~'pnc" \ t,. ¡ W', ¿UJr) 2. Operator Name: 3. Address: BP Exploration (Alaska), Inc. Repair WellO Pluç¡ PerforationsD Pull TubingD Perforate New POOIO Operation ShutdownD Perforate I!] 4. Current Well Class: Development 0 Stimulate 0 WaiverD f.f,n¡"'!,~~n-rEJ: a , h ~ ,~!.'. 'J,,,," . !I.~ Other 1. Operations Performed: Abandon 0 Alter CasingD Change Approved ProgramD 46.30 8. Property Designation: ADL-028327 11. Present Well Condition Summary: StratigraphicO 9. Well Name and Number: 09-37 §JCploratoryD '"'"'.' ií~'''''"", ð t I.l ServiceŒl' Time ExtensionO Re-enter Suspended WellO 5. Permit to Drill Number: 1 8 PI Number 50-029-22451-00-00 P.O. Box 196612 Anchorage, Ak 99519·6612 7. KB Elevation (ft): 10. Field/Pool(s): Prudhoe Bay Field / Prudhoe Bay Pool Total Depth measured 10810 feet true vertical 9189.0 feet Effective Depth measured 10709 feet true vertical 9094.0 feet Plugs (measured) Junk (measured) None Perforation depth: Length Size MD TVD Burst Collapse 80 20" 91.5# H-40 32 112 32.0 112.0 1490 470 2 10-3/445.5# L-80 26 28 26.0 28.0 5210 2480 3502 9-5/8" 40# L-80 28 - 3530 28.0 - 3530.0 5750 3090 10783 5-1/2" 17# L-80 21 - 10804 21.0 - 9184.0 7740 6280 t:;t'~ ~~ ~N~'J~r-: t} IN' ,,~ """, ~ý c;.,-,.. II Casing CONDUCTOR SURFACE SURFACE PRODUCTION Measured depth: 10436-10442,10474-10480,10490·10504, 10530-10544, 10597-10637 True vertical depth: 8839-8845,8874-8880,8889-8902,8927-8940,8989-9027 Tubinç¡ ( size, ç¡rade, and measured depth): 3-1/2" 7# QT800 TBG-CT 2-7/8" 6.5# L-80 @ 18 @ 8992 8992 9026 Packers & SSSV (type & measured depth): 5-1/2" Otis XN Nipple 5-1/2" Sealbore Receptacle wi XN Lock 3-1/2" Cameo DS SSSV Nipple @ @ @ 8992 8993 2981 12. Stimulation or cement squeeze summary: Intervals treated (measured): Treatment descriptions including volumes used and final pressure: 13 Oil-Bbl Representative Dailv Averaae Production or Iniection Data Gas-Met Water-Bbl Casin Pressure 5827 1350 o Tubing Pressure 1377 677 Prior to well operation: Subsequent to operation: 14. Attachments: ~ 15. Well Class after proposed work: Exploratory(] 16. Well Status after proposed work: OilD GasD DevelopmentD ServiceŒ] Copies of Logs and Surveys run _ Daily Report of Well Operations_ WAG 0 GINJD WINJŒ WDSPLD Prepared by DeWayne R. Schnorr (907) 564-5174 Sundry Number or N/A if C.O. Exempt: NIA 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact DeWayne R. Schnorr Printed Name DeWayne R. Schnorr Signature Title Petroleum Engineer Phone 564-5174 Date 10/24/06 Form 10-404 Revised 4/2004 OCT 2 7 2D06 . . 09-37 DESCRIPTION OF WORK COMPLETED NRWO OPERATIONS EVENT SUMMARY AWGRS 07/30/2006 TII/O=1150/1200/180 MIT OA 2500 psi PASSED (Reg compliance)(Temp=Hot) Pumped 2.4 bbls of 60* diesel down OA to reach 2500 psi 1 st test 1 st 15 min lost 40 psi 2nd 15 min lost 20 psi for a total of 60 psi in 30 min bleed OA psi down bleed back 2+ bbls Final Whp's=1150/1200/160 AWGRS 08/05/2006 T/I/O = 1150/920/200 Schmoo-B-Gone Treatment. Pump 106 bbls of SBG mixture down tubing. Flush hose with 1 bbl neat methanol. Let soak for 3 hours then pump 80 bbls of 1 % KCL for a flush. Flush hose with 3 bbls of neat methanol. Let for another 3 hours, DSO to POI. Final WHP's = 800/650/60 AWGRS 09/06/2006 TII/0=30/0+/0+, Temp=SI. Monitor WHP's, TBG & IA FL's (pre FB). TBG FL @ 1014' (9 bbls), IA FL @ surface. AWGRS 09/08/2006 ***WELL SHUT IN ON ARRIVAL*** BRUSH NX NIPPLE, TAG TD @ 10,609' MD W/2" DUMMY GUN. PERFS=1 0,597'-1 0,637'. 12' OPEN PERFS 28' COVERED. NO SAMPLE. SET 2.31" XN CAT. STANDING VALVE @ 9000' SLM, PERFORM CMIT TBG. & lA, TBG FAILED, IA PASSED (SEE LRS PUMP REPORT FOR DETAILS) NOTE LEFT STANDING VALVE IN HOLE ***WELL LEFT SHUT IN*** AWGRS 09/08/2006 T/I/O=O/O/O Assist Slickline CMIT TxIA, Spear in W/5 Bbls Neat flush W/ 233 Bbls 1 % KCL, Freeze Protect W/ 22 Bbls 60/40. Slickline set plug, then attempted to CMIT TxlA. Tubing wouldn't hold pressure. Rigged onto IA. MITIA PASSED to 2500psi. Lost 30psi 1 st 15min, lost 5psi 2nd 15min, for a total of 35psi in 30m in. Tubing pressure fell 120psi during MITIA. No apparent communication w/ CAT SV in hole @ 9020'. Bled down pressure. FWHP's = 500/0/50 AWGRS 09/30/2006 T/I/O =250/0/80 [AOGCC CMIT-TXIA TO 2500 psi.] Witnessed by {John Spaulding} PASSED Final WHP=420/420/80. See Ann Comm report for details AWGRS 09/30/2006 TII/0=250/0/80. Temp=SI. CMIT-TxIA PASSED to 2500 psi (for W/C). AOGCC State Witnessed by John Spaulding. Pumped 50/50 meth to CMIT-TxIA to 2550 psi. 1st 15 minutes TP/IAP decreased 180/180 psi. 2nd test: 1 st 15 minutes TPIIAP decreased 40/30 psi, 2nd 15 minutes TPIIAP decreased 20/20 psi. Bled back to 420/420 psi. Final T /1/0=420/420/80. AWGRS 10/03/2006 ***WELL S/I ON ARR.*** (PULL 2 7/8" CAT VALVE) ATTEMPTED TO PULL CAT VALVE W/2.5 GR BAIL W/2.5" BAILER. AWGRS 10/04/2006 RUN 2.25" P. BAILER TO 8981' SLM (BAIL WHAT APPEARS TO BE .25 GAL OF INJ MUNG) LAY DOWN FOR WEATHER STAND-BY. AWGRS 10/05/2006 (Pre add perf) PULLED CAT STANDING VALVE @ 8991' SLM TAG T.D @ 10,611'MD W/11' OF 21/8" STEM, PERFS= 10597'-10637'.14' OPEN PERFS, 26' COVERED.(SAMPLE OF INJ MUNG) ***NOTIFY DSO LEFT LEFT S/I*** AWGRS 10/15/2006 PERFORATED ZONES 10,530' - 10,544',10490' - 10504', AND 10474' - 10480' USING 2" HSD GUNS WITH PJ 2006, HMX CHARGES. PEN = 20.4", ENTRANCE HOLE = 0.26", WEIGHT = 7 GRAMS. RAN GR JEWELRY LOG FROM 10557' TO 8895'. Page 1 . . 09-37 DESCRIPTION OF WORK COMPLETED NRWO OPERATIONS AWGRS 10/16/2006 CONTACT DSO UPON ARRIVAL. SPOT EQUIPMENT AND HELD PJSM. RU. RIH WITH 10' PERFORATING GUN/SECURE FIRING HEAD/ CCL/ WIEGHT BAR. TIED IN TO SHORT JOINT AT 10,497' ON JEWELRY LOG. CCL TO TOP SHOT = 4.2'. PERFORATED ZONE FROM 10436' -10442' LOADED IN 10' GUN CARRIER. 2" HSD GUN LOADED WITH 37 PJ 2006 CHARGES @ 6JSPF. CHARGE DATA: PENETRATION = 20.4", ENTRANCE HOLE = 0.26", WEIGHT = 7 GRAMS TestEvent 10/22/2006 Test Event Inj Press, psi: 677 Type: PW Vol: FLUIDS PUMPED BBLS 4 Diesel --- PT Surface Equipment 45 Neat Methanol 31 60/40 Methanol Water 313 . 1 % KCL Water 2.4 Diesel 106 Schmoo-B-Gone Treatment 501.4 TOTAL Page 2 TREE = WB..LHEAD= ACTUA TOR= KB. B..EV = BF. B..EV = KOP= Max Angle = Datum MD = OatumTVD= 4"FMC CrN BA KER C 46' 4057' 50 @ 5921' 10444' 8800'SS 110-3/4" CSG, 45,5#, L80, ID = 9.953" I I 9-5/8" CSG, 40#, L80, ID = 8,835" I 3530' Minimum ID = 2.25" @ 9020' 2-7/8" OTIS 'XN' NIPPLE I 3-1/2" TBG-CT, 7#, QT800, .0093 bpt, ID = 3,094" TOPOF 2-7/8" TBG I 8992' 8992' 12-7/8" TBG, 6,5#, L-80, ,0058 bpf, 10 = 2.441" I 9026' PERFORA TION SUMMARY REF LOG: SWS CNI-G ON 08/21/94 A NGLE A T TOP PERF; ??? @ 10436' Note; Refer to Production DB tor historical perf data SIZE SPF INTERV AL Opn/Sqz OA TE 2" 6 10436 - 10442 0 10/16/06 2" 6 10474 - 10480 0 10/16/06 2" 6 10490 - 10504 0 10/16/06 2" 6 10530 - 10544 0 10/16/06 3-3/8" 6 10597 - 10637 0 09/02/94 IPBTDI 10709' 15-1/2" CSG, 17#. L80, .0232 bpf, ID = 4.892" I 10804' OA TE REV BY COMMENTS 08/18/94 ORIGINAL COM PLErION 09/15/94 LAST WORKOVER 05/16/01 RNITP CORRECTIONS 02/06/03 JMP/KK WANER SAFETY NOTE 09/05/05 OA V /PJC SSSV NIP CORRECTION 03/16/06 EZUPAG WANER SAFETY NOTE (03/08/06) DATE 09/08/06 10/05/06 10/16/06 09-37 SAFEr ES: ***TxIA COMM. OPERATING LIMITS: MAX lAP = 2000 PSI, MAX OAP = 1000 PSI (03/08/06 WAIVER). PWlINJ ONLY - NO MIINJECTIN ALLOWED.... REV BY CJNlTLH KSB/TLH T8../TLH -l 10-3/4" X 9-518" XO . 2981· -13-1/2" CAM OS SSSV NIP, ID = 2,812" 7999' 5-1/2" PARKER SWS NIP, (BEHIND CT) 10 = 4,562" 8985' -13-1/2" OTIS XN NIP, 10 = 2,75" I -15-1/2" OTIS XN NIP, 10 = 4.455" I -:13-1/2" X 2-7/8" XO, ID = 2.375" I -l5-1/2" SEALBORERECEPrACLEW/XN LOCK -12-7/8" LOC SEAL UNfT (BEHIND CT LINER) I 9020' -12-7/8" OTIS XN NIP, 1D=2,25 9026' -12-7/8" MULESHOEWLEG I H B..MD- IT - NOT LOGGBJ COMMENTS CATSTANOINGVLV SET CAT STANDING VLV PULLBJ PERFS ADDED PRUDHOE BA Y UNfT WB..L; 09-37 PERMfT No; 1940280 API No; 50-029-22451-00 SEC 1, T10N, R15E. 1204.02' FB.. & 3110.1' FNL BP Exploration (Alaska) MEMORANDUM . State of Alaska . Alaska Oil and Gas Conservation Com miss TO: . .r).. hm Regg \ ,.¿",. 'ol'~ ,i '-''-' . /'J'Jf~'-/ P.I. Supervisor I i /;1 )c I ;;I-/O,p ( . DA TE: Tuesday, October 03,2006 SUBJECT: Mechanical Integrity Tests BP EXPLORATION (ALASKA) INC 09-37 PRUDHOE BA Y UNIT 09-37 ~ () ~ct \~Ù{ FROM: John Spaulding Petroleum Inspector Src: Inspector Reviewed By: P.I. Suprv '- 'J"ß¡2..- Comm NON-CONFIDENTIAL Well Name: PRUDHOE BAY UNIT 09-37 Insp Num: miÙS060930122052 Rei Insp Num Permit Number: 194-028-0 Inspector Name: John Spaulding Inspection Date: 9/30/2006 API Well Number 50-029-22451-00-00 Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. Well: 09-37 ¡Type Inj. I N I TVD i 7627 ì IA ì 0 I 2540 " , 1'- ------,--- P.T. ! 1940280 íTypeTest i SPT I Test psi' 1906.75 I OA I 80 80 futerval REQVAR PfF ~ - Tubi;;-gT- 250 .! 2530 Notes Annual test required by variance. Tubing tail plug set at 9200'md ---r-----------~ 2500 I 2480 , 2480 i ---~-~,~----+--,-,-~- 80 I 80 : 80 1 ! .~--..,.----- 2500 2480 i 2480 i .- Tuesday, October 03, 2006 Page I of 1 MEMORANDUM TO: Jim Reggv ,J öJ.. 7ja;' P.I. Supervisor \\ fé{C{ r,L FROM: Lou Grimaldi Petroleum Inspector Well Name: PRUDHOE BAY UNIT 09-37 Insp Num: mitLG05090913 1142 Rei Insp Num ) State of Alaska ) ~ \~U(/ cP Reviewed By: ,~ P.I. Suprv '-J p¡z.- Comm Inspector Name: Lou Grimaldi Inspection Date: 9/7/2005 Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. Well 09-37 IType Inj. N i TVD 8992 I IA I 180 2540 2445 I 2460 2440 P.T. 1940280 ITypeTest SPT I Test psi 2248 lOA 380 200 215 215 215 Interval REQVAR PIF P Tubing 1600 2580 2520 2500 2480 Notes Test required for Variance compliance. WfL plug set in tubing tail at 9017 (WLM). Thursday, October 27, 2005 Alaska Oil and Gas Conservation Commission DATE: Thursday, October 27,2005 SUBJECT: Mechanical Integrity Tests BP EXPLORA nON (ALASKA) lNC 09-37 PRUDHOE BA Y UNIT 09-37 Src: Inspector NON-CONFIDENTIAL API Well Number 50-029-22451-00-00 Permit Number: 194-028-0 ~CANNED NOV 1 7 2005 Page I of 1 ~'- STATE OF ALASKA ( ALASKA OIL AND GAS CONSERVATION COMMISSION Mechanical Integrity Test Email to: Winton_Aubert@admin.state.ak.us; Bob_Fleckenstein@admin.state.ak.us; Jim_Regg@admin.state.ak.us OPERATOR: FIELD I UNIT I PAD: DATE: OPERATOR REP: AOGCC REP: BP Exploration (Alaska) Inc. Prudhoe Bay / PBU /0809 11/03/03 A. Oube Not Witnessed Packer Depth Pretest Initial 15 Min. 30 Min. Well 09-37 Type Inj. S TVD 7,626' Tubing 1,260 800 800 800 Interval 1 P.T.D. 1940280 Type test P Test psi 1,907 Casing 760 2,500 2,170 1,860 P/F F Notes: Annual LLRT required by sundry#301-351 , .31 gpm @ 2500 psi Well Type Inj. TVD Tubing Interval P.T.D. Type test Test psi Casing P/F Notes: Well Type Inj. TVD Tubing Interval P.T.D. Type test Test psi Casing P/F Notes: Well Type Ini. TVD Tubing Interval P.T.D. Type test Test psi Casing P/F Notes: Well Type Ini. TVD Tubing Interval P.T.D. Type test Test psi Casing P/F Notes: Test Details: TYPE INJ Codes F = Fresh Water Inj G = Gas Inj S = Salt Water Inj N = Not Injecting TYPE TEST Codes M = Annulus Monitoring P = Standard Pressure Test R = Internal Radioactive Tracer Survey A = Temperature Anomaly Survey D = Differential Temperature Test INTERVAL Codes I = Initial Test 4 = Four Year Cycle V = Required by Variance T = Test during Workover a = Other (describe in notes) MIT Report Form Revised: 06/19/02 2003-11 03_MIT _(LLRTLPBU_09-37.xls II¡IE'---- llJ'£""[' fi'~~-"iO'O"""1 '"-,, -- - ,"" - --- -' - ,-" - - . r ' @[iA\J~Nj",j,: i r \Þ <Ù 0 ¿ <.1 STATE OF ALASKA ' ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: Operation shutdown_ Stimulate_ Plugging _ Perforate _ Water Injection Only Pull tubing _ Alter casing _ Repair well _ Other_X H20 INJECT ONLY 2. Name of Operator 5. Type of Well: 6. Datum elevation (DF or KB feet) BP Exploration (Alaska), Inc. Development__ RKB 46 feet 3. Address Explorato~ 7. Unit or Property name P. O. Box 196612 Stratigraphic__ Anchorage, AK 99519-6612 Service__x Prudhoe Bay Unit 4. Location of well at surface 8. Well number 5077' FNL, 4961' FEL, Sec. 01, T10N, R15E, UM (asp's 718733, 5941680) 09-37 At top of productive interval 9. Permit number / approval number 3110' FNL, 1345' FEL, Sec. 01, 71 ON, R15E, UM (asp's 722292, 5943676) 194-028~/301-351 At effective depth 10. APl number 3127' FNL, 1235' FEL, Sec. 01, T10N, R15E, UM (asp's 722400, 5943738) 50-029-22451-00 At total depth 11. Field / Pool 3110' FNL, 1204' FEL, Sec. 01, T10N, R15E, UM (asp's 722430, 5943756) Prudhoe Bay Oil Pool 12. Present well condition summary Total depth: measured 10810 feet Plugs (measured) true vertical 9189 feet Effective depth: measured 10709 feet Junk (measured) true vertical 9094 feet Casing Length Size Cemented Measured Depth True Vertical Depth Conductor 112' 20" 260 sx Arcticset (Approx) 144' 144' Surface 3504' 9-5/8" 1095 sx CS 11/375 sx 'G' 3530' 3530' Production 10783' 5-1/2" 800 sx Class 'G' 10804' 9183' Perforation depth: measured Open Parrs 10597' - 10637' true vertical Open Perfs 8989' - 9027' Tubing (size, grade, and measured depth) 3-1/2", 7#, QT800 TBG-CT @ 8992' MD. 3-1/2" x 2-7/8" @ 8992'; 2-7/8", 6.5#, L-80 TBG @ 9026'. Packers & SSSV (type & measured depth) 5-1/2" x 2-7/8" Sealbore Receptacle W/XN Lock @ 8993' MD. 3-1/2" Camco SSSV Nipple, A-1 ISSSV @ 2981' MD. 13. Stimulation or cement squeeze summary Intervals treated (measured) (see attached) Treatment description including volumes used and final pressure 14. Representative Daily Average Production or Injection Data OiI-Bbl Gas-Mcr Water-Bbl Casing Pressure 'Fu~ ing Pressure Prior to well operation 10/15/2001 3560 2440 Subsequent to operation 11/24/2001 11987 1653 15. Attachments 16. Status of well classification as: Copies of Logs and Surveys run__ Daily Report of Well Operations __ Oil __ Gas __ Suspended __ Service WATER iNJECTOR 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. ~~~..~~)~ Title: Technical Assistant Date January 04, 2002 Prepared by DeWayne R. Schnorr 564-5174 Form 10-404 Rev 06/15/88 · SUBMIT IN DUPLICATE 09-37 DESCRIPTION OF WORK COMPLETED NRWO OPERATIONS 09/04/2001 09/06/2001 10/08/2001 10/16/2001 10/20/2001 10/29/2001 11/10/2001 11/11/2001 11/24/2001 ANN-COMM: MITIA/LLRT-IC ANN-COMM: EVAL HIGH IA PRESSURE ANN-COMM: KILL TBG AND MITIA, LLRT IA ANN-COMM: PULL ISSSV/SET TT PLUG (PRE CMIT) ANN-COMM: CMIT-T+IA TO 3000 PSI PRE-AOGCC ANN-COMM: MITOA/MIT-T/LLRT-T ANN-COMM: PULL TTP ANN-COMM: PULL PLUG BODY (POST MIT) WATER INJECTION STARTED EVENT SUMMARY 09/04/01 MITIA FAILED/LLRT-IC 0.6 GPM @ 3000 PSI (FOR W/C) 09/06/01 TIO = 2620/1900/280. BLED IA TO 600 PSI. 10/08/01 MITIA FAILED ON PRESSURE STABILIZATION, 100 PSI/15 MIN 10/16/01 PULLED 3 1/2" A-1 ISSSV (SERIAL# HKS-425). SET 2 1/2" PXN TT PLUG (PRONG - 83" LONG & 1 3/8" FN). BLED 300 PSI FROM TOP OF PLUG---HELD. RDMO. LEFT WELL SHUT-IN FOR CMIT. 10/20/01 CMIT-T+IA TO 3000 PSI FOR PRE-AOGCC (PASSED.) 10/29/01 MITOA PASSED/MIT-T FAILED (0.7 GPM @ 3000 PSI) 11/1 o/01 PULLED P-PRONG FROM PULG BODY @ 9002' SLM. UNABLE TO LATCH PLUG BODY DUE TO WHAT LOOKS LIKE DRY SHMOO, MADE 2 RUNS W/2.5 D.D. BAILER. RECOVERED BAILER FULL ON BOTH RUNS, WAS ABLE TO GET DOWN TO 7792' SLM. LAY DOWN EQUIPMENT DUE TO WEATHER. 11/11/01 BAIL IRON SULPHITE. PULLED PXN PLUG BODY. DSO TO PLACE WELL ON INJECTION. 11/24/01 WATER INJECTION STARTED. WATER INJECTION RATE - 11987 BWPD @ 1653 PSI WHP. FLUIDS PUMPED BBLS 1 PRESSURE TEST LUBRICATOR W/1 BBL OF DIESEL, (1 TESTS) 78 METHANOL WATER 7 [50/50 METHANOL WATER 66 !CRUDE 270 ~KCL WATER 322 TOTAL Page 1 STATE OF ALASKA ' ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 1. Type of request: Abandon_ Suspend_ Operational shutdown _ Re-enter suspended well _ Alter casing _ Repair well _ Plugging _ Time extension _ Stimulate _ Change approved program _ Pull tubing _ Variance _X Perforate _ Other _ 2. Name of Operator BP Exploration (Alaska), Inc. 3. Address P. O. Box 196612 Anchorage, AK 99519-6612 4. Location of well at surface 5077' FNL, 4961' FEL, Sec. 01, T10N, R15E, UM At top of productive interval 3110' FNL, 1345' FEL, Sec. 01, T10N, R15E, UM At effective depth 3127' FNL, 1235' FEL, Sec. 01, T10N, R15E, UM At total depth 3110' FNL, 1204' FEL, Sec 01 T10N, R15E, UM 5. Type of Well: Development __ Exploratory __ Stratigraphic __ Service~X (asp's 718733, 5941680) (asp's 722292, 5943676) (asp's 722400,5943738) (asp's 722430,5943756) 6. Datum elevation (DF or KB feet) RKB 46.3 feet 7. Unit or Property name Prudhoe Bay Unit 8. Well number 09-37 9. Permit number/approval number 194O28O 10. APl number 50-029-22451 11. Field / Pool Prudhoe Bay Oil Pool 12. Present well condition summary Total depth: measured true vertical Effective depth: measured true vertical Casing Length Conductor 1 12' Surface 3504' Production 10783' Size 20" 9-5/8" 5-1/2" 10810 feet Plugs (measured) 9189 feet 10709 feet Junk (measured) 9094 feet Cemented 260 sx Arcticset (Approx) 1095 sx CS 11/375 sx 'G' 800 sx Class 'G' Measured Depth 144' 3530' 10804' True vertical Depth 144' 3530' 9183' RECEIVED Perforation depth: measured Open Perfs 10597' - 10637' true vertical Open Perfs 8989' - 9027' Tubing (size, grade, and measured depth Packers & SSSV (type & measured depth) 3-1/2", 7#, QT800 TBG-CT @ 8992' MD. 3-1/2" XO 2-7/8" @ 8992'; 2-7/8", 6.5#, L-80 TBG @ 9026'. 5-1/2" x 2-7/8" Sealbore Receptacle W/XN Lock @ 8993' MD. 3-1/2" Camco SSSV Nipple, A-1 ISSSV @ 2981' MD. 13. Attachments Description summary of proposal __X Detailed operations program__ BOP sketch__ 15. Status of well classification as: 14. Estimated date for commencing operation December 10, 2001 16. If proposal was verbally approved Name of approver Date approved Oil __ Gas __ Suspended __ Service Prod Water Inj 17. I hereby cedify that the foregoing is true and correct to the best of my knowledge. Signeddo~nE ~ Title: Well Integrity Engineer FOR COMMISSION USE ONLY Questions? Call Joe Anders 907/659-5102. Date December 10, 2001 Prepared by DeWayne R Schnorr 564-5174 Conditions of approval: Notify Commission so representative may witness \k~ J~'t'm~ ~ ~ t,% ~. ~J I Approval no. Plug integri~__ BOPT~t ~ Locatio~ cl'~aran' ~e~ ~ '~ [ ~[- ~[ Mechanical Integri~ Test ~ ~ ~~__ ~bsequent form required 10- ~~ ~[ ~'t ~ . ~'. -- _ ~ T~-- ~ Approved by order of the Commi~ion O,igJo,' Sig,,d ", commissioner Date~~~'A'~t'. Form 10-403 Rev 06/15/88 · SUBMIT IN TRIPLICATE 09-37 Description Summary of Proposal 12/09/01 Problem: Injector with slow TxlA communication Well History and Status Well 09-37 (PTD 1940280) is an injector that failed an MIT-IA on 09/04/01. The Drill Site Operator reported high IA pressure and an MITIA was conducted to evaluate the pressure source. A LLR of .6 gpm @ 3000 psi established. Recent events: > 09/04/01: MITIA Failed .6 gpm @ 3000 psi > 10/08/01: MITIA Failed, 100 psi/15 min > 10/16/01: SL set TTP > 10/20/01: CMIT Passed to 3000 psi > 10/29/01: MITOA Passed, MIT-T Failed .7 gpm @ 3000 psi > 11/10/01: SL pulled TTP This sundry request is to allow for continued injection of water. The following suppods the request: - A CMIT-TxlA Passed on 10/20/01 to 3000 psi against a tubing plug, demonstrating competent production casing. - Pressures and injection rates will be monitored and recorded daily and checked for indications of a production casing leak. - An annual IA leak rate test will be conducted to monitor the leak severity. - A CMIT TxlA against a TTP will be conducted every 4 years to confirm production casing integrity. Proposed Action Plan 1. Allow well to continue water-only injection. 2. Record wellhead pressures and injection rates daily. 3. Perform an annual IA leak rate test. 4. Perform combination MIT Tubing x IA against a plug every 4 years. 5. Submit a monthly report of daily pressures and injection rate. 6. Stop injection and notify the AOGCC if there is any indication of loss of production casing integrity. DATE REV BY COMMENTS DATE REV BY COMIVENTS 08/18/94 i ORIGNAL COMPLETION 09/15/94 LAST WORKOVER 12/23/00 SIS-SLT CONVERTED TO CANVAS 03/02/01 SIS-MD FINAL 05/16/01 RN/TP CORRECTIONS TREE= 4" FMC SAFETY NOTES - WAIVERED WELL - T x 09 37IA corrmunication on MI service; w aivered ' ACTUATOR=- BAKER C .~..].~.~...~ ................................................................. for 3000 psi on rvl. 46'j ~F. a_EV: I KOP: 4057'j / ,.~x.~.?...g!_e.~ ................ ~...0...._~.._..~.~.~!..i.'/ % 28' H 10-3/4,, x 9-5/8,, xoj Datum IvE)= 10444' ~ I !'~'i'~n ~'b~ ........ §§~°¢ ]10-3/4"CSG, 45.5#,L80,1D=9.953"H 20, IQ ----t 2981 Jd3-1/2" CAM DS SSSV NIP, A-11SSSV, D=2.812" [ 9:5/8" CSO, 40#, L80, ID = 8.835" Id 3530' Minimum ID =2.25"@ 9020' I 2-7/8" OTIS 'XN' NIPPLEJ ! ! --t 7999' Id5-1/2" PA RKER SWS NIP, I I i-L--{ 8985' I--~3-1/2"OT'SXNN,P,'D=2.75"I I 3-1/2"TBG-CT, 7#,QT800,.0093bpf, ID : 3.094" Id 8992' I " I----~ 8992' Id5-1/2"OTISXNNIP, ID:4.455"I ITOPOF2-7/8"TBeI--[ ~992' I 09.a' 1--15-1/2"SEALBORERECEPTACLEW/XNLOCKI , ~ 8993' I-~2-7/8" LQC SEAL UNIT(BEHIND CT LINER) i I I-- --I 9020' I-1~-7~'' OT,S XN N,,. ,~=2.~5 I I ~-~",~, ~.~, ~-~0, .00~ ~¢, ,~= ~.44~"H ~02~' ] P[J:~FORAIIO~ SUb/g/IA R¥ I REF LOG: SWS CNI-G ON 08/21/94 ANGLEATTOP PERF: 21 @ 10597' ~1 Note: Refer to Produc~on DB for historical perf data 3-3/8'1 6 10597 - 10637 0 09/02/94 I ~,="CSG, ~, L80,.0232 bpf, lD:4.892" I--I ~oso4' ~ ~~,~ I DATE REV BY I COMMENTS DATE REV BY ~ COMIVENTS ~ PRUDHOEBAY UNIT 08/18/94 I ORIGNAL COMPLETION WELL: 09-37 09/15/94 LAST WORKOVER I PERMIT No: 94-028 12/23/00 SIS-SLT CONVERTED TO CANVAS AR No: 50-029-22451-00 03/02/01 SIS-MD FINAL SEC1, T10N, R15E1 1204.02 FEL3110.1 FF~_ 05/16/01 RN/TP CORRECTIONS I I BP Exploration (Alaska) Wavered Injection Well Document Prudhoe Bay Unit 09-37 PTD t90-169 Sundry 301-350 in mid July 2001, the Prudhoe Bay Well integrity Engineer proposed a "categorization" method for Class Ii injection wells that had exhibited some form of mechanical integrity (MI) failure. A well has MI if the annular space between the tubing string and production casing (generally referred to as the Inner Annulus or IA) is capable of holding an applied positive pressure. The ability to hold such a positive pressure gives assurance that the tubing, casing and packer are competent. Occasionally, observations will indicated that some pressure communication has developed into the IA. Regulations require the operator to notify the Commission on the next working day and propose a diagnostic plan to determine the failure. If the MI failure occurs on a gas well (residue or miscible injectant), the well must be converted to water service or shut in. If the failure occurs on a well injecting water, permission may be obtained to begin performing the diagnostic tests while keeping the well in service. Depending on the results of the diagnostics, the regulations allow the welt to be kept in service, provided MI is demonstrated by an alternate method and the daily operating pressures and rates are monitored and reported monthly to the Commission. Through the years, a number of wells throughout the state have experienced MI failures. As the failures and M! issues have been resolved, a number of similar yet different testing requirements have been put in place to assure the MI of the "damaged" well. The proposal advanced by the Well Integrity Engineer catagorizes the wells based on the determined characteristics of the leak and proposed a consistent enhanced testing program for the wells. The determined categories, leak characteristics and MI test requirements are: Category IV Category !11 Category II Category I Slow tubing x IA communication Leak rate < 10 gpm Rapid tubing x IA communication Leak rate > 10 gpm IA x OA communication Production casing leak Report daily rate and pressure Annual Leak Loss Rate Test/MITIA CMIT T x IA every 4 years Report daily rate and pressure CMIT T x IA every 2 years Report daily rate and pressure CMIT IA x OA every 2 years Report daily rate and pressure MIT OA every year On September 4, 2001, PBU well DS 09~37 failed a MIT IA after the operator reported observing high IA pressure. Subsequent diagnostic work determined that the well had a tubing leak with a rate of 0.6 gpm at 3000 psi. On October 20, the well passed a CMIT T x IA. BP has applied to keep the well on water injection only service since MI has been demonstrated using an aitemate test. Based on the described classification system, this well is Category IV. ! recommend that BP's proposal for a waver for the subject well be approved with monitoring and Mi determinations as noted for Category IV above. Sr. Petroleum Engineer Re: Well 09-37 (PTD 1940280) Failed M!~TIA S~ubjec{: Re: Well 09-37 (PTD 1940280) Failed MITIA Date: Fri, 12 Oct 2001 14:33:53 -0800 From: Tom Maunder <tom_maunder@admin.state.ak. us> To: "NSU, ADW Well Integrity Engineer" <NSUADWWelllntegrityEngineer@BP.com> Joe, Thanks for the notice. I don't know that there is much consideration we can give with regard to keeping 9-37 on MI with a known (although small) tubing leak. The strong precedent that has been set is that we only give waivers for water only injection. I know that the preference is to keep the well on MI, but I seriously doubt that moving such a proposal forward to the Commissioners would be successful. There probably needs to be some serious diagnostics done to locate the tubing leak and effect some sort of repair. Unfortunately this well drew the short straw in this case. Good luck. Tom >, >, >, "NSU, ADW Well Integrity Engineer" wrote: > Hello Tom. > Injection Weft 09-37 (PTD 1940280) failed an MIT-IA due to lack of pressure > stabilization. On 10/08/01, an MIT-IA was attempted to evaluate high IA > pressure. The IA was pressured to 3000 psi and several pressure tests were conducted. The final test lost 100 psi at 15 minutes and 120 psi in the second I5 min ('220 psi in 30 min). Calculated leak rate is .2 GPM @ 3000 psi. The weft is currently on MI injection. Normal procedure is to put an injector with a failed MITIA on water injection then conduct additional pressure testing and leak detection where feasible. In this case, due to the slow leak rate, we are evaluating requesting to continue MI injection but with enhanced surveillance. For the case of slow TxlA communication, if the production casing were to fail, the "feed" rate from the tubing leak is slow enough that well control options are still viable. Our plan is to set a tubing taft plug and pressure test the tubing, production and surface casing. We will then evaluate submitting a sundry to continue WAG injection. We will keep you informed of diagnostic work progress. Please carl if you have any questions. Joe Joe Anders, PE / Kevin Yeager Well Integrity Engineer BP Exploration, Alaska Inc. (907) 659-5102 - Work (907) 659-5100, x1154- Pager emaih NSUADWWelllntegrityEngineer@bp. com Tom Maunder <tom maunderC_,admin.state.ak.us> Sr. Petroleum Engineer Alaska Oil and Gas Conservation Commission 1 of 2 12/18/01 5:23 PM ARCO DS 9-37 Subject: ARCO DS 9-37 Date: Tue, 8 Jun 1999 16:24:01 -0900 From: "PRB Problem Wells" <P 1041 ~mail. aai. arco. corn> To: Blair_Wondzell@admin.state. ak.us CC: "PRB Problem Wells" <P 1041 ~mail. aai.arco.com> Blair: A note for your files. ARCO Prudhoe Bay well 9-37 is a WAG injector with a coiled tubing completion. The well was swapped a year ago to PWI injection due to T x IA communication when on the MI cycle. In an effort to do more trouble-shooting, we recently returned the well to MI injection. The well will communicate fairly rapidly, requiring bleeding about 3 times per week to control the IA pressure less than 2000 psi (our standard IA maximum pressure). Injection on the well is running 3100 psi on MI, 1700 psi on PWI. We performed an MITIA yesterday (June 7, 1999) to 3000 psi, which passed with no problems. There is no other indication of communication on the well. We suspect one of the coiled tubing connectors to be the culprit. The leak is too small to attempt logging or repair. We have decided to let the well remain on MI service allowing the IA to have a new maximum pressure limit of 3000 psi. We will reduce the IA pressure to less than 2000 when on PWI cycle. Should any further problems result in the future with this well, we will let you know. I will send the MIT test form to your office via mail. Jerry Dethlefs ARCO Problem Well Specialist 907-659-5102 1 of 1 6/9/99 7:27 AM PERHIT A,."';-:~,~.c Znd.~i vi~ .-~ .... ......... ,...~u,.::~i ',,,/e i I ,3~o i og'i~ca't Hal:.er"~'a i s Znventor'y D,&TA T DATA_PLUS 94--~028 9a.~-(;)28 ~/OP R COHI::' DATE~ 09/02/'9a. R 08/0i--09/I6/9/~ iR 0,~00 ...... 10747 ANADR~LI... 9a....--028 94 --~ 028 L.. 9000'-i 066~'',.,~ L 10300- 10800 9.4--02o L. '10290w10800 9/il '" 02O'.' (,/E' T~ [~ *'tFkE' c, ,:: ..... o 94-~- 028 ~Tlt) T F' 0425-- 10671 I0278~10668 94--028 ~6-734 94.'"'028 ~735 94-028 L 9950-'-I0699 D 10688-10300 TDT D 10672--10300 CH/'CNTG D I0279-10808 OH/CDR D 10702~10297 TDT ,4r'.e dr'y cJ~'tch samp'ies r'equi'fed? yes r~ And i"ece'i'vect? y~ Was the wel'i cor'ed? yes ~Anal ysi's ~. descr"~'p!:'i'on r'ece~' ved'~zs - no ~ Reoet' red'? ,/es GeoQuest 500 W. International Airport Road Anchorage, AK 99518-1199 ATTN: Sherrie Well / j~L~ob #/'~~'~ NO. 9581 Company: Alaska Oil & Gas Cons Comm Attn: Larry Grant 3001 Porcupine Drive Anchorage, AK 99501 Field: Prudhoe Bay Floppy Log Description Date BL RF Sepia DIR MWD Disk 7/18/95 D.S. 9-37*"? 95235 DUAL BURSTTDTp 940831 1 / D.S. 9-37* 95236 CNTG 940827 1 D.S. 9-37** 94288 REDO CDR 940814 I I I TDT-P & CNTG: THESE DEPTH SHIFTED TAPES REPLACE TAPES SENT 30-DE0-95 WHICH WERE NOT DEPTH S~I~I~~ ** THESE DEPTH SHI~ED_.~INTS/TAP~REPLACE,._____, ,.,~ PRINTS/TAPE SENT 09-JUN-95 WHICH WERE N~T~ DEP'I'~IF~,D .. ~ U Please sign and return one copy of this transmittal to Sherrie at the above address. Thank you. GeoQuest 500 w. International Airport Road Anchorage, AK 99518-1199 ATTN: Sherrie NO. 9571 7/12/95 Company: Field ,~ Floppy Well Job # Log Description Date BL RF Sepia DIR MWD Disk Alaska Oil & Gas Cons Comm Attn: Larry Grant · 3001 Porcupine Drive Anchorage, AK 99501 Prudhoe Bay D.S. 5-6A :~' ., . 95225 CBT SONIC VIA COILED TUBING' 950626 I I "' D.S. 5-6 A ~' ~-~'~"- (-// 95225 OH CBT/IRT W/REPROCESSED DT "' 950626' " 1 .. , . , . , ...... , ,, , ,, ,, .... , , Please sign and return one copy of this transmittal to Sherrie at the above address. Thank you. GeoQuest 5ol) W. International Airport Road Anchorage, AK 99518-1199 A'n'N: Sherrie NO. 9515 Company: Alaska Oil & Gas Cons Comm Attn: Larry Grant 3001 Porcupine Drive Anchorage, AK 99501 6/9/95 Field: Prudhoe Bay Floppy Well Job # Log Description Date BL RF Sepia DIR MWD Disk ............................... .................... .... , , .................. ..... . . , . , SIGNED: Please sign and return one copy of this transmittal to Sherrie at the above address. Thank you. RECEIVED Alaska Oil 8, 6as 6ons. 6ommissior~ A~chorage GeoQuest 500 w. International Airport Road Anchorage, AK 99518-1199 ATrN: Sherrie NO. 9510 Company: Alaska Oil & Gas Cons Corem Attn: Larry Grant 3001 Porcupine Drive Anchorage, AK 99501 6/7/95 Field: Prudhoe Bay Floppy Well Job # Log Description Date BL RF Sepia DIR MWD Disk D.S. 05-16A 95111 SLIM1MwDGR ..... 110794 ........... 1 , , , D.$. 2-13A 95109 MWDGR 022795 1 'D.S. 4-16 CNTD 052295 1 1 'D.S. 4-19 ' DUAL BURST TDT. P 052895 I '' ..1 . . ' D.S. 4-47 DUAL BURST TOT-P 052595 I 1 .... D.S. 6-7 CHEMICAL CUTTER RECORD 05 2795 1 1 ,,, D.S. 9-37 DUAL BURST TDT-P 052495 I 1 D.S. 18-20 PRODUCTION pRoFILE 052695 I 1 , , , D.S. 15-14 : PERFORATION RECORD 052695 I 1 ..... ..... ......... , , , , , , ..... SIGNED: Please sign and return one copy of this transmittal to Sherrie at the above address. Thank you. RECEIVED DATE: JUN 09 1995 A,~.a ~ & ~a~ Cans. Commission GeoQuest 500 W. International Airport Road Anchorage, AK 99518-1199 ATTN: Sherrie NO. 9139 Company: Alaska Oil & Gas COns Comm Attn: Larry Grant 3001 Porcupine Drive Anchorage, AK 99501 12/30/94 Field: Prudhoe Bay Floppy Well Log Description BL RR Sepia RF Sepia Mylar Disk I O.S. 6-7 "~'O 2--'1 DUAL BURST TDT-P (7-13-9'4) D.s. 6-8 _"~_~., O-~-~/-7.~ " DUAL BURST TDT-P (6-15-94) D.S. 6-12A ~..-~ -~ ? DUAL BURST TDT-P (5-29-93) D.S. 6-14A. ~ [ ~ ~ ~ / DUAL BURST TDT-P (4-8-94) D.S. 6-1~A'~ CNTD (2-14-93) D.S. 6-22A ~ ~,-6~7 CNTD (5-22-94) ~ D.S. 7-18 ~ ~- ~ CNTD (5-21-94) D.S. 9-32 ~ C~ ~ ~ ~ CN~D (5-10-93) D.S. 9-32 ~ 0 ~ --l,~,O ,~:~UAL BURST TDT-P (7-7-94) ~?' ;" ...... ~NTG (8-27-94) D.S. 9-37i ~ ~*~ ,'/i~ D.S. 9-37i / ~~'~~ ~ ~ ~ I :DUAL BURST TDT-P (8-31-94) D.S. 11-29i ~ ~ CNTG ~. ~ /~ -~ (5-31-94) ~.S. 11-29i ~ DUAL BURST TDT-P (5-31-9~) D.S. 11-33 ~ ~~ ~ DUAL BURST TDT-P (8-25-94) D.S. 12-26 ~~O~ CNTD (6-22-93) D.S. 14-3 7 ~- G~~ CNTD (3-28-94) SIGNED.~~/'~ Please sign and retrun one copy DATE: Anchorage Page 3 STATE OF ALASKA ~ · ALASKA OIL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMP LETION REPORT AND LOG 1. Status of Well Classification of Service Well OIL [] GAS [] SUSPENOED [] ABANDONED [] SERVICE I~ WAG Iniector 2. Name of Operator 7. Permit Number ARCO Alaska, Inc. 94-28 3. Address 8. APl Number P. O. Box 196612, Anchorage, Alaska 99519-6612 50- 029-22451 4. Localion of well at surface : ~:~f~;:~i~l';:r~ ~: Prudhoe Bay Unit 2093'NSL, 1345'WEL, SEC. l s T10NsR15Ei~r'<?;~'?;~I '~~ 9-37 At Total Depth i ..... . ........ '---:~- :.' :!; Prudhoe Bay Field/Prudhoe Bay Pool 2170'NSL, 1207' WEL, SEC. 1, TION, R15E 5. Elevation in feet (indicate KB, DF, etc.) [6. Lease Designation and Serial No. KBE = 46.3' ! ADL 28327 12. Date Spudded 13. Date T.D. Reached 14. Date Comp., Susp. or Aband. 115, Water Depth, if offshore 116. No. of Completions 8/1/94 8/14/94 9/2/94I N/A feet MSL I One 17. Total Depth (MD+TVD) 18. Plug Back Depth (MD+TVD) 19, Directional Survey 120. Depth where SSSV set [21. Thickness of Permafrost 10810'MD/9189'TVD 10718'MD/9103'TVD YES [] NO []I 2981' feet MDI 1900'(Approx.) 22. Type Electric or Other Logs Run GR/RES/MWD 23. CASING, LINER AND CEMENTING REC_xS~D SE'ri'lNG DEPTH MD CASING SIZE WT. PER FT. GRADE TOP Be'FI'OM HOLE SIZE CEMENTING RECORD AMOUNT PULLED 20" 91.5# H-40 32' 112' 30" 260 sx Arcticset (Approx.) 9-5/8" 40# L-80 26' 3530' 12-1/4" 1095 sx CS !1/375 sx "G" 5-1/2" 17# L-80 21' 10804' 8-1/2" 800 sx Class 'G" 24. Perforations open to Production (MD+TVD of Top and Bottom and .~5. TUBING RECORD interval, size and number) SIZE DEPTH SET (MD) PACKER SET (MD) Gun Diameter 3-3/8" 6 spf 3-1/2"x 2-7/8" 9025' 'XN' Nipple @ 9020' MD TVD 10597'-10637' 8989'-9027' Coil tubing 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED 27. PRODUCTION TEST Date First Production JMethod of Operation (Flowing, gas lift, etc.) 10/18/94 J Injection Date of Test Hours Tested PRODUCTION FOR OIL-BBL GAS-MCF WATER-BBL CHOKESIZE IGAS-OIL RATIO TEST PERIOD I FIow Tubing Casing Pressure 3ALCULATED OIL-BBL GAS-MCF ~ATER-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. .[ F_C IV ED -~,~ Oil & G[ts Corl~,Commission A[~ch0r[ ' ........ Submit in duplicate Form 10-407 Rev, 7-1-80 CONTINUED ON REVERSE SIDE 29. , 30. , GEOLOC=~ 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. BKB Top Sadlerochit 10363' 8772' Zone 3 10363' 8772' Zone 2 103 75' 8783' Base Sadlerochit 10643' 9033' 31. LIST OF ATTACHMENTS 32. I hereby certify that the foregoing is true and correct to the best of my knowledge Signed /~/~ TitleOri]][r~Eng[noorSu. oorv[sor Date //"//°'~ ( INSTRUCTIONS General: This form is designed for submitting a complete and correct well completion report and Icg on all types of lands and leases in Alaska. Item 1: Classification of Service Wells: Gas injection, water injection, steam injection, air injection, salt water disposal, water supply for injection, observation, injection for in-situ combustion. Item 5: Indicate which elevation is used as reference (where not otherwise shown) for depth measurements given in other spaces on this form and in any attachments. Item 16 and 24: If this well is completed for separate production from more than one interval (multiple completion), so state in item 16, and in item 24 show the producing intervals for only the interval reported in item 27. Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval. Item 21: Indicate whether from ground level (GL) or other elevation (DF, KB, etc.). Item 23: Attached supplemental records for this well should show the details of any multiple stage cement- ing and the location of the cementing tool. Item 27: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water In- jection, Gas Injection, Shut-in, Other-explain. ~_~;~) Item 28: If no cores taken, indicate "none". ~C~ ~ ~ Form 10-407 BP/.a~AI SHARED SERVICE DAILY OPERATIONS PAGE: 1 WELL: DS 9-37I BOROUGH: NORTH SLOPE UNIT: PRUDHOE BAY FIELD: PRUDHOE BAY LEASE: API: 50- PERMIT: APPROVAL: ACCEPT: 07/31/94 03:00 SPUD: 07/31/94 10:30 RELEASE: OPERATION: DRLG RIG: DOYON 16 WO/C RIG: DOYON 16 08/01/94 ( 1) TD: 469' ( 469) 08/02/94 ( 2) TD: 618' ( 149) 08/03/94 (3) TD: 1672' (1054) 08/04/94 (4) TD: 3542' (1870) DRILLING MW: 8.9 VIS:285 MOVE RIG F/42 T/37I, LEVEL/SHIM, BUILD BERMS/SET MUD, WATER, CUTTINGS & SLOP TANK. PU & INSTALL BUSHINGS ON 5" KELLY. FLUSH MUD TANKS W/FRESH WATER. TAKE ON SPUD MUD, COND. MODIFY NIPPLE INSTAL TURN BUCKLES ON RISER. GATHER UP BHA & PUT IN PIPE SHED. TRQ KELLY CONN LUBE RIG. INSTALL MOUSE HOLE. SPOT & HOOK UP TRANSFER PUMP. FUCTION TEST DVRTR SYST. 30 SEC. CLOSURE. CHECK FOR LEAKS, CHK FLT SWITCH ON TRANSFER PUMP. SPUD DRILL T/120'. WORK ON CUTTINGS CONVEYOR & DRILL F/120 T/469. TIH T/CHANGE MWD MW: 8.9 VlS:188 CLEAN OUT DESILTER, DRILL. TOOH T/TIGHTEN PUMP BELTS. EMPTY SCREEN IN FILTER SUB. TIH PU KELLY. MUD SYSTEM LOSDED W/GRAVEL. TOOH T/FILTER SUB. CLEAN MUD SYST. CUTTINGS TANK, MUD TANK. CHANGE VALVES & SEATS IN PUMP. CLEAN SUCTION IN PUMP, INSTALL NEW SCREEN IN SUCTION. BUILD MUD VOL. TRIP T/UNPLUG BIT. DRLG T/618. MWD FAILURE. CIRC WHILE ATTEMPTING TO GET MWD T/WORK. DRILLING MW: 8.9 VIS:244 TIH F/MWD TOOL. PU KELLY DRILLING F/618 T/1233. REPLACE BELTS ON CONVEYOR. DRLG & SURV. F/1233 T/1288. TRIP OUT T/REPAIR CONVEYOR. REPLACE SPROCKET ON CUTTINGS CONVEYOR. TIH T/1233 & WASH T/1288. DRLG & SURV. 1288 T/1672. TOOH T/RUN CASG MW: 9.6 VIS:205 DRLG & SURV. F/1672 T/2659. CBU. SHORT TRIP T/1200. PU KELLY WASH T/BTTM. NO FILL. DRLG F/2659 T/3542. CIRC HOLE CLEAN. SHORT TRIP T/2000. CIRC & COND HOLE. TOOH T/RUN 9-5/8" CASG. SLM. WEL,L : DS 9-37I OPERATION: RIG : DOYON 16 PAGE: 2 08/05/94 (5) TD: 3542' ( 0) 08/06/94 (6) TD: 3542' ( 0) 08/07/94 (7) TD: 5100' (1558) 08/08/94 (8) TD: 6011' ( 911) 08/09/94 (9) TD: 7344' (1333) 08/10/94 (10) TD: 8437' (1093) 08/11/94 (11) TD: 9017' ( 580) MU CASG HEAD & TBG SPOOL MW: 9.6 VIS: 0 TOOH LD BHA. RU T/RUN 9-5/8" CASG. RUN 40# L-80 BTC CASG, BAKER LOK 1ST 3 CONNECTIONS. INSTALL BOW SPRING CENT'S ON 1ST 20 JTS. FILL EVERY JT. RU/CIRC & RECIP CASG. CMT CASG - IN PLACE @21:45 HRS. BUMP PLUG W/2000. RELEASE PRESS. FLTS. HELD. NO CMT ON RETURNS. RU BJ PUMP 40 BBLS TOP JOB. WASH UP CMT LINES. RIG DOWN BJ. LD CMT BACK OUT LANDING JT. ND DIVERTOR SYST. INSTALL SPLIT HEAD. DRLG PLUGS & CMT IN 9 5/8" MW: 8.4 VIS: 29 INSTALL 13 5/8" SPLIT UNIHEAD. SET BOP'S. COMPLETE TIGHTING UNIHEAD. TEST SEAL. CONTINUE TO NIPPLE UP BOPE. TEST BOPE. INSTALL WEAR BUSHING. NIPPLE UP DRLG NIPPLE AND FLOWLINE. PICK UP 8.5" BHA. TRIN INTO 2673'. LD 60 JTS 5" GRADE GPU 60 JTS GRADE E 5" TRIP IN TO 3444' TAG CMT PLUGS. PU KELLY. FILL PIPE. TEST 9 5/8" CSG. DRLG OUT PLUGS AND CMT. DRILLING MW: 9.3 VIS: 35 DRILL CMT PLUGS FC AND SHOE. DRILLED 10' NEW HOLE TO 3562'. CIRC BTTMS UP. TAKE LEAK OFF TEST. CLOSED RAMS PUMPED 14 STROKES, BROKE DOWN, BLED BACKKK AND HELD. SHOE TEST. DRILLING F. 3562-3650', ORIENT AND START DIRECTIONAL DRILLING F/ 3650-4398'. CIRC SHORT TRIP TO SHOE @3529'. PU KELLY. DRILLING AND SURVEYS W/ ANADRIL F/ 4398-5018' SHORT TRIP 8 STDS T/ 4200'. DRILLING F/ 5018-5100'. DRILLING MW: 9.4 VIS: 36 DRILLING F/ 5100-5607'. CIRC SHORT TRIP 10 STANDS. DRILLING F/ 5607-5961'. CBUo PUMP PILL TRIP OUT FOR BIT AND BHA CHANGE. CHANGE MOTOR-BIT-BHA-RIH, FILL PIPE @3496'. DRILLING F/ 5961-6011' DRILLING MW: 9.4 VIS: 36 DRILG F/6011 T/6975. CBU & WORK PIPE. SHORT TRIP 20 STNDS T/5129. DRLG F/6975 T/7344. TRIP OUT F/BIT #4 MW: 9.7 VIS: 45 DRLG F/7344 T/7900. CIRC. SHORT TRIP 11 STNDS. DRLG F/7900 T/8437. CBU. TRIP OUT F/MWD & BIT #4. DRLG 8-1/2" HOLE AT 9017' MW: 9.8 VIS: 49 COMPLETED POH FOR BIT CHANGE. P/U NEW BIT. SURFACE TESTED MWD. RIH TO SHOE. SLIPPED AND CUT DRILL LINE. CONT'D RIH TO BOTTOM AT 8437'. HOLE IN GOOD CONDITION. DRILLED (ROT+SMM) /SURVEYED (MWD)/ORIENTED (AS REQ'D) 8-1/2" HOLE FROM 8437' TO 9017'. WELL : DS 9-37I OPERATION: RIG : DOYON 16 PAGE: 3 08/12/94 (12) TD: 9630' ( 613) 08/13/94 (13) TD: 9845'( 215) 08/14/94 (14) TD:10682' ( 837) 08/15/94 (15) TD:10810' ( 128) 08/16/94 (16) TD:10810' ( 0) DRLG 8-1/2" HOLE AT 9630' MW: 9.8 VIS: 50 CIRC B/U AT 9017'. POH ON SHORT TRIP TO 9-5/8" SHOE AT 3529'_ HOLE IN GOOD CONDITION. MAX O/P 10-15 KLBS. CIRC HOLE CLEAN. RIH TO BOTTOM AT 9017' DRILLED (ROT + SMM) ORIENTED (AS REQ'D)/SURVEYED (MWD) ~-1/2" HOLE FROM 9017' TO 9630'. ADT 13 HRS. DRILLING MW: 9.7 VIS: 48 DRLG F/9630 T/9653. ERRRATIC TRQ, ROP DROPPED F/50-60 FPH T/25-30 FPH. CBU POOH F/NEW BIT, SM_M, MWD CHANGE OUT. SLM +3.6-NO CORRECTION LD SLM & MWD. PULL WB, RUN TEST PLUG, TEST RAMS , C& KINES/VALVES, CHOKE MANIFOLD, FLOOR VALVES 500/5000, ANNULAR 300/3000. TEST WITNESSED BY BOOBY FOSTER-STATE REP W/AOGCC. RE-RAN WB. PU NEW BIT. MU BHA W/REPLACEMENT SMM, MW/), SURFACE TESTED SM_M, MWD. RIH T/5853, TOOK BNCHMRK SURV. GOOD . RIH T/9600. WASH & REAM F/9600 T/9635, HOLE GOOD. DRILLED F/9653 T/9845. DRILLING MW: 9.8 VIS: 49 DRLG F/9845 T/10009. ELEC. MOTOR ON SHALE SHAKER FAILED. MADE 20 STND SHORT TRIP T/8135 WHILE REPLACING MOTOR. TIGHT SECTION @9216. WORKED THRU WHEN POOH. RIH OK. DRILG F/10009 T/10682. CIRC T/COND MUD MW:10.0 VIS: 48 DRLG F/10682 T/10810. CBU. POOH ON CONDITIONING TRIP. PU LWD COLLAR. HOLE IN GOOD SHAPE. LD BIT, SMM, MWD COLLAR. PU RR BIT. MU BHA W/LWD COLLAR. RIH T/SHOE. SLIP & CUT DL. CONT RIH T/10295. MADE MAD LOGGING RUN W/LWD WHILE RIH T/10810. CBU T/COND. MUD PRIOR T/POOH. LD DP T/RUN CASG. RUNNING 5-1/2" CSG MW:10.0 VIS: 53 COMPLETED CIRC TO CONDITION MUD/HOLE FOR CSG. POH LAYING DOWN DP/BHA TO RUN CSG. HOLE IN GOOD CONDITION. R/U TO RUN CSG. CHANGED RAMS TO 5-1/2". HELD SAFETY MEETING. RAN 5-1/2" 17 PPF CASING AS PER PROGRAM. AT REPORT TIME HAVE 184 JTS RAN OUT OF TOTAL 261 JTS TO RUN. HAVE EXPERIENCED NO HOLE PROBLEMS TO REPORT TIME. WEL~L : DS 9-37I OPERATION: RIG : DOYON 16 .. ; PAGE: 4 08/17/94 (17) TD:10810' ( 0) 08/18/94 (18) TD:10810 PB: 0 N/U DRY HOLE TREE MW: 8.5 VIS: 28 DURING REPORT PERIOD: NO ACCIDENTS; NO SPILLS; WELL UNDER BUDGET. COMPLETED RUNNING 5-1/2" CSG. RAN TOTAL OF 261 JTS (27 JTS NEW NSCC CSG ON BOTTOM (ABOVE SHOE JTS) PLUS MARKER JT; 234 JTS RECLAIMED LTC CSG) 5-1/2" 17 PPF L80 NSCC/LTC R3 CSG. INSTALLED TBG HGR. M/U LANDING JT. LANDED TBG HGR. SHOE AT 10803' R/U CMT HD/LINES. CIRC TO CONDITION MUD/HOLE FOR CMT. CIRC W/PUMP RATES TO 14 BPM. CLEARED RIG LINES W/SW. RU BJ. PUMPED 5 BBLS FW. TESTED LINES TO 4000 PSI. PUMPED 15 BBLS FW PREFLUSH FOLLOWED BY 70 BBLS BJ MCS-4 11.0 PPG SPACER. DROPPED BOTTOM PLUG. RELOADED HD. MIXED AND PUMPED 422 SX "G" 15.7 PPG TAIL SLURRY. BOTH SLURRYS W/ADDITIVES AS PER PROGRAM. FLUSHED CMT OUT OF SURFACE LINES. DROPPED TOP PLUG. DISPLACED W/248 BBLS INHIBITED SW AT 13.5 - 14 BPM. BUMPED PLUG W/2500 PSI. INCREASED PRESS TO 3500 PSI. TESTED CSG FOR 30 MIN. GOOD TEST. CIP @ 15:03 HRS. R/D CSG RUNNING EQUIP. DRAINED/FLUSHED STACK. RECOVERED LANDING JT. INSTALLED 7-5/8" PACK-OFF. FILDS. TESTED PACK-OFF TO 5000 PSI FOR 15 MIN. GOOD TEST. R/U SURFACE LINES TO 5-1/2" X 9-5/8" ANN. INJECTED 250 BBLS 10.0 PPG MUD DOWN ANN AT AV REATE/PRESS OF 3/5 BPM @ 850 PSI. RIH PICKING UP 2-7/8" 6.5 PPF TRG TO 2000' NOTE: DSM INJECTED 90 BBLS INHIBITED METHANOL WATER DOWN ANNULUS THILE RIH TBG. RATE/PRESS - 3 BPM @ 600 PSI. REV CIRC HOLE TO DIESEL AT 2000'. POH LAYING DOWN 2-7/8" TBG. R/D TBG RUNNING EQUIP. INSTALLED FALSE BOWL W/BPV. N/D, SET BACK BOP STACK. N/U ADAPTER FLANGE W/FULL 7-1/6" THRU BORE GATE VALVE (DRY HOLE TREE) RIG RELEASED MW: 8.5 Seawater CONPLETED NU DRY HOLE TREE W/7-1/16" THRU BORE VALVE. TESTED TREE T/3000 W/DIESEL. PREPARED RIG F/MOVE. CLEANED LOCATION. RIG RELEASED WELL DS 9-37I @ 7:30 HRS ON 8/17. SIGNATURE: (drilling superintendent) DATE: 9-37i DESCRIPTION OF WORK COMPLETED COILED TUBING COMPLETION INSTALLATION 8/25/94: RIH & tagged PBTD at 10649' MD. 8/27/94: Ran GR/CCL/CNT-G/CET/CNL logs. 8/31/94: Ran TDT/USIT logs. 9/2/94: RIH w/perforation guns & tagged PBTD at 10675' MD, then PU & shot 40' of initial perforations at: 10597 - 10637' MD (Z1) Ref Log: SWS CDR 8/14/94. Shot the perfs at 6 spf, at 60 degree phasing, from 3-3/8" carriers. shots fired. Rigged down. POOH w/perf guns; noted all 9/10/94: Ran & set a Sealbore Receptacle / Tail Assembly in the wellbore as follows: MIRU Crane. RIH w/Sealbore Receptacle assembly & set in the XN Nipple at 8992' MD (equipment details & set depths on schematic attached). POOH w/setting tools, then RIH & set a 2-7/8" XXN plug inside the Sealbore assembly at 9005' MD. PT assembly to 2700 psi; had slow leak. RIH & pulled the XXN plug. Rigged down. 9/1 I/94: MIRU & RIH to set a 2-7/8" XXN plug inside the Sealbore assembly at 9005' MD. PT assembly to 3000 psi for 30 minutes; tested OK. RIH & pulled the XXN plug, then ran & set a DXXN plug in the XN nipple at 9005' MD. Rigged down. 9/13/94 - 9/16/94: Ran & set a 3-1/2" Coiled Tubing Completion in the well as follows: MIRU 3-1/2" CT Spool #1 & PT equipment. MU & RIH w/Seal Assembly & 3-1/2" Coiled Tubing (details of assembly on schematic attached). Spooled off CT to RIH to 6015' MD, then cut the CT, & moved in 3-1/2" CT spool #2. MU Connectors; PT connectors. Continued RIH w/CT Spool #2 to land in Sealbore Receptacle. Cut the CT at the surface, MU connection, & landed the tubing hanger. PT backside to 1500 psi for 30 minutes; tested OK. Rigged down. · -- - I I · I II II II Wall Date PrBp,Bad By: A,C, ' " ......... ~OD' -:-~'' ~ '-; I I ~ J l ~ __4~;~~1~; ~,~ ~,OO4 , ~910- _~ ' ! ( ~!.011 J ~ 10 ~UNr~~) ,:. 3 ,2'979, . 0.08 9001 i ~ n -~ . .[]_i~tJ ; I B~ . o~4,ao, i g~j1~ L ISl~ 7~ ~P Lees ~,~ 4 [ fl l..g ~ gOiS,/g . t g J..g_l .... -j--lq"n ~ .-' ,,.. I , lB ~lw~ ~_~. r _ ~ --~---- , ~ g I., 8 ...... - -- , I .! JI I~'~ ' ' :--r-_~ !!! .i._.i1':~'~--. ,, . ...... i -.ii !.[7i ~ l['J il..!14i . ~ ..... , .... ,-- ., i, ~!'I ~! _ j II I . I.._~t61 .... ~, , ~-~1 i.~.i , , ~ I.t - ~11, ~ ,- ...... ~ _I~ ' ~,86~ i--Z~-.~ ........... .,, , ,, ,, ,-- .............. i"-- ]- L ~ ~.'J_ ~~~ ........ ' , ",! ! ! I ~ ~ ,_ ~~AJ~I~R ...... , , -'L.I t ~._I t _- . , ' ' -~ i ~.I._[ ~ ..... -~ L,Ir-I , t i - ii I j ~ ,~ ;, ; i ! ' , Bm iii it ''"' ' · · ~LL HEN) I,[]C,~TIO~: L~T(W-S) DI~'G/-W) 0,00 AZ..MUTH 14~OM ROTARY ?~L~ TO TAR~ IS 62.4& TIE IH POIHT(I'IP) : ~ DEPTH 0,00 ~ VERT D~:~H 0,00 I~LIHATIOH ~ZII'bTH 0,00 :ATIll.q)E(I,[/-S) D~ARTI.~d~ (E/-W) 0,00 I~A~ Ihrl]~AL V~E~ICAL DL~H DEPTH ft ft ft 0,~ 0,0 0,00 197.17 197,2 197.17 288,90 91.7 28B,90 37&07 87.2 ~8.00 181,~ SLRV~Y ~?IONS ~*~ MINIMU~ CtJRVAII. Kd~ w~4oh~w~, ?AR~ S?A?ION AZI~FrH IATIlt~£ ~ION INCLN. ft deg. deg ft 0,00 0.00 0.00 O.OC 0,47 0,28 50,28 0.31 0,78 0.11 70,74 0,4~ 0,94 0,12 26,08 0,59 1,11 0,04 351,20 0,82 7~'-~ 09-37I D~'ARTL~E DISPLACBgB4T at AZI~JrH ft ft deg 0,00 0,00 0,00 0,37 0.4~ 50.28 0,63 0,79 52,62 0.75 0,95 51.78 0.82 1.16 45.05 DIS deg/ lOOft 0.00 0,14 0,19 0,09 738,25 924,73 1113.22 1294,93 1484,55 180.3 738.25 186.5 924.72 188,5 1113.21 181,7 1294.91 189.6 1484.53 1,89 0,51 81,02 1,01 1,61 1.90 57,96 0,29 3.03 0.27 101.40 1,05 2.86 3.05 69,84 0,15 3.69 0,20 77.79 1.04 3,63 3,77 74.07 0,06 4.14 0,14 115,36 1.01 4,14 4,26 76,27 0.07 4,80 0,34 81.29 1,00 4,90 5,00 78,45 0,13 1672,70 1856.71 2043,44 2231,95 2416,28 188,2 1672,68 184,0 1856.69 186.7 2O43,42 188,5 2231.92 184.3 2416,3 5.97 0.46 95.00 1,02 6,20 6,28 80,67 0.08 6,58 0.10 156,22 0,81 7.00 7.05 83.43 0,23 7.03 0,33 94,45 0.62 7.61 7,63 85.38 0.16 8.77 0,78 70,65 1,00 9,37 9,43 83,91 0,26 11,32 0,82 51,91 2,23 11,60 11,81 79.11 0,14 2601.25 2787,03 2973,41 3160,27 3349.89 185,0 2601.19 185.8 2786,95 I86.4 2973,32 186,9 3160,14 189,6 3349.72 13,79 0.73 61,35 3.61 13.67 14,14 75.20 0,08 16.05 0,69 74.83 4,47 15.78 16.40 74.19 0.09 18.18 0.86 104,32 4,41 18.20 18,73 76.37 0,23 20.47 1,29 115,95 3+15 21,44 21.67 81,65 0.26 21,52 1,14 159,14 0,45 24.03 24.04 88.92 0,48 3484.22 3686,12 3778.22 3870,82 3964.93 4057.24 4151,70 4245,07 4337,65 134,3 3484,03 99.7 593,73 I02.2 3685,87 92,1 3777.77 92.6 3869,90 92.3 4054.11 94,5 93.4 4237,09 92,6 4325.83 21.19 0,94 161.61 -1,83 24.85 24.92 94,22 0.16 20,79 0,77 176,57 -3.28 25,15 25.36 97,42 0,28 23.04 2,89 73,23 -3,22 27,66 27,84 96,63 3,09 29,12 4,74 65.67 -0.98 33,35 33,37 91,68 2.08 38.39 6.76 65.3'5 2.87 41,80 41.89 86.07 2,18 51,16 8,85 64,32 8.32 66.72 10.59 58,43 15.84 86.02 13,0q 56.47 26.30 108.76 15.20 59.25 38.4C 135.11 17,92 59,37 51,86 53.36 54.00 81.13 2,22 66.99 68.83 76,69 2,17 83,30 87.36 72,48 2,67 102.64 109.58 69.49 2.38 125.33 135.64 67,52 2,94 4432,57 4525.10 4618.97 470%95 4803,51 94,9 4415,37 92.5 4501.11 93,9 4586,97 91,0 4669.42 93.6 4753.10 16651 20,80 58,6.4 68.08 201,23 23,34 60.95 85,53 239.18 24.35 62,22 103,~ 277,62 25,64 60,90 121,90 319,42 27.49 59,23 142,7~ 152.29 166.81 65.91 182.35 201,41 64,87 215,73 239.31 64.35 249.53 2.77.72 &3.96 285,78 319.47 63,45 3,04 2,90 1.21 1,54 2.12 4897.38 4989,78 5081.29 5173.52 52~8,38 93.9 4895.14 92.4 4913,74 91.5 498?.98 92.2 5065,17 94,9 5139.70 364.97 30.64 60,64 165,61 413.54 32,81 62.87 188.57 464,13 ~,20 63.44 211,42 517.51 36,45 64.60 234.71 576.13 39.95 63,99 260.07 3~.25 364.98 63.02 3,44 368,06 413,55 62,87 2.66 413,20 464,14 62.90 1,70 461,26 517.54 63.03 2.46 514,15 576.18 63.17 3,72 DtTTH DF_~IH ft ft ft 5360,76 ?2,4 5209.48 5452,62 91,9 5276,20 5547,78 95,2 5342.~ 5734.08 186,3 5465,36 5921,17 187,1 ~,35 ******~******: A~4DRILL ?NU~ ~ATI~ ~I)tLrTH LATIlqJD~ S£L-TIOH IN~LH, N/-S ft d~ deg 768.47 47,52 61,76 347,80 ~.~ 49.59 62.94 412,~ 1~.78 49.~ 6I. 36 479, ~ D~PAR~ DISF'LA~ID,Fr at AZIMLFI'H ~-W ft ft deg 568,43 636.71 63.22 624,62 6~?,83 63.19 685,31 768.51 63.09 809,00 908.13 62.98 ~5,16 1050,81 62,87 DLS lO~ft 2.18 3.34 2.79 1.21 0.66 6105,80 62Ix3. I4 6480.19 66~.20 6849.11 184,6 57.06,59 187,3 58..~,74 187,1 5955,31 183,0 6077,70 185,9 6203,~ 1190.86 48,91 60.67 547.1~ 1331,05 48.08 60,05 616,51 1470,55 48,42 69+23 682,77. 1606,59 47,65 60.24 747, I8 1743,63 47,40 60,75 814,72 1057.73 1190.66 62.65 1179,67 1331.05 62,4I 1302.45 1470.56 62.34 1422,28 1606,60 62,2? 1541.62 1743.66 62,14 0.57 0.51 1+26 1.29 0.25 703620 7221,63 7407,88 7594,12 7779,74 187.1 6328.67 185.4 6450.95 186,2 6573,36 186.2 ~95,71 185.6 6816,88 1882,34 48,40 59,87 8S3.48 2021.62 49,09 60.18 953.1~ 2161,88 48,73 60,35 1022,75 2302,27 49,14 62,75 1089,6~ 2442+89 49+36 62,08 1154,74 1662,19 1882,40 62,01 1782.95 2021.73 61,87 1904,83 2162,04 61.77. 2028,2? 2302,44 61.75 2152,92 2443.05 61.79 0.64 0,40 0,21 1,00 0.30 7964.67 8147,94 8335,39 8522,25 8615,46 184,9 6~7.65 183.3 70b'7,~ 187,4 7179,~ 186,9 73~2,79 93,2 7364.96 2582,93 49,09 62,74 1219,60 2721,68 49,32 62,86. 12(k3,02 28~9.42 49.00 65.02 1345+31 3004,14 48,83 64,57 1405.29 3073,54 47.49 64,39 1435.21 2277,04 2583,09 61.83 0.31 2400.45 2721.62 61,88 0.13 2527,82 286;3,52 61.98 0,88 2655.25 3004,20 62.11 0.20 2717,92 3073,58 62,16 1.45 8708,89 8800.88 8893.30 8987.63 9078,12 99,4 7428.27 92,0 7491,38 92,4 7536,02 94+3 7623,31 90,5 7689,20 3142.21 47,20 64,57 1464.81 9209.13 46.17 62,43 1494,67 ~5,18 45.06 62.~ 1524,99 ::~)41.28 43.93 62,~ 1555,11 3403.29 42.60 62,60 1563,51 2779.93 3142,24 62,21 2839,83 3209,15 62.24 2898.50 3275,20 62,25 295"/,3'5 3341,30 62,26 3012,48 3403,31 62,27 0.34 2,03 1,27 1,20 1.~ 9169,56 9263.3~ 9353,75 9446,17 9539.58 91,4 7757.08 ?3,8 7828.18 90.4 7898,13 92.4 7971,08 93.4 8046.31 3464.56 41.54 62.76 1611.6~ 3525,78 39.93 62,37 1639,84 3582,?? 38,64 61.74 1666,65 3639.72 37,1I 62,74 1693,08 3695,07 35.58 63.25 1718.2~ 3066,91 3464.57 62,28 1,17 3121,25 3525.00 62,28 1.74 3171,79 3583,01 62,28 1,49 3221,?? 3639,74 62,28 1,79 3271.30 3695,09 62.29 1,67 9631+96 9724,38 9816.91 9911,60 lO(X)4,01 92,4 8122,36 92,4 8200,30 92,5 8279,98 94,7 8362,73 92,4 8444.39 3747,49 33,61 65.31 1741,00 3797,09 31,39 64,59 17~.2,02 3844.I2 29,73 62.35 17~,01 3890,15 28.44 62,29 1804.3~ 3933,40 Z7,3~ 64,58- 1823,75 3318,54 3747.50 62.32 3363.52 3797.10 62,35 3405.61 3844.13 62,37 3446,38 3890,16 62,37 3485,06 3933.41 62.38 2,48 2.44 2.18 1,35 1.63 10097.20 10188.61 10280,67 10375,03 10467,70 99.2 8527.88 ~74,78 ~,35 91,4 8610,89 4013,05 24,15 62,89 92,1 ~95.33 ~9,71 ~.79 62.89 94,4 8782.55 4085.70 22,06 62.80 92,7 8868,65 411%?? 21,38 62,21 1842,~. 3522,04 3974.78 62.39 1860,04 355'5,96 4013,05 62.3~ 1876,74 3588,59 4049,71 62,39 18~.17 3620,62 4085.70 62,40 1909,00 3651,03 4119.99 62,40 __ ~,~- E~} gD. chorL 2,51 1,38 1,48 0,7[ 0.77 $[~'V~ ~~TI~ ~'~ ~-~ ~TI~ I~. ~-S E/-~ ft it ft ft d~ d~ ft ft ft de9 l~t 1~61.23 93,5 8~,87 4153,~ ~,~ ~,63 1~,1~ ~0.69 4153,75 62,~ 0,76 106~,07 ~.8 9~3.74 4186,6~ ~.14 59.41 194t,60 37~,21 41~.65 62,37 0,97 10747.~ 92,3 91~,42 ~18.18 19,88 GeoQuest 600 W. International Airport Road Anchorage, AK 99518-1199 ATTN: Shenie NO. 89;35 Company: Alaska Oil & Gas Cons Comm , Attn: Larry Grant i ;3001 Porcupine Drive Anchorage, AK 99501 911 5194 Field: Prudhoe Bay Well Log Description BL RR Sepia RF Sepia Mylar -~. 'L~ v D.S. 9-;371 STATIC BOTTOM HOLE PRES SURVEY (9.04.94) 1 1 I -- D.S. 9-371 PERF RECORD (9-02-94) 1 1 _ D.S. 9-37i DUAL BURST TDT-P (8-31-94) 1..... 1 D.S. 9-,371 CBT (8-27.-94) 1 1 D.S. 9-;371 DUAL COMP NEUTRON EPITH ERMAL & THERMAL (8-27-94) 1 1 _ D.S. 9-~371 ..USIT (8-;31-94) 1 1 . .. , , , ? SIGN PI~ sign and ream one copy of ~is transmiflal to Sheffie at the above addre~. ~ank you. MEMORANDUM TO: THRU: State of Alaska Alaska Oil and Gas Conservation Commission David Joh[~n, Chairmarr~ Blair Wondzell, '~' t~' P. I. Supervisor FROM: Bobby Foster-~~ SUBJECT: Petroleum Inspector DATE: August 12, 1994 FILE NO: AFIIHLBD.doc BOPE Test - Doyon 16 ARCO - PBU - DS 9-371 PTD # 94-0028 Prudhoe Bay Field Friday, August 12, 1994' I traveled this date to ARCO's DS 9, well 371 and witnessed the BOPE test on Doyon rig 16. As the attached AOGCC BOPE Test Report shows there were no failures. The last test witnessed on this rig, on the 27th of July, a lot of failures occured. The stack has been repaired and is in good condition. The rig was clean and all of the equipment seemed to be in good working order. The location was clean and there was good access to the rig. Summary: I witnessed the BOPE test on Doyon rig 16 drilling well DS 9-371 - test time 3 hours - No failures. Attachment: AFIlHLBD.XLS STATE OF ALASKA OIL AND GAS CONSERVATION COMMISSION BOPE Test Report OPERATION: Drlg: X Drlg Contractor: Operator: Well Name: Casing Size: 9.625" Test: Initial Workover: DOYON Rig No. 16 PTD # 94-0028 ARCO Rep.: DATE: 8/12/94 Rig P 659-4610 / 11 BRUCE CAMPBELL DS g-371 Rig Rep.: JAMES (SNAKE) WILLINGHAM Set @ 3529' Location: Sec. I T. 1ON R. 15E Meridian UM Weekly X Other MISC. INSPECTIONS: Location Gen.: OK - Housekeeping: OK (Gen) Reserve Pit N/A Well Sign OK Drl. Rig OK BOP STACK: Quan. Annular Preventer 1 Pipe Rams Lower Pipe Rams Blind Rams Choke Ln. Valves HCR Valves Kill Line Valves Check Valve N/A Test Pressure P/F 300./3,000 P 500/5, 000 P 500/5,000 P 500/5,000 P 500/5,000 P 500/5,000 P 500/5,000 P MUD SYSTEM: V~ual Alarm Tdp Tank YES YES Pit Level Indicators YES YES Flow Indicator YES YES Meth Gas Detector YES YES H2S Gas Detector YES YES FLOOR SAFETY VALVES: Upper Kelly / IBOP Lower Kelly / IBOP Ball Type Inside BOP Test Quan. Pressure P/F I 500/5, 000 P 500/5,000 P 500/5,000 P 500/5,000 P CHOKE MANIFOLD: No. Valves 14 No. Flanges Manual Chokes Hydraulic Chokes I Test Pressure P/F 500/5, 000 P 38 500/5,000 P I P Functioned Functioned ACCUMULATOR SYSTEM: System Pressure Pressure After Closure 200 psi Attained After Closure 0 System Pressure Attained 2 Blind Switch Covers: Master: Nitgn. Btl's: 6 ~ 2200 3,050 ] P 1,450 P minutes 31 sec. minutes 22 sec. YES Remote: YES Psig. Number of Failures: 0 ,Test Time: 3.0 Hours. Number of valves tested 22 Repair or RepJace'~'~ of Failed Equipment will be made within 0 days. Notify the Inspector and follow with Written or Faxed verification to the AOGCC Commission Office at: Fax No. 276-7542 Inspector North Slope Pager No. 659-3607 or 3687 if your call is not returned by the inspector within 12 hours please contact the P. I. Supervisor at 279-1433 REMARKS: GOOD TEST. Distribution: orig-Weii File c- Oper./Rig c - Database C - Trip Rpt File c- Inspector STATE WITNESS REQUIRED? YES X NO 24 HOUR NOTICE GIVEN YES X NO Waived By: Witnessed By: BOBBY D. FOSTER F1-021L (Rev. 7/19) AFlIH LBD.XLS ALASKA OIL AND GAS CONSERVATION COMMISSION WALTER J. HICKEL, GOVERNOR 3001 PORCUPINE DRIVE ANCHORAGE, ALASKA 99501-3192 PHONE: (907) 279-1433 TELECOPY: (907) 276-7542 February 24, 1994 Terry Jordan Drilling Engineer Supervisor ARCO Alaska, Inc. P O Box 196612 Anchorage, AK 99519-6612 Re: Prudhoe Bay Unit 9-37 ARCO Alaska, Inc. Permit No: 94-28 Sur. Loc. 201'NSL, 318'EWL, Sec. 1, T10N, R15E, UM Btmhole Loc. 2163'NSL, l195'WEL, Sec. 1, T10N, R15E, UM Dear Mr. Jordan: Enclosed is the approved application for permit to drill the above referenced well. The permit to drill does not exempt you from obtaining additional permits required by law from other governmental agencies, and does not authorize conducting drilling operations until all other required permitting determinations are made. The blowout prevention equipment (BOPE) must be tested in accordance with 20 AAC 25.035; and the mechanical integrity (MI) of the injection wells must be demonstrated under 20 AAC 25.412 and 20 25.030(g)(3). Sufficient notice (approximately 24 hours) of the MI test before operation, and of the BOPE test performed before drilling below the surface casing shoe, must be given so that a representative of the Commission may witness the tests. Notice may be given by contacting the Commission petroleum field inspector on the North Slope pager at 659-3607. David W. ~hnsto~ ~--- Chairman BY ORDER OF THE COMMISSION dlf/Enclosures CC: Department of Fish & Game, Habitat Section w/o encl. Department of Environmental Conservation w/o encl. ,',?j,:'~ print(,rt f)n rr, o,,(:l,,r, pal)pr b y C.D. STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION PERMIT TO DRILL 20 AAC 25.005 la. Type of work Drill [] Redrill Dllb. Type of well. Exploratoryl-I Stratigraphic Test [] Development Oil [] Re-Entry [] DeepenI-II Service [] Development Gas [] Single Zone [] Multiple Zone [] 2. Name of Operator 5. Datum Elevation (DF or KB) 10. Field and Pool ARCO A/aska, /nc. KBE = 53.9' feet Prudhoe Bay Fie/d/Prudhoe 3. Address 6. Property Designation Bay Poo/ P. O. Box 196612. Anchoraae. Alaska 9~1~-~12 ADL 28327 4. Location of well at surf-ace [7. Unit or property Name 11. Type Bond(se,, 20 ^^c 25.025) 201' NSL, 318' EWL, SEC. 1, TION, R15E Prudhoe Bay Unit At top of productive interval 18. Well number Number 2129'NSL, 1261' WEL, SEC. 1, TION, R15E 9-37 U-630610 At total depth 9. Approximate spud date Amount 2163' NSL, 1195' WEL, SEC. 1, TION, R15E 3/1/94 $200,000.00 12. Distance to nearest 13. Distance to nearest well 14. Number of acres in property15. Proposed depth(UDandTVD) property line ADL 28345-1195 feet 9-14-413'@ 7799'MD feet 2560 10840'MD/9102' TVD feet 16. To be completed for deviated wells 17. Anticipated pressure (see 2o AAC 25.035 (e)(2)) Kickoff depth 3700 feet Maximum hole angle so o Maximum surface 3330 psig At total depth (TVD) 8800'/4390 ps~ 18. Casing program Setting Depth s~ze Specifications Top Bottom Quantity of cement Hole Casing Weight Grade Coupling Length MD TVD MD TVD (include stage data) 30" 20" 91.5# H-40 Weld 80' 32' 32' 112' 112' 260 sx Arcticset (Approx.) 12-1/4" 9-5/8" 47# NTaOLS NSCC 3525' 31' 31' 3556' 3556' 948 sx CS IIl/295 sx "G"/250 sx CS II 8-1/2" 5-1/2" 17# LSO/NSO BTC/LTC 10800' 30" 30' 10830' 9093' 730 sx Class "G" 19. To be completed for Redrill, Re-entry, and Deepen Operations. Present well condition summary Total depth: measured feet Plugs (measured) true vertical feet Effective depth: measured feet Junk (measured) true vertical feet Casing Length Size Cemented Measured depth True Vertical depth Structural Conductor SurfaceRECEIVED Intermediate Production FEB -9 1994 Liner Perforation depth: measured Alaska 0il & Gas Cons. Commission true vertical Anchorage 20. Attachments Filing fee [] Property plat [] BOP Sketch [] Diverter Sketch [] Drilling program ITl Drilling fluid program [] Time vs depth plot [] Refraction analysis[] Seabed report[] 20 AAC 25.050 requirementsl-] 21. I hereby certify that the f,p, regoing is true and correct to the best of my knowledge SJ~ned ~/.~~ Title Drilling Engineer Supervisor Date ~.--~-~ [¢ Commission Use Only Permit Number IAPI number IApproval date [See cover letter ~,-_~__ ? J50-o ~..~- ~_.z, ¢-"o-'/ J ~¢, ~¢3.,,.¢--~_~ Jfor other requirements Conditions of approval Samples required [] Yes J~ No Mud Icg required []Yes,~ No Hydrogen sulfide measures [] Yes ~ No Directional survey required ~ Yes [] No Required working pressure for BOPE FI2M; i-13M; ~f'SM; Fll0M; r-115M; Other: Original Signed By by order of Approved by David W. Johnston Commissioner me commission Date'Z/~_~'~( Form 10-401 Rev. 12-1-85 Submit in triplic ]Well Name: IDS9-37i Well Plan Summary Type of Well (producer or injector): [ WAG INJECTOR Surface Location: 201'FSL 318'FWL S01 T10N R15E UM Target Location: 2129' FSL 1261' FEL S01 T10N R15E UM Bottom Hole Location: 2163' FSL 1195' FEL S01 T10N R15E UM [AFE Number: [ 4J0246 I Estimated Start Date: ] 2/13/93 IMD: I 10,840' I I Rig: [ Doyon 16 I I Operating days to complete: ! 15 ITVD: 19,102' I [RTE: Well Design (conventional, slimhole, etc.): 53.9' [ Ultra-Slimhole Longstring Formation Markers: Formation Tops TVD (brt) MD (brt) K-15 4942 4984 K-10 7615 8820 K-5 9543 8089 TSAD/Ivishak 10416 87 61 Zone2/2C 10428 8772 Zone 2B/Tango 10469 8809 Zone 2A/Romeo 10582 8913 Zone 1B/L. Romeo 10623 8898 Top HOT 10675 9001 Base SAD/Kavik 10690 9015 TD 10840 9102 Casing/Tubin: ['rogram: Wt/l Hole Size Csg/ Wt/Ft Grade Conn Length Top Btm Tbg O.D. MD/TVD MD/TVD 30" 20" 91.5# H-40 Weld 80 32/32 110/110 12-1/4" 9-5/8" 47# NT-80LS NSCC 3525 31/31 3556/3556 8.5" 5-1/2" 17# L80/N80 BTC/LTC 10800 30/30 10830/9093 N/A 3-1/2" Coil 0.203" LB0 Equiv N/A (+/-) 5971 29/29 (+/-) 6000/5100 Tubing Logging Program: RECEIVED FEB 11 1994 A~aska Oil & Gas Cons. Commission Anchorage Well Plan Summary Page 1 Open Hole Logs: Cased Hole Logs: LWD:GR and Resistivity from the Base SAD to 200' above TSAD USIT/CBL from TD to 200' above K15 CNGT, TDT, GR from the base SAD to 200' above TSAD Mud Program: I Special 'design considbrations i None. Surface Mud Properties: I ,, Density Marsh Yield 10 sec 10 min pH Fluid (PPG) Viscosity Point gel gel Loss 8.5 200 30 30 40 9 15 tO tO tO tO tO tO tO 9.2 300 60 60 80 10 25 Intermediate Mud Prppertie..s: Density Marsh Yield 10 sec 10 min pH Fluid (PPG) Viscosity Point gel gel Loss N/A ,, N/A N/A Production Mud Properties' Density Marsh Yield 10 sec 10 rain pH Fhfid (PPG) Viscosity Point gel §el Loss 9.0 25 8 3 7 8 4 tO tO tO tO tO tO tO 9.8 50 13 10 15 10 10 Well Control: Well control equipment consisting of 5000 psi W.P. pipe rams, blind rams, and annular preventer will be installed and is capable of handling maximum potential surface pressures. Diverter, BOPE and drilling fluid system schematics on file with AOGCC. Directional'. [ KOP: 3700' TVD @ 2.0 deg/100' [Maximum Hole Angle: [50.0 DEG Close Approach Well: 9-17: 413' @ 7799' MD. The above listed wells will be secured during the close approach. Well Plan Summary RECEIVED FEB - 9 1994 Alaska Oil & Gas Cons. Commission gnchora..o.e Page 2 . , , , , . . . , 10. 11. 12. Notes: b. C, Operations Summary DS 9-37i MIRU drilling rig. N/U diverter and function test same. Drill 12-1/4" hole to surface casing point. Run and cement 9-5/8" surface casing. Nipple up BOPE and function test same to 5000/250 PSI. PU 8.5"" BHA and RIH. Test casing to 3000 psi for 30 minutes. Drill 10' new hole and perform leak-off test. Drill 8.5" hole to TD. Wiper Trip, Primary Plan is to Icg with LWD (Gamma/4 phase resistivity) from 200' above TSAD to Base of Same. If not, then secondary plan is to Back Up Drill Pipe Conveyed. Perform Conditioning Trip after Wireline Logs. Run and cement 5-1/2" production casing-- Bump Plug with filtered Seawater. Test casing to 3500 psi for 30 minutes. Back out Landing Joint, Run & Test Packoff to 5000 psig. RIH w/3.5" DP to 2000' and Displace Filtered Sea Water w/diesel for freeze protection. POOH L/D 3-1/2" drill pipe. Freeze protect top 2000' of 5-1/2" x 9-5/8" annunlus with 50/50 methanol water mixture. ND BOP's, NU Tree and Test same. Release Rig. MIRU wireline unit run cement bond Icg to 500' above TSAD. RDMO wireline unit. MIRU Coil Tubing Unit and perform Coil Tubing Completion. Anticipated BHP: 3698 psi @ 8800 sstvd Maximum Anticipated BHP: 3698 psi @ 8800 sstvd Surface Pressure: 2900 psi Planned Completion Fluid: 8.6 ppg Sea Water The drilling fluid program and surface system will conform to the regulations set forth in 20AAC25.003. Maximum surface pressure is based on BHP and a full column of gas to TD (0.10 psi/fi).. Based on previous logs at Drill Site 4, no potential productive zones are anticipated above 8523' TVD (TSAD). RECEIVED FEB -9 1994 Alaska Oil & Gas Cons. Commission DS9-37i CEMENT PLAN - BJ Casing Size: Circ. Temp.: Spacer: Lead Cement: Tail Cement : Top Job: 9-5/8" SURFACE CASING 9-5/8", 47# 38°F 50 bbls fresh water ahead of lead slurry Coldset III Additives: Retarder Weight: 12.2 ppg Yield: 1.92 cuftJsx Class G Additives: Weight: Yield: Volume (sacks): 948 Coldset II Additive: Weight: Yield: Mix Water: 10.5 gps Thickening Time: > 4 hrs @ 50°F Volume (sacks): 295 2% A-7, FP-6L l ghs 15.8 ppg Mix Water: 5.0 gps 1.15 cu[t/sx Thickening Time: >3-1/2 hrs @ 50°F Retarder 15.6 ppg 0.95 cuft/sx Cement Volume Summary! (1) Lead slurry to surface w/100% excess Volume (sacks): 250 Mix Water: 3.7 gps Thickening Time: >2 hrs @ 50°F (2) Tail slurry volume ( to cover 500' of casing shoe w/100% excess + 80' shoe volume) (3) Top job volume 250 sx (fixed volume) 5-1/2" LONGSTRING CASING Casing Size: Circ. Temp.: Spacer: 5-1/2", 17# 140oF 50 bbls of MCS-4 Spacer weighted I ppg above current mud weight Lead Cement: ._ Tail Cement : Class G Additives: Weight: Yield: Fluid Loss: Class G Additives: Weight: Yield: Fluid Loss: Volume (sacks): 450 A-2: 3%, FL-52: 0.4%, CD-32: 0.5%, FP-6L: lghs 11.0 ppg Mix Water: 20.92 gps 3.31 cuft/sx Thickening Time: >5 hrs @ 140°F 150-250 cc Free Water: 0.0 cc Volume (sacks): 280 A-2: 0.1%, FL-52: 0.3%, CD-32: 0.5%, FP-6L: lghs 15.8 ppg Mix Water: 4.85 gps 1.14 cuft/sx Thickening Time: 3.5 - 4.5 hrs @ 140°F 100-150 cc Free Water: 0.0 CC Cement Volume Summary: (1) Lead Slurry to 500' MD above top of Cretaceous (top of K15 @ 4984' MD) with 30% excess (2) Tail Slurry to 600' MD above Top of Sadlerochit (top of SAD @ 10,416 MD) with 30% excess plus 80' of 5-1/2", 17# capacity for float joints RECEIVED FEB -9 1994 utt& Gas Cons. C0mm[ssi0n Anchorage Prudhoe Bay Drillin Prudhoe Bay Unit, Alaska Drill Site 09 Well' 09-37i Wellpath' 09-37i WP3 2/7/94 5,30 p~ HALL I BURTON [x~ ILL lNG SYS1EMS VERTICAL VIEW SCALE 500 ft. / DIVISION TVD REF: WELLHEAD VERTICAL SECTION REF: WELLHEAD 3000~ 3500---]-- L9 5/8 In OD, e 3556 MD, 3556 TVD / 3700 ! 0 3824 3 4000 -- 4500 -- 4942 5000 -- z83 5500 -- 5861 984 6000 6500 -- 7000 -- 7500 -- 7615 8000 -- 8089 8164 8500 -- 876] - 9500 -500 0 500 lO00 VERTICAL SECTION PLANE: 62.48 HOR]ZONTAL ~,qEW (TRUE NORTH) SCALE 500 ft. / DIVISION SURVEY REF: WELLHEAD 2850 --1750 --1250 --750 i ---250 ---~5 0 500 0 500 ! 0O0 ] 500 2000 2500 3000 3500 4000 0.00' 9_ 3700 MD KOP / START OF BUILD @ 2.00'/100 2.48' e 3824 MD qV3 4,00' e 3900 MD 6.00' e 4000 MD 8.00' ~ 4100 HD I O. 00' I~ 4200 HD 12.00' e 4300 MD 14.00' e 4400 MD 16.00' e 4500 MD 18.00' e 4600 MD 20.00' e 4700 HD 2~'. 00' e 4800 HD 24.00' e 4~00 MD 25.69" ~ 4985 MD K-15 28.00' ~ 51 O0 MD 3;-Z°o'o X'~34 . 00' 36.00' @ 5500 MD 38,00' 8 5600 MD 40.00' e 5700 MD '.~ 4.9. 00' 8 5800 MD ~ 44.00' @ 5900 MD ~'0.~.46. 00' I~ 6000 MD 9 ~D END DF BUILD · -.. ~545 3631 LAST TARG ET TVD 895 1.90 MD ] 0623.30 VS 4172.57 N/S 1928.21 N E/W 3700.32 E CRITICAL POINT DATA MD [nc Az;. 0 0.00' O.00' 3700 0.00' 0.00' 3824 2.48' 62.48' a985 25.69' 62.48' 6149 48.98' 62.48' 8820 48.98' 62.48' 9543 48.98' 62.48' 9657 48.98' 6~.48' TVD 0 3700 N/S ElY 0N 0 £ ON 0E IIE IN KOP / START DF BUILD e 2.00'/100 tt Sv3 K-15 END OF BUILD k-I 0 F-5 51ART DF Di~OP e 3.00'/100 Ft LCU / IVISHAK ]04)6 / TOP SAD / ZONE 3 ZONE 2 / 2C 10428 ZONE 2B / 10469 TANGO ZONE 2A / POM[O !orget / ZONE ]0623 ;B ~ LOwEP POMEO lOP HOT ]0675 BASE SAD / 10690 kAVIK 3824 ] N 2 E 4942 )3] N 25] E 5861 455 N 873 E 7615 1386 N 2660 E 8089 1638 N 3144 E 8164 1678 N 3220 E 26.23' 62.48' 8761 1891 N 3G28 E 25.87' 24 64' 21 25' 20 00' 68.48' 8772 1893 N 3633 E 62.48' 8809 1901N 3648 E 62.48' 8913 1921 N 3687 E 62.48' 8952 1928 N 3700 E '- Target -.~ 20 00' 20 0o' 62.48' 9001 1936 N 3716 E 62.48' 9015 1939 N 3721E 8952 1928 N 3700 E 722375 Gr,d Y 5943715 48.98' e 8820 ~D K-lO -.. '""0. 48.98' 8 9543 MD K-5 '% 48.98' ~ 9~57 MD qTA~T DC DPOP @ 3.00'/100 Ft 5 ~5.98' ~ 9757 MD \~ 4~.98' ~ 9857 MD '~. 39.98' e 9957 MB b, 36.98' e 10057 MD %~ 33.98' m~ 10157 MD ~ 30.98' e 10257 HO ]500 2000 2500 3000 3500 4 000 4500 RECEIVED A,k&sk& Oil & Gas Cons. Commission Anchorage _ Do%e PIo~ed Creoted By Checked By Approved By Do~e 2/7/94 Pmudhoe ]~ay D~iUing Prudhoe Bay Uni% Alaska Site 09 Well: Well~h: 09-371 ~P3 TnaveUing Cyllndem - Least Distance Re£emence Well - 09-37i WP3 MD: 0 - 10773 F~, Interval, 50 Ft. All DiPec±ions Rel ~o T~ue No~h 27O° 240~ CL,~_.~S$1 POit~ S 0004 C,c;- 04o 0c,05 C015 0O8? ~0 0~ 0~5 SIo~ OO-Ol C,9-O4A CF~07 OC~Y3 (~7 0~85 09-27 O0-30Sl' 0O-32 00--3:8 00-4 ! 00-48 00-44 00-.~5 O0-4g 867.01 382~3 ~ C05P.04 1056-62 10S&61 113024 8~5.3 17652l J 6~ 44 ~ 70 0~.16 7~.87 707 ~ 676.4~ 3~.15 4~01 1~.1~ 86084 370~4 ~0~5.~ 1~510 ~7.7~ 21 l gO1 1761 ~ 1220~ B~O 78 828 Z ~ 3 ~70~ ~5~ g78 65 1~ 78 ~.33 61544 239 70 21329 273 o~ 2'ETS 84 29SC-~ 3~372 34.9,.46 349A3 347.01 348 12 5,1 08 ,4502 42 60 34001 34~.73 73A3 5361 1534Q 347.00 $66.8~, 2'5380 247.7.0 847.79 '314.47 3~5 4Q 315.51 317.36 3] 7 74 .318 2,4 310.53 3101~S 31338 34,900 32184 349 O0 32705 14.35 ?DSO1 103~1 3~6 Per .~D 4600C0 3403 CO 275000 2703C0 87COO] 270303 280003 ~OD CO · ?~CO CO 88030D ~7C000 ~05OOO ~03.00 000 7C0.00 0.00 3703 O0 270D03 85COD0 000 45300 1003C0 175003 6~'~)300 7053 CO PeF TVD 3000 45, 458527 34oo,003 27%,303 2700{)3 870'0 27C0 03 4865 21 883003 8CC0 03 88"'..0 CO 655; 87 5044,94 448064 33C0 ,DD 7593 03 370,3 03 39406,9 0.00 76OOO 0~0 370.0 CO 3840 03 8030 O0 ~700 03 2350 OD 5343 !8 534318 55OOO 000 06O 6D38 72' ~ 75000 63'S4 3~ 64528~ 5 70 4360 556O 1703 l~O 7~ ~0 iOC~ 47 I0 I.~ ~10 6724 ~3~0 ~70 70 375 I0 4~ 40 107.~ 70~ 130.70 105~ t88~ 242 ~ 411.~ I~.10 2211 40 ~310 ~510 7~ I 1~970 ~0 RECEIVED FEB - 9 1994 Alaska 0il & ~as Cons. Commission Anchorage 4~0 1~0o HALLIBURTON' 18CP { lorae~ Nar-e TVD NS Ew I~,'id X C,';O Y [lorget 8.c~52 I9k8 l.l 9700 E 728375 5943715 OD r-.iD ]nc AZ; 1 VD N/S / 9 5/8 ;r, ]5~_~ OF JO° o.rfdo'~5,6 0 N C?]IICAL F'~)I,,I1 DA1A r4D ]nc AZ;. TVD t,'/S E/W liE lN 0 003° O.OC_.P 0 0 N 0 KB=' /STAR, T 3703 0.00° 0.00° 3700 0 f'~ 0 ElF BUILD @ 2.00° / 1 C)3 £t SV3 3S2~ 2.4S~ 62.48~ 3'82a I N 2 K-15 49;:3~ 25.~_, .r? 6x?.4b~4942 END EF ~UILD 6J40 48.Q'8°~62.48° 5P.~SI 455 Iq 873 K-lO 88,20 48..'78°_ 68.4b-¢7615 13P..,6 N ~660 t..'-5 q~43 48.99° 6248,.o~O 16~"~ r4 3J44 ~l'A~f [}-' DF?CP .o2,5? 48.98° 68.48° 8164 1678 N 3~293 @ 3.00°/100 f't LEU / ]VISHA,W. ~0416 26.83° 68.48° 8761 1891 N 36c-~8 /l[iD SAD / ZO,£ 3 ZE~ 2 / L:::{ 10428 ~.87° 62.4F~ 8772 l¢3 r,l '3633 ZEI4E 2B / 10469 24,64° 62.48° 8.'309.]901 N 3648 ZEr,E 2A / 10.5~__,2 21.25° E~.4Er:' 8913 1921 N 3687 lo~*qet / ZD',£ 106~3 20.0? 6~.48° 895~ 1928 N 3700 lIP POI 10G75 ~f-J.O0":' 6248° 0001 1936 Iq 371(:, BASE SAD / ~06cDo ~0,00° 6~48° 9015 ]93~ N 3721 karl1< PP[POSE O DL ; VD .%092.~ MD 1077 T, L30 VS 4223.87 hMS lC)SI 92 E/'w 3745.::31 [k, le Plot ted O'eo ted By C;-ecPed By /~¢f.~' oved By IX-, te 2/7/94 WELL PERMIT cHECK'LI'ST' ' ' . .... ~o.~NzS~ON ............................................................. · 1. Permit fee attached .................. N 2. Lease number appropriate ............... N 3. Unique well name and number .............. N 4. Well located in a defined pool ............. ~ N 5. Well located proper distance from drlg unit boundary..~ N 6. Well located proper distance from other wells ..... N 7. Sufficient acreage available in drilling unit ..... ~ N 8. If deviated, is wellbore plat included ........ .~ N 9. Operator only affected party .............. ~ N ~ 10. Operator has appropriate bond in force ......... .~_ N 11. Permit can be issued without conservation order .... ~ N ~ D~j~ 12. Permit can be issued without administrative approval..~ N ~ 13. Can permit be approved before 15-day wait ....... ~ N ENGINEERING GEOL ~ ~(J ,?"3 7 PROGRAM= exp FI UNIT# dev [] redrll [] serv~ ON/OFF SHORE , 14. Conductor string provided ............... ~L~ N 15. Surface casing protects all known USDWs ........ ~ N 16. CMT vol adequate to circulate on conductor & surf csg..~ N 17. CMT vol adequate to tie-in surf csg to next string .... Y 18. CMT will cover all known productive horizons ...... ~ N 19. Casing designs adequate for C, T, B & permafrost. ~ N 20. Adequate tankage or reserve pit ............. 21. If a re-drill, has a 10-403 for abndnmnt been approved..Y 22. Adequate wellbore separation proposed. ~ N 23. If diverter required, is it adequate..'.'.'.'.'.'.'.'.~ N 24. Drilling fluid program schematic & equip list adequate .~ N 25. BOPEs adequate ..................... ~ N 26. BOPE press rating adequate; test to ~ psig.~ 27. Choke manifold complies w/API RP-53 (May 84) ....... Y 28. Work will occur without operation shutdown.. ~ .... ~ N 29. Is presence of H2S gas probable ............. Y N GEOLOGY APPR 30. Permit can be issued w/o hydrogen sulfide measures .... Y N/ 31. Data presented on potential overpressure zones ..... Y 32. Seismic analysis of shallow gas zones .......... Y/N 33. Seabed condition survey (if off-shore) ......... 7 N 34. Contact name/phone for weekly progress reports .... / Y N [exploratory only] GEOLOGY: ENGINEERING: COMMISSION: Comments/Instructions: z HOW/jo - A:~FORMS~cheklist rev 01/94 Well History File APPENDIX Information of detailed nature that is not particularly germane to the Well Permitting Process but is part of the history file. To improve the readability of the Well History file and to simplify finding information, information of this nature is accumulated at the end of the file under APPENDIX. No special effort has been made to chronologically organize this category of information. ALASKA COMPUTING CENTER SCHLUMBERGER ....... COMPANY NAME : ARCO ALASKA, INC. WELL NAME : D.S. 9-37 FIELD NAME : PRUDHOE BAY BOROUGH : NORTH SLOPE STATE : ALASKA AP1 NUMBER : 50-029-22451-00 REFERENCE NO : 95236 RECEIVED JUL 1 9 19~§ Alaska Oil & Gas Cons. Commission Anchorage LIS Tape Verification Listing Schlumberger AlaskaCComput'ing Center 17-JUL-1995 10:26 **** REEL HEADER **** SERVICE NAME : EDIT DATE : 95/e7/~7 ORIGIN : FLIC REEL NAME : 95236 CONTINUATION # : PREVIOUS REEL : COMMENT : ARCO ALASKA INC., PRUDHOE BAY, D.S. 9-37, 50-029-2245~-~0 **** TAPE HEADER **** SERVICE NAME : EDIT DATE : 95/07/~7 ORIGIN : FLIC TAPE NAME : 95236 CONTINUATION # : 1 PREVIOUS TAPE : COMMENT : ARCO ALASKA INC., PRUDHOE BAY, D.S. 9-37~ 50-029-22451-00 TAPE HEADER PRUDHOE BAY CASED HOLE WIRELINE LOGS WELL NAME: D.S. 9-37 AP1 NUMBER: 5~029224510~ OPERATOR: ARCO ALASKA, INC. LOGGING COMPANY: SCHLUMBERGER WELL SERVICES TAPE CREATION DATE: ~7-JUL-95 JOB NUMBER: 95236 LOGGING ENGINEER: T.WEST OPERATOR WITNESS: M.REYNOLDS SURFACE LOCATION SECTION: TOWNSHIP: 1ON RANGE: ~SE FNL: FSL: 201 FEL: 4962 FWL: ELEVATION(FT FROM MSL KELLY BUSHING: 46.30 DERRICK FLOOR: 45.30 GROUND LEVEL: 20.7~ WELL CASING RECORD OPEN HOLE CASING DRILLERS CASING BIT SIZE (IN) SIZE (IN) DEPTH (FT) WEIGHT (LB/FT) 1ST STRING le.75e 28.0 2ND STRING 9.625 3530.9 3RD STRING 5.500 10804.0 PRODUCTION STRING CURVE SHIFT DATA - ALL PASSES TO STANDARD(MEASURED DEPTH) 45.5~ 40.00 [7.00 PAGE: LIS Tape Verification Listing Schlumberger Alaska'Comput'ing Center 17-JUL-1995 10:26 BASELINE CURVE FOR SHIFTS LDWG TOOL CODE: TDTP LDWG CURVE CODE: GRCH RUN NUMBER: 2 PASS NUMBER: 1 DATE LOGGED: 24-MAY-95 LOGGING COMPANY: SCHLUMBERGER WELL SERVICES BASELINE DEPTH GRCH EQUIVALENT UNSHIFTED DEPTH CNTG 88888.0 88884.5 88883.5 10642.5 10638.0 10642.0 10638.5 10616.0 10613.0 10614.0 10610.0 10s7g.o 10576.0 10555.0 10551.0 10551.0 10522.0 10517.5 10521.0 10517.5 10459.5 10456.0 10456.0 10425.0 1~421.5 10424.5 10421.5 10395.5 10391.0 10364.0 10359.0 10340.5 10336.0 10340.0 10336.0 10318.5 10313.5 10307.5 10303.0 10306.0 10303.0 100.0 95.5 97.0 $ REMARKS: The depth adjustments shown above reflect cased hole 1st pass GRCH to the 24-MAY-95 passl GRCH logged with magnetic marked line, The first pass NPHI was shifted to the same MAY-95 Base GRCH. The curve identified on this tape as GRCH.BASE is from the TDTP logged MAY-95, THIS TAPE REPLACES THE ONE DELIVERED 30-DEC-94. $ $ **** FILE HEADER FILE NAME : EDIT SERVICE : FLIC VERSION : 001C01 DATE : 95/07/17 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : PAGE: FILE HEADER FILE NUMBER: LIS Tape Verification Listing Schlumberger Alaska'Comput'ing Center 1T-JUL-1995 10:26 EDITED CURVES Depth shifted and clipped curves for each pass in separate files. PASS NUMBER: 1 DEPTH INCREMENT: 0.5000 FILE SUMMARY LDWG TOOL CODE START DEPTH STOP DEPTH GRCH 10660.0 10300.0 CNTG 10672.0 10300.0 $ CURVE SHIFT DATA - PASS TO PASS(MEASURED DEPTH) BASELINE CURVE FOR SHIFTS LDWG CURVE CODE: GRCH PASS NUMBER: EQUIVALENT UNSHIFTED DEPTH BASELINE DEPTH $ REMARKS: This file contains CNTG Pass #1. shifts were applied to this data. $ LIS FORMAT DATA No pass to pass PAGE: DATA FORMAT SPECIFICATION RECORD SET TYPE - 64EB ** TYPE REPR CODE VALUE 1 66 0 2 66 0 3 73 68 4 66 5 66 6 73 7 65 8 68 0.5 9 65 FT 11 66 15 12 68 13 66 0 14 65 FT 15 66 68 16 66 0 66 0 LIS Tape Verii~icai:ion Li$t:ing Sch I umberger Alaska 'Compui:'i ng Cent, er SET TYPE - CHAN *~ 17-JUL-1995 10:26 PAGE: NAME SERV UNIT SERVICE API API API API FILE NUMB NUMB SIZE REPR PROCESS ID ORDER ~ LOG TYPE CLASS MOD NUMB SAMP ELEM CODE (HEX) DEPT FT 619044 00 000 00 0 1 [ ~ 4 68 0000000900 NPHI CNTG PU-S 6~9944 99 999 99 9 ~ 1 1 4 68 9999999999 ENPH CNTG PU-S 6~9944 99 999 99 9 1 1 ! 4 68 9999999999 CPHI CNTG PU-S 6~9944 99 999 99 9 1 1 ~ 4 68 9999999999 NRAT CNTG 619944 99 099 99 9 ~ ~ ~ 4 68 9999999999 CRAT CNTG 6~9944 99 999 99 9 1 ! [ 4 68 9999999999 ENRA CNTG 619944 99 099 99 9 ~ ~ [ 4 68 9999999999 NCNT CNTG CPS 619944 99 999 99 9 1 [ [ 4 68 9999999999 FCNT CNTG CPS 619944 99 999 99 9 ~ ~ 1 4 68 9999999999 CFTC CNTG CPS 619944 99 999 99 9 ~ ~ ~ 4 68 9999999999 CNTC CNTG CPS 619044 99 999 99 9 ! [ 1 4 68 9999999999 CFEC CNTG CPS 619944 99 999 99 9 1 [ [ 4 68 9999999999 CNEC CNTG CPS 6~9944 99 999 99 9 1 ~ ~ 4 68 9999099999 GRCH CNTG GAPI 6~9944 99 999 99 9 [ ~ ~ 4 68 9999999999 TENS CNTG LB 619944 99 999 99 9 1 [ ~ 4 68 9999999999 CCL CNTG V 619944 99 999 99 9 [ [ ~ 4 68 9999999999 GRCH BASE GAPI 6~9944 99 999 99 9 ! ~ 1 4 68 9999999999 ** DATA ** DEPT. 19677.999 NPHI.CNTG -999.259 ENPH.CNTG -999.259 CPHI.CNTG NRAT.CNTG -999.259 CRAT.CNTG -999.250 ENRA.CNTG -999.259 NCNT.CNTG FCNT.CNTG -999.259 CFTC.CNTG -999.259 CNTC.CNTG -999.259 CFEC.CNTG CNEC.CNTG -999.259 GRCH.CNTG -999.259 TENS.CNTG -999.259 CCL.CNTG GRCH.BASE 68.438 DEPT. [9295.599 NPHI.CNTG -999.250 ENPH.CNTG -999.259 CPHI.CNTG NRAT.CNTG -999.259 CRAT.CNTG -999.250 ENRA.CNTG -999.259 NCNT.CNTG FCNT.CNTG -999.259 CFTC.CNTG -999.259 CNTC.CNTG -999.259 CFEC.CNTG CNEC.CNTG -999.259 GRCH.CNTG 144.999 TENS.CNTG -999.259 CCL.CNTG GRCH.BASE -999.259 -999.259 -999.259 -999.250 -999.259 -999.259 -999.259 -999.259 -999.250 END OF DATA ** **** FILE TRAILER **** FILE NAME : EDIT .991 SERVICE : FLIC VERSION : 901C01 DATE : 95/97/~7 MAX REC SIZE : 1924 FILE TYPE : LO LAST FILE : LIS Tape Verification List!ng Schlumberger Alaska Computing Center · ,~* FILE HEADER ~* FILE NAME : EDIT .002 SERVICE : FLIC VERSION : 001C01 DATE : 95/07/17 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : 17-JUL-1995 10:26 PAGE: FILE HEADER FILE NUMBER: 2 EDITED CURVES Depth shifted and clipped curves for each pass in separate files. PASS NUMBER: 2 DEPTH INCREMENT: ~.5000 FILE SUMMARY LDWQ TOOL CODE START DEPTH STOP DEPTH GRCH 10660.0 10300.0 CNTG 10672.0 1030~.0 $ CURVE SHIFT DATA - PASS TO PASS(MEASURED DEPTH) BASELINE CURVE FOR SHIFTS LDWG CURVE CODE: GRCH PASS NUMBER: I EQUIVALENT UNSHIFTED DEPTH BASELINE DEPTH GRCH CNTG 88888.0 88884.5 88884.0 10638.5 10635.0 10626.5 10623.0 10622.5 1~619.5 10610.5 10606.5 10606.5 10603.5 10602.5 10599.0 10598.5 1~595.5 1~594.5 10574.5 10571.5 10570.5 10567.0 10566.0 10566.5 10563.0 1~562.5 1~559.0 10558.5 1~554.5 10550.5 10547.0 10546.5 10542.5 10542.5 1~538.5 10538.5 10534.0 10530.5 10526.5 10526.5 10523.0 10506.5 10503.0 10502.0 10502.5 10498.5 10498.5 LIS Tape Verification Listing Schlumberger AlasEa 'Comput'ing Center 17-JUL-1995 10:26 10495.5 10495.0 10458,5 10454.5 10454.5 10451.0 10450.5 10447.5 10446.5 10443.5 10442.5 1~439.0 10439.0 10438.5 10435.5 10435.5 10434.5 10432.0 10431.0 10430.5 1~427.5 10422.5 10419.0 10418.5 10414.5 10414.5 10410.5 10410.5 104~7.0 10406.5 1~403.5 10403.0 10402.5 10399.0 10398.5 10398,5 10395.~ 10394.5 10390.5 10390.5 10386.5 10386.5 10382.0 10378.5 10375.0 10370.5 10366.0 10354.5 10350.0 1035~.5 10545.5 10346.5 10342.0 10342.5 10338.0 10338.5 10334.5 10330.5 10326.0 10326.5 10321.5 100.0 95.0 96.0 $ REMARKS: This file contains CNTG Pass #2. The depth shifts shown above relect GRCH pass ~2 to GRCH pass #1 and NPHI pass #2 to NPH[ pass #1. $ LIS FORMAT DATA PAGE: DATA FORMAT SPECIFICATION RECORD SET TYPE - 64EB ** TYPE REPR CODE VALUE 1 66 0 2 66 0 3 73 64 4 66 5 66 6 73 7 65 8 68 0.5 LIS Tape Veri~icat~ion Li$t~ing Schlumberger Alaska'¢omput~|ng Cent~er 17-JUL-1995 10:26 PAGE: TYPE REPR CODE VALUE 9 65 FT 11 66 16 12 68 13 66 0 14 65 FT 15 66 68 16 66 0 66 I 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 619044 0~ ~0 00 0 2 1 1 4 68 00000~00~0 NPHI CNTG PU-S 619044 00 ~00 ~ 0 2 1 1 4 68 0000000~0~ ENPH CNTG PU-S 619044 00 000 ~0 0 2 ! 1 4 68 0000000000 CPHI CNTG PU-S 619~44 0~ ~00 00 0 2 ! I 4 68 0~00000~00 NRAT CNTG 619~44 ~0 ~00 00 0 2 1 I 4 68 0000~00~ CRAT CNTG 619~44 ~ ~ 00 0 2 1 1 4 68 0000000000 ENRA CNTG 619044 0~ ~00 00 0 2 1 1 4 68 ~0~0~00000 NCNT CNTG CPS 619044 FCNT CNTG CPS 619044 00 ~0 00 0 2 1 1 4 68 ~0~0~00000 CFTC CNTG CPS 619044 00 ~0 ~0 0 2 1 I 4 68 0000000000 CNTC CNTG CPS 619044 00 00~ ~0 0 2 1 1 4 68 000~000000 CFEC CNTG CPS 619~44 0~ ~00 ~0 0 2 1 1 4 68 0000~00~00 CNEC CNTG CPS 619044 ~0 00~ ~0 0 2 1 1 4 68 ~000000000 GRCH CNTG GAPI 619044 ~0 000 ~ 0 2 1 1 4 68 ~00000~000 TENS CNTG LB 619044 00 ~00 00 0 2 1 I 4 68 ~00000000~ CCL CNTG V 619044 00 000 ~0 0 2 1 1 4 68 000000000~ ** DATA DEPT. 10668.0~0 NPHI.CNTG 31.979 ENPH.CNTG 36.381 CPHI.CNTG NRAT.CNTG 3.146 CRAT.CNTG 3.157 ENRA.CNTG 5.288 NCNT.CNTG FCNT.CNTG 540.1~7 CFTC.CNTO 581.044 CNTC.CNTG 1794.747 CFEC.CNTG CNEC.CNTG 2867.576 GRCH.CNTG -999.250 TENS.CNTG 3225.~00 CCL.CNTG DEPT. 10295.000 NPHI.CNTG -999.250 ENPH.CNTG -999.25~ CPHI.CNTG NRAT.CNTG -999.250 CRAT.CNTG -999.250 ENRA.CNTG -999.250 NCNT.CNTG FCNT.CNTG -999.250 CFTC.CNTG -999.250 CNTC.CNTG -999.250 CFEC.CNTG CNEC.CNTG -999.250 GRCH.CNTG 146.000 TENS.CNTG -999.250 CCL.CNTG 27.688 1706.312 542.276 -0.007 -999.250 -999.250 -999.250 -999.250 END OF DATA LIS Tape Verification Listing Schlumberger Alaska'Computing Center · ,,, FILE TRAILER ,,,, File NAME : EDIT .002 SERVICE : FLIC VERSION : 001C01 DATE : 95/07/17 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : 1T-JUL-1995 10:26 PAGE: · ,,, FILE HEADER ,,,, FILE NAME : EDIT .003 SERVICE : FLIC VERSION : ~01C01 DATE : 95/07/17 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : FILE HEADER FILE NUMBER: EDITED CURVES Depth shifted and clipped curves ~or each pass in separate ~iles. PASS NUMBER: 3 DEPTH INCREMENT: 0.5000 FILE SUMMARY LDWG TOOL CODE START DEPTH STOP DEPTH GRCH 10660.0 10300.0 CNTG 10672.0 1~30~.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 CNTG 88888.0 88884.5 88883.5 10638.5 10635.0 10634.5 10631.5 10630.0 10630.5 10627.5 10626.5 10623.0 10622.5 10619.5 10594.5 10590.0 10582.5 1~579.5 1~578.5 10575.5 10575.0 10574.5 10571.0 10566.5 10563.0 LIS Tape Verification Listing Schlumberger Alaska ,Computing Center 17-JUL-1995 10:26 PAGE: LIS 10562.5 10558.5 10542.5 10538.5 10539.0 10538.5 10535.0 10534.5 10534.5 10531.0 10530.5 10530.5 10526.5 10526.0 10526.5 10523.0 1049~.5 1~486.0 10486.5 10482.5 10482.5 10478.5 10478.5 10475.0 10474.5 10470.5 10458.5 10454.5 10454.5 10451.~ 10446.5 10443.0 10442.5 10439.5 10438.5 10434.e 10434.5 10431.0 10430.5 1043e.5 10427.5 10418.5 1~414.5 10414.5 10411.5 10410.~ 10410.5 10407.0 10406.0 10406.5 10403.0 10402.5 10402.5 10398.5 1~400.0 10398.5 10394.~ 10395.5 10394.5 10391.0 10390.5 10387.5 10356.5 10382.0 10382.5 10378.0 10378.5 10373.5 10374.0 10374.5 10369.5 1037e.5 10366.0 10354.5 1~350.0 10350.5 10345.5 10346.5 10342.e 10342.5 10339.5 10330.5 [0326.0 10327.5 10326.5 10321.5 10324.0 10322.5 10318.5 100.0 95.0 96.0 $ REMARKS: This ~ile contains CNTG Pass #3. The depth shifts shown above relect GRCH pass #3 to GRCH pass #1 and NPHI pass #3 to NPHI pass #1. $ FORMAT DATA LIS Tape Veri~|cat|on Listing Schlumberger Alaska-Computing Cen~er 1T-JUL-1995 19:26 DATA FORMAT SPECIFICATION RECORD SET TYPE - 64EB ** TYPE REPR CODE VALUE 1 66 0 2 66 9 3 73 64 4 66 1 5 66 6 73 7 65 8 68 9.5 9 65 FT 12 68 13 66 0 14 65 FT 15 66 68 16 66 1 9 66 1 PAGE: SET TYPE - CHAN ** NAME SERV UNIT SERVICE APl AP1 AP1 AP1 FILE NUMB NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUMB SAMP ELEM CODE (HEX) DEPT FT 619944 ~ ~90 09 NPHI CNTG PU-S 619944 0~ 090 99 ENPH CNTG PU-S 619944 90 ~00 00 CPHI CNTG NRAT CNTG CRAT CNTG ENRA CNTG NCNT CNTG FCNT CNTG CFTC CNTG CNTC CNTG CFEC CNTG CNEC CNTG QRCH CNTG TENS CNTG CCL CNTG PU-S 619044 ~0 000 00 619044 ~0 ~0~ ~0 619044 00 00~ ~ 619044 00 CPS 619044 00 CPS 619044 00 CPS 619044 ~ CPS 619044 00 CPS 619044 ~0 CPS 619044 ~ GAPI 619044 ~0 LB 619044 ~ V 619044 00 0 3 1 1 4 68 0e~0000000 0 3 1 1 4 68 00~e000000 0 3 I 1 4 68 00~000000 0 3 1 1 4 68 0000000900 0 3 1 1 4 68 00000~0000 ~ 3 1 1 4 68 ~000000000 0 3 1 1 4 68 0000000~00 0 3 1 1 4 68 00~0090000 0 3 1 1 4 68 0~00000000 0 3 1 1 4 68 0000000900 0 3 1 1 4 68 0009~00000 0 3 1 1 4 68 ~00~00000 ~ 3 1 1 4 68 0000~0~0 0 3 1 I 4 68 0000000090 0 3 1 1 4 68 0~000000~0 0 3 I I 4 68 00~00~000~ DATA DEPT. NRAT.CNTG FCNT.CNTG CNEC.CNTG 19667.590 3.095 483.174 2868.267 NPHI.CNTG 32.653 ENPH.CNTG CRAT.CNTG 3.194 ENRA.CNTG CFTC.CNTG 565.578 CNTC.CNTG GRCH.CNTG -999.259 TENS.CNTG 35.608 CPHI.CNTG 5.215 NCNT.CNTG 1804.633 CFEC.CNTG 3139.890 CCL.CNTQ 29.247 1705.290 549.981 -0.095 LIS Tape Verification Listing Schlumberger Alaska-Computing Center 17-JUL-1995 10:26 PAGE: END OF DATA **** FILE TRAILER **** FILE NAME : EDIT .003 SERVICE : FLIC VERSION : 001C01 DATE : 95/0T/~7 MAX REC SIZE : ~024 FILE TYPE : LO LAST FILE : **** FILE HEADER **** FILE NAME : EDIT .0~4 SERVICE : FLIC VERSION : 001C01 DATE : 95/07/17 MAX REC SIZE : 1~24 FILE TYPE : LO LAST FILE : FILE HEADER FILE NUMBER: 4 AVERAGED CURVES Compensated Neutron: Arithmetic average of edited passes for all curves. DEPTH INCREMENT 0.5000 PASSES INCLUDED IN AVERAGE LDWG TOOL CODE PASS NUMBERS CNTG 1~ 2~ 3~ $ REMARKS: The arithmetic average of passes 1,2, A 3 was computed after all depth shifts and clipping was applied. $ LIS FORMAT DATA LIS Tape Verif|cat|on L|st|ng Schlumberger Alaska Computing Center [7-JUL-1995 10:26 DATA FORMAT SPECIFICATION RECORD SET TYPE - 64EB ** TYPE REPR CODE VALUE [ 66 0 2 66 0 3 73 64 4 66 5 66 6 73 7 65 8 68 0.5 9 65 FT 12 68 [3 66 0 14 65 FT 15 66 68 16 66 0 66 PAGE: 12 SET TYPE - CHAN ** NAME SERV UNIT SERVICE AP1 AP1 AP1 AP1 FILE NUMB NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUMB SAMP ELEM CODE (HEX) DEPT FT 619044 00 eeo eo 0 4 1 [ 4 68 0000000000 NPHI CNAV PU-S 619044 00 e00 eO 0 4 1 1 4 68 00000000~0 NRAT CNAV 619044 0~ 000 00 0 4 [ 1 4 68 0000000~00 CPHI CNAV PU-S 619044 ~0 ~00 ~0 0 4 1 I 4 68 00~0000000 CRAT CNAV 619044 ~0 ~0~ 00 0 4 [ I 4 68 0000000000 ENPH CNAV PU-S 619044 00 0~0 00 0 4 I [ 4 68 00~00000~0 ENRA CNAV 619044 00 ~00 00 ~ 4 [ I 4 68 00~0000~0 NCNT CNAV CPS 619~44 ~0 ~00 00 0 4 1 I 4 68 00~00000~0 FCNT CNAV CPS 619~44 CFTC CNAV CPS 619044 00 000 00 0 4 1 1 4 68 0000000e~0 CNTC CNAV CPS 619~44 0~ 0~0 ~ 0 4 1 1 4 68 00~0000000 CFEC CNAV CPS 619044 00 000 00 0 4 [ [ 4 68 0000000000 CNEC CNAV CPS 619044 00 ~00 ~0 0 4 [ [ 4 68 000000~00~ ORCH TDTP GAPI 619044 ~0 000 00 0 4. I [ 4 68 0000000000 TENS TDTP LB 619~44 00 000 ~0 0 4 [ 1 4 68 0000000000 CCL TDTP V 619044 eO 00e 00 0 4 I [ 4 68 0000000000 ** DATA DEPT. 10667.5~e NPHI.CNAV 31.620 NRAT.CNAV 3.[52 CPHI.CNAV CRAT.CNAV 3.[37 ENPH.CNAV 34.8[7 ENRA.CNAV 5.139 NCNT.CNAV FCNT.CNAV 5[2.202 CFTC.CNAV 581.667 CNTC.CNAV [810.781 CFEC.CNAV CNEC.CNAV 2839.599 GRCH.TDTP -999.250 TENS.TDTP 3225.000 CCL.TDTP 28.084 1738.010 552.587 -0.0~7 LIS Tape Verification L|sting Schlumberger Alaska .Comput{ng Center 17-JUL-1995 10:26 PAGE: 13 DEPT. 10295.500 NPHI,CNAV -999,250 NRAT,CNAV -999,250 CPHI,CNAV CRAT.CNAV -999,250 ENPH,CNAV -999,250 ENRA,CNAV -999,250 NCNT,CNAV FCNT.CNAV -999.250 CFTC,CNAV -999,250 CNTC,CNAV -999.250 CFEC.CNAV CNEC.CNAV -999.250 GRCH,TDTP 144,000 TENS,TDTP -999.250 CCL,TDTP -999,250 -999,25~ -999,250 -999,250 ** END OF DATA ** **** FILE TRAILER **** FILE NAME : EDIT .004 SERVICE : FLIC VERSION : 001C01 DATE : 95/07/17 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : **** FILE HEADER FILE NAME : EDIT .005 SERVICE : FLIC VERSION : 001C01 DATE : 95/07/17 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : FILE HEADER FILE NUMBER 5 RAW CURVES . Curves and log header data for each pass in separate files; raw background pass in last file PASS NUMBER: 1 DEPTH INCREMENT: 0.5~00 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH CNTG le688,5 $ 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): 1~294,5 27-AUG-94 40.2 1447 27-AUG-94 10718.0 10675.0 10671.0 2500.0 LIS Tape Verification Listing Schlumberger Alaska Compu%ing Cen~er 17-JUL-1995 10:26 DEPTH CONTROL USED (YES/NO): TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE NO TOOL NUMBER CNTG CNTG CNTG CNTG CNTG CNTG CNTG $ COLLAR LOCATOR TELEMETRY CARTRIDGE GAMMA RAY COMPENSATED NEUTRON BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLERS CASING DEPTH (FT): LOGGERS CASING DEPTH (FT): CAL YA 229 TCC B 840 SGC SA 59 CNTG 125 FLEX CBC 86 CBS 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): 28.0 NEUTRON TOOL TOOL TYPE (EPITHERMAL OR THERMAL): MATRIX: MATRIX DENSITY: HOLE CORRECTION.(IN): SEAWATER EPITHERMAL 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): FAR COUNT RATE HIGH SCALE (CPS): NEAR COUNT RATE LOW SCALE (CPS): NEAR COUNT RATE HIGH SCALE (CPS): REMARKS: TOOL STANDOFF (IN): TIE-IN SWS LWD CDR DATED [4-AUG-I994. LOG DEPTH DRIFTS WRT THE CDR TOWARD THE BOTTOM, SO THE LOG WAS TIED-IN AT THE CENTER OF THE EXPECTED PERFS LOG RUN BEFORE WELL WAS PERFORATED. $ PAGE: 14 LIS Tape Verification Listing Schlumberger Alaska-Comput-ing Center LIS FORMAT DATA ~7-JUL-~995 ~0:26 PAGE: 15 DATA FORMAT SPECIFICATION RECORD SET TYPE - 64EB ,~ TYPE REPR CODE VALUE ~ 66 0 2 66 0 3 73 76 4 66 ~ 5 66 6 73 7 65 8 68 0.5 9 6~ FT ~! 66 ~3 12 68 13 66 0 14 65 FT 15 66 68 16 66 1 ~ 66 I ** SET TYPE - CHAN ** NAME SERV UNIT SERVICE AP1 AP1 AP1 AP1 FILE NUMB NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUMB SAMP ELEM CODE (HEX) DEPT FT 619044 00 000 00 0 5 I 1 4 68 00~0~00~0 ENPH PS1 PU 619044 00 00~ 00 0 5 1 1 4 68 000~0~0000 ENRA PS1 619044 00 ~00 00 0 5 I I 4 68 000000~000 CFEC PS1 CPS 619044 00 ~00 00 0 5 I I 4 68 000000~000 CNEC PS1 CPS 619044 00 00~ 00 0 5 1 1 4 68 0~0~000000 RCEF PS1 CPS 619044 00 000 00 0 5 1 I 4 68 ~00000000~ RCEN PS1 CPS 619~44 00 ~00 00 0 5 I 1 4 68 000000~000 NPHI PS1 PU 619~44 00 ~00 ~ 0 5 I I 4 68 ~000000000 TNPH PS1 PU 619044 00 000 00 0 5 1 1 4 68 0000000000 TNRA PS1 619044 00 000 00 0 5 1 1 4 68 000000000~ RTNR PS1 619~44 00 000 00 ~ 5 ! 1 4 68 0000000000 NPOR PS1 PU 619044 00 000 00 0 5 1 1 4 68 000000~000 RCNT PS1 CPS 619044 ~0 000 00 0 5 1 1 4 68 00000~0000 RCFT PS1 CPS 619044 ~0 000 00 0 5 1 1 4 68 000~00~00~ CNTC PS1 CPS 619~44 00 000 00 0 5 1 1 4 68 00000~0000 CFTC PS1 CPS 619044 ~0 000 00 0 5 1 1 4 68 0000000000 GR PS1 GAPI 619044 00 000 00 0 5 I 1 4 68 ~000000000 TENS PS1 LB 619044 00 000 00 0 5 1 1 4 68 ~000000000 CCL PS1 V 619~44 00 0~0 00 0 5 1 1 4 68 00~0000000 LIS Tape Verification Listing Sch I umberger A I aska .Comput.i ng Center DATA DEPT, 10688,500 ENPH,PS1 CNEC,PS1 2798,519 RCEF,PS1 TNPH.PS1 27,036 TNRA,PS1 RCNT,PS1 1690,345 RCFT.PS1 GR,PS1 74,563 TENS,PS1 DEPT, 10294.500 ENPH,PS1 CNEC.PS1 2740.616 RCEF.PS1 TNPH.PS1 38.845 TNRA,PS1 RCNT,PS1 1442,820 RCFT,PS1 GR,PS1 151,375 TENS.PS1 17-JUL-1995 10:26 33,182 ENRA,PS1 556,364 RCEN,PS1 3,110 RTNR,PS1 525,247 CNTC,PS1 2370,000 CCL,PS1 39,992 ENRA,PS1 493,768 RCEN.PS1 3.742 RTNR.PS1 369,742 CNTC,PS1 2840.000 CCL.PS1 4,981 2669,773 3,176 1764,666 -0.007 5.618 2605.730 4.013 1558.736 -0.005 CFEC.PS1 NPHI.PS1 NPOR.PS1 CFTC.PS1 CFEC.PS[ NPHI.PS1 NPOR.PS1 CFTC.PS1 PAGE: 16 561,823 31,124 27,036 579.390 487.866 42.653 40.409 ** END OF DATA **** FILE TRAILER **** FILE NAME : EDIT .005 SERVICE : FLIC VERSION : 001COI DATE : 95/07/17 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : **** FILE HEADER **** FILE NAME : EDIT .006 SERVICE : FLIC VERSION : 001C01 DATE : 9~/07/17 MAX REC SIZE : 1~24 FILE TYPE : LO LAST FILE : FILE HEADER FILE NUMBER 6 RAW CURVES Curves and log header data for each pass in separate files; raw background pass in last file PASS NUMBER: 2 DEPTH INCREMENT: 0.5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH CNTG $ LOG HEADER DATA 10695.5 10260,5 LIS Tape Verification Listing Schlumberger Alaska-Computing Center 17-JUL-1995 10:26 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 27-AUG-94 40.2 1447 27-AUG-94 10718.0 10675.0 10671.0 NO TOOL NUMBER CNTG CNTG CNTG CNTG CNTG CNTG CNTG $ COLLAR LOCATOR TELEMETRY CARTRIDGE GAMMA RAY COMPENSATED NEUTRON CAL YA 229 TCC B 840 SGC SA 59 CNTG 125 FLEX CBC 86 CBS 160 BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLERS CASING DEPTH (FT): LOGGERS CASING DEPTH (FT): 28.0 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): SEAWATER NEUTRON TOOL TOOL TYPE (EPITHERMAL OR THERMAL): MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): EPITHERMAL 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): FAR COUNT RATE HIGH SCALE (CPS): NEAR COUNT RATE LOW SCALE (CPS): NEAR COUNT RATE HIGH SCALE (CPS): PAGE: 17 LIS Tape Ver|flcatJon Listing Schlumberger Alaska oComput-Jng Center ~7-JUL-~995 ~:26 TOOL STANDOFF (IN): REMARKS: TIE-IN SWS LWD CDR DATED 14-AUG-1994. LOG DEPTH DRIFTS WRT THE CDR TOWARD THE BOTTOM, SO THE LOG WAS TIED-IN AT THE CENTER OF THE EXPECTED PERFS 10600'. LOg RUN BEFORE WELL WAS PERFORATED. $ LIS FORMAT DATA PAGE: 18 ** DATA FORMAT SPECIFICATION RECORD ** ** SET TYPE - 64EB ** TYPE REPR CODE VALUE 1 66 0 2 66 0 3 73 76 4 66 5 66 6 73 7 65 8 68 0.5 9 65 FT 11 66 13 12 68 13 66 0 14 65 FT 15 66 68 16 66 ~ 66 ** SET TYPE - CHAN ** NAME SERV UNIT SERVICE AP1 AP1 AP1 AP1 FILE NUMB NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUMB SAMP ELEM CODE (HEX) DEPT FT 619044 00 000 00 0 6 1 1 4 68 00~0000000 ENPH PS2 PU 619044 00 000 00 0 6 1 1 4 68 ~00~000000 ENRA PS2 619044 ~0 000 00 0 6 1 1 4 68 0~0000~000 CFEC PS2 CPS 619044 00 000 00 0 6 1 1 4 68 000000~000 CNEC PS2 CPS 619~44 00 000 00 0 6 I 1 4 68 0000000000 RCEF PS2 CPS 619044 00 000 00 0 6 1 1 4 68 0000000000 RCEN PS2 CPS 619044 00 000 00 0 6 1 1 4 68 0000000000 NPHI PS2 PU 619044 00 000 00 0 6 1 1 4 68 0000000000 TNPH PS2 PU 619044 00 000 00 0 6 1 1 4 68 0000000000 TNRA PS2 619044 00 0~0 00 0 6 1 1 4 68 0000000000 RTNR PS2 619044 00 000 00 0 6 1 1 4 68 0000000000 NPOR PS2 PU 619~44 00 000 00 0 6 1 1 4 68 0000000000 RCNT PS2 CPS 619044 00 000 00 0 6 1 1 4 68 00000~0000 LIS Tape Verification L|st|ng Schlumberger Alaska Somput.~ng Center 97-JUL-1995 le:26 PAGE: ~9 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) RCFT PS2 CPS 6~9044 00 000 00 0 6 9 9 4 68 0000000000 CNTC PS2 CPS 6~9044 00 000 00 0 6 9 9 4 68 0000000000 CFTC PS2 CPS 619044 00 000 00 0 6 9 9 4 68 0000000000 GR PS2 GAPI 6~9044 0~ 000 00 0 6 9 9 4 68 0000000000 TENS PS2 LB 619044 00 0~0 00 0 6 9 9 4 68 0000000000 CCL PS2 V 699044 00 000 00 0 6 9 9 4 68 0000000000 DATA DEPT. 90695.500 ENPH.PS2 30.610 ENRA.PS2 4.724 CFEC.PS2 CNEC.PS2 2749.277 RCEF.PS2 576.380 RCEN.PS2 2622.797 NPHI.PS2 TNPH.PS2 39.560 TNRA.PS2 3.406 RTNR.PS2 3.479 NPOR.PS2 RCNT.PS2 9749.397 RCFT.PS2 493.599 CNTC.PS2 1897.879 CFTC.PS2 GR.PS2 80.000 TENS.PS2 2005.000 CCL.PS2 -0.e~7 DEPT. 1~260.500 ENPH.PS2 39.296 ENRA.PS2 4.785 CFEC.PS2 CNEC.PS2 2796.389 RCEF.PS2 586.749 RCEN.PS2 2832.974 NPHI.PS2 TNPH.PS2 33.064 TNRA.PS2 3,325 RTNR.PS2 3.949 NPOR,PS2 RCNT.PS2 1842.528 RCFT.PS2 466.459 CNTC.PS2 9770,624 CFTC.PS2 GR.PS2 949.925 TENS.PS2 2785.000 CCL.PS2 -0.~7 582.035 36.526 31.560 544.392 584.39~ 35.e52 29.838 595.592 ** END OF DATA ** **** FILE TRAILER **** FILE NAME : EDIT .~06 SERVICE : FLIC VERSION : 009C01 DATE : 95/07/17 MAX REC SIZE : [024 FILE TYPE : LO LAST FILE : **** FILE HEADER **** FILE NAME : EDIT .e07 SERVICE : FLIC VERSION : 009C09 DATE : 95/07/~7 MAX REC SIZE : 9024 FILE TYPE : LO LAST FILE : FILE HEADER LIS Tape Verification Listing Schlumberger Alaska Comput,]ng Center 17-JUL-1995 10:26 PAGE: 20 FILE NUMBER 7 RAW CURVES Curves and log header data for each pass in separate files; raw background pass in last file PASS NUMBER: 3 DEPTH INCREMENT: 0.5000 # FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH CNTG $ LOG HEADER DATA 10690.5 10293.0 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 27-AUG-94 40.2 1447 27-AUG-94 10718.0 10675.0 10300.0 10671.~ 2500.0 NO TOOL NUMBER CNTG CNTG CNTG CNTG CNTG CNTG CNTG $ COLLAR LOCATOR TELEMETRY CARTRIDGE GAMMA RAY COMPENSATED 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 TOOL TYPE (EPITHERMAL OR THERMAL): MATRIX: CAL YA 229 TCC B 840 SGC SA 59 CNTG 125 FLEX CBC 86 CBS 160 28.0 SEAWATER EPITHERMAL SANDSTONE LIS Tape YetiS|ca%ion LJs%ing Schlumberger Alaska ~Compu~Jng Cen%er 17-JUL-1995 10:26 MATRIX DENSITY: HOLE CORRECTION (IN): 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): FAR COUNT RATE HIGH SCALE (CPS): NEAR COUNT RATE LOW SCALE (CPS): NEAR COUNT RATE HIGH SCALE (CPS): TOOL STANDOFF (IN): REMARKS: TIE-IN SWS LWD CDR DATED 14-AUG-1994, LOG DEPTH DRIFTS WRT THE CDR TOWARD THE BOTTOM, SO THE LOG WAS TIED-IN AT THE CENTER OF THE EXPECTED PERFS 10600' LOG RUN BEFORE WELL WAS PERFORATED. $ LIS FORMAT DATA PAGE: 21 DATA FORMAT SPECIFICATION RECORD SET TYPE - 64EB ,~ TYPE REPR CODE VALUE 2 66 ~ 3 73 76 4 66 1 5 66 6 73 7 65 8 68 0.5 9 65 FT 12 68 13 66 0 14 65 FT ~ 66 68 16 66 1 0 66 1 LIS Tape Verifica~,ion List~ing ScH I umberger A I aska ~Comput~'i ng Cent~er SET TYPE - CHAN ** 17-JUL-1995 10:26 PAGE: 22 NAME SERV UNIT SERVICE AP1 AP1 AP1 AP1 FILE NUMB NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUMB SAMP ELEM CODE (HEX) DEPT FT 619044 00 000 00 0 7 1 1 4 68 0000000000 ENPH PS3 PU 619044 00 000 00 0 7 1 1 4 68 0000000000 ENRA PS3 619044 00 000 00 0 7 1 1 4 68 0000000000 CFEC PS3 CPS 619044 00 000 00 0 7 1 1 4 68 0000000000 CNEC PS3 CPS 619044 00 000 00 0 7 1 1 4 68 0000090000 RCEF PS3 CPS 619944 00 999 00 0 7 I 1 4 68 9090099099 RCEN PS3 CPS 619044 00 000 09 0 7 1 1 4 68 0009099900 NPHI PS3 PU 619044 90 000 09 9 7 1 1 4 68 0909999090 TNPH PS3 PU 619044 00 900 09 0 7 1 1 4 68 0909090000 TNRA PS3 619044 00 999 99 9 7 1 1 4 68 0009099000 RTNR PS3 619044 00 000 09 0 7 1 1 4 68 0909009909 NPOR PS3 PU 619944 90 999 99 9 7 1 1 4 68 9999999999 RCNT PS3 CPS 619944 99 999 99 9 7 1 1 4 68 9999099999 RCFT PS3 CPS 619944 99 999 99 9 7 1 1 4 68 9999990999 CNTC PS3 CPS 619944 99 999 99 9 7 1 1 4 68 9099999999 CFTC PS3 CPS 619944 99 099 90 0 7 1 1 4 68 9990999999 GR PS3 GAPI 619944 99 990 99 9 7 1 1 4 68 9999999990 TENS PS3 LB 619944 99 999 00 0 7 1 1 4 68 9999999999 CCL PS3 V 619944 99 000 99 0 7 1 I 4 68 9999999999 ** DATA ** DEPT. 10690.599 ENPH.PS3 31.749 ENRA.PS3 4.838 CFEC.PS3 CNEC.PS3 2879.949 RCEF.PS3 589.318 RCEN.PS3 2746.600 NPHI.PS3 TNPH.PS3 27.869 TNRA.PS3 3.164 RTNR.PS3 3.232 NPOR.PS3 RCNT.PS3 1742.669 RCFT.PS3 531.899 CNTC.PS3 1819.281 CFTC.PS3 GR.PS3 74.688 TENS.PS3 2149.999 CCL.PS3 -9.995 DEPT. 19293.999 ENPH.PS3 49.547 ENRA.PS3 5.667 CFEC.PS3 CNEC.PS3 2736.205 RCEF.PS3 462.789 RCEN.PS3 2567.847 NPHI.PS3 TNPH.PS3 38.727 TNRA.PS3 3.828 RTNR.PS3 3.931 NPOR.PS3 RCNT.PS3 1549.696 RCFT.PS3 396.671 CNTC.PS3 1572.154 CFTC.PS3 GR.PS3 169.599 TENS.PS3 2745.099 CCL.PS3 -9.954 595.100 32.117 27.869 586.727 482.860 44.298 37.714 415.915 ** END OF DATA ** **** FILE TRAILER FILE NAME : EDIT .997 SERVICE : FLIC VERSION : 9o1C91 DATE : 95/97/17 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : LIS Tape Verificat~ion Listing Schlumberger Alaska ~Somput'ing Center 17-JUL-1995 10:26 PAGE: 23 **** TAPE TRAILER **** SERVICE NAME : EDIT DATE : 95/07/17 ORIGIN : FLIC TAPE NAME : 95236 CONTINUATION # : [ PREVIOUS TAPE : COMMENT : ARCO ALASKA INC., PRUDHOE BAY, D.S. 9-37, 50-029-22451-00 **** REEL TRAILER SERVICE NAME : EDIT DATE : 95/07/17 ORIGIN : FLIC REEL NAME : 95236 CONTINUATION # : PREVIOUS REEL COMMENT : ARCO ALASKA INC., PRUDHOE BAY, D.S. 9-37, 50-029-22451-00 ALASKA COMPUTING CENTER · SCHLUMBERGER ....... COMPANY NAME : ARCO ALASKA, INC. WELL NAME : D.S. 9-37 FIELD NAME : PRUDHOE BAY BOROUGH : NORTH SLOPE STATE : ALASKA AP1 NUMBER : 5~-029-22451-e0 REFERENCE NO : 95235 RFCE1VED JUL ! 9 i99~ Alaska Oil & Gas Cons. 6ommis,~ion Anchorage ~/' L-!S Tap~ Veri~icat,ion List,ing Schlumberger Alaska Comput,Jng Cent, er 14-JUL-1995 13:29 · ,*, REEL HEADER ,~,, SERVICE NAME : EDIT DATE : 95/07/14 ORIGIN : FLIC REEL NAME : 95235 CONTINUATION # : PREVIOUS REEL : COMMENT : ARCO ALASKA INC., D.S. 9-37, PRUDHOE BAY, 50-029-22451-90 **** TAPE HEADER **** SERVICE NAME : EDIT DATE : 95/97/14 ORIGIN : FLIC TAPE NAME : 95235 CONTINUATION # : ~ PREVIOUS TAPE : COMMENT : ARCO ALASKA INC., D.S. 9-37, PRUDHOE BAY, 59-929-2245~-99 TAPE HEADER PRUDHOE BAY CASED HOLE WlRELINE LOGS WELL NAME: D.S. 9-37 API NUMBER: 599292245~99 OPERATOR: ARCO ALASKA, INC. LOGGING COMPANY: SCHLUMBERGER WELL SERVICES TAPE CREATION DATE: ~4-JUL-95 JOB NUMBER: 95235 LOGGING ENGINEER: SIMMONS OPERATOR WITNESS: REYNOLDS SURFACE LOCATION SECTION: TOWNSHIP: RANGE: FNL: FSL: 29~ FEL: 4962 FWL: ELEVATION(FT FROM MSL KELLY BUSHING: 46.39 DERRICK FLOOR: 45.39 GROUND LEVEL: 29.79 WELL CASING RECORD OPEN HOLE CASING DRILLERS CASING BIT SIZE (IN) SIZE (IN) DEPTH (FT) WEIGHT (LB/FT) 1ST STRING 19.759 28.9 2ND STRING 9.625 3539.9 3RD STRING 5.599 19894.9 PRODUCTION STRING CURVE SHIFT DATA - ALL PASSES TO STANDARD(MEASURED DEPTH) 45.59 49.99 17.99 PAGE: L-IS Tape, Veri{ication Listing i4-JUL-1995 13:29 Schlumberger Alaska Computing Center BASELINE CURVE FOR SHIFTS LDWG TOOL CODE; TDTP LDWG CURVE CODE: GRCH RUN NUMBER: 2 PASS NUMBER: DATE LOGGED: 24-MAY-95 LOGGING COMPANY: SCHLUMBERGER EQUIVALENT UNSHIFTED DEPTH BASELINE DEPTH GRCH TDTP 88888.0 88884.0 88884.0 10642.0 10638.0 10638.0 10591.5 10587.5 10587.5 1~555.0 10551.0 10551.0 10520.5 10517.5 10517.5 10488.5 10485.0 10485.0 10458.5 10455.5 10455.5 10424.0 10421.5 1042i.5 [e340.5 [0336.5 1~336.5 le309.0 103e5.0 103e5.0 le0.0 96.0 96.0 $ REMARKS: The depth adjustments shown above reflect cased hole Ist pass GRCH to the 24-MAY-95 pass1GRCH logged with magnetic marked llne. The first pass SIGM was shifted the same as the first pass GRCH and all other TDTP curves were carried with the SIGM shifts. The curve identified on this tape as GRCH.BASE is from the TDTP logged MAY-95. THIS TAPE REPLACES THE ONE DELIVERED 30-DEC-94. $ $ **** FILE HEADER FILE NAME : EDIT .00[ SERVICE : FLIC VERSION : DATE : 95/07/~4 MAX REC SIZE : [024 FILE TYPE : LO LAST FILE : PAGE: FILE HEADER FILE NUMBER: EDITED CURVES Depth shifted and clipped curves for each pass in separate files. PASS NUMBER: DEPTH INCREMENT: 0.5000 FILE SUMMARY LDWG TOOL CODE START DEPTH STOP DEPTH L~S Taps Verification Listing Schlumberger Alaska Computing Center 14-JUL-1995 13:29 PAGE: GRCH 1065S.0 TDTP 1966B.~ CURVE SHIFT DATA - PASS TO PASS(MEASURED DEPTH) BASELINE CURVE FOR SHIFTS LDWG CURVE CODE: PASS NUMBER: EQUIVALENT UNSHIFTED DEPTH BASELINE DEPTH $ REMARKS: This file contains TDTP Pass #1. shifts were applied to this data. LIS FORMAT DATA No pass to pass DATA FORMAT SPECIFICATION RECORD SET TYPE - 64EB ** TYPE REPR CODE VALUE 1 66 0 2 66 0 3 73 88 4 66 5 66 6 73 7 65 8 68 0.5 9 65 FT 12 68 13 66 0 14 65 FT 15 66 68 16 66 ~ 66 0 SET TYPE - CHAN ** NAME SERV UNIT SERVICE AP1 AP1 AP1 AP1 FILE NUMB NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUMB SAMP ELEM CODE (HEX) DEPT FT 500540 90 0e0 ~0 9 1 I I 4 68 0000000000 SIGM TDTP CU 590549 90 900 90 0 I I 1 4 68 0000000009 L~S Tape, VerJ~|cat~ion Listing Schlumberger Alaska Comput~Jng Cent~er 14-JUL-1995 13:29 PAGE: NAME SERV UNIT SERVICE AP1 AP1 AP1 AP1 FILE NUMB NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUMB SAMP ELEM CODE (HEX) SIGC TDTP CU 500540 00 000 0~ 0 1 1 1 4 68 0000000000 SIBH TDTP CU S0~540 00 0~0 00 0 1 1 1 4 68 00~0000000 SDSI TDTP CU 500540 00 000 00 0 1 1 1 4 68 0000000000 SBHN TDTP CU 500540 00 000 00 0 1 1 1 4 68 0000~00000 SBHF TDTP CU 500540 00 000 00 0 1 1 1 4 68 0000000000 TPHI TDTP PU-S 500540 00 000 00 0 1 1 1 4 68 0000000000 TRAT TDTP 500540 00 000 00 0 1 I 1 4 68 ~0000000 TCAN TDTP CPS 5~540 ~0 000 0~ 0 1 1 1 4 68 0~0~00000 TCAF TDTP CPS 50~540 ~0 000 00 0 1 1 1 4 68 0000000000 TCND TDTP CPS 5~0540 00 000 00 0 1 1 1 4 68 0000000000 TCFD TDTP CPS 50~540 00 000 0~ 0 1 1 1 4 68 0000~0~000 TSCN TDTP CPS 50054~ ~0 000 00 ~ 1 1 1 4 68 000~0~0000 TSCF TDTP CPS 50~540 00 000 00 0 1 1 1 4 68 0e00000000 INND TDTP CPS 50~540 00 000 00 0 1 I 1 4 68 0000000000 INFD TDTP CPS 5e~540 ~0 e00 00 0 1 1 1 4 68 000000~000 BACK TDTP CPS 50054e ~0 000 00 0 1 I 1 4 68 0~0~000000 TBAC TDTP CPS 5e~540 ~0 0~0 00 0 1 1 1 4 68 00e~000000 GRCH TDTP GAPI 5~540 00 000 00 0 1 1 1 4 68 0000000000 TENS TDTP LB 5~540 00 000 00 0 1 1 1 4 68 0000000000 GRCH BASE GAPI 5~540 00 000 00 0 1 1 1 4 68 0000000000 DATA DEPT. 1~677.~0 SIGM.TDTP -999.250 SIGC.TDTP -999.250 SIBH.TDTP SDSI.TDTP -999.250 SBHN.TDTP -999.250 SBHF.TDTP -999.250 TPHI,TDTP TRAT.TDTP -999.250 TCAN.TDTP -999.250 TCAF.TDTP -999.250 TCND.TDTP TCFD.TDTP -999.250 TSCN.TDTP -999.250 TSCF.TDTP -999.250 INND.TDTP INFD.TDTP -999.250 BACK.TDTP -999.250 TBAC.TDTP -999.250 GRCH.TDTP TENS.TDTP -999.250 GRCH.BASE 68.438 DEPT. le295.5~0 SIGM.TDTP 44.7e0 SIGC.TDTP 0.00~ SIBH.TDTP SDSI.TDTP 0.629 SBHN.TDTP 47.778 SBHF.TDTP 42.628 TPHI.TDTP TRAT.TDTP 2.029 TCAN.TDTP 66826.219 TCAF.TDTP 15232.145 TCND.TDTP TCFD.TDTP 3343.547 TSCN.TDTP 1418.669 TSCF.TDTP 327.969 INND.TDTP INFD.TDTP 391.530 BACK.TDTP 145.493 TBAC.TDTP 32.466 GRCH.TDTP TENS.TDTP 241~,~00 GRCH,BASE -999,250 -999.250 -999.25~ -999.250 -999.250 -999.250 54.576 64.051 15003.441 1845.208 66.438 ** END OF DATA ** LZ.S Tape' Verii~icat~ion List~ing Schlumberger Alaska Comput~ing Center **** FILE TRAILER **** FILE NAME : EDIT .001 SERVICE : FLIC VERSION : 001C01 DATE : 95/07/14 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : **** FILE HEADER FILE NAME : EDIT .002 SERVICE : FLIC VERSION : 001C0! DATE : 95/07/14 MAX REC SIZE : Z024 FILE TYPE : LO LAST FILE : 14-JUL-lg95 13:2g PAGE: 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 10655.0 ~3~0.0 TDTP ~0658.~ 103~.0 $ ~ '. CURVE SHIFT DATA - PASS TO PASS(MEASURED DEPTH) BASELINE CURVE FOR SHIFTS LDWG CURVE CODE: GRCH PASS NUMBER: 1 EQUIVALENT UNSHIFTED DEPTH BASELINE DEPTH GRCH TDTP 88888 10655 10647 ~0637 [0633 [0629 10627 [0625 ~0623 ~062~ .0 88884.0 88884.5 .5 10652.0 .5 10647.5 5 10643.e 5 10633.5 5 10629.5 5 10626.0 5 10623.0 5 10621.5 5 10619.5 5 10617.5 LIS Tape, Verii:icaf, ion Lisf, ing Schlumberger Alaska Computing Center 14-JUl-1995 ~3:29 PAGE: 10617.5 1~615.5 ~0613.5 ~0607.S ~99,5 ~0587.5 10585.5 10583.5 10581.5 10579.5 10577,5 1~573,5 ~0567.5 ~563.5 1~559.5 ~0543.5 10539.5 ~0535.5 1~529.5 10525.5 10509.5 10507.5 10505.5 10503.5 1~501.5 10499.5 10495.5 10491.5 10489.5 1~487.5 10485.5 1~451.5 10475.5 1~471.5 10463.5 10459.5 10441.5 1~437.5 10433.5 1~429.5 10419.5 10415.5 10409.5 10405 5 10401 5 10399 5 10397 5 10395 5 10393 5 10391.5 10389.5 10613.0 10610.0 10586.0 10581.5 10578.0 10573.5 10570.0 10526.0 10522.5 10506.5 10502.0 10498.5 10486.5 10482.0 10478.5 10438.5 10434.0 i0430.5 10426.0 10406.0 10401.5 10397.0 1~393.0 10359.5 10385.5 10611.5 10608.0 10604.0 1~599.5 1~596.0 10588.0 10583.5 10579.5 10576.0 10564.0 10559.5 10556.0 10540.0 1~535.5 10532.~ 10504.0 105~0.5 10496.0 1~492.5 10488.5 1~484.0 10472.0 1~467.5 10459.5 10456.0 10416.~ 10411.5 1~395.5 10392.0 10357.5 LIS Tape, Verit:ication List~ing Schlumberger Alaska Computing Cent~er 14-JUL-1995 13:29 10355.5 10381.0 10377.5 10373.0 10373.5 10369.5 10355.5 10353.5 10349.5 10351.5 10349.5 10345.0 10329.5 10325.0 10325.5 10321.5 100.0 96.0 $ 10351.5 10347.0 95.5 REMARKS: This file contains TDTP Pass #2. The depth shifts shown above relect GRCH pass #2 to GRCH pass #1 and SIGM pass #2 to SIGM pass #1. $ LIS FORMAT DATA PAGE: DATA FORMAT SPECIFICATION RECORD SET TYPE - 64EB ** TYPE REPR CODE VALUE I 66 0 2 66 0 3 73 84 4 66 5 66 6 73 7 65 8 68 0.5 9 65 FT 11 66 12 12 68 13 66 0 14 65 FT 15 66 68 16 66 0 66 ** SET TYPE - CHAN ** NAME SERV UNIT SERVICE AP1 AP1 AP1 AP1 FILE NUMB NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUMB SAMP ELEM CODE (HEX) DEPT FT 500540 ~0 000 00 SIGM TDTP CU 50~540 ~0 ~00 00 SIGC TDTP CU 500540 00 000 00 SIBH TDTP CU 50~540 ~0 ~00 00 0 2 1 1 4 68 00~00~0~0 0 2 I 1 4 68 0000000000 0 2 1 1 4 68 0000000000 0 2 1 1 4 68 0000000000 LIS Tape. Verification List|ng Schlumberger Alaska Computing Center ~4-JUL-1995 ~3:29 PAGE: NAME SERV UNIT SERVICE API API API API FILE NUMB NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUMB SAMP ELEM CODE (HEX) SDSI TDTP CU 500540 00 000 00 0 2 1 1 4 68 0000000000 SBHN TDTP CU 50~540 00 000 00 0 2 1 1 4 68 0000~00000 SBHF TDTP CU $00540 00 000 00 0 2 I I 4 68 0000900000 TPHI TDTP PU-S 599549 99 999 99 9 2 1 1 4 68 9999999999 TRAT TDTP 599549 99 999 99 9 2 1 1 4 68 9999999999 TCAN TDTP CPS 599549 99 999 99 9 2 1 1 4 68 9999999999 TCAF TDTP CPS 599549 99 999 99 9 2 1 1 4 68 9999999999 TCND TDTP CPS 599549 99 999 99 9 2 I 1 4 68 9999999999 TCFD TDTP CPS 599549 99 999 99 9 2 I 1 4 68 9999999999 TSCN TDTP CPS 599549 99 999 99 9 2 1 1 4 68 9999999999 TSCF TDTP CPS 599549 99 999 99 9 2 1 1 4 68 9999999999 INND TDTP CPS 599549 99 999 99 9 2 1 1 4 68 9999999999 INFD TDTP CPS 599549 99 999 99 9 2 1 1 4 68 9999999999 BACK TDTP CPS 599549 99 999 99 9 2 1 1 4 68 9999999999 FBAC TDTP CPS 599549 99 999 99 9 2 1 1 4 68 9999999999 GRCH TDTP OAPI 599549 99 999 99 9 2 1 1 4 68 9999999999 TENS TDTP LB 599549 99 999 99 9 2 1 1 4 68 9999999999 DATA DEPT. 19664.599 SIGM.TDTP 36.463 SIGC.TDTP 1.391 SIBH.TDTP SDSI.TDTP 9.642 SBHN.TDTP 43.479 SBHF.TDTP 34.992 TPHI.TDTP TRAT.TDTP 1.911 TCAN.TDTP 59724.099 TCAF.TDTP 16995.313 TCND.TDTP TCFD.TDTP 4171.666 TSCN.TDTP 2117.649 TSCF.TDTP 692.852 INND.TDTP INFD.TDTP 379.912 BACK.TDTP 195.996 FBAC.TDTP 59.672 GRCH.TDTP TENS.TDTP 2615.999 ** END OF DATA ** 44.$92 47.698 17035.238 1831.497 -999.259 **** FILE TRAILER FILE NAME : EDIT .992 SERVICE : FLIC VERSION : 991C91 DATE : 95/97/14 MAX REC SIZE : 1924 FILE TYPE : LO LAST FILE : LIS Tape, Verification Listing Schlumberger Alaska Computing Center · **- FILE HEADER ,--, FILE NAME : EDIT .003 SERVICE : FLIC VERSION : 001C01 DATE : g5/07/14 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : 14-JUL-1995 13:29 PAGE: FILE HEADER FILE NUMBER: 3 EDITED CURVES Depth shifted and clipped curves for each pass in separate files. PASS NUMBER: 3 DEPTH INCREMENT: 0.5000 FILE SUMMARY LDWG TOOL CODE START DEPTH STOP DEPTH GRCH 10655.0 10300.0 TDTP 10668.0 $ CURVE SHIFT DATA - PASS TO PASS(MEASURED DEPTH) BASELINE CURVE FOR SHIFTS LDWG CURVE CODE: GRCH PASS NUMBER: ,EQUIVALENT UNSHIFTED DEPTH BASELINE DEPTH GRCH TDTP 88888.0 10655.5 1~651.5 1~643.5 10633.5 10629.5 10627.5 1~625.5 10623.5 10621.5 10617.5 10615.5 1~613.5 1~611.5 10609.5 1~589.5 1~585.5 10581.5 10577.5 1~575.5 10567.5 88883.9 10628.5 10624.5 10621.0 10617.9 10613.5 10609.5 10606.0 10586.0 L0581.5 10578.0 10573.5 10570.0 88884.5 10652.0 1~647.5 1~639.5 1~623.0 1M619.5 10611.5 1~608.0 1~564.0 : LIS Tap~,V~rificai:ion Listing Schlumberger Alaska Computing Center 14-JUL-1995 13:29 1~563.5 10559.5 1~559.5 10556.0 1~533.5 10530.0 10529.5 1~525.5 10527.5 10524.0 10525.5 10522.0 10523.5 10519.5 10521.5 10518.$ 10519.5 10516.0 1~511.5 105~8.~ 10507.5 10504.5 1~491.5 10488.5 10487.5 10484.0 10473.5 10470.5 10469.5 1~466.0 10465.5 10461.5 10461.5 10458.0 10451.5 10448.0 10447.5 10444.5 10443.5 10441.0 1~439.5 10436.0 10419.5 10416.0 10415.5 10411.5 10405.5 10402.0 104~1.5 10397.5 10391.5 10387.5 10387.5 10383.0 10377.5 1~373.5 10373.5 1~370.~ 10369.5 10365.5 10353.5 10349.5 10349.5 10345.0 10323.5 10319.0 10315.5 10312.0 10~.0 95.5 96.5 REMARKS: This file contains TDTP Pass #3. The depth shifts shown above relect GRCH pass #3 to GRCH pass #1 and SIGM pass #3 to SIGM pass $ LIS FORMAT DATA PAGE: 10 DATA FORMAT SPECIFICATION RECORD ** ** SET TYPE - 64EB ** TYPE REPR CODE VALUE 1 66 0 2 66 0 LIS Tape 2!erit:ication Lis~,ing Schlumberger Alaska Compu~,ing Cent, er 14-JUL-1995 13:29 PAGE: 11 TYPE REPR CODE VALUE 3 73 84 4 66 1 5 66 6 73 7 65 8 68 0.5 9 65 FT 13 66 0 14 65 FT 15 66 68 0 66 1 SET TYPE - CHAN ** NAME SERV UNIT SERVICE aPI API APl APl FILE NUMB NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUMB SAMP ELEM CODE (HEX) DEPT FT 50054~ ~0 000 00 0 3 1 1 4 68 000~000000 SIGM TDTP CU 50~540 00 0~ ~0 0 3 I 1 4 68 0000000000 SIGC TDTP CU 500540 ~0 0~0 00 0 3 I 1 4 68 0000000000 SIBH TDTP CU 5~0540 ~0 000 00 0 3 I 1 4 68 0000000000 SDSI TDTP CU 50~540 00 000 00 0 3 I 1 4 68 0000000000 SBHN TDTP CU 5~540 ~0 000 00 0 3 1 1 4 68 00000000~0 SBHF TDTP CU 500540 00 0~0 ~0 0 3 1 1 4 68 00000~0000 TPHI TDTP PU-S 50054~ ~0 ~ 00 ~ 3 1 1 4 68 0000000000 TRAT TDTP 500540 00 000 00 0 3 I 1 4 68 0000000000 TCAN TDTP CPS 500540 00 0~0 00 0 3 1 1 4 68 000~000000 TCAF TDTP CPS 50~540 ~ ~00 00 0 3 1 1 4 68 0000000000 TCND TDTP CPS 50054~ ~0 00~ 00 0 3 I 1 4 68 ~00000000 TCFD TDTP CPS 50~54~ 00 ~0 0~ 0 3 I 1 4 68 0000000000 TSCN TDTP CPS 5~054~ 00 000 0~ 0 3 1 1 4 68 0000000000 TSCF TDTP CPS 5~054e ee 000 00 0 3 1 1 4 68 e000000000 INND TDTP CPS 50054~ Oe 0~0 Oe 0 3 1 1 4 68 0000000000 INFD TDTP CPS 5e0540 00 e00 00 0 3 I 1 4 68 0000000000 BACK TDTP CPS 50054~ 00 0~0 00 0 3 1 1 4 68 ~000000000 FBAC TDTP CPS 500540 00 0e0 00 0 3 1 1 4 68 e000000000 GRCH TDTP GAPI 500540 ~0 0e0 00 0 3 I 1 4 68 00000~0000 TENS TDTP LB 50e540 00 000 00 0 3 1 1 4 68 0000000000 ** DATA DEPT. 10664.500 SIGM.TDTP 37.537 SIGC.TDTP 1.192 SIBH.TDTP SDSI.TDTP 0.648 SBHN,TDTP 43.831 SBHF.TDTP 37.956 TPHI.TDTP TRAT,TDTP 1.885 TCAN.TDTP 58595.859 TCAF.TDTP 15865,709 TCND,TDTP TCFD,TDTP 4052,887 TSCN.TDTP 2047,112 TSCF.TDTP 588,497 INND.TDTP INFD.TDTP 375,531 BACK.TDTP 216.098 FBAC.TDTP 45,613 GRCH,TDTP 45.622 46.438 16778.023 1880.612 -999.250 LIS Tape Verification Listing Schlumberger Alaska Computing Center TENS.TDTP 2690.090 END OF DATA 14-JUL-lggs 13:29 PAGE: 12 **** FILE TRAILER FILE NAME : EDIT .993 SERVICE : FLIC VERSION : go1cgl DATE : 95/97/14 MAX REC SIZE : ~24 FILE TYPE : LO LAST FILE : **** FILE HEADER **** FILE NAME : EDIT .~94 SERVICE : FLIC VERSION : 091C91 DATE : 95/97/14 MAX REC SIZE : 1924 FILE TYPE : LO LAST FILE : FILE HEADER FILE NUMBER: 4 AVERAGED CURVES Pulsed Neutron: Unaveraged edited Pass 1 Gamma RaN and backround counts; arithmetic average of edited static baseline passes for all other curves. DEPTH INCREMENT 9.5909 PASSES INCLUDED IN AVERAGE LDWG TOOL CODE PASS NUMBERS TDTP l, 2~ 3~ $ REMARKS: The arithmetic average of passes 1~2 & 3 was computed after all depth shifts and clipping was applied, $ LIS FORMAT DATA LIS Tape Verif|cation Listing Schlumberger Alaska Computing Center 14-JUL-1995 13:29 DATA FORMAT SPECIFICATION RECORD *~ set TYPE - 64EB ~ TYPE REPR CODE VALUE 1 66 0 2 66 0 3 73 80 4 66 5 66 6 73 T 65 8 68 0.5 9 65 FT 12 68 13 66 0 14 65 FT 15 66 68 16 66 0 66 PAGE: 13 SET TYPE - CHAN ** NAME SERV UNIT SERVICE APl AP1 AP1 AP1 FILE NUMB NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUMB SAMP ELEM CODE (HEX) DEPT SIGM PNAV SIGC PNAV SIBH PNAV SDSI PNAV SBHN PNAV SBHF PNAV TPHI PNAV TRAT PNAV FT 500540 00 000 00 CU 5~0540 00 00~ 00 CU 5~54~ 0~ 000 00 CU 50~540 00 ~00 0~ CU 5~0540 00 0~0 00 CU 5~054~ 00 0~0 0~ CU 500540 00 000 00 PU-S 50~540 00 0~0 00 500540 00 000 00 TCAN PNAV CPS 50054~ 00 0~0 ~0 TCAF PNAV CPS 5~0540 ~0 000 00 TCND PNAV CPS 500540 0~ 0~0 00 TCFD PNAV CPS 5~540 0~ 0~0 ~0 TSCN PNAV CPS 50054~ 00 000 0~ TSCF PNAV CPS 500540 00 000 ~0 INND PNAV CPS 500540 00 0~0 00 INFD PNAV CPS 50054~ 00 000 00 BACK TDTP CPS 5~054~ 00 ~00 0~ FBAC TDTP CPS 500S40 00 000 0~ GRCH TDTP GAPI 50~40 00 ~00 00 0 4 1 1 4 68 0000000000 0 4 1 1 4 68 00000~000 0 4 1 1 4 68 00~0000000 0 4 1 I 4 68 00~00~000~ 0 4 1 I 4 68 ~0~0000000 0 4 1 1 4 68 00000~0000 0 4 1 1 4 68 0~0~0~0000 0 4 1 1 4 68 0~00000000 0 4 1 1 4 68 0~0~000~00 0 4 1 1 4 68 0~00000000 0 4 1 1 4 68 00000~0~00 0 4 I 1 4 68 000000~000 0 4 1 I 4 68 ~000000000 0 4 1 I 4 68 0000000000 0 4 1 1 4 68 0000000000 0 4 1 1 4 68 0~00~0~00 0 4 i 1 4 68 ~0~0000000 0 4 1 1 4 68 ~00000000 0 4 1 I 4 68 0000000000 0 4 1 1 4 68 00~0000000 ** DATA ** LIS Tape Verification Listing Schlumberger Alaska Computing Cent, er 14-JUL-1995 13:29 PAGE: 14 DEPT. Z0664.500 SIGM.PNAV 37.e02 SIGC.PNAV 1.200 SIBH.PNAV SDSI.PNAV 0.617 SBHN.PNAV 43.717 SBHF.PNAV 36.754 TPHI.PNAV TRAT.PNAV 1.890 TCAN.PNAV 60780.922 TCAF.PNAV ~6567.~29 TCND.PNAV TCFD.PNAV 4~64.5g~ TSCN.PNAV 2111.936 TSCF.PNAV 609.213 INND.PNAV INFD.PNAV 372.056 BACK.TDTP 128.734 FBAC.TDTP 32.995 GRCH.TDTP 45.368 46.617 [7042.828 1840.402 -999.250 END OF DATA **** FILE TRAILER FILE NAME : EDIT .004 SERVICE : FLIC VERSION : 001C0~ DATE : 95/07/14 MAX REC SIZE : ~024 FILE TYPE : LO LAST FILE : **** FILE HEADER FILE NAME : EDIT .005 SERVICE : FLIC VERSION : DATE : 95/07/~4 MAX EEC SIZE : ~024 FILE TYPE : LO LAST FILE : FILE HEADER FILE NUMBER RAW CURVES Curves and log header data ~or each pass in separate ~|les; raw background pass in last ~ile PASS NUMBER: DEPTH INCREMENT: 0.5~00 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH TDTP ~0668.0 $ 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): 31-AUG-94 CP38.2 [025 31-AUG-94 10804.0 [0300.0 10668.0 LIS Tape Verification Listing Schlumberger Alaska Computing Ceni~er 14-JUL-1995 13:29 PAGE: 15 LOGGING SPEED (FPHR): DEPTH CONTROL USED (YES/NO): 600.0 NO TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE TOOL NUMBER TDTP THERMAL DECAY TNC-P 50 TDTP THERMAL DECAY TND-P 78 TDTP THERMAL DECAY TNG-P 21 TDTP THERMAL DECAY MINITRON 8496 TDTP THERMAL DECAY ATC 1163 TDTP THERMAL DECAY CAL-U 597 TDTP THERMAL DECAY ATM-AB 283 $ BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLERS CASING DEPTH (FT): LOGGERS CASING DEPTH (FT): 10804.0 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): FAR COUNT RATE HIGH SCALE (CPS): NEAR COUNT RATE LOW SCALE (CPS): NEAR COUNT RATE HIGH SCALE (CPS): TOOL STANDOFF (IN): REMARKS: CORRELATED TO SWS CBL LOG OF 27-AUG-1994. THREE PASSES LOGGED ON SANNDTONE MATRIX AT 600 FPH. $ LIS FORMAT DATA LIS Tape Veri~ica~,ion List;lng Schlumberger Alaska Compu~,ing Center ~4-JUl-~995 ~3:29 PAGE: 16 DATA FORMAT SPECIFICATION RECORD SET TYPE - 64EB ** TYPE REPR CODE VALUE I 66 0 2 66 0 3 73 132 4 66 1 5 66 6 73 7 65 8 68 0.5 9 65 FT 11 66 7 12 68 13 66 0 14 65 FT 15 66 68 16 66 1 0 66 1 SET TYPE - CHAN ** NAME SERV UNIT SERVICE AP1 AP1 AP1 AP1 FILE NUMB NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUMB SAMP ELEM CODE (HEX) DEPT FT 5~0540 ~e 000 0~ 0 5 1 1 4 68 0000000000 SIGM PS1 CU 5~0540 00 000 00 0 5 1 1 4 68 0~0~0000~0 STDT PS1 5~0540 00 ~00 00 0 5 1 1 4 68 0000000000 TPHI PS1 PU 5ee54~ ~e eee ~e e 5 1 1 4 68 e~ee~eeee ISHU PS1 V see54e ee ee~ aa e 5 I 1 4 68 eeea~e~ae SFFD PS1 CU S~OS40 ~0 000 0~ ~ 5 1 1 4 68 000e0000~0 SFND PS1 CU 5e0540 00 000 00 0 5 I ! 4 68 000~0e0000 SBHF PS1 CU 500540 00 0e0 00 0 5 1 1 4 68 00e0000000 SBHN PS1 CU 500540 00 00~ Oe 0 5 1 1 4 68 0000000000 FTDT PS1 CPS 50054e 00 000 00 0 5 1 1 4 68 0000~000~0 NTDT PS1 CPS 500540 ~0 000 00 0 5 1 1 4 68 0000~000~ AFFD PS1 CPS 5~0540 00 000 00 0 5 1 1 4 68 0000000000 ABFD PS1 CPS 50~54~ 00 000 00 0 5 1 1 4 68 0000000000 AFND PS1 CPS Se0540 eO 0e0 00 0 5 1 1 4 68 0000000e00 ABND PS1 CPS 5ees4e ee eee ee e 5 1 1 4 68 eeeeeeeeee SIGC PS1 CU 50054e 00 000 00 0 5 1 1 4 68 0000000000 SIBH PS1 CU 500540 00 000 00 0 5 1 1 4 68 000~0~0000 MMOF PS1 5~0540 eO 000 00 0 5 1 1 4 68 0000000000 TEAT PS1 500540 00 000 00 0 5 I 1 4 68 0000000000 SDSI PS1 CU 500540 00 000 00 0 5 1 1 4 68 00000000~0 BACK PS1 CPS 500540 00 000 00 0 5 1 1 4 68 0000000~00 FBAC PS1 CPS 500540 00 000 00 0 5 1 1 4 68 0000000000 TCAN PS1 CPS 500540 00 000 00 0 5 1 1 4 68 000e000000 TCAF PS1 CPS 500540 00 000 00 0 5 1 1 4 68 0000000000 LIS Tape Verificat, ion Listing 14-JUl-1995 13:29 Schlumberger Alaska Computing Cent, er PA~E: 17 NAME SERV UNIT SERVICE AP1 AP1 AP1 AP1 FILE NUMB NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUMB SAMP ELEM CODE (HEX) TCND PS1 CPS 500540 00 000 00 0 5 1 I 4 68 0000000000 TCFD PS1 CPS 500540 00 000 00 0 5 1 1 4 68 0000000000 TSCN PS1 CPS 500540 90 999 99 9 5 1 1 4 68 9999999999 TSCF PS1 CPS 599549 99 999 99 9 5 1 1 4 68 9999999999 INND PS1 CPS 599549 99 999 99 9 5 1 1 4 68 9999999999 INFD PS1 CPS 599549 99 999 99 9 5 1 ~ 4 68 9999999999 gR PS1 gAPI 599540 99 999 99 9 5 1 ~ 4 68 9999999999 TENS PS1 LB 599549 99 999 99 9 5 1 1 4 68 9999999999 CCL PS1 V 509549 99 999 99 9 5 1 1 4 68 9999999999 DATA ** DEPT. 19686.999 SIGM.PS1 13.589 STDT.PS1 66.999 TPHI.PS1 ISHU.PSl 39.469 SFFD.PS1 14,699 SFND,PS1 16,566 SBHF.PS1 SBHN.PS1 39.219 FTDT.PS1 19.685 NTDT.PSl 39.887 AFFD.PS1 ABFD.PS1 118.296 AFND.PS1 389.368 ABND.PS1 475.834 SIGC.PS1 SIBH.PS1 39.219 MMOF.PS1 9.947 TRAT.PS1 1.972 SDSI.PS1 BACK.PS1 37.729 FBAC.PS1 19.136 TCAN.PSI 39997.281 TCAF.PS1 TCND.PS1 26521.137 TCFD.PS1 8153.375 TSCN.PS1 8473.984 TSCF.PS1 INND.PS1 1636.965 INFD.PS1 389.161 GR.PS1 98.688 TENS.PS1 CCL.PS1 9.999 DEPT. 19296.999 'SIGM.PS1 43.462 STDT.PS1 66.999 TPHI.PS1 ISHU.PS1 59.781 SFFD.PS1 43.586 SFND.PS1 44.188 SBHF.PS1 SBHN.PS1 47.935 FTDT.PS1 3.288 NTDT.PS1 13.733 AFFD.PS1 ABFD.PS1 97.366 AFND.PS1 414.955 ABND.PS! 449.935 SIGC.PS1 SIBH.PS1 54.931 MMOF.PSl 1.947 TRAT.PS1 1.974 SDSI.PS1 BACK.PS1 147.199 FBAC.PS1 34.595 TCAN.PS1 64126.172 TCAF.PS1 TCND.PS1 14929.645 TCFD.PS1 3332.497 TSCN.PS1 1412.496 TSCF.PS1 INND.PS1 1841.811. INFD.PS1 385.595 GR.PS1 63.188 TENS.PS1 CCL.PS1 9.999 39.271 32.681 91.481 1.947 9.221 15568.813 3395.919 1999.999 61.259 44.779 81.399 9.319 9.549 14978.666 342.835 2529.999 ** END OF DATA ** **** FILE TRAILER **** FILE NAME : EDIT .995 SERVICE : FLIC VERSION : 991C91 DATE : 95/97/14 MAX RE¢ SIZE : 1924 FILE TYPE : LO LAST FILE : LIS Tape Verification List|ng Schlumberger A~aska Computing Center · ,,, FILE HEADER ~*-~ FILE NAME : EDIT .006 SERVICE : FLIC VERSION : 001C01 DATE : 9~/07/14 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : 14-JUl-1995 13:29 PAGE: 18 FILE HEADER FILE NUMBER 6 RAW CURVES Curves and log header data for each pass in separate files; raw background pass in last file PASS NUMBER: 2 DEPTH INCREMENT: 0.5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH TDTP $ LOG HEADER DATA 10665.~ 103~0.0 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 31-AUG-g4 CP38.2 1025 31-AUG-94 lg8g4.g 10300.0 1~668.0 600.0 NO TOOL NUMBER TDTP THERMAL DECAY TNC-P 50 TDTP THERMAL DECAY TND-P 78 TDTP THERMAL DECAY TNG-P 21 TDTP THERMAL DECAY MINITRON 8496 TDTP THERMAL DECAY ATC 1163 TDTP THERMAL DECAY CAL-U 597 TDTP THERMAL DECAY ATM-AB 283 $ BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLERS CASING DEPTH (FT): LOGGERS CASING DEPTH (FT): BOREHOLE CONDITIONS FLUID TYPE: 10804.0 SEA WATER LIS Tape Veri~icat|on Listing Schlumberger A~aska Comput|ng Cent~er 14-JUL-1995 13:29 PAGE: 3.9 FLUID DENSITY (LB/G): SURFACE TEMPERATURE (DEGF): BOTTOM HOLE TEMPERATURE (DEGF): FLUID SALINITY (PPM): FLUID LEVEL (FT): FLUID RATE AT WELLHEAD (BPM): WATER CUTS (PCT): GAS/OIL RATIO: CHOKE (DEG): NEUTRON TOOL TOOL TYPE (EPITHERMAL OR THERMAL): MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): 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): FAR COUNT RATE HIGH SCALE (CPS): NEAR COUNT RATE LOW SCALE (CPS): NEAR COUNT RATE HIGH SCALE (CPS): TOOL STANDOFF (IN): REMARKS: CORRELATED TO SWS CBL LOG OF 27-AUG-3.gg4. THREE PASSES LOGGED ON SANNDTONE MATRIX AT 609 FPH, $ LIS FORMAT DATA DATA FORMAT SPECIFICATION RECORD SET TYPE - 64EB *~ TYPE REPR CODE VALUE 1 66 0 2 66 e 3 73 3.32 4 66 3. 5 66 6 73 7 65 8 68 9.5 9 65 FT 3.1 66 7 3.2 68 13 66 0 LIS Tape Verification Li$%ing Schlumberger Alaska Compu%ing Cen%er [4-JUL-1995 [3:29 PAGE: 20 TYPE REPR CODE VALUE 14 65 FT 15 66 68 16 66 0 66 SET TYPE - CHAN *~ NAME SERV UNIT SERVICE API API API API FILE NUMB NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUMB SAMP ELEB CODE (HEX) DEPT FT 500540 Se ese es S 6 1 I 4 68 SSSSSSSSSS SIGM PS2 CU 5SSS4S es ese se s 6 1 I 4 68 SSSSSSSSSS STDT PS2 5SS54S eS ese es s 6 I I 4 68 ssssssssss TPH~ PS2 PU 5SS54S es ese se s 6 I 1 4 68 ssssssssss ISHU PS2 V 5SS54S eS SOS aS S 6 I 1 4 68 SSSSSSSSSS SFFD PS2 CU 5SS54S es ese se 0 6 1 1 4 68 ssssssssss SFND PS2 CU 5SS54S es ese es s 6 1 ~ 4 68 ssssssssss SBHF PS2 CU 5SS54S es ese se s 6 1 1 4 68 SSSSSSSSSS SBHN PS2 CU 5SSS4S es ese se s 6 I 1 4 68 sssssessss FTDT PS2 CPS 5SSS4S eS ese se s 6 [ [ 4 68 ssssssssss NTDT PS2 CPS 5SS54S es ess se s 6 1 [ 4 68 ssssssssss AFFD PS2 CPS 5SS54S es ese es s 6 I 1 4 68 ssssssssss ABFD PS2 CPS 5SSS4S se ese se s 6 [ 1 4 68 ssssssssss AFND PS2 CPS SSe54S es ese se s 6 1 I 4 68 SSSSSSSSSS ABND PS2 CPS SSSS4S eS ese es s 6 1 I 4 68 ssssssssss SIBH PS2 CU SSSS4S eS ese se o 6 1 I 4 68 ssssssssss TEAT PS2 5SS54S Se ese es s 6 1 1 4 68 ssssosssss SDSI PS2 CU 5SS54S eS ese Se 0 6 1 1 4 68 sSssssssss BACK PS2 CPS 50S54S es ese es s 6 1 1 4 68 ssssssssss FBAC PS2 CPS 50S540 Se ese eS S 6 1 1 4 68 SSSSSSSSSO TCAN PS2 CPS 5SS540 Se ese se 0 6 1 1 4 68 SOSOOSOOOS TCAF PS2 CPS 50S540 eS ese es 0 6 1 1 4 68 ssssssssss TCND PS2 CPS 5SS54S eS ese se 0 6 I 1 4 68 osssososss TCFD PS2 CPS 5SS54e Se ese Se S 6 I 1 4 68 SSSOSSOS00 TSCN PS2 CPS 50S54S eS ese se 0 6 I 1 4 68 sssoooosss TSCF PS2 CPS 5SS54S Se ese eS 0 6 1 1 4 68 ssOsSOOOse INND PS2 CPS 5SS54S eS 0S0 00 0 6 1 1 4 68 SOOSOSOSSO INFD PS2 CPS 5SS54S Se ese es s 6 I 1 4 68 sssssossss GR PS2 GAP[ 50S54S Se ese se s 6 I 1 4 68 osssssssss TENS PS2 LB 5SS54S se ese es 0 6 I 1 4 68 osssssssss CCL PS2 V SSOS4S eS ese es s 6 1 1 4 68 ssosSsssos DATA LIS Tape Verii:ication Listing Schlumberger Alaska Computing Center DEPT. 10688.500 SIGM.PS2 ISHU.PS2 42.563 SFFD.PS2 SBHN.PS2 47.935 FTDT.PS2 ABFD.PS2 97.366 AFND.PS2 SIBH.PS2 54.931 MMOF.PS2 BACK.PS2 147.109 FBAC.PS2 TCND.PS2 14929.645 TCFD.PS2 INND.PS2 1841.811 INFD.PS2 CCL.PS2 0.999 DEPT. 19277.599 SIGM.PS2 ISHU.PS2 38.188 SFFD.PS2 SBHN.PS2 45.858 FTDT.PS2 ABFD.PS2 199.547 AFND.PS2 SIBH.PS2 59.229 MMOF.PS2 BACK.PS2 174.664 FBAC.PS2 TCND.PS2 15594.164 TCFD.PS2 INND.PS2 1899.586 INFD.PS2 CCL.PS2 9.999 14-JUL-1995 13:29 43.462 STDT.PS2 43.586 SFND.PS2 3.288 NTDT.PS2 414.955 ABND.PS2 1.947 TRAT.PS2 34.595 TCAN.PS2 3332.497 TSCN.PS2 385.595 GR.PS2 41.732 42 391 3 898 414 972 1 129 38 348 3591 241 392.154 STDT.PS2 SFND.PS2 NTDT.PS2 ABND.PS2 TRAT.PS2 TCAN.PS2 TSCN.PS2 GR.PS2 66.999 TPHI.PS2 44.188 SBHF.PS2 13.733 AFFD.PS2 449.935 SIGC.PS2 1.974 SDSI.PS2 64126.172 TCAF.PS2 1412.496 TSCF.PS2 257.999 TENS.PS2 66.999 TPHI.PS2 42.731 SBHF.PS2 15.377 AFFD.PS2 442.829 SIGC.PS2 1.974 SDSI.PS2 59955.188 TCAF.PS2 1635.578 TSCF.PS2 89.259 TENS.PS2 PAGE: 21 61.259 44.779 81.399 9.319 9.549 14978.666 342.835 1969.999 56.396 41.398 85.997 9.427 9.486 14581.289 418.789 2495.999 END OF DATA ** **** FILE TRAILER **** FILE NAME : EDIT .996 SERVICE : FLIC VERSION : 991C91 DATE : 95/97/14 MAX REC SIZE : 1924 FILE TYPE : LO LAST FILE : **** FILE HEADER **** FILE NAME : EDIT .997 SERVICE : FLIC VERSION : 991C91 DATE : 95/97/14 MAX REC SIZE : 1924 FILE TYPE : LO LAST FILE : FILE HEADER FILE NUMBER RAW CURVES Curves and log PASS NUMBER: DEPTH INCREMENT: FILE SUMMARY header data 3 9.5999 ~or each pass in separate {iles; raw background pass in last ~ile LIS Tape Verification Listing Schlumberger Alaska Computing Center 14-JUl-1995 13:29 VENDOR TOOL CODE START DEPTH STOP DEPTH TDTP $ LOG HEADER DATA 10668.0 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 10300.0 3J-AUG-94 CP38.2 1025 3J-AUG-94 ~0804.0 10300.0 10668.0 600.0 NO TOOL NUMBER TDTP THERMAL DECAY TNC-P 50 TDTP THERMAL DECAY TND-P 78 TDTP THERMAL DECAY TNG-P 2~ TDTP THERMAL DECAY MINITRON 8496 TDTP THERMAL DECAY ATC ~163 TDTP THERMAL DECAY CAL-U 597 TDTP THERMAL DECAY ATM-AB 283 $ BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLERS CASING DEPTH (FT): LOGGERS CASING DEPTH (FT): 10804.0 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): PAGE: 22 LIS Tape Verification Listing Schlumberger Alaska Comput~ing Cent~er 14-JUL-1995 13:29 BLUELINE COUNT RATE SCALES SET BY FIELD ENGINEER FAR COUNT RATE LOW SCALE (CPS): FAR COUNT RATE HIGH SCALE (CPS): NEAR COUNT RATE LOW SCALE (CPS): NEAR COUNT RATE HIGH SCALE (CPS): TOOL STANDOFF (IN): REMARKS: CORRELATED TO SWS CBL LOG OF 27-AUG-1994, THREE PASSES LOGGED ON SANNDTONE MATRIX AT 69~ FPH. $ LIS FORMAT DATA PAGE: 23 DATA FORMAT SPECIFICATION RECORD SET TYPE - 64EB ** TYPE REPR CODE VALUE 1 66 0 2 66 0 3 73 132 4 66 5 66 6 73 7 65 8 68 0.5 9 65 FT 11 66 7 12 68 13 66 0 14 65 FT 15 66 68 16 66 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 500540 00 000 ~0 0 7 1 1 4 68 0000900000 SIGM PS3 CU 590540 00 000 00 0 7 1 ! 4 68 0000000000 STDT PS3 59~540 ~ ~ ~ 9 7 1 1 4 68 0000000900 TPHI PS3 PU 590549 00 900 09 0 7 1 1 4 68 0000000000 ISHU PS3 V 590540 00 0~0 00 ~ 7 1 1 4 68 0009000~00 SFFD PS3 CU 590549 00 000 00 0 7 1 1 4 68 0090900~00 SFND PS3 CU 500540 00 000 00 0 7 I I 4 68 0090990900 SBHF PS3 CU 500540 00 000 00 0 7 1 I 4 68 0000900000 SBHN PS3 CU 509540 90 900 00 0 7 1 1 4 68 0000000000 LIS Tape Verifica~,ion Lis~,|n9 Schlumberger Alaska Compuf, ing Cen~er 14-JUL-1995 13:29 PAGE: 24 NAME SERV UNIT SERVICE AP1 AP1 AP1 AP1 FILE NUMB NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUMB SAMP ELEM CODE (HEX) FTDT PS3 CPS 500540 0~ 0~0 0~ 0 7 1 1 4 68 0000000~00 N'i'DT PS3 CPS 500540 00 000 00 0 7 1 1 4 68 ~0~0000000 AFFD PS3 CPS 500540 00 000 00 0 7 1 I 4 68 0000~00000 ABFD PS3 CPS 500540 00 0~0 00 0 7 I I 4 68 0000000000 AFND PS3 CPS 500540 00 000 00 0 7 1 1 4 68 0000000000 ABND PS3 CPS 500540 00 000 00 0 7 1 1 4 68 0000000000 SIGC PS3 CU 50~540 00 000 ~0 0 7 1 1 4 68 0000000000 SIBH PS3 CU 500540 00 000 00 0 7 1 1 4 68 000~000~00 MMOF PS3 500540 00 000 ~0 0 7 1 1 4 68 0000000000 TRAT PS3 500540 00 000 0~ 0 7 I 1 4 68 0~0000~00 SDSI PS3 CU 50~540 00 000 00 0 7 1 1 4 68 00~0000000 BACK PS3 CPS 500540 00 000 00 0 7 I 1 4 68 ~00000000~ FBAC PS3 CPS 500540 00 0~0 0~ 0 7 1 1 4 68 0000000000 TCAN PS3 CPS 50~540 0~ 0~0 00 0 7 1 1 4 68 000~000000 TCAF PS3 CPS 500540 00 0~0 00 0 7 1 1 4 68 000~000000 TCND PS3 CPS 50~540 0~ ~0~ 00 0 7 1 I 4 68 0000000000 TCFD PS3 CPS 50~540 0~ 0~0 00 0 7 1 1 4 68 ~000~00000 TSCN PS3 CPS 50~540 00 0~0 ~0 0 7 I 1 4 68 000000000~ TSCF PS3 CPS 50~540 0~ 000 00 0 7 1 I 4 68 0000000000 INND PS3 CPS 500540 00 ~00 00 0 7 I I 4 68 0000000000 INFD PS3 CPS 500540 00 000 ~0 ~ 7 1 1 4 68 ~00~000000 GE PS3 GAPI 500540 00 000 00 0 7 1 I 4 68 0000e00000 TENS PS3 LB 50054e 00 0e0 eO 0 7 1 I 4 68 ~0~0000000 CCL PS3 V 50e54e 00 000 eo 0 7 1 1 4 68 0000~00e00 DATA ** DEPT. 10690.000 SIGM.PS3 41.732 STDT.PS3 66.000 TPHI.PS3 ISHU.PS3 46.375 SFFD.PS3 42.301 SFND.PS3 42.731 SBHF.PS3 SBHN.PS3 45.858 FTDT.PS3 3.898 NTDT.PS3 15.377 AFFD.PS3 ABFD.PS3 100.547 AFND.PS3 414.072 ABND.PS3 442.820 SIGC.PS3 SIBH.PS3 50.220 MMOF.PS3 1.120 TRAT.PS3 1.974 SDSI.PS3 BACK.PS3 174.664 FBAC.PS3 38.348 TCAN.PS3 59955.188 TCAF.PS3 TCND.PS3 15594.164 TCFD.PS3 3591.241 TSCN.PS3 1635.578 TSCF.PS3 INND.PS3 1809.586 INFD.PS3 392.154 GR.PS3 71.188 TENS.PS3 CCL.PS3 0.0~0 DEPT. 10296.0e0 SIGM.PS3 ISHU.PS3 44.688 SFFD.PS3 SBHN.PS3 48.426 FTDT.PS3 ABFD.PS3 95.137 AFND.PS3 SIBH.PS3 56.045 MMOF.PS3 BACK,PS3 182.135 FBAC,PS3 TCND.PS3 14852.525 TCFD.PS3 INND.PS3 1905.253 INFD.PS3 CCL.PS3 0.000 44.087 44 135 3 240 405 726 I 042 41 327 3318 792 385 439 STDT.PS3 66.0~0 TPHI.PS3 SFND.PS3 44.087 SBHF.PS3 NTDT.PS3 13.973 AFFD.PS3 ABND.PS3 432.362 SIGC.PS3 TRAT.PS3 2.034 SDSI.PS3 TCAN.PS3 6918~.125 TCAF.PS3 TSCN.PS3 1440.513 TSCF.PS3 GR.PS3 91.313 TENS.PS3 56.306 41.398 85.007 0.427 0.486 14581.289 418.789 2030.000 65.570 48.095 82.112 0.000 0.579 15987.568 333.624 2400.~00 LIS Tape Verif|cation List~ing Schlumberger Alaska Compuf~ing Cent~er 14-JUL-1995 13:29 PAGE: 25 END OF DATA · ~* FILE TRAILER FILE NAME : EDIT .007 SERVICE : FLIC VERSION : DATE : 95/07/14 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : · *~ TAPE TRAILER SERVICE NAME : EDIT DATE : 95/07/~4 ORIGIN : FLIC TAPE NAME : 95235 CONTINUATION # : 1 PREVIOUS TAPE : COMMENT : ARCO ALASKA INC.~ D,S. 9-37, PRUDHOE BAY~ 50-029-2245~-00 · *~ REEL TRAILER ,~, SERVICE NAME : EDIT DATE : 95/07/~4 ORIGIN : FLIC REEL NAME : 95235 CONTINUATION # : PREVIOUS REEL : COMMENT : ARCO ALASKA INC.~ D.S, 9-37~ PRUDHOE BAY~ 5~-029-2245~-00 · ALASKA COMPUTING CENTER · ....... SCHLUMBERGER COMPANY NAME : ARCO ALASKA, INC. WELL NAME : DS e9-37 FIELD NAME : PRUDHOE BAY BOROUGH : NORTH SLOPE STATE : ALASKA APl NUMBER : 50-029-22451 REFERENCE NO : 94288 LIS Tape Verification LJst|ng Schlumberger Alaska Comput|ng Center 13-JUL-199S 13:14 · *** REEL HEADER SERVICE NAME : EDIT DATE : 95/e7/13 ORIGIN : FLIC REEL NAME : 94288 CONTINUATION # : PREVIOUS REEL : COMMENT : ARCO ALASKA INC., PRUDHOE BAY, DS 09-37, API #50-029-22451-00 **** TAPE HEADER **** SERVICE NAME : EDIT DATE : 95/07/13 ORIGIN : FLIC TAPE NAME : 94288 CONTINUATION # : 1 PREVIOUS TAPE : COMMENT : ARCO ALASKA INC., PRUDHOE BAY, DS 09-37, API #50-~29-22451-00 TAPE HEADER PRUDHOE BAY MWD/MAD LOGS WELL NAME: API NUMBER: OPERATOR: LOGGING COMPANY: TAPE CREATION DATE: JOB DATA D.S. 9-37 500292245Ze0 ARCO ALASKA, INC. SCHLUMBERGER WELL SERVICES 13-JUL-95 BIT RUN ! BIT RUN 2 BIT RUN 3 JOB NUMBER: 94288 LOGGING ENGINEER: JACKSON OPERATOR WITNESS: SURFACE LOCATION SECTION: i TOWNSHIP: i~N RANGE: iSE FNL: FSL: 201 FEL: 4962 FWL: ELEVATION(FT FROM MSL 0) KELLY BUSHING: 46.30 DERRICK FLOOR: 45.30 GROUND LEVEL: 20.70 WELL CASING RECORD OPEN HOLE CASING DRILLERS BIT SIZE (IN) SIZE (IN) DEPTH (FT) lST STRING 9.625 3532.0 2ND STRING 8.500 PAGE: LIS Tape Verification 'Listing Schlumberger AlasEa Computing Center 13-JUL-1995 13:14 3RD STRINg PRODUCTION STRINg REMARKS: WASHDOWN PASS FROM 10300' TO 10805' NO DRILLING PASS WAS LOGGED. THIS TAPE REPLACES THE ONE DISTRIBUTED 7-JUN-95. $ $ · ,-, FILE HEADER *=*, FILE NAME : EDIT .OO1 SERVICE : FLIC VERSION : OO1CO1 DATE : 95/07/13 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : PAGE: FILE HEADER FILE NUMBER: EDITED MERGED MAD Depth shifted and clipped curves; all MAD runs merged using earliest passes. DEPTH INCREMENT: 0.5000 FILE SUMMARY LDWG TOOL CODE START DEPTH STOP DEPTH MAD $ MERGED DATA SOURCE LDWG TOOL CODE 10279.e 10808.0 MAD RUN NO. MAD PASS NO. MERGE TOP MERGE BASE MAD 1 1 10279.~ 10808.0 $ REMARKS: Only one MAD pass wsa logged and it was depth shifted to the TDTP GRCH logged by SCHLUMBERGER 24-MAY-95. This file also contains the Very Enhanced ~RO resisitivity with 2' average that was reprocessed at Geoquest. No MWD data was logged. $ LIS FORMAT DATA LIS Tape Verificat|on Listing Schlumberger Alaska Comput|ng Center 13-JUL-1995 13:14 DATA FORMAT SPECIFICATION RECORD SET TYPE - 64EB *~ TYPE REPR CODE VALUE 1 66 0 2 66 0 3 73 36 4 66 5 66 6 73 7 65 8 68 0.5 9 65 FT 11 66 28 12 68 13 66 0 14 65 FT 15 66 68 16 66 0 66 0 SET TYPE - CHAN ** PAGE: NAME SERV UNIT SERVICE AP1 AP1 AP1 AP1 FILE NUMB NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUMB SAMP ELEM CODE (HEX) DEPT FT Oe eO~ 00 e I 1 1 4 68 0000000000 GR MAD GAPI eO eoe 00 0 I 1 I 4 68 e000000000 ROP MAD FPHR 00 00e ee 0 I I I 4 68 0000000000 RA MAD OHMM ~ 00~ 00 0 I 1 1 4 68 000~0000~0 RP MAD OHMM 00 0e0 Oe 0 I I I 4 68 000000000e DER MAD OHMM ~0 ~00 ~0 0 I I 1 4 68 ~000~0e000 VRA MAD OHMM eO e00 00 0 I I I 4 68 0~0~00000e VRP MAD OHMM 00 eoe oe 0 I 1 1 4 68 000ee00000 GRCH TDTP GAPI 0~ 00~ 00 0 1 I I 4 68 000000e000 DATA DEPT. loSe6.eoo GR.MAD -999.250 ROP.MAD 27.60e RA.MAD RP.MAD -999.250 DER.MAD -999.250 VRA.MAD -999.250 VRP.MAD GRCH.TDTP -999.25~ DEPT. 10276.500 GR.MAD 203.253 ROP.MAD -999.25e RA.MAD RP,MAD -999.25e DER,MAD -999.25e VRA,MAD -999.250 VRP.MAD GRCH.TDTP -999.250 -999.250 -999.250 -999.250 -999.250 END OF DATA LIS Tape Verif|ca%ion L|s~|ng Schlumberger Alaska Compu~,|ng Cenf, er · ,-~ FILE TRAILER FILE NAME : EDIT SERVICE : FLIC VERSION : 001C~1 DATE : 95/07/13 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : · *** FILE HEADER **** FILE NAME : EDIT .002 SERVICE : FLIC VERSION : 001C~1 DATE : 95/07/13 MAX EEC SIZE : le24 FILE TYPE : LO LAST FILE : 13-JUL-1995 13:14 PAGE: FILE HEADER FILE NUMBER: 2 EDITED MAD PASSES Depth sh|~ed and clipped curves; ~or each pass o4 each run in separate ~iles, MAD RUN NUMBER: MAD PASS NUMBER: DEPTH INCREMENT: FILE SUMMARY LDWG TOOL CODE START DEPTH STOP DEPTH MAD 10279.0 10808.0 $ BASELINE CURVE FOR SHIFTS: GRCH.TDT CURVE SHIFT DATA (MEASURED DEPTH) EQUIVALENT UNSHIFTED DEPTH BASELINE DEPTH GR.MAD 88888.0 88886.0 10662.5 10660.5 10640.5 10638.0 10612.5 10610.0 10580.0 10576.0 10568.5 10564.0 10561.0 10555.0 10554.e 10551.5 10520.0 10517.5 10457.0 10455.S 10355.5 10353.0 1~335.5 10336.5 1~3~5.5 103~3.0 100.0 97.5 LIS Tape Verification Listing Schlumberger Alaska Comput|ng Center 13-JUL-1995 13:14 REMARKS: The depth adjustments shown above reflect the MAD GR to the TDTP GRCH logged by SCHLUMBERGER 24-MAY-9S. The MA¥-gs TDTP was logged with magnetic marked line. All other MAD curves were carried with the GR. This file also conta|ns the Very Enhanced QRO resis|tivity with 2' average that was reprocessed at GeoQuest. No MWD data was logged. $ LIS FORMAT DATA PAGE: DATA FORMAT SPECIFICATION RECORD SET TYPE - 64EB ** TYPE REPR CODE VALUE 1 66 2 66 0 3 73 32 4 66 1 5 66 6 73 7 65 8 68 0.5 9 65 FT 11 66 32 12 68 13 66 0 14 65 FT 15 66 68 16 66 0 66 SET TYPE - CHAN ** NAME SERV UNIT SERVICE AP1 AP1 API AP1 FILE NUMB NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUMB SAMP ELEM CODE (HEX) DEPT FT 00 000 00 0 2 1 1 4 68 ~0~0000000 GR MAD GAPI 00 000 Oe ~ 2 1 1 4 68 0000e00000 ROP MAD FPHR 00 000 ~ 0 2 1 1 4 68 0000000000 RA MAD OHMM ~ 000 00 0 2 1 1 4 68 0000000000 RP MAD OHMM ~e 000 eO 0 2 1 1 4 68 0000000000 DER MAD OHMM 00 000 eO 0 2 1 1 4 68 0000000000 VRA MAD OHMM 00 e00 00 0 2 1 1 4 68 00e0000000 VRP MAD OHMM 00 000 00 0 2 1 1 4 68 0000000e00 LIS Tape Verification Listing Schlumberger Alaska Computing Center ** DATA ** DEPT. 10806.000 GR.MAD RP.MAD -999.250 DER.MAD 13-JUL-1995 13:14 -999.250 ROP.MAD 27.600 -999.250 VRA.MAD -999.250 RA.MAD VRP.MAD PAGE: -999.250 -999.250 ** END OF DATA **** FILE TRAILER **** FILE NAME : EDIT .002 SERVICE : FLIC VERSION : 001C~1 DATE : 95/~7/13 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : **** FILE HEADER FILE NAME : EDIT .e~3 SERVICE : FLIC VERSION : ~01C~1 DATE : 95/~7/13 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : FILE HEADER FILE NUMBER 3 RAW MAD Curves and log header data for each pass of each run in separate files, MAD RUN NUMBER: MAD PASS NUMBER: DEPTH INCREMENT: 0.500~ FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH MAD 10279.e $ LOG HEADER DATA DATE LOGGED: SOFTWARE: SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY or REAL-TIME): TD DRILLER (FT): TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): 10808.~ 14-AUG-g4 FAST2.5/V20 MEMORY 10808.0 10279.~ 10796.0 LIS Tape Verli:icat~ion Lis~;ing Schlumberger Alaska Computlng Cen~oer 13-JUL-1995 13:14 BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG) MINIMUM ANGLE: MAXIMUM ANGLE: TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE 19.9 24.2 TOOL NUMBER CDR $ COMPENSATED RESISTIVITY BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLERS CASING DEPTH (FT): BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: MUD CHLORIDES (PPM): FLUID LOSS (C3): RESISTIVITY (OHMM) AT TEMPERATURE (DEGF): MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX ClRCULATIONG TEMPERATURE MUD FILTRATE AT (MT): MUD CAKE AT (MT): NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): EWR FREQUENCY (HZ): REMARKS: ****************************** GR TO BlT: 21.65' RES TO BIT: 11.23' WASH DOWN INTERVAL: 10300' TO 10808' $ LIS FORMAT DATA RGSOS5 8.500 3532.0 1.830 1.910 72.0 72 .el PAGE: ** DATA FORMAT SPECIFICATION RECORD ** ** SET TYPE - 64EB ** TYPE REPR CODE VALUE 1 66 0 2 66 la 3 73 28 LIS Tape Verificat|on Listing Schlumberger Alaska Comput~ing Center ~3-JUL-Z995 Z3:Z4 PAGE: TYPE REPR CODE VALUE 4 66 5 66 6 73 7 65 8 68 0.5 9 65 FT Z! 66 36 ~2 68 13 66 0 14 65 FT 15 66 68 16 66 1 0 66 SET TYPE - CHAN ** NAME SERV UNIT SERVICE API API API API FILE NUMB NUMB SIZE REPR PROCESS ID ORDER # LOg TYPE CLASS MOD NUMB SAMP ELEM CODE (HEX) DEPT FT 00 e00 00 0 3 I I 4 68 0000000000 GR MA1 GAPI 00 000 00 0 3 I I 4 68 00009000~0 ROPE MA1 F/HR 09 909 00 0 3 I I 4 68 0099000090 ROP5 MAZ F/HR 99 099 99 e 3 I I 4 68 eeeeeeeee9 ATR MAZ OHMM 99 99e e9 9 3 I 1 4 68 9900990999 PSR MA1 OHMM 09 999 99 9 3 I I 4 68 999e99e999 DER MA1 OHMM 9e 999 e9 e 3 I I 4 68 9ee~gege99 ** DATA ** DEPT. zgeee.e99 GR.MA1 ATR.MA1 -999.259 PSR.MA1 DEPT. 10279.999 GR.MAZ ATR.MA1 -999.259 PSR.MA1 END OF DATA -999.259 ROPE.MAZ -999.259 DER.MA1 391.949 ROPS.MA1 -999.259 293.253 ROPE.MAZ -999.259 ROPS.MA1 -999.259 DER.MA1 -999.259 27.600 -999.259 **** FILE TRAILER **** FILE NAME : EDIT .993 SERVICE : FLIC VERSION : e91C91 DATE : 95/97/13 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : LIS Tape Verification Listing Sch I umberger A I aska Comput ing Center 13-JUL-1995 13:14 PAGE: *~*- TAPE TRAILER SERVICE NAME : EDIT DATE : 9~/e7/13 ORIGIN : FLIC TAPE NAME : 94288 CONTINUATION # : ! PREVIOUS TAPE : COMMENT : ARCO ALASKA INC., PRUDHOE BAY, DS 09-37, API #50-029-22451-0~ · ~*= REEL TRAILER SERVICE NAME : EDIT DATE : 95/07/13 ORIGIN : FLIC REEL NAME : 94288 CONTINUATION # : PREVIOUS REEL : COMMENT : ARCO ALASKA IN¢.~ PRUDHOE BAY~ DS 09-37~ API #5~-029-224~-0e ALASKA COMPUTING CENTER SCHLUMBERGER · ****************************** COMPANY NAME WELL NAME FIELD NAIdE BOROUGH STATE API NUMBER REFERENCE NO : ARCO ALASKA, INC. : D.S. 9-37 : PRUDHOE BAY : NORTH SLOPE : ALASKA : 5~-~29-22451-~ : 95196 Nasga Oil & Gas Go~s. C;o~[ss~on LIS Tape Verifica~,ion Lisf, ing Schlumberger Alaska Compuf, ing Cent, er Il-JUL-1995 12:91 **** REEL HEADER **** SERVICE NAME : EDIT DATE : 95/97/11 ORIGIN : FLIC REEL NAME : 95196 CONTINUATION # : PREVIOUS REEL : COMMENT : ARCO ALASKA INC, DS 9-37, PRUDHOE BAY, 59-929-22451-99 · ~=~ TAPE HEADER SERVICE NAME : EDIT DATE : 95/97/11 ORIGIN : FLIC TAPE NAME : 95196 CONTINUATION # : 1 PREVIOUS TAPE : COMMENT : ARCO ALASKA INC, DS 9-37, PRUDHOE BAY, 59-929-22451-99 TAPE HEADER PRUDHOE BAY CASED HOLE WIRELINE LOGS WELL NAME: D,S. g-37 API NUMBER: 509292245199 OPERATOR: ARCO ALASKA, INC. LOGGING COMPANY: SCHLUMBERGER WELL SERVICES TAPE CREATION DATE: 11-JUL-95 JOB NUMBER: 95196 LOGGING ENGINEER: D.WARNER OPERATOR WITNESS: S.WHIDDON SURFACE LOCATION SECTION: TOWNSHIP: RANGE: 1SE FNL: FSL: 291 FEL: 4962 FWL: ELEVATION(FT FROM MSL KELLY BUSHING: 46.39 DERRICK FLOOR: 45.39 GROUND LEVEL: 20.79 WELL CASING RECORD OPEN HOLE CASING DRILLERS CASING BIT SIZE (IN) SIZE (IN) DEPTH (FT) WEIGHT (LB/FT) 1ST STRING 9.625 3539.9 2ND STRING 5.509 19894.9 3RD STRING 3.599 8992.9 PRODUCTION STRING 2.875 9926.9 CURVE SHIFT DATA - ALL PASSES TO STANDARD(MEASURED DEPTH) 47.99 17.99 7.99 6.59 PAGE: LIS Tape Verification Listing Schlumberger Alaska Computing Center BASELINE CURVE FOR SHIFTS LDWG TOOL CODE: LDWG CURVE CODE: RUN NUMBER: PASS NUMBER: DATE LOGGED: LOGGING COMPANY: BASELINE DEPTH ll-JUL-1995 12:01 EQUIVALENT UNSHIFTED DEPTH $ REMARKS: No depth adjustments were made because this TDTP logging run has been established by ARCO as the Primary Depth Control log for this well. A magnetic marked wireline was used with this survey. $ $ PAGE: · *** FILE HEADER FILE NAME : EDIT .OO1 SERVICE : FLIC VERSION : OOICO1 DATE : MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : FILE HEADER FILE NUMBER: 1 EDITED CURVES Depth shifted and clipped curves for each pass in separate files. PASS NUMBER: 1 DEPTH INCREMENT: 0.5~00 FILE SUMMARY LDWG TOOL CODE START DEPTH STOP DEPTH GRCH 10677.0 1~297.0 TDTP 107~2.0 10297.0 $ CURVE SHIFT DATA - PASS TO PASS(MEASURED DEPTH) BASELINE CURVE FOR SHIFTS LDWG CURVE CODE: PASS NUMBER: EQUIVALENT UNSHIFTED DEPTH BASELINE DEPTH LIS Tape Verification Listing Schlumberger Alaska Computing Center ll-JUL-199~ 12:01 REMARKS: This file contains TDTP Pass #1. shifts were applied to this data. $ LIS FORMAT DATA No pass %0 pass PAGE: ** DATA FORMAT SPECIFICATION RECORD SET TYPE - 64EB ** TYPE REPR CODE VALUE 1 66 0 2 66 3 73 92 4 66 5 66 6 73 7 65 8 68 0.~ 9 65 FT 12 68 13 66 0 14 65 FT 15 66 68 16 66 0 66 ** SET TYPE - CHAN ** NAME SERV UNIT SERVICE API API API API FILE NUMB NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUMB SAMP ELEM CODE (HEX) DEPT FT 501039 00 ~00 00 ~ 1 I 1 4 68 ~000~00~0 SIGM TDTP CU 501039 00 00~ 00 0 1 I I 4 68 0~00~00000 TPHI TDTP PU-S 5~1039 00 000 00 9 I 1 I 4 68 9999999990 SBHF TDTP CU 591939 99 999 99 9 I 1 1 4 68 9999909999 SBHN TDTP CU 501039 00 000 09 9 1 1 1 4 68 9~00090990 SIGC TDTP CU 591039 ~9 909 90 9 1 1 1 4 68 9099999999 SIBH TDTP CU 591939 99 900 09 0 1 1 1 4 68 9099999999 TRAT TDTP 591939 99 009 99 9 1 1 I 4 68 9999999999 LCgl TDTP 591939 99 909 90 9 1 1 1 4 68 9909999990 SDSI TDTP CU 591039 99 999 90 9 1 1 1 4 68 00999009~0 BACK TDTP CPS 591039 99 999 90 0 1 ! 1 4 68 0990999099 FBAC TDTP CPS 591939 99 999 99 9 1 I 1 4 68 9999999990 TCAN TDTP CPS 591939 99 999 99 9 1 1 1 4 68 9999999999 TCAF TDTP CPS 501039 90 990 09 9 1 1 1 4 68 0009999990 TCND TDTP CPS 591039 99 900 99 9 1 1 1 4 68 00~0009090 TCFD TDTP CPS 591039 99 900 09 0 1 1 1 4 68 0009900900 TSCN TDTP CPS 591039 90 990 00 9 1 1 1 4 68 0000900000 LIS Tape Verit~ication List~ing Schlumberger Alaska Computing Center Il-JUL-1995 12:01 PAGE: NAME SERV UNIT SERVICE AP1 AP1 AP1 AP1 FILE NUMB NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUMB SAMP ELEM CODE (HEX) TSCF TDTP CPS 501039 INND TDTP CPS 501039 INFD TDTP CPS 501~39 GRCH TDTP GAPI 501039 TENS TDTP LB 5~1039 CCL TDTP V 501039 ~0 000 00 0 1 I I 4 68 0000000~00 ~0 000 00 0 1 I I 4 68 0000000000 ~0 ~00 00 0 1 I I 4 68 00~0~00000 ~0 000 00 0 1 I I 4 68 00000~0000 ~0 000 00 0 I 1 1 4 68 000000~000 00 000 ~0 0 I 1 I 4 68 0000000000 DATA DEPT. 107~2.000 SBHN.TDTP 46.615 LCO1.TDTP 3.523 TCAN.TDTP 23179.227 TSCN.TDTP 22~7,084 GRCH.TDTP -999.25~ DEPT. 1~297.~00 SBHN.TDTP 47.322 LCO1.TDTP 4.225 TCAN.TDTP 25442.711 TSCN.TDTP 1360.092 GRCH.TDTP 1~9.00~ SIGM.TDTP 38.727 TPHI.TDTP 51.e69 SBHF.TDTP SIGC.TDTP 0.706 SIBH.TDTP 51.937 TRAT.TDTP SDSI.TDTP 0.941 BACK.TDTP 72.656 FBAC.TDTP TCAF.TDTP 6304.742 TCND.TDTP 18137.934 TCFD.TDTP TSCF.TDTP 626.514 INND.TDTP 1500.876 INFD.TDTP TENS.TDTP 3285.0~0 CCL.TDTP 0.~00 SIGM.TDTP 44.835 TPHI.TDTP 58.038 SBHF.TDTP SIGC.TDTP 0.266 SIBH.TDTP 53.541 TRAT.TDTP SDSI.TDTP 1.181 BACK.TDTP 101.105 FBAC.TDTP TCAF.TDTP 5837.362 TCND.TDTP 14918.$55 TCFD.TDTP TSCF.TDTP 321.943 INND.TDTP 1377.736 INFD.TDTP TENS.TDTP 2885.000 CCL.TDTP ~.000 42.428 1.864 24.750 445~.532 372.584 45.602 1.938 23.557 3284.220 326.959 END OF DATA **** FILE TRAILER **** FILE NAME : EDIT' .~01 SERVICE : FLIC VERSION : 001C01 DATE : 95/~7/~1 MAX REC SIZE : 1~24 FILE TYPE : LO LAST FILE : **** FILE HEADER **** FILE NAME : EDIT .002 SERVICE : FLIC VERSION : 0~1C01 DATE : 95/07/11 MAX REC SIZE : ~024 FILE TYPE : LO LAST FILE : LIS Tape Verit:ication Listing Schlumberger Alaska Comput~ing Center ll-JUL-199S 12:01 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 10677.0 10297.0 TDTP 10702.0 10297.0 $ CURVE SHIFT DATA - PASS TO PASS(MEASURED DEPTH) BASELINE CURVE FOR SHIFTS LDWG CURVE CODE: GRCH PASS NUMBER: EQUIVALENT UNSHIFTED DEPTH BASELINE DEPTH GRCH TDTP 88888.0 10693.5 10685.5 10681.5 10669 5 10665 5 1~661 5 1~659 5 10657 5 1~653 5 10649.5 1~645.5 1~641.5 10637.5 1~617.5 10613.5 10609.5 10589.5 10585.5 1~581.5 10565.5 1~565.5 10561 5 1~559 5 10557 5 10555 5 10541 5 10537 5 10533 5 10529.5 10525.5 10523.5 10519.5 88888.5 10660.0 10564.0 10560.5 10556.0 10524.0 10520.5 88888.5 10694.0 10686.0 10681.5 10669.5 10665.0 10661.5 10658.0 1~654.5 10650.0 10646.0 10641.5 10638.0 10618.0 10614.5 10610.0 10590.0 10586.5 10582.0 10566.9 19562.5 19558.0 19542.0 19537.5 19534.0 10529.5 19526.0 PAGE: LIS Tape Verification Listing Schlumberger Alaska Computing Center 11-JUL-1995 12:01 PAGE: 10515.5 1~509.5 105~5.5 10501.5 10485.5 10481.5 10477.5 10473.5 10469.5 10465.5 10451.5 1~449.5 10447.5 1~445.5 10443.5 10441.5 10437.5 10433.5 10429.5 10425.5 1~421.5 1~415.5 1~413.5 1~411,5 104~9.5 1B407.5 104~3.5 103~.5 10397.5 10393.5 10377.5 1~373.5 1~371 5 10369 5 10333 5 1~331 5 1~329 5 10327 5 10323 $ 10319.5 $ 10516.0 10452.0 10447.5 10444.0 10416.0 104~8.0 1B4~3.~ 10399.~ 10370.5 10330.5 10327.~ 10323.0 10318.5 99.0 10510.0 10506.5 10502.0 10486.0 10481.5 10478.0 10474.0 10469.5 10466.0 10450.0 1~446.5 1~442.0 10437.5 10433.0 10428.5 le425.0 10420.5 10412.5 10409.0 10401.0 10396.5 10393.0 10377.0 10374.0 10365.5 10332.5 10327.5 98.0 REMARKS: This file contains TDTP Pass #2. The depth shifts shown above relect GRCH pass #2 to GRCH pass ~1 and SIGM pass #2 to SIGM pass #1. $ LIS FORMAT DATA LIS Tape Verification Listing Schlumberger Alaska Computing Center Il-JUL-1995 12:01 DATA FORMAT SPECIFICATION RECORD SET TYPE - 64EB ~* TYPE REPR CODE VALUE 1 66 0 2 66 0 3 73 92 4 66 5 66 6 73 7 65 8 68 0.5 9 65 FT 11 66 11 12 68 13 66 0 14 65 FT 15 66 68 16 66 0 66 PAGE: ** SET TYPE - CHAN ** NAME SERV UNIT SERVICE AP1 AP1 AP1 AP1 FILE NUMB NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUMB SAMP ELEM CODE (HEX) DEPT FT 501039 00 0~0 0~ 0 2 1 1 4 68 0000000000 SIGM TDTP CU 501039 ~0 0~0 00 0 2 1 I 4 68 000~000000 TPHI TDTP PU-S 5~1039 ~0 0~0 0~ 0 2 1 1 4 68 0000000000 SBHF TDTP CU 501039 00 00~ 00 0 2 1 1 4 68 0000000000 SBHN TDTP CU 501039 00 000 ~0 0 2 1 1 4 68 0000000000 SIGC TDTP CU 501039 00 000 ~ 0 2 1 1 4 68 ~000000000 SIBH TDTP CU 501039 00 000 00 0 2 1 1 4 68 000000000~ TRAT TDTP 501039 ~ 000 00 0 2 1 1 4 68 00000~00~0 LC01 TDTP 501039 00 0~0 ~0 0 2 1 1 4 68 ~00~000000 SDSI TDTP CU 501039 00 000 0~ 0 2 1 1 4 68 0000000000 BACK TDTP CPS 5~1039 00 000 00 0 2 1 1 4 68 0000000000 FBAC TDTP CPS 501039 ~0 000 00 0 2 1 1 4 68 ~000000000 TCAN TDTP CPS 5~1~39 00 0~0 00 0 2 1 1 4 68 0000000000 TCAF TDTP CPS 501039 00 000 00 0 2 1 1 4 68 0000000000 TCND TDTP CPS 501039 0~ 0~0 00 0 2 1 1 4 68 0000000000 TCFD TDTP CPS 501039 0~ 000 00 ~ 2 1 1 4 68 ~000000000 TSCN TDTP CPS 501039 ~ 000 00 0 2 1 1 4 68 0000000000 TSCF TDTP CPS 501039 00 0~0 00 0 2 1 1 4 68 0000000000 INND TDTP CPS 501039 00 0~0 00 0 2 1 1 4 68 0000000000 INFD TDTP CPS 5~1039 00 000 00 0 2 1 1 4 68 0000000000 GRCH TDTP GAPI 501039 00 000 00 0 2 1 1 4 68 0000000000 TENS TDTP LB 501039 Oe 000 00 0 2 1 1 4 68 00000000~0 CCL TDTP V 501039 00 0~0 00 0 2 1 1 4 68 0000000000 LIS Tape Verification Listing Schlumberger Alaska Computing Center ** DATA ii-JUL-1995 12:01 DEPT. ~0702.50~ SIGM.TDTP 38.374 TPHI.TDTP 49.83~ SBHN.TDTP 47.993 SIGC.TDTP ~,045 SIBH,TDTP 55.062 LCO1.TDTP 3.405 SDSI.TDTP 0.942 BACK,TDTP 122,870 TCAN.TDTP 2~908.555 TCAF,TDTP 6~08.660 TCND,TDTP ~7457.~13 TSCN.TDTP 2109.973 TSCF.TDTP 619.691 INND.TDTP 1450.~51 GRCH.TDTP -999.250 TENS.TDTP 3220,~00 CCL.TDTP 0.000 DEPT. 10295.000 SIGM.TDTP 45.64~ TPHI.TDTP SBHN.TDTP 52.242 SIGC.TDTP 0.000 SIBH.TDTP LCO1.TDTP 4.~60 SDSI.TDTP ~.~69 BACK.TDTP TCAN.TDTP 25880.62~ TCAF.TDTP 5937.67~ TCND.TDTP TSCN.TDTP 1310.639 TSCF.TDTP 315.025 INND.TDTP GRCH.TDTP -999.250 TENS.TDTP 2930.000 CCL.TDTP 65.068 64.702 ~43.509 14891.354 1438.085 0.000 SBHF.'TDTP TRAT.TDTP FBAC.'T'DTP TCFD.TDTP INFD.TDTP SBHF.TDTP TRAT.TDTP FBAC.TDTP TCFD.TDTP INFD.TDTP PAGE: 45.720 1.797 30.633 4323.226 359.681 42.660 1.890 32.316 3316.681 332.529 ** END OF DATA **** FILE TRAILER **** FILE NAME : EDIT .002 SERVICE : FLIC VERSION : eelCOl DATE : 95/e7/ii MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : **** FILE HEADER **** FILE NAME : EDIT .003 SERVICE : FLIC VERSION : 0~1C01 DATE : 95/~7/11 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : FILE HEADER FILE NUMBER: EDITED CURVES Depth shifted and PASS NUMBER: DEPTH INCREMENT: FILE SUMMARY LDWG TOOL CODE GRCH TDTP 3 clipped 3 0.5000 curves START DEPTH 10677.0 107e2.0 for each pass STOP DEPTH 10297.0 le297.0 in separate files. LIS Tape Verification Listing Sch I umberger A I aska Comput i ng Center ll-JUL-i995 12:01 $ CURVE SHIFT DATA - PASS TO PASS(MEASURED DEPTH) BASELINE CURVE FOR SHIFTS LDWG CURVE CODE: GRCH PASS NUMBER: BASELINE DEPTH ORCH EQUIVALENT UNSHIFTED DEPTH TDTP 88888.~ 88888.5 le693.5 1~689.5 i0685.5 10677.5 10673.5 1~665.5 1~661.5 10657.5 10653.5 10651.5 10652.~ 1~649.5 10647.5 1~648.0 10645.5 10643.5 10643.5 10641.5 1~637.5 10629.5 10625.5 10621.5 1~619.5 10619.5 1~615.5 10616.0 106~5.5 106~1.5 10599.5 106~0.0 1~595.5 1~595.5 1~593.5 1~591.5 1~591.5 10559.5 1~587.5 10587.0 10583.5 10583.5 1~567.5 1~S67.5 10565.5 10563.5 10564.0 leS61.S 10537.5 i0533,5 1~529,5 10525.5 1~521.5 10519.5 1~52~.0 10517.5 1~515.5 10516.5 10513.5 88888.5 10694.0 le690.0 le685 5 10677 S 10673 0 10665 0 10660 0 1~658 0 1~653 5 10649.5 1~646.~ 10641.5 10638.0 10630.0 10625.5 1~622.0 le6e6.o 10593.5 10590.0 10566.0 1~561.5 10558.0 10538.0 1~534.5 10530.0 10526.0 10522.5 10514.0 PAGE: LIS Tape Ver|fication L|st|ng Schlumberger Alaska Computing Center ll-JUL-199S 12:0~ PAGE: 10 10509.5 10487.5 10483.5 10481.5 10479.5 10477,5 10475,5 10473,5 10469.5 10465.5 1~451.5 10449.5 10447.5 10445.5 10443.5 10441.5 10435.5 10433.5 10431.5 10429.5 10417.5 10415.5 10413,5 10411.5 10409.5 10407.5 10405 5 10403 5 10401 5 10397 5 10387 5 10377 5 10373 5 10371 5 10369.5 10357.5 10353.5 10349.5 10345.5 10331,5 10329.5 10327,5 10325.5 10313.5 $ 10510.5 10488.5 10484.0 10482.5 10480.0 10478.0 10476.5 10474.5 10471,0 10466.5 10452.5 10450.5 10448.0 10445.5 10444.5 10441.0 10436.5 10433.0 10432.0 1~428.5 10416.5 le416.0 10412.~ 10411.0 10409.5 10405.0 1~4~5.5 1~4~3.~ 10401.0 10397.5 1~387.~ 10377.5 10374.5 10371.5 10369.5 10357.5 10353.0 10349.0 10345.5 10331.5 10329.5 10325.0 10324.0 10313.5 100.5 10~.~ REMARKS: This file contains TDTP Pass #3. shown above relect GRCH pass #3 SIGM pass #3 to SIGM pass #1. $ LIS FORMAT DATA The depth shifts GRCH pass #1 and LIS Tape Verification Listing Schlumberger Alaska Computing Center Il-JUL-1995 12:01 PAGE: 11 DATA FORMAT SPECIFICATION RECORD SET TYPE - 64EB ,= TYPE REPR CODE VALUE 1 66 0 2 66 0 3 73 92 4 66 5 66 6 73 7 65 8 68 0.5 9 65 FT ll 66 12 68 13 66 0 14 65 FT 15 66 68 16 66 0 66 SET TYPE - CHAN ** NAME SEEV UNIT SERVICE AP1 AP1 AP1 AP1 FILE NUMB NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUMB SAMP ELEM CODE (HEX) DEPT FT 501¢39 ~0 000 00 0 3 1 1 4 68 00~0000000 SIGM TDTP CU 501039 00 ~00 00 0 3 1 1 4 68 0000000000 TPHI TDTP PU-S 501039 00 ee~ eo 0 3 1 1 4 68 00~0~000~ SBHF TDTP CU 501039 00 000 00 0 3 1 1 4 68 ~0e0000000 SBHN TDTP CU 501059 00 000 00 0 3 1 1 4 68 00~0e00000 SIGC TDTP CU 501~39 ~0 00~ ~ 0 3 1 1 4 68 00000~0000 SIBH TDTP CU 501~39 ~0 00e 00 ~ 3 1 1 4 68 0~000e000 TEAT TDTP 5e1039 00 000 ~0 0 3 1 1 4 68 00~00000e0 LC01 TDTP 5e1~39 eO 000 00 0 3 1 1 4 68 00000~0000 SDSI TDTP CU 501~39 00 ~00 00 0 3 1 1 4 68 0000000000 BACK TDTP CPS 501039 00 00e eO 0 3 1 1 4 68 00~0000000 FBAC TDTP CPS 501039 00 000 00 0 3 1 1 4 68 0000000000 TCAN TDTP CPS 501039 00 000 ¢0 0 3 1 1 4 68 00e00000~0 TCAF TDTP CPS 501039 00 00e 00 0 3 1 1 4 68 0000000000 TCND TDTP CPS 501039 ~0 000 ~0 0 3 1 1 4 68 0000000000 TCFD TDTP CPS 501039 ~0 000 00 0 3 I 1 4 68 00~0000000 TSCN TDTP CPS 501039 00 000 00 0 3 1 1 4 68 000000~000 TSCF TDTP CPS 5~1039 00 000 00 0 3 1 1 4 68 0000000000 INND TDTP CPS 501039 00 000 00 0 3 1 1 4 68 0000000000 INFD TDTP CPS 501039 00 000 00 0 3 1 1 4 68 0000000~00 GRCH TDTP GAPI 501039 00 000 00 0 3 1 1 4 68 0000000000 TENS TDTP LB 501039 ~0 000 00 0 3 1 1 4 68 000000e009 CCL TDTP V 501039 09 000 09 0 3 1 1 4 68 0900090909 LIS Tape Verification Listing Schlumberger Alaska Computing Center Il-JUL-1995 12:01 PAGE: 12 ** DATA ** DEPT. 10702.5~0 SIGM.TDTP SBHN.TDTP 46.147 SIGC.TDTP LCO1.TDTP 3.296 SDSI.TDTP TCAN,TDTP 22540.395 TCAF.TDTP TSCN.TDTP 2202,975 TSCF.TDTP GRCH,TDTP -999.250 TENS.TDTP DEPT. SBHN.TDTP LCO1.TDTP TCAN.TDTP TSCN.TDTP GRCH.TDTP 10297 500 49 182 4 377 26713 887 1372 650 -999~250 35.493 TPHI.TDTP 1.805 SIBH.TDTP 0.925 BACK.TDTP 6434.952 TCND.TDTP 668.327 INND.TDTP 3470.000 CCL.TDTP 44.119 50.875 154.846 17947.570 1438.532 0.000 SIGM.TDTP 45.381 TPHI.TDTP 65.097 SIGC.TDTP ~.0~0 SIBH.TDTP 57.760 SDSI.TDTP 1.226 BACK.TDTP 164.758 TCAF.TDTP 6047.214 TCND.TDTP 15154.824 TSCF.TDTP 313.598 INND,TDTP 1393.22~ TENS.TDTP 3215.000 CCL.TDTP 0.00~ SBHF.TDTP TRAT.TDTP FBAC.TDTP TCFD.TDTP INFD.TDTP SBHF.TDTP TRAT.'rDTP FBAC.TDTP TCFD.TDTP INFD.TDTP 45.593 1.784 36.034 4562.222 365.258 44.472 1.992 34.360 3369.140 336.268 ** END OF DATA ** **** FILE TRAILER **** FILE NAME : EDIT .003 SERVICE : FLIC VERSION : ~1C~1 DATE : 95/07/11 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : **** FILE HEADER **** FILE NAME : EDIT- .004 SERVICE : FLIC VERSION : 0~1C~1 DATE : 95/~7/11 MAX REC SIZE : 1~24 FILE TYPE : LO LAST FILE : FILE HEADER FILE NUMBER: EDITED CURVES Depth shifted and PASS NUMBER: DEPTH INCREMENT: FILE SUMMARY LDWG TOOL CODE 4 clipped 4 0.5000 curves START DEPTH for each pass STOP DEPTH in separate files. LIS Tape Vet|fica%ion L|s%ing Schlumberger Alaska Compu%ing Cen%er Il-JUL-1995 12:01 PAGE: 13 [0360.0 [0360.0 GRCH 10677.0 TDTP 107~2.0 $ CURVE SHIFT DATA - PASS TO PASS(MEASURED DEPTH) BASELINE CURVE FOR SHIFTS LDWG CURVE CODE: GRCH PASS NUMBER: 1 EQUIVALENT UNSHIFTED DEPTH BASELINE DEPTH GRCH TDTP 88888.0 88887.5 88888.0 10693.5 10693.5 10685.5 10685.5 10681.5 10681.0 10677.5 10677.5 10669.5 10669.5 10665.5 10665.0 10661.5 le661.5 10659.5 10657.5 1~653.5 1~649.5 1~635.5 1~631.5 le603.5 10599.5 10597.5 10595.5 10593.5 10591.5 10589.5 le587.5 10585.5 10583.5 10581.5 10577.5 10575.5 10569.5 1~565.5 10561.5 10557 5 10553 5 10545 5 10541 5 10537 5 10533 5 10531 5 10529.5 10527.5 1~525.5 10523.5 10521.5 10659.0 10635.0 10631.5 106~3.5 10599.0 le595.5 10591.5 le587.0 10583.5 10531.5 10527.0 10523.5 10657.0 10652.5 le649.5 10597.5 1~593.0 le589.0 le585.5 10581.0 10577.0 le575.5 10569.0 10565.0 10561.5 le557.5 10553.0 10545.0 10541.5 10537.0 1~533.5 10529.0 10525.5 10521.0 LIS Tape Verifica%ion Lis%lng Schlumberger Alaska Computing Cen%er ll-JUL-lgg5 12:01 10S01.5 10497.S 10485.5 1~477.S 1~465.S 1~461.5 10457.S 1~4S3.5 104S1.5 10449.5 10447.5 1~445.$ 10443.5 10439.5 10437.5 10435.5 1~433.5 1~431.5 10429.5 10427.5 10423.5 10407.5 10403.5 1~399.5 1~353.5 $ 1~451.5 10447.0 1~443.5 10439.0 1~435.5 1~431.0 1~427.0 10423.5 10407.5 10402.0 10398.0 10381.0 97.5 10513.0 10S09.5 10S05.5 10501.0 10497.5 10485.S 10481.0 10477.~ 10465.S 10461.0 104S7.5 104S3.5 10448.5 1~445.0 10437.0 10432.5 10428.0 98.5 REMARKS: THIS FILE CONTAINS BORAX PASS #1 OF THE TDTP. THE DEPTH CORRECTIONS SHOWN ABOVE REFLECT BORAX PASS #1 GRCH TO BASE PASS #1 GRCH AND BORAX PASS #1 SIGM TO BASE PASS #1 SIGM'.' ALL OTHER TDTP CURVES WERE CARRIED WITH THE SIGM SHIFTS. $ LIS FORMAT DATA PAOE: 14 DATA FORMAT SPECIFICATION RECORD ** SET TYPE - 64EB ** TYPE REPR CODE VALUE 1 66 0 2 66 0 3 73 92 4 66 1 S 66 LIS Tape Verification Listing Schlumberger Alaska Computing Center Il-JUL-1995 12:01 PA~E: 15 TYPE REPR CODE VALUE 6 73 7 65 8 68 0,5 9 65 FT 12 68 13 66 0 14 65 FT 15 66 68 16 66 1 0 66 I ** SET TYPE - CHAN ** NAME SERV UNIT SERVICE AP1 AP1 AP1 AP1 FILE NUMB NUMB SIZE REPR PROCESS ID ORDER # LOg TYPE CLASS MOD NUMB SAMP ELEM CODE (HEX) DEPT FT 501039 00 000 00 0 4 I 1 4 68 09e0000~00 SIGM TDTP CU 501039 00 000 00 0 4 1 1 4 68 e900000000 TPHI TDTP PU-S 501039 00 000 00 0 4 1 1 4 68 0000000000 SBHF TDTP CU 5~1039 ~0 000 00 0 4 1 1 4 68 00000~0090 SBHN TDTP CU 501039 0~ ~00 00 0 4 1 1 4 68 ~00~00000 SIGC TDTP CU 501039 00 ~00 00 ~ 4 1 I 4 68 00~0~0000 SIBH TDTP CU 591039 00 000 00 0 4 1 1 4 68 ~00~00000 TRAT TDTP 50~039 00 ~00 00 0 4 1 1 4 68 00~0~00~00 LCO1TDTP 501039 ~ ~00 ~0 0 4 1 1 4 68 0000~00000 SDSI TDTP CU 501039 00 000 0~ 0 4 1 1 4 68 ~000~900~0 BACK TDTP CPS 501039 00 ~0 00 0 4 I 1 4 68 000~0~00 FBAC TDTP CPS 5~1039 00 000 ~0 0 4 I 1 4 68 ~000000000 TCAN TDTP CPS 501039 00 ~00 ~0 0 4 I ~ 4 68 0000000000 TCAF TDTP CPS 50~039 00 900 00 0 4 1 ~ 4 68 00~00000 TCND TDTP CPS 50103'9 ~ 000 00 0 4 I 1 4 68 00~00~0000 TCFD TDTP CPS 50~039 00 ~00 ~0 0 4 1 1 4 68 ~0000~0000 TSCN TDTP CPS 501039 0~ 0~0 ~0 0 4 1 1 4 68 ~0~9000~00 TSCF TDTP CPS 501039 00 000 00 0 4 1 1 4 68 00000~0000 INND TDTP CPS 501039 00 000 00 0 4 1 1 4 68 0000000000 INFD TDTP CPS 501039 00 000 00 0 4 1 1 4 68 00~00~000 GRCH TDTP GAPI 5~1039 0~ 000 00 0 4 I 1 4 68 0~0~00000 TENS TDTP LB 50~039 00 0~0 00 0 4 1 1 4 68 0000000000 CCL TDTP V 501039 0~ 000 0~ 0 4 1 1 4 68 ~0~00~0000 DATA DEPT. 10702.000 SBHNiTDTP 48.468 LCO1.TDTP 3.208 TCAN.TDTP 22972.395 TSCN.TDTP 2213.~45 GRCH.TDTP -999.250 SIGM TDTP SIGC TDTP SDSI TDTP TCAF TDTP TSCF TDTP TENS TDTP 35 639 1 941 0 854 6592 ~07 689 956 3185 TPHI.TDTP 46.616 SBHF.TDTP SIBH.TDTP 56.140 TRAT.TDTP BACK.TDTP ~46.244 FBAC.TDTP TCND.TDTP 18154.48~ TCFD.TDTP INND.TDTP 1453.564 INFD.TDTP CCL.TDTP 0.000 40.591 1,754 35.540 4485.229 368.863 LIS Tape Verification Listing Schlumberger Alaska Computing Center Il-JUL-1995 12:01 PAGE: 16 DEPT. 10357.500 SIGM.TDTP -999.250 TPHI.TDTP -999.250 SBHN.TDTP -999.250 SIGC.TDTP -999.250 SIBH.TDTP -999.250 LCO1.TDTP -999.250 SDSI.TDTP -999.250 BACK.TDTP -999.250 TCAN.TDTP -999.250 TCAF.TDTP -999.250 TCND.TDTP -999.250 TSCN.TDTP -999.250 TSCF.TDTP -999.250 INND.TDTP -999.250 GRCH.TDTP 54,063 TENS,TDTP -999.250 CCL.TDTP -999.250 SBHF.TDTP TRAT.TDTP FBAC.TDTP TCFD.TDTP INFD.TDTP -999.250 -999.250 -999.250 -999.250 -999.259 END OF DATA **** FILE TRAILER **** FILE NAME : EDIT .994 SERVICE : FLIC VERSION : 001C01 DATE : 95/07/11 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : **** FILE HEADER FILE NAME : EDIT .005 SERVICE : FLIC VERSION : 001C01 DATE : 95/07/11 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : FILE HEADER FILE NUMBER: 5 EDITED CURVES Depth shifted and clipped curves for each pass in separate files. Pass NUMBER: 5 DEPTH INCREMENT: 0.5000 FILE SUMMARY LDWG TOOL CODE START DEPTH STOP DEPTH GRCH 10677.0 10360.0 TDTP 10702.0 19360.0 $ CURVE SHIFT DATA - PASS TO PASS(MEASURED DEPTH) BASELINE CURVE FOR SHIFTS LDWG CURVE CODE: GRCH PASS NUMBER: E~UIVALENT UNSHIFTED DEPTH, LIS Tape Ver|ficat|on L|sting Schlumberger Alaska Computing Center ~l-JUL-1995 12:01 PAGE: 17 BASELINE DEPTH 88888,0 10693.5 10677.5 10673.5 10669.5 10665.5 10661.5 10659.5 10657.5 10653.5 10651.5 10649.5 10645.5 10641,5 10621,5 10617.5 10613.5 10609,5 1~563,5 10559,5 10555.5 10551 5 1~543 5 10539 5 10535 5 10533 5 10529 5 10525,5 10521.5 10517.5 10513,5 10509,5 10465.5 10461,5 10457,5 10455.5 10453.5 10451,5 10449.5 10445.5 1~441.5 10437.5 10433,5 1~431,5 10429 5 10427 5 10419 5 1~415 5 10413 5 10411 5 10409 5 10407 5 10405 5 GRCH 88887.5 10659.0 10651.5 1~563.5 1~560.0 1~555.0 10551.5 10543.5 10540.0 1~535.5 1~455.5 10451.0 1~431.0 10427.5 1~419,5 10416,0 10407.5 TDTP 88888.0 10693.5 10677.5 10674.0 10669.5 10665.0 10661.5 10657.0 10653.5 10649.0 10645.0 10641.5 10621.5 10618.0 10614.0 10609.5 10533.5 10529.0 10526.~ 10521.5 10517.0 10513.0 10509.5 10465.5 10461.0 1~457.5 10453.5 1~448.5 10444.5 10441.0 10437.0 10432.5 10428.0 10412.0 10408.5 10404.0 LIS Tape Verification List|ng Schlumberger Alaska Comput|ng Center 11-JUL-~99~ ~2:0~ 10403.5 1B402.5 10397.5 10396.0 10393.5 10392.5 10389.5 10388.5 10385.5 10384.0 10381.5 10380.~ 10377.5 10376.5 1~0.0 99.0 99.0 $ REMARKS: THIS FILE CONTAINS BORAX PASS #2 OF THE TDTP. THE DEPTH CORRECTIONS SHOWN ABOVE REFLECT BORAX PASS #2 GRCH TO BASE PASS #1 GRCH AND BORAX PASS #2 SIGM TO BASE PASS #1 SIGM. ALL OTHER TDTP CURVES WERE CARRIED WITH THE SIGM SHIFTS, $ LIS FORMAT DATA PAGE: 18 DATA FORMAT SPECIFICATION RECORD SET TYPE - 64EB ** TYPE REPR CODE VALUE ! 66 0 2 66 0 3 73 88 4 66 5 66 6 73 7 65 8 68 0.5 9 65 FT 11 66 12 68 13 66 0 14 65 FT 15 66 68 16 66 0 66 SET TYPE - CHAN ** NAME SERV UNIT SERVICE AP1 AP1 API API FILE NUMB NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUMB SAMP ELEM CODE (HEX) DEPT FT 501039 00 000 00 0 5 1 1 4 68 000~000000 SIGM TDTP CU 501039 00 000 eO 0 5 1 1 4 68 0000000000 TPHI TDTP PU-S 5010@9 00 000 00 0 5 I 1 4 68 0000000000 SBHF TDTP CU 501039 00 000 00 0 5 1 1 4 68 0000000000 LIS Tape Verification Listing Il-JUL-1995 12:01 Schlumberger Alaska Computing Center PAGE: 19 NAME SERV UNIT SERVICE AP1 AP1 AP1 AP1 FILE NUMB NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUMB SAMP ELEM CODE (HEX) SBHN TDTP CU 501039 00 000 00 0 5 1 1 4 68 0000000000 SIGC TDTP CU 501039 00 000 00 0 5 1 1 4 68 0000000000 SIBH TDTP CU 501039 00 000 00 0 5 1 1 4 68 0000000000 TRAT TDTP 501039 00 000 00 0 5 1 1 4 68 0000000000 SDSI TDTP CU 501039 00 000 00 0 5 1 1 4 68 0000000000 BACK TDTP CPS 501039 00 000 00 0 5 1 1 4 68 0000000000 FBAC TDTP CPS 501039 00 000 00 0 5 1 1 4 68 0000000000 TCAN TDTP CPS 501039 00 000 00 0 5 1 1 4 68 0000000000 TCAF TDTP CPS 501039 00 000 00 0 5 1 1 4 68 0000000000 TCND TDTP CPS 501039 00 000 00 0 5 1 1 4 68 0000000000 TCFD TDTP CPS 501039 00 000 00 0 5 1 1 4 68 0000000000 TSCN TDTP CPS 501039 00 000 00 0 5 1 I 4 68 0000000000 TSCF TDTP CPS 501039 00 000 00 0 5 1 1 4 68 0000000000 INND TDTP CPS 501039 00 000 00 0 5 1 1 4 68 0000000000 INFD TDTP CPS 501039 00 000 00 0 5 1 1 4 68 0000000000 GRCH TDTP GAPI 501039 00 000 00 0 5 I I 4 68 0000000000 TENS TDTP LB 501039 00 000 00 0 5 1 1 4 68 0000000000 CCL TDTP V 501039 00 000 00 0 5 I 1 4 68 0000000000 ** DATA ** DEPT. 10702.000 SIGM.TDTP 36.460 TPHI.TDTP 45.586 SBHF.TDTP SBHN.TDTP 48,814 SIGC,TDTP 1.872 SIBH,TDTP 56.925 TRAT.TDTP SDSI,TDTP 0,932 BACK.TDTP 189.072 FBAC,TDTP 40.774 TCAN.TDTP TCAF,TDTP 6707.414 TCND,TDTP 17675,992 TCFD,TDTP 4495.460 TSCN.TDTP TSCF.TDTP 659.189 INND.TDTP 1493,786 INFD.TDTP 369.483 GRCH.TDTP TENS.TDTP 3195.000 CCL.TDTP 0.000 DEPT. 10359.000 SIGM.TDTP 14.912 TPHI.TDTP 22.413 SBHF.TDTP SBHN.TDTP 75.668 SIGC.TDTP 0.081 SIBH.TDTP 107.828 TRAT.TDTP SDSI.TDTP 0.283 BACK.TDTP 168.588 FBAC.TDTP 33.534 TCAN.TDTP TCAF.TDTP 12653.854 TCND.TDTP 15635.889 TCFD.TDTP 5969.234 TSCN.TDTP TSCF.TDTP 2313.349 INND.TDTP 1411.996 INFD.TDTP 388.730 GRCH.TDTP TENS.TDTP 2890.000 CCL.TDTP 0.000 42.608 1.715 23190.043 2103.360 -999.250 63.047 1.533 25558.898 4672.619 61.438 ** END OF DATA **** FILE TRAILER **=* FILE NAME : EDIT .OO5 SERVICE : FLIC VERSION : OO1CO1 DATE : 95/07/11 MAX RE¢ SIZE : 1024 FILE TYPE : LO LAST FILE : LIS Tape Verification Listing Schlumberger Alaska Computing Center **** FILE HEADER **~* FILE NAME : EDIT .006 SERVICE : FLIC VERSION : 001C01 DATE : 95/07/11 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : 11-JUL-1995 12:01 PAGE: 20 FILE HEADER FILE NUMBER: 6 EDITED CURVES Depth shifted and clipped curves for each pass in separate files. PASS NUMBER: 6 DEPTH INCREMENT: 0.5990 FILE SUMMARY LDWG TOOL CODE START DEPTH STOP DEPTH GRCH 19677.9 19369.9 TDTP 19792.9 19369.9 $ CURVE SHIFT DATA - PASS TO PASS(MEASURED DEPTH) BASELINE CURVE FOR SHIFTS LDWG CURVE CODE: GRCH PASS NUMBER: BASELINE DEPTH 88888.9 19693.5 19689.5 19685.5 19677.5 19673.5 19665.5 19661.5 19659 5 19653 5 19649 5 19645 5 19641 5 19637 5 19629.5 19625.5 19619.5 19617.5 19615.5 19613.5 19695.5 EQUIVALENT UNSHIFTED DEPTH QRCH TDTP 88888.9 88888.5 19694.9 19699.9 19685.5 19677.5 19674.9 19666.9 19661.5 19659.5 19653.5 19649.9 19645.9 19641.5 19638.9 19639.9 19625.5 19619.5 19617.5 10616.9 19614.9 19696.9 LIS Tape Verifica~|on Lis~ing Schlumberger Alaska Computing Cen~er Il-JUL-1995 12:01 PAGE: 21 10601.5 10601.S 10599.5 10600.0 10S95.5 10595.5 ~0593.5 10593,5 10591.5 10591.0 10~$9.S 10590.0 10587.5 10587.5 10585.5 10586.0 10~81.5 10581.5 10565.5 10565.5 10563.5 10563.5 10561.5 10562,0 10559.5 ~0560.0 10557.5 10558.0 10555.5 10555.5 ~0553.5 10553.5 1054~.5 10541.5 10537.5 ~0538.0 10533.5 10533.5 10529.5 10529.5 10525.5 10525.0 10521.5 10521.5 10501.5 10501.5 10497.5 10495.~ 10493.5 10494.~ 1~459.5 1~489.5 1~455.5 10486.0 10481.5 1~453.5 10449.5 10448.5 10445.5 10441.5 10437.5 10437.0 10435.5 10435.5 1~433.5 10432.5 10431.5 1~431.~ 10429.5 10425.0 10427.5 10427.5 1~415.5 10415.5 10413.5 10412.0 10411.5 1~409.5 104~$.5 1~407.5 10407.5 10405.5 104~4.0 10403.5 10402.5 10401°5 10397.5 10396.~ 100.0 99.0 98.5 $ REMARKS: THIS FILE CONTAINS BORAX PASS #3 OF THE TDTP. THE DEPTH CORRECTIONS SHOWN ABOVE REFLECT BORAX PASS #3 GRCH TO BASE PASS #1 GRCH AND BORAX PASS #3 SIGM TO BASE PASS #1 SIGM. ALL OTHER TDTP CURVES WERE CARRIED WITH THE SIGM SHIFTS. LIS Tape Verifica%ion Listing Schlumberger Alaska Computing Center $ LIS FORMAT DATA ll-JUL-1995 12:01 PAGE: 22 ** DATA FORMAT SPECIFICATION RECORD ** SET TYPE - 64EB *~ TYPE REPR CODE VALUE 1 66 0 2 66 0 3 75 88 4 66 1 5 66 6 73 7 65 8 68 0.5 9 65 FT 12 68 13 66 0 14 65 FT 15 66 68 16 66 1 0 66 1 SET TYPE - CHAN ** NAME SERV UNIT SERVICE AP1 AP1 APl AP1 FILE NUMB NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUMB SAMP ELEM CODE (HEX) DEPT FT 501039 00 000 00 0 6 1 1 4 68 00000000~0 SIGM TDTP CU 501039 00 000 00 0 6 1 1 4 68 0000000000 TPHI TDTP PU-S 501039 00 0~0 00 0 6 1 1 4 68 000~000000 SBHF TDTP CU 501039 00 000 00 0 6 1 1 4 68 ~00~0~0~00 SBHN TDTP CU 501039 00 000 00 0 6 1 1 4 68 000~000~0~ SIGC TDTP CU 501039 00 0~0 00 0 6 1 1 4 68 0~00e~000 SIBH TDTP CU 5~1039 00 000 00 0 6 1 1 4 68 ~00000~000 TRAT TDTP 501~39 00 0~0 0~ 0 6 ~ 1 4 68 e00000~0~0 SDSI TDTP CU 501039 00 000 00 0 6 ~ 1 4 68 ~00000000 BACK TDTP CPS 501039 00 ~0~ 00 0 6 ~ 1 4 68 0000~0~000 FBAC TDTP CPS 501~39 00 000 0~ 0 6 ~ 1 4 68 000e00~000 TCAN TDTP CPS 501039 00 000 ~0 0 6 1 1 4 68 0000000000 TCAF TDTP CPS 501039 00 ~00 00 0 6 1 1 4 68 000~000000 TCND TDTP CPS 501039 00 000 ~e 0 6 1 1 4 68 ~00~0~000 TCFD TDTP CPS 501039 ~0 000 0~ 0 6 ~ 1 4 68 0000000000 TSCN TDTP CPS 5~1039 00 0~0 0~ 0 6 1 1 4 68 ~000000000 TSCF TDTP CPS 501039 00 000 00 0 6 ~ 1 4 68 0900000000 INND TDTP CPS 501939 00 0~0 99 0 6 ~ 1 4 68 9~09900000 INFD TDTP CPS 501039 90 090 99 0 6 ~ 1 4 68 9999900090 LIS Tape Verification Listing Schlumberger Alaska Computing Center ll-JUL-lgg5 12:01 PAGE: 23 NAME SERV UNIT SERVICE AP1 AP1 AP1 AP1 FILE NUMB NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUMB SAMP ELEM CODE (HEX) GRCH TDTP GAPI 501039 00 000 TENS TDTP LB 501039 00 000 CCL TDTP V 501039 00 000 00 0 6 1 1 4 68 0000000000 00 0 6 1 1 4 68 000~000000 00 0 6 1 I 4 68 00000000~0 DATA DEPT. 10702.500 SIGM.TDTP SBHN.TDTP 47.470 SIGC.TDTP SDSI.TDTP 0.913 BACK.TDTP TCAF.TDTP 6639.463 TCND.TDTP TSCF.TDTP 642.098 INND.TDTP TENS.TDTP 3275.~0~ CCL.TDTP DEPT. 10358.500 SIGM.TDTP SBHN.TDTP 42.948 SIGC.TDTP SDSI.TDTP 0.344 BACK.TDTP TCAF.TDTP 16~94.104 TCND.TDTP TSCF.TDTP 2911.582 ZNND.TDTP TENS.TDTP 2845.~0~ CCL.TDTP 38.066 TPHI.TDTP 50.747 SBHF.TDTP 0.872 SIBH.TDTP 53.876 TRAT.TDTP 183.895 FBAC.TDTP 45.259 TCAN.TDTP 18130.488 TCFD.TDTP 4464.269 TSCN.TDTP 1404.115 INFD.TDTP 392.928 GRCH.TDTP 14.779 TPHI.TDTP 22.174 SBHF.TDTP 1.533 SIBH.TDTP 43.442 TRAT.TDTP 18e.71~ FBAC.TDTP 37.591 TCAN.TDTP 24672.684 TCFD.TDTP 8075.055 TSCN.TDTP 1430.154 INFD.TDTP 376.080 GRCH.TDTP 42.216 1.834 24066.973 2217.302 -999.250 31.497 1.696 36910.898 6677.546 -999.250 END OF DATA **** FILE TRAILER **** FILE NAME : EDIT .006 SERVICE : FLIC VERSION : 0~1C01 DATE : 95/07/11 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : **** FILE HEADER **** FILE NAME : EDIT .0e7 SERVICE : FLIC VERSION : 001C01 DATE : 95/07/11 MAX REC SIZE : 1924 FILE TYPE : LO LAST FILE : FILE HEADER FILE NUMBER: 7 LIS Tape Verification Listing Schlumberger Alaska Computing Center ll-JUL-19g~ 12:0~ PAGE: 24 AVERAGED CURVES Pulsed Neutron: Unaveraged edited Pass 1 Gamma Ray and backround counts; arithrne~ic average of edited static baseline passes for all other curves. DEPTH INCREMENT 0.5090 PASSES INCLUDED IN AVERAGE LDWG TOOL CODE PASS NUMBERS TDTP 1~ 2, 3, $ REMARKS: The arithmetic average of passes 1,2 A 3 was computed after all depth shifts and clipping was applied. LIS FORMAT DATA DATA FORMAT SPECIFICATION RECORD SET TYPE - 64EB ** TYPE REPR CODE VALUE [ 66 9 2 66 9 3 73 84 4 66 1 5 66 6 73 7 65 8 68 9.5 9 65 FT 11 66 [2 12 68 13 66 9 14 65 FT 15 66 68 16 66 1 9 66 I SET TYPE - CHAN ** NAME SERV UNIT SERVICE AP1 AP1 AP1 AP1 FILE NUMB NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUMB SAMP ELEM CODE (HEX) DEPT FT 591939 99 909 99 9 7 1 1 4 68 0999999990 SIGM PNAV CU 591939 99 990 99 9 7 1 1 4 68 9999909999 TPHI PNAV PU-S 591939 99 999 99 9 7 1 I 4 68 9999999999 SBHF PNAV CU 591039 90 999 99 9 7 I 1 4 68 9900999990 SBHN PNAV CU 591039 99 999 99 0 7 1 I 4 68 9999990090 SIGC PNAV CU 591039 99 999 99 0 7 ~ I 4 68 0900999999 SIBH PNAV CU 591039 90 990 99 9 7 1 1 4 68 9999090999 LIS Tape Verifica%ion Lis%ing Schlumberger Alaska Computing Cen~er ll-JUL-199S 12:01 PAGE: 25 NAME SERV UNIT SERVICE AP1 AP1 AP1 AP1 FILE NUMB NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUMB SAMP ELEM CODE (HEX) TRAT PNAV 501039 00 000 00 0 7 1 1 4 68 0000000000 SDSI PNAV CU 501039 00 000 00 0 7 1 ! 4 68 0000000000 BACK TDTP CPS 501039 00 000 00 0 7 1 1 4 68 0000000000 FBAC TDTP CPS 501039 00 000 00 0 7 1 I 4 68 0000000000 TCAN PNAV CPS 501039 00 000 00 0 7 I 1 4 68 0000000000 TCAF PNAV CPS 501039 00 000 00 0 7 1 1 4 68 0000000000 TCND PNAV CPS 501039 00 000 00 0 7 1 1 4 68 0000000000 TCFD PNAV CPS 501039 00 000 00 0 7 1 1 4 68 0000000000 TSCN PNAV CPS 501039 00 000 00 0 7 1 1 4 68 0000000000 TSCF PNAV CPS 501039 00 000 00 0 7 1 1 4 68 0000000000 INND PNAV CPS 501039 00 000 00 0 7 1 1 4 68 0000000000 INFD PNAV CPS 501039 00 000 00 0 7 1 I 4 68 0000000000 LC01 PNAV 501039 00 000 00 0 7 1 1 4 68 0000000000 GRCH TDTP GAPI 501039 00 000 00 0 7 1 1 4 68 0000000000 ** DATA ** DEPT. 10702.000 SIGM.PNAV 37.274 TPHI.PNAV 48.721 SBHF.PNAV SBHN.PNAV 47.130 SIGC.PNAV 1.177 SIBH.PNAV 53.110 TRAT.PNAV SDSI.PNAV 0.951 BACK.TDTP 72.656 FBAC.TDTP 24.750 TCAN.PNAV TCAF.PNAV 6317.500 TCND.PNAV 17878.488 TCFD.PNAV 4464.611 TSCN.PNAV TSCF.PNAV 642.236 INND.PNAV 1456.386 INFD.PNAV 363.184 LCO1.PNAV GRCH.TDTP -999.250 DEPT. 10297.000 SIGM.PNAV -999.250 TPHI.PNAV -999.250 SBHF.PNAV SBHN.PNAV -999.250 SIGC.PNAV -999.250 SIBH.PNAV -999.250 TRAT.PNAV SDSI.PNAV -999.250 BACK.TDTP 101.105 FBAC.TDTP 23.557 TCAN.PNAV TCAF.PNAV -999.250 TCND.PNAV -999.250 TCFD.PNAV -999.250 TSCN.PNAV TSCF.PNAV -999.250 INND.PNAV -999.250 INFD.PNAV -999.250 LCOl.PNAV GRCH.TDTP 109.000 ** END OF DATA ** 44.641 1.818 22596.500 2188.011 3.410 -999.250 -999.250 -999.250 -999.250 -999.250 **** FILE TRAILER **** FILE NAME : EDIT .007 SERVICE : FLIC VERSION : oolcol DATE : 95/07/11 MAX EEC SIZE : 1024 FILE TYPE : LO LAST FILE : LIS Tape Verification Listing Schlumberger Alaska Compu%ing Center **** FILE HEADER FILE NAME : EDIT ,008 SERVICE : FLIC VERSION : ~01C01 DATE : 9S/07/~1 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : ll-JUL-lggs 12:~1 PAGE: 26 FILE HEADER FILE NUMBER 8 RAW CURVES Curves and log header data for each pass in separate Giles; raw background pass in last ~ile PASS NUMBER: DEPTH INCREMENT: 0.5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH TDTP $ LOG HEADER DATA 10702.0 10297.0 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 24-MAY-g5 CP42.2 1029 24-MAY-95 le718.e le71e.o io297.e io7o2.~ 18oo.o YES TOOL NUMBER GR GAMMA RAY CGRS-A 863 CCL COLLAR LOG CPSC-A 805 TDTP THERMAL DECAY TOOL TDT SET 2 TDTP THERMAL DECAY TOOL TDIC-A 816 $ 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): 3530.0 PUMP-IN SEAWATER/BORAX -10.0 LIS Tape Verification Listing Schlumberger Alaska Computing Center ll-JUL-199S 12:01 FLUID SALINITY (PPM): FLUID LEVEL (FT): FLUID RATE AT WELLHEAD (BPM): WATER CUTS (PCT): GAS/OIL RATIO: CHOKE (DEG): NEUTRON TOOL TOOL TYPE (EPITHERMAL OR THERMAL): THERMAL MATRIX: SANDSTONE MATRIX DENSITY: 2.65 HOLE CORRECTION (IN): BLUELINE COUNT RATE NORMALIZATION IN OIL ZONE TOP NORMALIZING WINDOW (FT): BASE NORMALIZING WINDOW (FT): BLUELINE COUNT RATE SCALES SET BY FIELD ENGINEER FAR COUNT RATE LOW SCALE (CPS): 0 FAR COUNT RATE HIGH SCALE (CPS): 12900 NEAR COUNT RATE LOW SCALE (CPS): 9 NEAR COUNT RATE HIGH SCALE (CPS): 39999 TOOL STANDOFF (IN): REMARKS: USED PRIMARY DEPTH CONTROL WITH MAGNETIC MARKS. LOG IS APPROX. 1 FOOT SHALLOW TO CDR DATED 14-AUG-94. WELL WAS ON INJECTION PRIOR TO LOGGING. RATE = 4999 BWPD AT 2190 PSI SURFACE PRESSURE. SIGMA BOREHOLE LOOKED GOOD ON FIRST TO PASSES AFTER PUMPIN BORAX, BUT SHOWS VERY LITTLE ENTERING PERFS. COULD BE CAU BY 5 1/2" LINER DRILLED WITH 8 1/2" BIT SIZE. +his is base pass $ LIS FORMAT DATA PAGE: 27 DATA FORMAT SPECIFICATION RECORD ** SET TYPE - 64EB ** TYPE REPR CODE VALUE 1 66 9 2 66 9 3 73 92 4 66 5 66 6 73 7 65 8 68 0.5 9 65 FT LIS Tape Veri~ica%ion Lis%ing Schlumberger Alaska Computing Cen%er 11-JUL-1995 12:01 PAGE: 28 TYPE REPR CODE VALUE 11 66 11 12 68 13 66 0 14 65 FT 15 66 68 16 66 1 0 66 ** SET TYPE - CHAN ** NAME SERV UNIT SERVICE AP1 AP1 AP1 AP1 FILE NUMB NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUMB SAMP ELEM CODE (HEX) DEPT FT 501039 00 000 90 9 8 I 1 4 68 9999999999 SIGM PS1 CU 591939 99 999 99 9 8 1 I 4 68 9999999999 TPHI PS1 PU 591039 99 999 99 9 8 1 1 4 68 9999999999 SBHF PS1 CU 591939 99 999 99 9 8 1 1 4 68 9999999999 SBHN PS1 CU 591939 99 999 99 9 8 1 1 4 68 9999999999 SIGC PS1 CU 591939 99 999 99 9 8 1 1 4 68 9999999999 SIBH PS1 CU 591939 99 999 99 9 $ 1 1 4 68 9999999999 TEAT PS1 591939 99 999 99 9 $ 1 I 4 68 9999999999 LCO1 PS1 591939 99 999 99 9 8 1 1 4 68 9999999999 SDSI PS1 CU 591039 99 999 99 9 8 1 1 4 68 9999999999 BACK PS1 CPS 591939 99 999 99 9 8 1 I 4 68 9999999999 FBAC PS1 CPS 591939 99 999 99 9 8 1 1 4 68 9999999999 TCAN PS1 CPS 591939 90 999 99 9 $ 1 1 4 68 9999909999 TCAF PS1 CPS 591939 99 999 99 0 8 1 1 4 68 9999999999 TCND PS1 CPS 591939 99 999 99 9 8 1 1 4 68 9999999999 TCFD PS1 CPS 591939 99 999 99 9 8 I 1 4 68 9999999999 TSCN PS1 CPS 591939 99 999 99 9 8 1 1 4 68 9999999999 TSCF PS1 CPS 591939 99 999 99 9 8 I 1 4 68 9999999999 INND PS1 CPS 591939 99 999 99 9 8 1 I 4 68 9999999999 INFD PS1 CPS 591939 99 999 99 9 8 1 1 4 68 9999999999 TENS PS1 LB 591939 99 999 99 9 8 1 1 4 68 9999999999 GR PS1 GAPI 591939 99 999 99 9 8 1 1 4 68 9999999999 CCL PS1 V 591939 99 999 99 9 8 1 1 4 68 9999999999 ** DATA DEPT. 19733.599 SIGM.PS1 19.354 TPHI.PS1 9.999 SBHF.PS1 SBHN,PS1 153.519 SIGC.PS1 9.999 SIBH,PS1 196.291 TRAT,PS1 LC91,PS1 9.999 SDSI,PS1 4.909 BACK,PS1 21,949 FBAC.PS1 TCAN,PS1 9,999 TCAF.PS1 9.909 TeND.PS1 -273,958 TCFD.PS1 TSCN.PS1 9.999 TSCF,PS1 9.999 INND.PS1 -9.746 INFD.PS1 TENS.PS1 2529.999 GE.PS1 73.259 CCL.PS1 -0.913 179.952 9.999 21.222 -258.929 -9.721 LIS Tape Verification Listing Schlumberger Alaska Comput|ng Center 11-JUL-1995 12:01 DEPT. 1~296.000 SIGM.PS1 45.410 TPHI.PS1 57.519 SBHN.PS1 46.922 SIGC.PS1 0.031 SIBH.PS1 52.635 LCO1.PS1 4.281 SDSI.PS1 1.292 BACK.PS1 102.326 TCAN.PS! 25434.547 TCAF.PS1 5841.711 TCND.PS1 14810.766 TSCN.PS1 1343.e55 TSCF.PS1 313.757 INND.PS1 1359.673 TENS.PS1 2900.000 GR.PS1 119.188 CCL.PS1 0.000 SBHF.PS1 TRAT.PS1 FBAC.PS1 TCFD.PS1 INFD.PS1 PAGE: 29 44.782 1.947 25.586 3310.724 333.659 ** END OF DATA **** FILE TRAILER **** FILE NAME : EDIT .008 SERVICE : FLIC VERSION : ~1C01 DATE : 95/~7/11 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : **** FILE HEADER FILE NAME : EDIT .009 SERVICE : FLIC VERSION : ~01C01 DATE : 95/07/11 MAX EEC SIZE : 1024 FILE TYPE : LO LAST FILE : FILE HEADER FILE NUMBER · 9 RAW CURVES Curves and log header data for each pass in separate files; raw background pass in last file PASS NUMBER: 2 DEPTH INCREMENT: 0.5~00 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH TDTP 1~702.0 $ 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): 10297.0 24-MAY-95 CP42.2 1029 24-MAY-95 10718.0 10710.0 10297.0 1~702.0 LIS Tape Verit~ication Listing Schlumberger Alaska Computing Center ll-JUL-199S 12:M1 LOGGING SPEED (FPHR): DEPTH CONTROL USED (YES/NO): TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE 1800.0 YES TOOL NUMBER GR GAMMA RAY CGRS-A 863 CCL COLLAR LOG CPSC-A 8~5 TDTP THERMAL DECAY TOOL TDT SET 2 TDTP THERMAL DECAY TOOL TDIC-A 816 BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLERS CASING DEPTH (FT): LOGGERS CASING DEPTH (FT): BOREHOLE CONDITIONS FLUID TYPE: FLUID DENSITY (LB/G): SURFACE TEMPERATURE (DEGF): BOTTOM HOLE TEMPERATURE (DEGF): FLUID SALINITY (PPM): FLUID LEVEL (FT): FLUID RATE AT WELLHEAD (BPM): WATER CUTS (PCT): GAS/OIL RATIO: CHOKE (DEG): NEUTRON TOOL TOOL TYPE (EPITHERMAL OR THERMAL): MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): 3530.0 PUMP-IN SEAWATER/BORAX -10.0 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): 12~00 NEAR COUNT RATE LOW SCALE (CPS): 0 NEAR COUNT RATE HIGH SCALE (CPS): 30000 TOOL STANDOFF (IN): REMARKS: USED PRIMARY DEPTH CONTROL WITH MAGNETIC MARKS. LOG IS APPROX. I FOOT SHALLOW TO CDR DATED 14-AUG-94. WELL WAS ON INJECTION PRIOR TO LOGGING. RATE = 4000 BWPD AT 2100 PSI SURFACE PRESSURE. SIGMA BOREHOLE LOOKED GOOD ON FIRST TO PASSES AFTER PUMPIN BORAX, BUT SHOWS VERY LITTLE ENTERING PERFS. COULD BE CAU BY 5 1/2" LINER DRILLED WITH 8 1/2" BIT SIZE. ~his is base pass #2. PAGE: 30 LIS Tape Verit~ica%ion Li$%ing Schlumberger Alaska Compu%ing Cen%er $ LIS FORMAT DATA 11-JUL-1995 12:01 PAGE: 31 · * DATA FORMAT SPECIFICATION RECORD SET TYPE - 64EB ,* TYPE REPR CODE VALUE 1 66 0 2 66 0 3 73 92 4 66 5 66 6 73 7 65 8 68 0.5 9 65 FT 12 68 13 66 0 14 65 FT ~ 66 68 0 66 SET TYPE - CHAN ** NAME SERV UNIT SERVICE API API API API FILE NUMB NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUMB SAMP ELEM CODE (HEX) DEPT FT 501059 ~0 000 00 0 9 1 1 4 68 0000000000 SIGM PS2 CU 501039 ~0 000 00 0 9 1 1 4 68 0000000000 TPHI PS2 PU 5~1039 00 0~0 0~ 0 9 1 1 4 68 0000000000 SBHF PS2 CU 501039 00 000 00 0 9 1 1 4 68 0000000000 SBHN PS2 CU 501039 00 000 00 0 9 1 1 4 68 0000000000 SIGC PS2 CU 5~1039 00 000 00 0 9 1 1 4 68 0000000000 SIBH PS2 CU 501039 00 000 00 0 9 1 1 4 68 0000000000 TRAT PS2 501039 00 000 00 0 9 1 1 4 68 0000000000 LC01 PS2 501039 00 000 00 0 9 1 1 4 68 0000000000 SDSI PS2 CU 501039 00 000 00 0 9 1 1 4 68 000~000000 BACK PS2 CPS 501039 00 000 00 0 9 1 1 4 68 0000000000 FBAC PS2 CPS 501039 00 000 00 0 9 1 1 4 68 0000000000 TCAN PS2 CPS 501039 00 000 00 0 9 1 1 4 68 0000000000 TCAF PS2 CPS 501039 00 000 00 0 9 1 1 4 68 0000000000 TCND PS2 CPS 501039 00 000 00 0 9 1 1 4 68 0000000000 TCFD PS2 CPS 501039 00 000 00 0 9 1 1 4 68 0000000000 TSCN PS2 CPS 501039 ~0 000 00 0 9 1 1 4 68 0000000000 TSCF PS2 CPS 501039 00 000 00 0 9 1 1 4 68 0000000000 INND PS2 CPS 501039 00 000 00 0 9 1 I 4 68 0000000000 LIS Tape Verif|cation Listing Schlumberger Alaska Comput|ng Center Il-JUL-1995 12:01 PAGE: 32 NAME SERV UNIT SERVICE AP1 AP1 AP1 AP1 FILE NUMB NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUMB SAMP ELEM CODE (HEX) INFD PS2 CPS 501039 00 000 00 0 9 1 1 4 68 0009000000 TENS PS2 LB 591939 99 999 99 9 9 1 1 4 68 9999999999 GR PS2 GAPI 591939 90 099 99 9 9 1 1 4 68 9999990990 CCL PS2 V 501939 99 999 99 9 9 1 1 4 68 9999999999 ** DATA ** DEPT. 19729.999 SIGM.PS2 SBHN.PS2 46,922 SIGC.PS2 LC91.PS2 4,281 SDSI.PS2 TCAN.PS2 25434.547 TCAF.PS2 TSCN.PS2 1343,~55 TSCF.PS2 TENS.PS2 2285.990 GR.PS2 DEPT. 10297,999 SIGM.PS2 SBHN.PS2 52,242 SIGC.PS2 LC91.PS2 4,169 SDSI.PS2 TCAN.PS2 25880.621 TCAF.PS2 TSCN.PS2 1310,639 TSCF.PS2 TENS,PS2 2939.999 GR.PS2 45.419 TPHI.PS2 9.931 SIBH.PS2 1.292 BACK.PS2 5841.711 TCND.PS2 313.737 INND.PS2 61.719 CCL.PS2 45,649 TPHI.PS2 9.999 SIBH.PS2 1.169 BACK.PS2 5937.671 TCND.PS2 315.925 INND.PS2 139.599 CCL.PS2 57,519 SBHF.PS2 52.635 TRAT.PS2 102.326 FBAC.PS2 14819.766 TCFD.PS2 1359.673 INFD.PS2 9.913 65,968 SBHF.PS2 64.792 TRAT.PS2 143,599 FBAC.PS2 14891.354 TCFD.PS2 1438.985 INFD.PS2 44.782 1.947 25.586 3310.724 333.659 42.669 1.890 32.316 3316.681 332.529 ** END OF DATA ** **** FILE TRAILER **** FILE NAME : EDIT .099 SERVICE : FLIC VERSION : 991C01 DATE : 95/97/11 MAX REC SIZE : 1924 FILE TYPE : LO LAST FILE : **** FILE HEADER **** FILE NAME : EDIT .010 SERVICE : FLIC VERSION : 991Cel DATE : 95/97/11 MAX REC SIZE : 1924 FILE TYPE : LO LAST FILE : FILE HEADER LIS Tape Verifica%ion Lis%ing Schlumberger Alaska Computing Cen~er ll-JUL-lgg5 12:01 PAGE: 33 FILE NUMBER RAW CURVES Curves and log header da%a for each pass in separa%e files; raw background pass in las% file PASS NUMBER: 3 DEPTH INCREMENT: ~.5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH TDTP $ LOG HEADER DATA le702.0 10297.0 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 24-MAY-95 CP42.2 1029 24-MAY-95 10718.0 10710.0 1~297.0 10702.0 1800.~ YES TOOL NUMBER GR CCL TDTP TDTP $ GAMMA RaY COLLAR LOG THERMAL DECAY TOOL THERMAL DECAY TOOL BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLERS CASING DEPTH (FT): LOGGERS CASING DEPTH (FT): BOREHOLE CONDITIONS FLUID TYPE: FLUID DENSITY (LB/G): SURFACE TEMPERATURE (DEGF): BOTTOM HOLE TEMPERATURE (DEGF): FLUID SALINITY (PPM): FLUID LEVEL (FT): FLUID RATE AT WELLHEAD (BPM): WATER CUTS (PCT): GAS/OIL RATIO: CHOKE (DEG): NEUTRON TOOL TOOL TYPE (EPITHERMAL OR THERMAL): MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): CGRS-A 863 CPSC-A 805 TDT SET 2 TDIC-A 816 353~.0 PUMP-IN SEAWATER/BORAX -10.0 THERMAL SANDSTONE 2.65 LIS Tape Verification Listing Schlumberger Alaska Comput|ng Center ll-JUL-~g9~ 12:0~ BLUELINE COUNT RATE NORMALIZATION IN OIL ZONE TOP NORMALIZING WINDOW (FT): BASE NORMALIZING WINDOW (FT): BLUELINE COUNT RATE SCALES SET BY FIELD ENGINEER FAR COUNT RATE LOW SCALE (CPS): 0 FAR COUNT RATE HIGH SCALE (CPS): 12000 NEAR COUNT RATE LOW SCALE (CPS): 0 NEAR COUNT RATE HIGH SCALE (CPS): $0000 TOOL STANDOFF (IN): REMARKS: USED PRIMARY DEPTH CONTROL WITH MAGNETIC MARKS. LOG IS APPROX. 1 FOOT SHALLOW TO CDR DATED 14-AUG-94. WELL WAS ON INJECTION PRIOR TO LOGGING. RATE = 4000 BWPD AT 21~0 PSI SURFACE PRESSURE. SIGMA BOREHOLE LOOKED GOOD ON FIRST TO PASSES AFTER PUMPIN BORAX~ BUT SHOWS VERY LITTLE ENTERING PERFS. COULD BE CAU BY 5 1/2" LINER DRILLED WITH 8 1/2" Blt SIZE. +his is base pass ~3. LIS FORMAT DATA PAGE: 34 DATA FORMAT SPECIFICATION RECORD SET TYPE - 64EB ** TYPE REPR CODE VALUE 1 66 0 2 66 0 3 73 92 4 66 1 5 66 6 73 7 65 8 68 0.5 9 65 FT 11 66 11 12 68 13 66 0 14 65 FT 15 66 68 16 66 1 0 66 1 LIS Tape Verification Listing Schlumberger Alaska Computing Center SET TYPE - CHAN ** 11-JUL-1995 12:01 PAGE: 35 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 5~1~39 ~0 0~0 ~0 0 10 1 1 4 68 SIGM PS3 CU 501039 00 ~00 ~0 0 10 I 1 4 68 TPHI PS3 PU 501039 00 000 00 0 10 I I 4 68 SBHF PS3 CU 501039 00 ~00 00 0 10 1 1 4 68 SBHN PS3 CU 501039 00 0~0 00 0 10 1 1 4 68 SIGC PS3 CU 501039 00 000 00 0 10 ! I 4 68 SIBH PS3 CU 501039 00 000 00 0 10 1 1 4 68 TRAT PS3 501039 00 000 00 0 10 1 1 4 68 LC01 PS3 501039 00 0e0 00 0 10 1 1 4 68 SDSI PS3 CU 501039 00 000 00 0 10 1 1 4 68 BACK PS3 CPS 501039 00 0e0 00 0 10 1 I 4 68 FBAC PS3 CPS 501039 00 0~0 eO 0 10 1 1 4 68 TCAN PS3 CPS 501039 00 000 00 0 10 1 1 4 68 TCAF PS3 CPS 501039 00 9~0 00 0 10 1 1 4 68 TCND PS3 CPS 501039 00 e00 00 9 10 ! I 4 68 TCFD PS3 CPS 501039 ~0 000 00 0 10 ! I 4 68 TSCN PS3 CPS 501e39 0~ e00 00 0 10 1 1 4 68 TSCF PS3 CPS 501039 00 000 00 0 10 ! I 4 68 INND PS3 CPS 501~39 ~ 000 00 0 10 I 1 4 68 INFD PS3 CPS 501039 00 0~0 ~0 ~ 10 1 1 4 68 TENS PS3 LB 501~39 ~0 000 ~0 0 10 1 1 4 68 GR PS3 GAPI 501039 00 ~00 00 0 10 1 I 4 68 CCL PS3 V 501039 00 ~00 00 0 10 1 1 4 68 ** DATA DEPT. 1~732.590 SIGM.PS3 SBHN.PS3 48.982 SIGC.PS3 LCO1,PS3 0.000 SDSI.PS3 TCAN.PS3 0.000 TCAF.PS3 TSCN.PS3 0.e00 TSCF.PS3 TENS.PS3 2395.~00 GR.PS3 44 756 0 356 9 819 9 000 0 81 125 DEPT. 10297.500 SIGM.PS3 45.381 SBHN.PS3 49.182 SIGC.PS3 9.0~0 LC91.PS3 4.377 SDSI.PS3 1.226 TCAN.PS3 26713.887 TCAF.PS3 6047.214 TSCN,PS3 1372,650 TSCF.PS3 313,598 TENS.PS3 3215.0~0 GR.PS3 127.000 TPHI.PS3 2.943 SBHF.PS3 SIBH.PS3 51.847 TRAT.PS3 BACK.PS3 7.361 FBAC,PS3 TCND.PS3 -999.259 TCFD.PS3 INND.PS3 -0.250 INFD,PS3 CCL.PS3 0.013 TPHI.PS3 65.097 SBHF.PS3 SIBH.PS3 57.769 TRAT.PS3 BACK.PS3 164.758 FBAC.PS3 TCND.PS3 15154.824 TCFD.PS3 INND.PS3 1393.229 INFD.PS3 CCL.PS3 0.009 44.495 0.000 2.629 -999.250 -0.089 44.472 1.992 34.360 3369.140 336.268 END OF DATA LIS Tape Verifica%ion Lis%ing Schlumberger Alaska Computing Cen~er **** FILE TRAILER FILE NAME : EDIT .010 SERVICE : FLIC VERSION : 001C01 DATE : 95/07/11 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : **** FILE HEADER FILE NAME : EDIT SERVICE : FLIC VERSION : 001C01 DATE : 95/07/11 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : ll-JUL-lgg5 12:01 PAGE: 36 FILE HEADER FILE NUMBER 11 RAW CURVES Curves and log header da~a for each pass in separa%e files; raw background pass in las~ file PASS NUMBER: 4 DEPTH INCREMENT: ~.5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH TDTP $ LOG HEADER DATA 10702.~ 10360.0 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 24-MAY-95 CP42.2 1029 24-MAY-95 10718.0 10710.0 10360.0 10702.0 1800.0 YES TOOL NUMBER GR GAMMA RAY CGRS-A 863 CCL COLLAR LOG CPSC-A 805 TDTP THERMAL DECAY TOOL TDT SET 2 TDTP THERMAL DECAY TOOL TDIC-A 816 LIS Tape Verification Lis%ing Schlumberger Alaska Compu%ing Cen%er Il-JUL-1995 12:01 PAGE: 37 BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLERS CASING DEPTH (FT): LOGGERS CASING DEPTH (FT): BOREHOLE CONDITIONS FLUID TYPE: FLUID DENSITY (LB/G): SURFACE TEMPERATURE (DEGF): BOTTOM HOLE TEMPERATURE (DEGF): FLUID SALINITY (PPM): FLUID LEVEL (FT): FLUID RATE AT WELLHEAD (BPM): WATER CUTS (PCT): GAS/OIL RATIO: CHOKE (DEG): NEUTRON TOOL TOOL TYPE (EPITHERMAL OR THERMAL): MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): THERMAL SANDSTONE 2.65 BLUELINE COUNT RATE SCALES SET BY FIELD ENGINEER FAR COUNT RATE LOW SCALE (CPS): 0 FAR COUNT RATE HIGH SCALE (CPS): 12000 NEAR COUNT RATE LOW SCALE (CPS): 0 NEAR COUNT RATE HIGH SCALE (CPS): 3000~ TOOL STANDOFF (IN): REMARKS: USED PRIMARY DEPTH CONTROL WITH MAGNETIC MARKS. LOG IS APPROX. 1 FOOT SHALLOW TO CDR DATED 14-AUG-94. WELL WAS ON INJECTION PRIOR TO LOGGING. RATE = 4~ BWPD AT 2100 PSI SURFACE PRESSURE. SIGMA BOREHOLE LOOKED GOOD ON FIRST TO PASSES AFTER PUMPIN BORAX, BUT SHOWS VERY LITTLE ENTERING PERFS. COULD BE CAU BY 5 1/2" LINER DRILLED WITH 8 1/2" BIT SIZE. +his is Borax pass #1. $ LIS FORMAT DATA 3530.0 PUMP-IN SEAWATER/BORAX -10.0 BLUELINE COUNT RATE NORMALIZATION IN OIL ZONE TOP NORMALIZING WINDOW (FT): BASE NORMALIZING WINDOW (FT): LIS Tape Ver|~icat|on Listing Schlumberger Alaska Computing Center Il-JUL-1995 12:01 DATA FORMAT SPECIFICATION RECORD SET TYPE - 64EB ** TYPE REPR CODE VALUE I 66 0 2 66 0 3 73 92 4 66 5 66 6 73 7 65 8 68 0.5 9 65 FT 12 68 13 66 0 14 65 FT 15 66 68 16 66 1 0 66 SET TYPE - CHAN ** PAGE: 38 NAME SERV UNIT SERVICE AP1 AP1 AP1 AP1 FILE NUMB NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUMB SAMP ELEM CODE (HEX) DEPT FT S01039 00 00~ eO 0 ll I 1 4 68 00~e000000 SIGM PS4 CU 501039 ~0 000 00 0 11 1 I 4 68 0000000000 TPHI PS4 PU 501039 ~0 ~ ~ ~ 11 1 1 4 68 ~0000~000 SBHF PS4 CU 501039 00 009 99 0 11 I 1 4 68 9999999999 SBHN PS4 CU 591939 99 999 99 9 11 I I 4 68 9999999999 SIGC PS4 CU 591939 99 999 99 9 11 I I 4 68 9999999999 SIBH PS4 CU 591939 99 999 99 9 11 I I 4 68 9999999999 TRAT PS4 591939 99 999 99 9 11 I I 4 68 9999999999 LC01 PS4 591939 99 999 99 9 11 1 1 4 68 9999999999 SDSI PS4 CU 591939 99 999 99 9 11 I I 4 68 9999999999 BACK PS4 CPS 591939 99 999 99 9 11 I I 4 68 9999999999 FBAC PS4 CPS 591939 99 999 99 9 11 1 1 4 68 9999999999 TCAN PS4 CPS 591959 99 999 99 9 11 1 1 4 68 9999999999 TCAF PS4 CPS 591939 90 099 ~9 0 11 1 1 4 68 ~009900999 TCND PS4 CPS 591939 99 999 99 9 11 1 1 4 68 9999900999 TCFD PS4 CPS 501939 09 999 99 9 ll 1 1 4 68 9999999999 TSCN PS4 CPS 591939 99 999 99 0 11 I I 4 68 9909999999 TSCF PS4 CPS 591939 99 999 99 9 11 1 1 4 68 9999999999 INND PS4 CPS 591939 99 099 99 9 11 1 1 4 68 9999909999 INFD PS4 CPS 591939 99 999 99 9 11 I 1 4 68 9909999999 TENS PS4 LB 591939 99 999 99 9 11 1 1 4 68 9999999999 GR PS4 GAPI 591939 99 999 99 0 11 1 1 4 68 9999999999 CCL PS4 V 591939 90 999 90 9 11 1 1 4 68 9999999999 LIS Tape Verification Listing Schlumberger Alaska Computing Center DATA DEPT. 10728.500 SIGM.PS4 SBHN.PS4 50.338 SIGC.PS4 LCO1.PS4 0.000 SDSI.PS4 TCAN.PS4 0.000 TCAF.PS4 TSCN.PS4 0.000 TSCF.PS4 TENS.PS4 2315.000 GR.PS4 DEPT. 10343.000 SIGM.PS4 SBHN.PS4 75.817 SIGC.PS4 LCO1.PS4 3.583 SDSI.PS4 TCAN.PS4 4075.064 TCAF.PS4 TSCN.PS4 746.115 TSCF.PS4 TENS.PS4 2890.000 GR.PS4 ** END OF DATA ** Il-JUL-1995 12:01 45.623 TPHI.PS4 0.105 SIBH.PS4 0.865 BACK.PS4 0.000 TCND.PS4 0.000 INND.PS4 98.750 CCL.PS4 24.942 TPHI.PS4 0.000 SIBH.PS4 4.946 BACK.PS4 1137.225 TCND.PS4 208.218 INND.PS4 134.625 CCL.PS4 1.797 SBHF.PS4 53.533 TRAT.PS4 333.542 FBAC.PS4 -3807.652 TCFD.PS4 -11.338 INFD.PS4 0.908 38.273 SBHF.PS4 118.183 TRAT.PS4 153.361 FBAC.PS4 9144.982 TCFD.PS4 1392.132 INFD.PS4 PAGE: 39 46.984 9.909 63.974 -682.685 -2.144 64.878 1.614 34.342 2237.976 339.393 **** FILE TRAILER **** FILE NAME : EDIT .gll SERVICE : fllC VERSION : 091C91 DATE : 95/07/11 MAX REC SIZE : 1924 FILE TYPE : LO LAST FILE : **** FILE HEADER FILE NAME : EDIT .912 SERVICE : fLIC VERSION : 901C91 DATE : 95/07/11 MAX REC SIZE : 1924 FILE TYPE : LO LAST FILE : FILE HEADER FILE NUMBER 12 RAW CURVES Curves and log header data for PASS NUMBER: 5 DEPTH INCREMENT: 9.5999 FILE SUMMARY VENDOR TOOL CODE START DEPTH TDTP 19792.9 $ each pass in separate files; STOP DEPTH 19360.9 raw background pass in last file LIS Tape Verification Listing Schlumberger Alaska Computing Center 11-JUL-1995 12:01 LOG HEADER DATA DATE LOGGED: SOFTWARE VERSION: TIME LOGGER ON BOTTOM: TD DRILLER (FT): TI) 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 24-MAY-95 CP42.2 1029 24-MAY-9S 10718.0 19360.0 10702.9 1899.9 YES TOOL NUMBER GR GAMMA RAY CGRS-A 863 CCL COLLAR LOG CPSC-A 805 TDTP THERMAL DECAY TOOL TDT SET 2 TDTP THERMAL DECAY TOOL TDIC-A 816 $ BOREHOLE AND CASING DATA OPEN HOLE Blt SIZE (IN): DRILLERS CASING DEPTH (FT): LOGGERS CASING DEPTH (FT): 3530.9 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): PUMP-IN SEAWATER/BORAX 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): 12900 NEAR COUNT RATE LOW SCALE (CPS): 0 NEAR COUNT RATE HIGH SCALE (CPS): 39900 TOOL STANDOFF (IN): PAGE: 40 LIS Tape Veri~ica%ion Lis%ing Schlumberger Alaska Computing Cen%er Il-JUL-1995 12:01 REMARKS: USED PRIMARY DEPTH CONTROL WITH MAGNETIC MARKS. LOG IS APPROX. 1 FOOT SHALLOW TO CDR DATED 14-AUG-94. WELL WAS ON INJECTION PRIOR TO LOGGING. RATE = 4000 BWPD AT 2100 PSI SURFACE PRESSURE. SIGMA BOREHOLE LOOKED GOOD ON FIRST TO PASSES AFTER PUMPIN BORAX, BUT SHOWS VERY LITTLE ENTERING PERFS. COULD BE CAU BY S 1/2" LINER DRILLED WITH $ 1/2" BIT SIZE. ~h|s is Borax pass #2. $ LIS FORMAT DATA PAGE: 41 ** DATA FORMAT SPECIFICATION RECORD ** SET TYPE - 64EB ~, TYPE REPR CODE VALUE 1 66 0 2 66 ~ 3 73 88 4 66 1 5 66 6 73 7 65 8 68 0.5 9 65 FT 11 66 11 12 68 13 66 0 14 65 FT 15 66 68 16 66 1 0 66 1 SET TYPE - CHAN ** NAME SERV UNIT SERVICE API API API API FILE NUMB NUMB SIZE REPR PROCESS ID ORDER ~ LOG TYPE CLASS MOD NUMB SAMP ELEM CODE (HEX) DEPT FT 501039 00 0~0 00 0 12 1 1 4 68 0000000000 SIGM PS5 CU 501039 ~0 0~0 00 0 12 1 1 4 68 0000000000 TPHI PS5 PU 5~1039 00 00~ 00 0 12 1 1 4 68 0000000000 SBHF PS5 CU 501039 00 000 00 0 12 1 1 4 68 0000000000 SBHN PS5 CU 5~1039 00 000 00 0 12 1 1 4 68 ~0~0~00000 SIGC PS5 CU 5~1039 00 000 00 0 12 1 1 4 68 0000000000 SIBH PS5 CU 501039 00 000 0~ 0 12 1 1 4 68 0000000000 TEAT PS5 501039 00 000 00 0 12 1 1 4 68 0000000000 SDSI PS5 CU 501039 09 909 00 0 12 1 1 4 68 0000099909 BACK PS5 CPS 591039 99 900 00 0 12 1 I 4 68 0000900909 LIS Tape Verification Listing Schlumberger Alaska Compu%ing Cen~er Il-JUL-1995 12:~1 PAGE: 42 NAME SERV UNIT SERVICE AP1 AP1 AP1 AP1 FILE NUMB NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUMB SAMP ELEM CODE (HEX) FBAC PS5 CPS 501039 00 000 90 9 12 1 1 4 68 9999999999 TCAN PS5 CPS 591939 99 999 99 9 12 1 1 4 68 9999999900 TCAF PS5 CPS 591939 99 999 99 0 12 1 1 4 68 9999999999 TCND PS5 CPS 591939 99 999 99 9 12 1 1 4 68 9099999999 TCFD PS5 CPS 591939 99 999 99 9 12 1 1 4 68 9999990990 TSCN PS5 CPS 501939 09 999 99 9 12 1 1 4 68 9099999999 TSCF PS5 CPS 591939 99 999 99 9 12 1 1 4 68 9099999999 INND PS5 CPS 591939 90 999 99 9 12 1 1 4 68 9999999990 INFD PS5 CPS 591939 99 999 99 9 12 1 1 4 68 9099999999 TENS PS5 LB 591939 99 999 99 9 12 1 1 4 68 9999099999 GR PS5 GAPI 591939 99 999 99 9 12 1 1 4 68 9999999999 CCL PS5 V 591939 99 999 99 9 12 1 1 4 68 9999999999 DATA DEPT. 19727.599 SIGM.PS5 24.942 TPHI.PS5 38.273 SBHF.PS5 SBHN.PS5 75.817 SIGC.PS5 9.999 SIBH.PS5 118.183 TRAT.PS5 SDSI.PS5 4.946 BACK.PS5 153.361 FBAC.PS5 34.342 TCAN.PS5 TCAF.PS5 1137.225 TCND.PS5 9144.982 TCFD.PS5 2237.976 TSCN.PS5 TSCF.PS5 298.218 INND.PS5 1392.132 INFD.PS5 339.393 TENS.PS5 GR.PS5 191.625 CCL.PS5 9.~98 DEPT. 10299.999 SIGM.PS5 45.256 TPHI.PS5 53.591 SBHF.PS5 SBHN.PS5 74.396 SIGC.PS5 9.999 SIBH.PS5 114.969 TEAT.PS5 SDSI.PS5 1.483 BACK.PS5 179.699 FBAC.PS5 37.968 TCAN.PS5 TCAF.PS5 3513.323 TCND.PS5 8415.641 TCFD.PS5 2956.722 TSCN.PS5 TSCF.PS5 153.544 INND,PS5 1391,525 INFD,PS5 341,567 TENS.PS5 GE.PS5 132.999 CCL.PS5 9.999 64.878 1.614 4975.964 746.115 2270.999 66.437 1.466 13130.258 541.723 2910.900 END OF DATA **** FILE TRAILER FILE NAME : EDIT .912 SERVICE : FLIC VERSION : 991C01 DATE : 95/97/11 MAX REC SIZE : 1924 FILE TYPE : LO LAST FILE : LIS Tape Verification Listing Schlumberger Alaska Computing Center **** FILE HEADER *~* FILE NAME : EDIT .013 SERVICE : FLIC VERSION : 001C01 DATE : 95/~7/11 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : 11-JUL-lg95 12:01 PAGE: 43 FILE HEADER FILE NUMBER 13 RAW CURVES Curves and log header data for each pass in separate files; raw background pass in last file PASS NUMBER: 6 DEPTH INCREMENT: ~.5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH TDTP $ LOG HEADER DATA 107e2.0 le36e.e DATE LOGGED: SOFTWARE VERSION: TIME LOGGER ON BOTTOM: TD DRILLER (FT): TD LOGGER(FT): TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): LOGGING SPEED (FPHR): DEPTH CONTROL USED (YES/NO): TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE 24-MAY-95 CP42.2 1029 24-MAY-95 10718.0 1~710.0 10360.0 10702.0 18e0.0 YES TOOL NUMBER GR CCL TDTP TDTP $ GAMMA RaY COLLAR LOG THERMAL DECAY TOOL THERMAL DECAY TOOL BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLERS CASING DEPTH (FT): LOGGERS CASING DEPTH (FT): BOREHOLE CONDITIONS FLUID TYPE: FLUID DENSITY (LB/G): SURFACE TEMPERATURE (DEGF): BOTTOM HOLE TEMPERATURE (DEGF): CGRS-A 863 CPSC-A 805 TDT SET 2 TDIC-A 816 3530.0 PUMP-IN SEAWATER/BORAX -10.0 LIS Tape Veri~ica%ion Lis%lng Schlumberger Alaska Compu%ing Cen%er Il-JUL-1995 12:01 FLUID SALINITY (PPM): FLUID LEVEL (FT): FLUID RATE AT WELLHEAD (BPM): WATER CUTS (PCT): GAS/OIL RATIO: CHOKE (DEG): NEUTRON TOOL TOOL TYPE (EPITHERMAL OR THERMAL): MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): BLUELINE COUNT RATE NORMALIZATION IN OIL ZONE TOP NORMALIZING WINDOW (FT): BASE NORMALIZING WINDOW (FT): BLUELINE COUNT RATE SCALES SET BY FIELD ENGINEER FAR COUNT RATE LOW SCALE (CPS): 0 FAR COUNT RATE HIGH SCALE (CPS): 12000 NEAR COUNT RATE LOW SCALE (CPS): 0 NEAR COUNT RATE HIGH SCALE (CPS): 30000 TOOL STANDOFF (IN): THERMAL SANDSTONE 2.65 REMARKS: USED PRIMARY DEPTH CONTROL WITH MAGNETIC MARKS. LOG IS APPROX. 1 FOOT SHALLOW TO CDR DATED 14-AUG-94. WELL WAS ON INJECTION PRIOR TO LOGGING. RATE = 4e0~ BWPD AT 2100 PSI SURFACE PRESSURE. SIGMA BOREHOLE LOOKED GOOD ON FIRST TO PASSES AFTER PUMPIN BORAX, BUT SHOWS VERY LITTLE ENTERING PERFS. COULD BE CAU BY 5 1/2" LINER DRILLED WITH 8 1/2" BIT SIZE. ~his is Borax pass ~3. $ LIS FORMAT DATA PAGE: 44 ** DATA FORMAT SPECIFICATION RECORD ** SET TYPE - 64EB ** TYPE REPR CODE VALUE 1 66 0 2 66 I~ 3 73 88 4 66 :~ 5 66 6 73 7 65 $ 68 9.5 9 65 FT LIS Tape Ver|~ica%ion Lis%|ng Schlumberger Alaska Compu%|ng Cen%er Il-JUL-1995 12:01 PAGE: 45 TYPE REPR CODE VALUE 12 68 13 66 0 14 65 FT 15 66 68 16 66 o 66 SET TYPE - CHAN *, NAME SERV UNIT SERVICE AP1 API AP1 AP1 FILE NUMB NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUMB SAMP ELEM CODE (HEX) DEPT FT 501039 00 0~ 00 0 13 1 1 4 68 ~000000000 SIGM PS6 CU 501~39 00 0~0 00 0 13 1 1 4 68 000000~0~ TPHI PS6 PU 501039 00 0~0 00 0 13 I 1 4 68 000~0~0000 SBHF PS6 CU 501~39 00 0~0 0~ 0 13 I I 4 68 0~000~00~0 SBHN PS6 CU 501039 00 000 00 ~ 13 1 1 4 68 0~0~000~0 SIGC PS6 CU 501039 00 000 00 ~ 13 1 1 4 68 0e000~0000 SIBH PS6 CU 501039 00 000 00 ~ 13 1 1 4 68 0000~00~00 TRAT PS6 501~39 00 00~ 00 ~ 13 1 1 4 68 00000000~0 SDSI PS6 CU 5~1039 00 000 00 0 13 1 1 4 68 0~00000000 BACK PS6 CPS 501039 00 000 00 0 13 1 1 4 68 ~0000~00~0 FBAC PS6 CPS 501~39 ~0 0~0 00 0 13 1 1 4 68 0~00000000 TCAN PS6 CPS 501~39 00 000 00 0 13 1 1 4 68 00000~0000 TCAF PS6 CPS 501039 00 000 ~0 0 13 I 1 4 68 0000000000 TCND PS6 CPS 501039 0~ 00~ 00 0 13 1 1 4 68 0000~00000 TCFD PS6 CPS 501039 00 0~0 00 0 13 I 1 4 68 0000000000 TSCN PS6 CPS 501039 0~ 000 00 0 13 1 1 4 68 0~0000~000 TSCF PS6 CPS 501039 00 000 00 0 13 1 1 4 68 0000000000 INND PS6 CPS 501039 00 000 00 0 13 1 1 4 68 0000000000 INFD PS6 CPS 501039 00 000 00 0 13 1 1 4 68 ~000000~00 TENS PS6 LB 501~39 00 000 00 0 13 1 1 4 68 0000000~00 GR PS6 GAPI 501039 00 0~0 00 0 13 1 1 4 68 00000~0000 CCL PS6 V $~1~39 00 000 00 0 13 1 1 4 68 0000000000 ** DATA ** DEPT. 10731.000 SIGM.PS6 45.256 TPHI.PS6 53.501 SBHF,PS6 SBHN.PS6 74.396 SIGC.PS6 0.000 SIBH.PS6 114.960 TRAT,PS6 SDSI.PS6 1.483 BACK.PS6 170.699 FBAC.PS6 37.968 TCAN.PS6 TCAF.PS6 3513.323 TCND.PS6 8415.641 TCFD,PS6 2056.722 TSCN,PS6 TSCF.PS6 153.544 INND.PS6 1391.525 INFD.PS6 341,567 TENS.PS6 GR,PS6 109.625 CCL.PS6 0.~08 DEPT. 10335.000 SIGM,PS6 41.483 TPHI.PS6 64.573 SBHF.PS6 SBHN,PS6 44,334 SIGC.PS6 0,225 SIBH,PS6 46.762 TRAT.PS6 SDSI.PS6 0.863 BACK.PS6 184.272 FBAC,PS6 44.065 TCAN.PS6 TCAF.PS6 5678.115 TeND,PS6 16636,914 TCFD.PS6 3583.224 TSCN,PS6 66.437 1.466 13130.258 541.723 2340.000 33.736 2.203 25471.898 1979.568 LIS Tape Verifica%ion Listing Schlumberger Alaska Computing Cen%er Il-JUL-1995 12:01 PAGE: 46 TSCF.PS6 437.758 INND.PS6 GR.PS6 170.000 CCL.PS6 1396.263 INFD.PS6 0.000 344.587 TENS.PS6 2890.000 ** END OF DATA **** FILE TRAILER FILE NAME : EDIT .0Z3 SERVICE : FLIC VERSION : 001601 DATE : 95/07/11 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : **** TAPE TRAILER SERVICE NAME : EDIT DATE : 95/07/1! ORIGIN : FLIC TAPE NAME : 95196 CONTINUATION # : 1 PREVIOUS TAPE : COMMENT : ARCO ALASKA INC, DS 9-37, PRUDHOE BAY, 50-029-22451-e0 **** REEL TRAILER **** SERVICE NAME : EDIT DATE : 95/e7/11 ORIGIN : FLIC REEL NAME : 95196 CONTINUATION ~ : PREVIOUS REEL : COMMENT : ARCO ALASKA INC, DS 9-37, PRUDHOE BAY, 50-029-22451-00 COMPANY NA~E : ARcO'-ALASKA, 'INC, ~g[,b NANE I D& 09-37 FIELD NAME I PRUDHOE" BAY BOROUGH : NORTH S. bOPE STATE : ALASKA AP! NUMBER I 5.0=0.2.9-22451 REFERENCE NO : ~a288 RE¢i IVED JUN 1 2 199~ t. ' LIS Tape Verlflcat~on Listing Schlumberger AlasKa Computing Center ?-~UN-1.995" 13:56 $*** REEL HEADER ***~ D~T~ : g5/06/ 7 ORIGIN : FbI¢ REEL NAME : 9428~ CONTINUATTON # PREVIOUS REEL COM~EN~ : ARCO ALASKA INC., PRUDHOE BAY, DS 09-37, 50.-029-22451-00 **~ TAPE HEADER ***~ SERVICE NAM~ : gDIT DATR : 95/06/ 7 ORIGIN : FLIC TAPE NAME : 94288 CONTINUATION # : J. PR. EVIODS TAPE : CO~u~'~,,,= . .. ...=,~, : ARCO ALASKA INC., PRUDHOE BAY,. PS 09-3?,. 50-029-22451-00 TAPE HEADER PRU~HOE BAY MWD/MAD LOGS API NU~BER~ OPE~ATOR~ LOGGING COMPANY: TAPF CREATION DATE: ~OB D~T~ JOB NUMBER~ LOGGING ENGINEEr: OPERATOR WITNESS: ~URFACE LOCATION SECTION: TOWNSHIP: RANGE~ FNL: FSL~ FEL~ ELEVATION(FT FROM MSL O) KELLY BUSHING: DERRICK FhOOR~ GROUND LEVEL: WEb[, CASING RECORD ~$T ST~ING 2~D STRING BIT RUN 1 942BB OACK$ON DS 0g-37 5002922451 ARCO ALASKA. ~N'C BCHbUMBERGER. SERVICES 'l-JUN-g5'-. BIT RUN 2 BlT RUN.3 1 ION .20:t 4962 46 0 20. OPEN HOLE. CASING- DRILLERS ~.IT SIZE tiN) SIZE (INI)' DEPTH' 8,500 9,625 3532,0 'PAGEI "1' LIS Ta~e Verification Llst~n~ Schlumberqer Alas~a'Co~putln~ ~en~er 7-JUN-1995' 13.=56 3RD STRING ' PRODUCTION STRING ~E~a~K$: ~8HDO~ PAS8 FRO~' 10300 TO 10808~ $ $ **** FILE HEADER FILE NAME : EDIT ,001 SERVICE t ~bIC VER$IOi~ ~ 001C01 D~T~ ~ q5/06/ M~X R~C SIZE : 1024 FILE TYPE : LO LAST FILE : FILE HE~DER FILF NU~SER: 1 .' EDITED ~ERGED NAD Depth shifted and clipped curves; ali MAD-runs m'er~e~ using ear[test PasseS-.~. DEPTH INCREf4ENT; 0'50~00' ' ' . # FILE SUmmARY [,DWG TOOL CODE -START DEPTH ~,D'''''''''''''' ~'~0:. ;7'''''0 $ ~ERGED DATA SOURCE [,DWG TOOL CODE ~EMARKS~ NO DEPTH SHIFTS APPLIED,: $ LIS FORqAT DATA STOP DEPTH 10808,0 NAD RUN NO,. NAD PASS NO, MERGE..TOP mmmmmmm~mm.m mmmmmmmmmmmm m~mmm~ NERGE .BASE mm~mmm~mmm~m ** DATA FORMAT SPECIFICATION RECORD'** SET TYPE - 64EB ** .. TYPE REPR CODE VALUE 1 6~ 0 2 66 0 3 73 32' 4 66 1 5 6b 6 ~3 '.PAGE~ :,2 :LIS Tape Verification [,istlnq Schlumberger AlasKa Computing Center 7-dUN-I995 13~56 "PAGE.I TYPE REPP CODE VALUE wmm--m.--~m~.mg.wm~~~.~~-- 7 65 11 66 12 6~ 13 66 -0 14 65 FT 15 6~ 68 16 66 0 66 0 ** SET N~ $~RV UNIT DEPT FT G~ ~D GAPI ROP MUD FPHR RA ~D OHM~ RP ~wD OHMM DER MUD OHM~ VRA M~D OHMM TYPE - CHAN ** SERVICE API API APi API FILE NUMB NUMB SIZE 'REPR PROCESS ORDER # bOG TYPE CLASS MOD NUM-B.'iSAMP ELEM CODE '(HEX) mmmmmmmmmmmm.mmMmmmmmmm~.wmm~mmmmmm~mm~mmwm~mmmmN~mm~mm~mm~m~M~N O0 000 O0 0 1 ' .1 .! 4 -68 ~0000000000 O0 .OO0 O0 0 ! ! 1 4 68 0000000000 O0 000 O0 0 ! ! .! 4 '68 !O00OO00000 O0 000 O0 0 I 1' ! 4 .68 0000000000 O0 000 O0 0 I ! 1 4 68 '000~000000 O0 000 O0 O- ! ! 1 4 68 ..000000.0000 00 000 00 0 1 I ! 4 68 0000000000 VRP MUD 0HMM O0 000 O0 0 1. '1 · 1 4 68 0000000000 DATA DEPT. 10808.000 GR.MWD -99~ 250 AP.MUD -999.250 DER,MUD -99 .:250 D~PT. 10500.000 GA,MUD '.15.893 RP.MKD 5.656 DER.MWD 5,47 9 DEPT. 10279.000 GR.MWD 203.253 RP.MWD -999.~$0 DER.,MWD -999°250 END OF DATA 'ROP,.MWD .VRA',MWD R.OP.MWD VRA,:MWD ROP.~MWD ':. VRAi, MWD ':27-.600 AA,MUD --999..2'.50 VR.'P,MWD .. 0g VR.P.,MWD · '999..250 'R'A.NWD -999-...250 VRP,MWD '~99 4.,994 '5~222 ~999~:25-0. "'999~250 '3" bis Tape verification Listing Schlom~erper AlaSKa Computino Center 7-jUN-.lg95 13:56 **** FILE TRAILER 'FILE NAME : EDIT .001 SERVICE ~ FblC VERSIO~ : 001. C01 DAT~ = 95/06/ 7 MAX REC STZE : 1024 FIL~ TYPE : LO LAST FILE **** FILE HEADER FILE NAME : EDIT .002 SERVICE : F5IC DATE : 95/06/ 7 MAX REC SIZE : 1024 FIL~ TYPE : LO ~AST FILE FILE HEADER FILE NUMBER: 2 EDITED ~AD PASSES Dept~ s~ifted and clipped curves; for each pass Of each-run'In'.seParate-fi}es,.. MAD RUN NUMBER: 1 MAD PASS NUMBER: D~PTH INCREHENT: 0.5o00 , FIL~ SL~RY LDW(; TOOL CODE START D~PTH STOP OEPTH . ......... ......................... ~WD ~0279'0 I0808,0 $ BASELINE CURVE FOR SHIFTS~ CURVE SHIFT DATA (MEASURED DEPTH] ' ...... ---EQUIVALENT BASELINE DEPTH MWD ~E~ARKS: NO DEPT~ SHIFTS APPLIED, $ F[IR~AT DATA PAGE,, . LIS Tape verification Listing Schlumberger'AlasKa Computing Center ?-jUN-I-995 13;56 FORMAT SPECIFICATIO~ RECORD ** SET TYPE - 64EB TYPE REPR CODE V'AhUE 1 66 0 2 66 0 3 7~ 32 4 66 5 66. 6 73 7 65 ~ 65 I1 66 32 12 68 13 66 0 14 65 FT 15 66 68 16 66 .1 0 66 1 DEPT FT GR u~O GAP ROP MND FPH RA Nil) OHM RP ~o OHM DER ~D OHM VRA M~P OHM TYPE - CHAN ** SERVICE API AP1 AP1 AP1 FILE· NUMB 'NUMB 'SIZE "REPR' PROCESS" ORDER ~ ~OG TYPE CLASS NOD 'NUNB- SANP ELEM. .CODE ':(HEX). O0 o00 O0 0 2 .: '1 I 4 68 -0-000000000 O0 000 O0 0 2" I .-1 4 68 '0000000000 O0 000 O0 0 2 .'. ,i .1 4 68 0000000000 OO 000 O0 0 2.'. I 1 4 68. ~000000'0000 O0 000 00' 0 2 :' I .1 4 68 000'000'0000. O0 000 O0 0 2 '. i 1 4 68 0000000000 O0 00o O0 0 2' : 1 1 4 68 '000000.0000 oo ooo oo .oooooo. oooo. -:. ·. . ......... . . .. .. DATA DEPT, RP.~WD DEPT, RP,~WD DKPT. RP.~WD 10808.000 GR.~wD · g99.250 -999.250 DER.A~D i 99:250 10500.000 GR.H'~{D =Z5.893 5.656 DER.~WD 5:479. 10279.000 GR,~iWD 203,~53 -999.250 I)ER,NWD -999,250 ROP.MWD ' 'V. RA..'N'WP VRAe'NWD .. R'OP,MWD V.RA-*.MWD ..:27.,600 999.,.250 '~0.09 -999~.2.50 RA,~WD -999-,250 --999.2'$0 . "-999,2.50' -999,250 :5 ElS Taue Verification Llstlno $chlumberqer AlasKa ComputlnO Center ?-dUN-1995 ':6' **** FILE TRAILER FILE NAME I EDTT ,002 SERVICE : FbIC DAT~ ~ 95/06/ 7 MAX REC SIZE : 1024 ' FIL~ TYPE : LO LAST FILE SERVICE VERSIO~ ~ 00lC01 DATE : 95/06/ 7 MAX REC SIZE : 10~4 FIL~ TYPE : hAST FILE FILE HEADER FTLE NI.J~BER 3 R~W MAD ' · Curves and loO header data for each pass of:each run. in.separate files,- MAD RUN NUMBER: 1 MAD PASS NUMBERI 1 DEPTH INCREMENT: 0.5000 FILE SUmmARY VENDOR TOOL CODE START DEPTH 02 ~ 79'o $ LOG H~ADER DATA DATE LOGGED: SOFTWARE: SURFACE SOFT~ARE VERSION:. DOWNHO~E SOFTWARE VERSION= DATA TYPE (MEMORY or REAL-TI~E): TD DRILLER (FT)~ TOP [,O~ INTERVAL (FT)t BOTTO~ bOG INTERVAL (FT): git ROTATING SPEED HOLE INCLINATION (DEG) MI~IMU~ ANGLE: M~XIMU~ ANGLEI STOP DEPTH 10808,0 TOOl, STRING (TOP TO BOTTOM) VENDOR TOOb CODE TOOL TYPE CDR C MPENSATED RESISTIVITY $ .14.-AUG-94 ~E.~0RY :.10'.808,0 10'2~9,0. · ·10'7 .1.9,9 24,.2' 'TO'O~.N.U~BER RG.'$055' LIS Tape Verification Listing Schlumberger AlasKa COmputing Center ?-OUN-l'g95 13:56 .P, OREHUbE .AND CASING DATA DRILLERS CASING DEPTH (FT)~ BOREHOLE CONDITIOn, S MUD TYPE3 ~UD ~UD ~UD ~UD FBUI RES! DENSITY ~L~/G): VISCOSITY ES): PH3 CHLORIDES CPPM)~ D bOSS (C3): STXVITY COHM~) AT TEMPERATURE.CDEGF): LID AT MEASURED TEMPERATURE (MT): UD AT ~AX CIRCULATIONG TEMPERATURE UD FILTRATE AT (MT): UD CAKE AT (MT): NEUTRON TOOL ~ATRIX: ~AT~XX DENSITYg HO[,E CORRECTION TOOL STANDOFF (IN): ~WR FREQUENCY. CHZ): GR TO BIT: 21 65' RES TO' ~l $ ~S FORMAT DATA 8, 500 3532.0 10'.00 .1.,830 ~'910 0.000 DATA FORMAT SPECIFICATION RECORD SET T~PE - 64EB ** . TYPE REPR CODE VALUE i 66 0 2 66 0 3 73 28 4 66 1- 5 66 6 73 7 65 . 9 65 F. 11 66 36 12 68 13 66 0 14 65 ~T 72,0 o:o ..7 bis Tape verification Listing Schlumberger AlasKa Computino Center ?-dUN-1995 13;56 'PAGE{ .8. TYPE REPR CODE VALUE 15 6b 68 16 66 o 6b ** SET TYPE - CHAN ** - NA~ SERV UNIT SERV%CE APl AP! AP! APl FILE. NUMB NUMB' SIZE R.~P.R PROCE$~ ID ORDER # DEPT FT GR LN1 GAP! ROP~ L~I F/HR ROP LWI FPHR A?R Lwl OHM~ DER L~I OH~ bOG TYPE CLASS MOD'NUMB .'$AMP. 'EGEM CODE. ~(HEX') 00 000 00 0 3 .' 1 I 4 68 -0000000000 00 000 00 0 3 . 1 I 4. 68 0000000000 00 000 O0 0 3 ' 1 ! 4 68 ' -0000000000 00 000 00 0 3 1 ! 4 -68 0000000000 O0 000 O0 0" 3 .- I 1 4 68. :0000000000 00 000 00 0 3 i 1 4 '68 0000000000 00 000 00 0 3 · 1 I 4' 68 ' 0000000000~ ** DATA DEPT, 10808°000 ATR.[,~I -999.250 DEPT. 10500.000 ATR..LW1 4.994 DEPT. ~0279.000 ATR.LW1 -999.250 END OF DATA PSR,LW~ · 999:,250 GR'LW! ~5.893 PS~,LW! 5~656 GR.LWl 203,253 PSR.LWl -999..250 RO.pE.bW1 -301.949 ROP,~Wi DER..bWl - 99'9~.250 ROPE-,.-hW1 276.-535 ROP'LW1 DER+ibWi 5'479 ROPE&'.~W~ '999~250 R.O~..LW! DER,.bW! -9'99~'250 ' '~27.,.600 .67'500 **** FILE FILE NAME VERSION FIL~ T~PE ~a$T FILE TRAILER : EOIT ,003 : FblC : 001C01 : 95/06/ 7 : 1024 i' 5IS Tape Verification Listing Schlumberger Alaska Computln~ Center 7-dUN-1995 13:56 **** TAPE TRAILER ***~ DATE : 95/06/ 7 .. ORIGIN : wGIC TAPK NA,~E ! 94~8~ CONTIN[~ATION # : 1 PREVIOUS TAPE : COMMENT : ARCO AI, ASKA INC., pRUDHOE BAY, DS-D9-37, 50-029-2~451-00 DAIE : 95/06/ 7 ORIGIN : FblC REEL NA~E : g4~88 CONTINUATION # : -- P~EVIOUS REE~ : COM~E~!T : ARCO AbASKA INC., PRUDHOE BAY, .!. · PAGEI .: ALASKA cOHPuTXNG· CENTER ******************************** *-----'- .BOROUGH ~EFERENC~ NO. AR¢'O'.'Ab:AEKA,'XNC~ PRUDHOE.BAY. I.'AbASKA ~o-o~..~-~'S~.oo 9431 RECEIV'ED JAN O :~. 1o~95 LZS ?ape Verification I.,istJnO Schlumberger AlasKa Computing Center DITF : o4/11/ O~ICI~ ~ ~hlC CONTIMUATIO PREVIOUS COa,E~T : ARCO ALASKA INCo, PRUDHOE 8AY, DS 9'37I, 500292245i SERVICE N~t~ : ~DIT DATF : 94/11./ 7 T~PF. NAME : 9~19 " CON~I~UAT~ON ~ P~EVIOUS TAPE CO,~!E~T : ~RCO ALASKA INC., PRUDHOE BAY, DS 9'371,..5002922451 .CASED HO~E wIRELINE ~OGS w~b[, NA~E: APl N!.!MBE~I OPE~ATO~I ~OGCI~G CnMPA.Y~ TAP~ CRFATInN DATE: JOB NU~BEP: IUR=ACE DOC!TION FNL~ FEL~ ~E~IC~ GROUWD bEV~b: WFb!, CASING REC~RO ST~ING STRING ST~IMG PRODUCTInN STRING 5002-92245~00' -. ARCO ALASKA-.'INC' SCHLU~B.ERGER WELL'SERVICES 5-0C~-94. 9431'9 ?, ~E~T 1 ION 201 4.~62 46, 30 ' 45,30 20,70 .- OPE~ ,OCE CASING DRibbZR6.:'....C.ASX~O. BIT SIZE (IN) .3XZE 1~,750 ..:28,0 45,i50 ,625 .3531'0 40'00 -5.5oo Io o ,0 1.? oo SHIRT DATA - ALB PASSES TO STANDARD(MEASURED DEPTH) LIS maue verification Listinq $chlumberqer AlasK8 ComputlnO Center EASEL1ME CURVE FOR SHIFTS bo~ ?Onb CoD~{ ~ CURVE ~0~ P~S~ ~U~BER: DATE LO,GED: LOG~IWG CO~PANY: --=--=----~OUIVALE~T UNSHIFTED DEPTH---''"----. PA~ELINE ORPTH ~ " ~E.ARKS: NO DEPTH SHIFTING. TO OPEN H.ObE GR ~ER':JOHN P.IE. RC~ ~.ARCO NO wIRELI~E UR LOGS ( MWD RAN .BY SCHbUM. BERGER),' $ FILw NA~E : ~DTT ,001 SFRVICE = FblC VFRSION = O01COI DATw : 94/1)/ 7 MAX REC SIZE : 10~4 FTL~ TYOE = 50 L~S· WlI, E : F~bF ~EADER " eu.v s ' ' Depth snitte~ and cllPoed curves-~or each pasS.i'n-seParate.:~iles,~ LDWG TOOl, CODE START DEPT~ STOp. DEPT~ CRC~ lO~bO,O 10300,0 -.. CNTG 1.0672,0 10300,0 CURVE SHI~T DATA - PASS TO PASS(MEA$URED. DEPTH} nASELI~E CURVE FOR SHIFTS bDWG CURV~ CODE: PASS ~U~BER= # ----------EQUIVALENT UNSHIFTED .ASEI, I~E DFPTH ~E~A~K$= THIS FILE CONTAIN8 PASS #1 OF THE CNTG,.'-NO.PAss:~O PASS SHIRTS WERE APPLIED TO THIS'DA'TR,= '' ' '' ' .- LIS Tape Yeriftcatlon Listing Schlumberger Alaska Computing Center PAGE] # LTS FOR.7',~AT r~ATA DATA FORMAT SPECIFICATION RECORD ** SET TYPE TYPE R~PR COPE VALUE I 66 0 2 66 3 73 4 66 5 66 6 73 7 65 8 68 9 65 11 · 66 17 68 13 66 14 65 1~ ~6 0 66 0 64 ! 0 FT 0 ** SET VYPE - C.HAN ** ., .... NAaF SFRV UNIT SERVICF AP1 AP! AP'I AP! FIbE NUMB 'NUMB.. 'SI~E''.'REPR PROCESS ID ORDE~ # LOG TYPE CbA&8 ~OO NUMB ,'$AMP'= .EbEM "., ..'.'CODE ...... (HEX.} DKPT FT 619044 O0 000 00 NUHT CN~G PU-8 619044 00 000 O0 EMPH C~TG PU-S 619044 00 000 00 CPHT' CNTG PU-$ 619044 00 O00 00 NRAT CNTG 619044 00 000 00 CART C~TG 619044 00 000 O0 ENR~ CNTG 610044 O0 000 O0 NCN~ C~TG CPS 619044 O0 000 O0 FCNT CNTG CPS ~1O044 00 000 00 CFTC C~TG CPS 619044 00 000 00 CNTC CNTG CPS ~19044 00 000 00 CFEC CNTG CPS 610044 00 0O0 00 CNEC C~TG CPS 619044 00 000 00 GPCH C~TG GAPI RIO044 O0 000 .00 bB 619044 O0 000 O0 V 61904-4 O0 000 O0 TFNS C~TG · COL CNTG .... . O0 1 0 I :. 0 1 ! 0 1 I- 0 I.. 0 1 '" 1 0 .1" 1. 0 1 .' 1 0 1 ' ..t. 0 .1. ! 0 1 0 t 0 ! 0 I 1 o. 1.. 1' 1 4 '. '! 4 I 4' .1 4 t. 4 1 4 ! ,4' 1 4. · ! 4 i' 4 1.,. ..4 68 .68 68 ' 6..8 68 6.8 .68. ".6'8 68 -68' .. · 0000000000. 0'000000000. 0000000000' 000000.0000 .000000'00.00 0000000000 000000.0000 0000000000 0000000000 0000000000 000000000.0 0000000000 0000000000 0000000.000 .0000000000 0000000000..- tis ~.ape Verificati. on Listing Schlumberger AlasKa Computi. no Center DEPT. 10672.o00 NRAT.CNTG 3.200 FCN~.C~TG 543.6~$ C~£C.C~TG ~7~0.7~7 CNaT.CNT~ CFTC.CNT~ NPHI..CNTG CHAT.CHUG CFTC.'CNTG GRCH.CNTG NPHI..CNTG CRRT.o. CNTG CFTC,CNTG GRCHeCNTG NPHI-.CHT~ CRAT°CNT~ CFTC.C~T~ GRCH.CNT~ DEPt. 10600.000 N~T.C~G 2.8~0 FCNT.C,.TG 7o4.97~ CNEC.CN'TG D~FT. 10400.900 N~AT.CNTG 2.728 FCNT.CaTG 6~3.646 .C~EC.CNTG 9~11.013' DEPT. 10300.000 NRAT.CNTG 3.~16 FCNT.Ca~G 473.618 Ca~EC.CNTG ~761.6~ EMD OF DATA FILF ~A~E : ~DIT .001 SrRVICE : FDIC VFRSION : O0~.CO! DATE : 94/11/ 7 MAX R~C SlZ~ ~ 1024 FILF TYPE : LO L~$T FILE : FTLF ~A~E : EDIT ,002 MMRVlCE ~ WLIC ¥~R$IO~ : n01. COl DaT~ : 94/11/ 7 ~X REC STZ~ : 10~4 FIL~ TYPE ~ LO LR$~ FILE 30.609 3.082 600.112 -g99..250 2:871 7~3-259 29.797 24'770 ~ 39.7 3.-5~61 463.236 144,000 ENPMVCNTG ENRA.,.CNTG CNTC'-CNTG ENPH*.CNTG ENRR,CN~G CN?C-~CNTG.. 'EN~H,CNTG CNTC{C.NTG. TEM$eCNTG '..ENPHgCNTG. "-ENRA{:CNT~ TENS~:CNTG .t762.,.05 '556,..94 ' '-0~00~ :206t.~.-7.39 -0',0'85 902 'o$~ ~525.,646' "514-',7.47 ":'.'-0'.007 FILe HEADER EDITED CUPVES DePth shifted amd clipped curves DFP?H I~CPE~ENT: 0,5000 for each mass .seParate'. Tape verI~Icatlo~ ~,istino $chlum~eTq~gA.tasKa ~o~utInO CenteT CODE STA. Rm DEPTH CNTG 10672..o $ · STOP DEPTH I0300..0 .10~00,0 # PASELINE CURVE FOR SHIRTS ' LD~G CURV~ CODE~ GRCH ~ASE[,I~E DEPTH ~8888.n 1066~,5 10663.5 1066~.~ 1065q.5 10639,5 !0635,5 10634,5 1.0631.5 10630.5 10627,5 106~6.5 10623.S !0610.5 ~0607.5 1.0606,5 1.0603.5 10602.~ 10599.5 10595.5 !0591.5 10587.5 10578,~ ~0574,5 ~0571,5 0570,5 ..0567,5 1.0566,5 1.,0563.~ ~0551.5 10547.5 1.054] 5 1.0542.5 ~0539,5 !0538.5 10535.5 10534,5 10531'5 10527:5 ------=---EOUIVA[,ENT UNSHIFT~D ' ' 1066710 10662.0 10662.5 10659.5' 106~9.5 10635,,0 10634.5 10631-5 10630.0 10627.5 10626.5 10623.0 10610.5 10607,0 10606o0 10603,,5 1060~.5 10599,0 10595,5 10591,5' 1055~.0 10578.5 10574,0 10S70,0 10566.5 1.054~.5 10538.0 1.0534,~ 10571,0 10566,5 10563.0 1.0551o. 0 1054 ,0 10543,.5 10539,.0 10535..5 10532,0 10527.5 DEPTH'".'''--.-'- bis ~aoe Verification bisttno Schlumberoer A].asKa Comput(rO Center '7.-k{OV-1.994' 18124 # bTS 10523.9 10519,5 1.011!.,5 10510,5 10510.S 10507.$ 10506.5 10506.O 10503,5 10502,5 1.0502,5' 1049q,5 10495,5 10471.5 10467,5 10463,5 10450.5 10447,5 10443,5 1043q,5 10438.5 10438.5 10435o5 10434,5 1.0434,0 10431,5 1.0407,5 10406,5 10406.0 10403.5 10402,5 10402,5 10395.5 1039!.,5 10390.~ 10390.5 lo387,5 ' 10386.5 10386,0 10383,5 1.038~,5 10382.5 10379,5 10363.5 10.350,5 1035R,5 10355,5 1.0354.5 10354.0 10351,5 1.0350,~ 10351.0 10347,5 10346,5 10346,5 30323,5 t. 00.0 100,0 10523.0 1051 5 10511,5 105U?.O 10503.0 10498 5 10495.~ 10471 10467 0 10463 0 10459 5 10447 5 10443 0 10439 5 10435,O 1043i.5 10407,5 10403,0 1039~.0 10391,~ 10387'.0 10383.0 lo37 .s 10363,5 ~0359,0 10355,:5 10351.5 10347,0 10323.5 100.0 TuIS ~LE COa?AI:NS PASS #2 OF THE CNTo. :THE-.:DEPTH · CORr~EC~[O~$ SHO~N ABOVE.' REFLECT .PASS ~2..GRCH" TO. PASS G~CH AHD PASG ~2 ~NPH TO PASS ~1. 'ENP. H'.'A.b-b OTHER CNTG CI.IRVES ~JERE CARRIED wITH THE-.ENPH .SHIFTS.,. '" FOR~AT ~ATA bi8 Ta~e Veriftcation Llstino Schlumberger AlasKa Computind Center TYPE REPP CODE VabUE ! 66 0 2 66 0 3 73 64 4 66 ! 5 66 6 73 7 65 I! 66 1~ 1~ 68 1] 66 0 14 65 FT 15 66 68 16 66 1 0 66 I SET TYPE - CHAN ** ." ,.. . ......... . ... .. ..... .. . . . .. . ~RDER # bOG TYPE CLASS MOD NUMB ."$AMP.'.-. ~b~M -,' ........ -~.'CODE -.'.(HEX.) F? 610044 nO 000 O0 '0 ~ 1' i 4 aa 0000000000 0000000000 DEPT NPHT CN~G ENpN CN~G CPHT CN~G NWAT CNTG CRAT CNTG E~RA CNTG NCNT CHTG FCNT C~TG CFTC CNTG CMTC CN~G CFEC CNTG P{.!-S 619044 O0 PU-S'610044 O0 PU-S 619044 O0 610044 O0 619044 O0 619044 O0 CPS 619044 00 CP$ 619044 O0 CPS 619044 O0 CPS 61o044 O0 000 O0 000 O0 000. O0 000 O0 0o0 O0 000 00- 000 O0 000 O0 000 O0 000 O0 O' '2 0 0 2 o 2 0 2 0 2 < 1 0 1~ I .... 0 2 1.-- 0 2 ..- 1 1 1 1 I' I ~... , 4 4 4 4 4 4 .4 4 4 68 .68 68 68 '00'0~000000 000 000000 000000.0000 000'0.000'000 0000000000 .000-0000000 :000000000.0 0000.00:00.0'0 0000000'000 CPS 619044 O0 0.00 O0 · 0 2 ' 1' 1 ' 4 ~g 000000'0'000 C~EC CNTG CPS 619044 oo 000 O0 0 ..'.2 1' '1 4 6~ -0000000'000 GRC~ CNTG GAPT 619044 O0 000 O0 -0 2 1 I 4. 68 0000000000 T~$ C~vTG LB fi19044 O0 000 O0 O' 2 ': 1 '1 4 6'8 .'0000000000 CCL CNTG V 619044 O0 000 O0 O. :2 .- 1~. 'l ' ...4 .... 68' .000000000.0 i' LIS Tape Veri~lcation tistin~ Schlumberger laska Computing Center DEP'r 10672.000 NPH~..CNTG NRA?'C~VG 3.146 CRAT.CNTG FC~T'CNTG 540.107 CF'~C.CNT~ CNEC:CNTG 2867.5?6 GRCH~CNTC, D~PT. lOb00.O00 NPHI.C'NTG NRA~.CNmG 2.8~4 CR~T,CN~G FCN~ CNTG 6~9.500 CFTCoCNTG C~EC:CNTG ~9~.5~6 GRCH.CNTG DEPT. 10400.000 NPH1,CNTG NRAT..CNTG 2~817 CRAT,CNTG FCN~.CNTG b49o026 CFTC'CNTG C~EC.CNTG 2~.102 ~RCH.CNTG DFPT. 10300,000 NPHI.-CNTG N~AT.CNTG 3*573 CR.AT'CNTG FCNT.CNTG 4~2,560 CFTC,CNT~ CNEC.CNTG 2771.005 CRCH,CWTG ** En)D OF DA~A ** F~LF ,A~E : ~DIT .002 VERSION : 001C01 DATF : 94/1~/ 7 N~X R~C SIZ~ : 102~ .F~L~ TYPE : LO L~$~ FILE ~ F~5F NA~E :'EDIT .003 $~RVlCE : VERSION ~ OOl. CO1 DAT? : O4/ll/ 7 M~X REC $~Z~ : 1024 FTL~ TYUE : LO b~S? FILE .. 7=N. OV-1.994 1'8 {24 .... '5~2;'88_ NCNT--,CNT:'G. 3225:,·000 CC~,eCNT·G: · 799 '.-ENRAiCNTG. .4,.{62 NCNT-.'CN?G' 762,906 :CNTC~..CNTG 212.7e391 .C~EC CN?G' '31.875 {'.?ENS'.~:CN?G 2958~344 'CCL CNTG .: . . -25.943 ~NPH,.CNTG :30,218 CPHI:.CNTG. · 2'g2-6 :-.ENRA~.C~TG ..4.,-683 NCN~ CNTG. 7~3..350 '~;CN?C$CNTG .:.2036*3.'85 CrEC 23..62s 28.85.000 '.cc 40.270 :':ENPH.i~N?G 36;.SSS CP.H~.-;CNTG' 3..6. 468...2~ ..ENRA.'CNTG- 5,335 HCN?,CH?G. 46..ooo 'TE S' ¢ XG 725 0'0 ':~-0..~007 .--.0,,054 i9.65-e49 602',~58 0..~088 · ~ 0:~! FILF NU~BERi 3 . EDITED CURVES ........ neuth shlited and cl~p~ed curves for each Pass ~n .Sepa.rate"~iles',~' P~SS NUmBS. RI 3 D~PTH INCREMENT: 0.5000 : F~Lw SU~NARY verification r, lstlno :.!iSehlumberqer Alaska Computtn~ Center 7-NOV-lg94 18:24 LD~C RASEL1N 10667,5 1066],5 1.0669,5 !0659.$ 1065~.5 10654,9 1O65O.5 10646,5 1064~.5 ~064g,5 ~063q,5 10635,~ ~061~.5 i0611,5 i0607,5 10603,5 ]0599,5 10595,~ 1.0582.5 10579 5 10575 5 ~0570 ~ 10567 5 10566 5 10~63 5 10567 5 10559 5 1054~ 5 10539 5 10~3~,5 10527,5 1052~,5 1.0~19.5 10515,5 0487,~ 0486.5 ~.0483,5 START DEPTH STOP DEPTH 0660.0 103'00,0 {067~.0 10300,0 DEPTH PASS TO PASS(MEASURED DEPTH] FOR G~IFTS CURVE CODE= GRCH ~U~DER: 1 GRCH CNTG 88887,5 t0667,0 1066~,5 1.0659,0 10654,5 10651.0 10647'0 1064~.K 10586.5 10571,0 t0566.5 10563,0 10543.0 10538,5 10486.5 ~0660.0 10644,0 10639,5 10635°5 10632,0 10616,0 10612"5 10608,0 106.04 ~ 10599~- 10595.5 10579,0 10575°5 10567,5 10564.0 10559,5 10539.5 10536,0 10528:~ 1052.3 .. 10516 10488 10483,~ UNSHZFTED. DEPTH-,,,'',,,,. bZ$ Ta~e VertftCatlon Listing $~hlUmberqerA!as,Ka Computing Center 1.0482 5 10483.0 ~0467.~ ~0463,~ 1045q,5 ~0454o5 104§5,0 ]0450.5 t0450.5 10446.5 10447,0 ~0443o5 10442,5 10442,5 !043q,5 10435.5 1043t.5 10415,5 10411.5 10406.5 10406.5 10402,5 10403o0 1.0395.5 10391,$ 10387,5 10386,5 !0387,0 10383,5 10382,5 10382,5 ]037~.5 ~037g.0 {0375,5 ..037t,5 10~5~.5 10359.0 10354.5 10354,5 1035].5 10350.5 1035i.0 10347.5 10327.5 10323,5 1031q,5 10311.~ lOn. O 100.5 I0467,5 10464.o 10459'5 10443.5 10440 0 10435 0 10432 0 10416 0 10411 5 10395'5 10391.0 10387,5 1.0384,0 0376 . 10351,5 10347,8 '10326':. 10323.5" 10319'5 10312.0 100"5 THIS VlbE CON?AINS.PAS$"#3 OF A~OVE, REFbECT P.AI$'.#i...'ORCH'~.O PASS:-# GRcHCOR~ECTIONSAND PAssSHOWN£NPH.TO#3 PAS& .#! ENPH~."Abb OIHER..CNIG.- 1 CURVES WERE CRRRIED"WITH THE $ DA?A } · Tape Vertflcatlon I,lstinq Schlumberger AlaSka Computin~ Center DATA FORMAT SPECIFICATION RECORD. ** ** SET TYPE - 64E8 ** ?=~OV'1~994 18124 TYPE .R~P~ CODE VAbUE... mmm~mm~m~mmmmmmm~mmmm~'~mm~mmm I 66 0 2 66 0 3 73 64 4 66 1 5 66 6 73 7 65 g 65 · 11. 66 12 68 13 66 0 14 65 FT 15 66 68 16 66 0 66 -1 mmmmmmmmmm,mmmmmmm, mmm~mmm~'~mm~m~ ** SET TYPE - CHAN *~ . . , .. . ....... ' ........ :' · ....... · ............. TD ''' ORDER # bOG TYPE CbAS$ MOD. NUMB..$AMP .... EbEM.' .- ' ..... CODE... .'.'.(HEX) mmmmmmmmmmmmmm mm DKPT ' FT 61q044 O0 000 00 0 3 ~-' i .' i 4 68. '' O.000.000'000 NDH! CNTG PU-$ 619044 O0 000 00 0 3 .'.! 2 · 4 .68 .0.000000000" ENPH CNTG PU-S 619044 O0 000 O0 0 3 1 .1 4 68 0000000000' CPM? C.NTG PU-$ 619044 O0 000 00 0. 3 I ! 4 68 .000'0.000000 NRAT CNTG 619044 O0 000 O0 0 ' 3 I { 4 68 .0.000000'000 CRAT ¢~TG 619044 O0 000 O0 0 3 ! 2- . 4 " 68 00000'0'0..'000 .E~R~ CNTG 619044 00 000. 00' '0 3 .! I 4 68. .00.00'00'0000 NCNT CNTG CPS 619044 O0 000 O0 0 :3 ':I ! 4 68 O'O00000000.. FCNT C~TG CPS 619044 O0 000 O0 0 ':3 : 1 ! 4 68 00000.0'0.000. CFTC CNTG CPS 619044 00 000 00 0' 3. , 1- 1. 4 68 -00000.0'0000' C~TC CgTG CPS 619044 O0 000 O0 0 3 1" i 4 68 '000'0000:000 CFtC CNTG CPS 619044 00 000 00 0 3 ' 1' 1 4 68 .'0000.000000 CNEC CNTG CPS 619044 00 000 00 0 . 3 ";1' ! 4 68 -.000000'0'000 G~C~ C~'TG GAPI 6190.44 00 000 00 0' 3 ::1..' I 4 68 .0000000'000 TENS CNTG LB 61q044 00 000 O0 0 3 '1 1. 4 .~8 -0000000000 CCL CNTG V 619044 00 000 00. 0 3 'i/ :'1:~ --I- .~4 68 -. -00000:O0.000 .. .. DATA DEPT.. 10672.000 ~P~I"CN~G NWAT.CNTG 3.095 CRAT.eCNTG FCN~.CNTG ' 483.174 CFTC,CNTG CMEC,CNTG ~868.267 GRCH.CNTG .. .578 :;CNTC¢.CN?G. -99'9..2'50 .~?ENS,-:C~T~. ' 35.608 '. CPHT..-:.,,¢N'rG... · - "5,'.215 NC'NT.CNTG I."/.05~.200 1804.,..633 CF.E.C,CN?G- '549~9'8.1 31.30o:000 CCb,-CNTG .. bis ?ama Vertflcett. on Llstlno Seh[umberqer AlasKa Computtnq Center D[PT. 10600.000 NPHI.Ct~TG N~AT.CNTG 2.944 CRAT.CNTG FCNT.CNTG bO0.a67 CFTC,'CNTG CNEC,CNTG 2870.188 GRCH,CNTG DFPT. 10400.000 NPHI,CNTG N~A~.CNTG 2.91.2 CRRT.,CNTG FCNT.C~TG b~0.271 CFTC.CNTG CNEC.CNTG ~818.772 GRCH.CNTG END Cr DATA ~*~* F'TL~ TRAILER **** FILF ~;A~ I EDIT .003 SFRVICE : rbTC VER~IO~ : oo~co1 DATF : 94/1~/ 7 NaX AEC SIZE : t024 **** FILE HEADER **** FILF NA,E : EDIT .004 SERVICE : FblC VFR~IO~ : O01COI DaT~ ~,q4/11/ 7 ~AX EEC SIZF : 1024 FIL~ TYPE ~ LO LAST FILE : .27,377 2.904 EN'RA~CNTG 758 188 CNTC~CNTG 32~' 44 .'TENS~C.NTG. . 26. 54 '~NPH:~CNTG ' '2.~76 '--£NRA*-C~TG 72 92 ' :.-CNTC.~CN?G 97 ~TENS~C~TG .. 38 .. 9.t ! !" EN~H*.CNTG 3-5.37 >E.N..A-gCNTGR 7~608 -CN?C'~CN?O ,2900, 983 CPH'{:i,CNTG' 65.9 NCNT~CN. TG 594 'CPE~ CNTG. ~O00 -C'Cb.CNTG,' 5 -CPHI .C~C · ~CNTG.. ~CNTG. :C'NTG.. C~'t:G..' :206~.~8..~- :61-6'~0'.3~. '-o~.oi6 .~925,'4¢1 .6'~..t~.¢356 '."0:*002 1529.0i 'S0'0¢6.0~ -~"o-..024 FIb~ ~U~B~R= 4 AVE"A~ED CU"VE$ .: ' Com~ensate~ ,eutron: Arithmetic average o~aedite.d-P'aSS'es.:'.Zor. all-curves:, .' ..... Pulseo ~ieutron= unaveraqed edtted.,-Pas$ 1. m'ma Ray and..-'uaekroUnd'co'unts"l.'"a:r[t'hme't[C.~aveta, g.e~ et edited static baseline Passes ~or a[1 o~he.r curves... · PASSES TNCLUDED I~I AVERAGE [,DWG TOOL CODE PASS NU~RERS '"'"'""' 1, 2, 3~ : ~;SChl,mberqer AlasKa Computt. nq Center .. · . . his FO~AT BATh · . DATA FORMAT SPECIFICATION RECORD SET TYPE - 54EB ** ?'¥PE ~P~ CODE VALUE. mmmmmwmmmmmmmmmmmmmmmmm~mmmmMm I 6b 0 2 66 0 ~ 66 ! 5 66 b 7 65 9 65 It 66 16 12 68 13 66 0 14 65 15 66 68 16 66 0 66 mmmmm~mlmmmmmmmMmmm~m~m#m~mmmm' ** SET TYPE - CHAN ** ~: · .. ,.. .... . ., .. .... .... . .' . . NANF SFRV UNIT SERVICE API APT APl API.'FIbE NUMB NUMB .:S~ZE."REPR ·PROC·ESS·. ~D ORDER # bOG TYPE CLASS MOD NUMB SAMP.. -EbEM ........... ·CODE·. ...... ..-(HEX):. . . DFp~ FT 619044 O0 000 O0 0 . 4 NPHT CNA'V PU-S 619044 O0 000. O0 0 4 N~A~ CNAV 619044 O0 000' O0 0 4 ; CPHT CNAV PU-$ 619044 O0 000 O0 0 4' C~A? CNAV 619044 O0 000 O0 0 4 E~P~~ C~;AV PU-$ 619044 O0 000 O0 0 4 E~RA C~AV 61~044 O0 000 O0 0 4 NCNq' CNAV CPS 619044 O0 000 O0 0 ' 4 FCNT CNAV CPS 619044 O0 000 O0 0 4 CFTC CNAV CPS 619044 O0 000 0'0 0 4 C~TC CNAV CP~ 61q044 O0 000 O0 0 4 CFEC CNAV CPS 619044 O0 000 O0 0 4 C~Ee.CN~V CPS 619044 O0 000 O0 0 4. G~C~ C~AV GAPI 619044 O0 000 O0 0 4 TFN$ CNAV b~ 619044 O0 000 O0 0 4 .! .1 . I 1 I ! 1' 1 I 1 1 I 1 ! 4 4 4. 4 '. 4 4 4 4 4 4 4 4 '4 4 4 68 00'00000000 68 000'00000.0.0 B 00'0'000000"0 8' 000000.000'0- 68 000000.0-00.0 68 -0000000000 68' '.000.0000000 'i'~ 000.0000000' 0000000000 6-8 00'000000'00 68 0000000000 6.8 00'00000000 68 0000000000 6'8 0.0-00000000 '68" 00000000.00 ID ~RDE~ ~ LOG TYPE CLASS MOD NUMB SAM. P -ELEM . ·CODE· · · :(HEX).. · .cc~ ~,~ ~ ~o~ oo ooo oo 2 ~ .:.~ ~' ~... :~.',..oooooooooo .. DATA, D.r-.t:'?. 1 Ob 72.000 .mNRATI*CNAV C~A?.C~AV 3. 144 ENRA,-CNAV FCN?,.C. NAV 522,337 'CNTC-~'CNAV' CJuEC,.CNAV 283B.5~3 'TE.N$.~'-C..NAV · D~P?. 10600,000 C~A~.CIVAV 2,BSB FCN? CNAV 698 376 C~EC' ' .CNAV 2902.600 D~PT. 10400.000 CmAT.C~AV 2oB21 FC~T.C~AV b64o248 CNEC.CNAV 2816,6~1 DEPT. 10300,000 C~AT.CNAV 3.576 FC~?.C~V 42~.3~7 C~{EC.CN~V 276 .3~8 ** E~D OF OATA ** NPHI.,CNAV ENPH..CNAV FTC$CNAV RCH,CNAV NPH ,C-~AV ENP~.CNAV CFTC.~CNAV GRCH.C~AV ~!PHI,CNAV ENDH.CNAV CFTC,CNAV GRCHoCNAV NPHI CNAV CF?C,CNAV GRCH.C~AV **** FILE T~AILE~ **** FILF ~A~E ~ EDIT .004 D.AT~ : q4/11/ 7 MAX RFC $IZ~ : 1024 FTLw TYPE : LO LAST FILE : 31,744 .35,094 582,t87 -g99,250 '26..536 '30-955 76'1.3'75 '3~35 25.853 -2g.,B82 731~'.5.3.6 '.2].9'09 ..'~9-,629. 7,580 46g~658 .145-027 NRAT.~.CNAV ENRA*..CNAV CN.TC~C'NAV TE.NS;~.:CNAV ENRA.~CNAV .CNTC~.'.CMAV /'.CNTC*.CNAV ?~ENS'*C~AV · ~. 1'4.7 CPHX.:.* CNA V 5~i65 .1B0.5-302 CFEC..CNAV. -' 4:~7"5.8 NCNT:.'CNAV "2,825 ..-..4,649 .2846,'3.82 ..~.~.:~o~ CpHI·.'CNAV NCNT.C'NAV CFEC,CNAV CCL:.,CNAV: CPHi..CNAV NCNT,-CNAV CFEC-'~'CNAV CCL,CNAV FILF NAME : EDTT .005 S~RVICE : FLIC V£RSION : ~0!C01 DAT? i ,94/11./ 7 ~AX REC STZE : 1024 FIL~ TYPE : LO LAS? FILE ~ t, 18 Ta~e Verification Llstino $chlumbercer AlasKa Co~putina Center :. '?-,OV'lgg4' ~ 8="24 PASS NUMBER= 1 DFPTH I~CREME~{Tm ~)L~ SUMMARY VENDOR ToOL CODE START DEPTH CNTG ~OG HFADE~ DATA ... FILE HEADER RAW CURVES Curves and log header data.for each pass in separate -: · STOP. PEPTH. 10294,9 DATE LOGGED= SOFTWARE mIME LOGGER ON TD D~ILLER TD LOGGE~(FT)~ TOP LOG INTE~VA~ (FT)~ ROTTO~ LOG IMTERVAL (FT)= DEPTH CONTROL USED (YES/NO)~ TOOL STqING (TOP ~0 BOTTOH) VFNDO~ TOOL CODE TOOL TYPE C~T~ C~TG C~TG C~TG C~T~ C~TG nOREHOLE A~D CASING ~ATA DRILLERS CASING DEPTH LOGGERS CASING DEPTH ~OREHOLE CONDITIOM~ FLUID TYP~= FLUID DENSITY (DB/G)= . SURFACE TEMPERATURE (DEGF)= BOTTOM HOLE TEMPERATURE (DEGF): FLOID S~b?NITY ~b[.~ID bEVEL (FT)~ FLUID RATE AT ~!FLLH~AD fBPN)g ~aTMR CUTS (PCT): GAS/OTb RaTIOm ~EU~ROM, TOOL TOOt, TYPE (~PITHE~Ab O~ COLLA~.LOCATOR TELEHETRY CARTRIDGE' GAM~A RAY COHPE,SAT~D ~EUTRON 7'AUG-94 -.144'7 '-27"" .AUG'94 .'..'1.06'75-,0 .103'00'.:'0" ...-2500.-.:0 CA'.~.-...¥A.229 · '--TCC':B 8 59 '::..S¢.~...-SA.40 !-CN.'G 1.25 "~EX' CB"C86 CBS 160 ..... .. ~r'ound Pas. s'.tn iasc bls Tane verificatlon T, istino Schlumberger Alaska Computing Center , .. ~:.'$ANDSTONE.. ~T~IX ~E~$~Y~ 2.65 . TOP NOP~RbTZING WINDOW BASE NOR~AL, IZING WINDOW (FT)~ RLUE[,INE COUNT RATE SCA~E$ SET BY FIEbD ENGINEER rA~ COUNT RATE LOW SCALE (CPS)t ' ~"' mAR COUNT RATE HIGH SCRb~ N~RR COUNT RRT~ LOW SCAL~ ~EAR COUNT RaT~ HIgH SCALE TOOL STA~DOFF (IN)~ R~RK$~ TEE-IN SWS LWD CDR DATED LOG DEPTH DRIFTS WRT:THE CDR TOWAR'DjTHE ,BOTTO.M, WAS TIED-IN AT THE CENTER'OF THE .E',~PECT£D.'PERFS ~0'600',"' bOG RUN' BEFOR~ WE.Lb WAS PERFORATED* FnR~AT nATA ** OATA FORMAT SPECIFICATION RECO~D ** ** SET TYPE - 64EB ** -' TYPE .REPa CODE ..VALUE 1 66 0 2 66 0 3 '73 76 4 66 ! 5 66 6 73 7 65 8 68 0.5 1! 66 12 68 13 '66 0 14 65 FT' 15 66 68 16 66 0 66 t. LIS Tape verification I,istlno .,Schlumberger Alaska Computing Center :., ..{ :.. NR~r S~RV U~IT ~EPVlC~ .APl AP! APl APZ FIbE NUMB NUNB '8ZZE REPR PROCESS ~D ORDE~ # bOG TYP~ CLASS MOD'NUMB '$A~P.: ELEN.. CODE, (HEX) ....... ' O~P~ rT K1~044 O0 000 O0 0 5 l" ! 4' 68 0000000000 ENP~ PS! PU 619044 O0 0~0 O0 0 '5 I I 4. 68 0-0000000'00 ENRa PSi 610044 O0 000 O0 0 5 i- .1 4 6.8 0000000000 CFEC PS1 CPS 619044 O0 000 O0 0 5 1 I 4 68 0000000'000 CNEC PSi. CPS 619044 O0 000 O0 0 ~ 1' I 4' 68 0000000000 RCE~ P~l CP~ ~1q044 O0 000 O0 0 5' 1- .1 4 6.8 .0-0000.00000 RCE~ P~! CPS 619044 O0 000 O0 0 5' I'. I 4 68 .0000000000 NPHT PS1 PU 6190~4 O0 000 O0 0 5 I :I' 4. 68 . - 00000'000.0 TNP~ PSi PU 619044 O0 000 O0 .0 5 .1 I 4" ..6~ ' 00000000 0 T~R~ PSi 619044 O0 000 O0 0 5 .1 I 4' '68 "000.0000000 RTN~ P&I 619044 O0 000 O0 0 5 1.. I 4' ' '68 '0000000000 NPOR PSi PU 619044 O0 000 O0 0 5 l- I 4 68 ."0000'00'0000 RCNT PSi CPS 619044 O0 000 O0 0 5' I 1 4 68 0000.000'0~0 RCF~ PSi CP~ 619044 O0 00'0 00' 0 5 I ! 4 68 '0000000.0 0 CNTC PS1 CPS 619044 O0 000 O0 0 5 1 .1 4 68 0000000'000 CFTC PSi CPS 619044 O0 000 O0 0 5" 1' 1 .4' 68 -0000000'000 GR P~l GAPI 619044 O0 000 00' 0 5 't- -! 4' 68 '00'00.000.000 TENS PSi. bB 619044 O0 000 O0 0 5 1. 1 '4' '68 0000000000 CCh PSi V 619044 O0 00'0. 00' 0 5 .' 1:- .1 ...... 4 ..... 6'8'. '00'00'000:000 ,. ~* DATA ** ': PEpT. 10688 ~8 ~NPH'PSI .~3'182 ;":E'NRA~PsI.' RC~F',.P$i '5'.'6.',-']64 '".RC~N~!P$1' · ' ':¢NTC~P$1 1'764.*.6'66 RCN? PSi 1690 ~i{ RCFT,P81 G~.PS] 74 TENS*PS1 2370,000 -'..CC.L:~P$1 .'-0~007 DEP? 10600.000 8NPH:*PSi .30-91'! ENRA~PS1 ---'4-754 CFEC~pS! C~EC:PS! 2914.966 RCEF.*PS1 -596-,i- 0 :.'RCEN~:PSI. T~PH PSi 23,567 TNRA'iPSl 8~1 .28!e+?0'4 ReNT PSi 206i,739 ~CFT:5'PS1 -70.~11971 .'CNTC~PSI- "2i. 4~ NP'OR-*:PS! · - · . · ,!..3~ -CFTC*PS1 G~.PS! 29.?q? TENS,PS1 .28351,:000- ~ CCb~P81- '0..095'. D~PT. 10400.000 ENPHiPSi .29.'920 ENRA~pS.I.. 4~.6'53 C~EC..~P~I C~EC.P&I. 2811,013 RC~F~P$1 591:,.5.03 ;!RCEN~:PS.I 2730*'568 NPHI~P$1. T~PH.P$1 ~t.902 TNRA'P81 2,.761' ,R?NRfPSI.. -'.-"2-.721 NP.OR*p&I' ReNT.PS! 1949,090 ~CFT,PSI 693.,646 CN?C~P.81 .20'5.0,-437 DEPT 10294.500 ENPH,.PSi '$9.9.9~ .!.'ENRA-.~PS! ·. 5'16i'8 .C~:EC. PS1 C~EC*PSI 2740,616 RCEF,P$ 493.76 -RC'EN.~.PSI'. ,.2605,.~30 NPH~,..PS1 T~P~:P$! $8.845 TNRA.,-PSl 3,742 .i~T~R'~PS1 '. 4,-013' NPOR~P&!' · · * * CFTC.PS1 RCN~ PS1 1442 820 RCFT~.PSI 369.?42 .'"'.CNTC~PSI .1-5~8~.~36 G~.P$i 151·375 T~$~PSl 2840.000 ~:" C:b'{'PS! ..26,.~75 - :.2 ..76.3~,~S~.. o~:3e5 487:~.e66 '42~653 '4.0"409 [,IS Taue Veriflcatlo. £,lst~ng Schlumberger AlasKa Computln~ Center '/-NOV-1994 18:24 ~8 SFRVICE : FLTC VERSION : 001C01 DATF MAX REC STZM : 1024 FTL~ TYPE : LO b~S~ FILE V~SlO~ : ~o~COl D~TE ~ 04/1{/ 7 ~AX REC STZ~ : 1024 FTb~ ~YPE : LO ~mST FILE FTLm NEADMR RAW CURVES · · .. Curves and lno header ~ata ~or each U.ass in~se, uara.t.e ~lesJ'raw"bacK'oround pass in last PASS ~U~ER~ 2 DFPTH INCREMENT: 0o5000 F?L~ SUMMARY VE~I)OR TOOL COnE START DEPTH CNTG 0695'5 LOG HEADE~ DATA SOFTWARE TD ~R1LbER TD bOGGEPCFT)~ ~OP bOG INTERVAL ROTTO~ bOG I~TERVA[, (FT): LO~GING SPEED (FPHR)I DEDTN CONTROL UGFO (YES/NO): TOO;, ST~I~G VE~DO~ TOOL CODE TOO[, TYPE >2?'AUG-g4. ;40·- :..10718..0 ~0.$?.~'. .:~$00o-0 '~T:OOL.NUMBER : : . ..[ .:. i"iT, IB ?ape Veri~ication Schlumberger Alaska Computlnq Center ... ,-: '":; CNTG .. :-'. C h~ T ~ [~ C~,~T~ , CFTG ?--NOV-i. 994 18{24 C06LAR LOCATOR TF.,h~IRTR¥ CARTRIDGE ~A~,~1A Ct3~PENSATED NEUTRON· ROPEHOLE AND CASING DATA OPEN HOL~ ~TT STZ~ ~RT6LE~S CASIt~G DEPTH (FT)~ LOGGERS CASfNG DEPTH (FT)~ ROREHOLE CONDI?IO~!$ FLUID TYPE{ FLUID DENSITY (LB/G): $!~EFACE TEMPErATUrE (DE~F){ BOTTO~ NOLE T~{~PERATURE FLUID SALINTTY FbUID LEVEL (FT)I FLUID RATE AT wELLHEAD WATER CUTS GA$/OI6 RATIO~ CHOK~ CDEG): ~E!!TRON TOOL T~OL TYPE (£PITHE~MAL OR THERMAL)~ BATRIX DENSTTY: HOf, K CORRECTION (IN): CAL ~AB40 TCC 22.9 . . ,SGC $A-59 CNTG 12'5 FbEX, CBC 86. CBS'I60 .. '2B.O 'SEAWATER 'EP.ITHE:RMAb "SAND'STONE 2.6'5 BLUrb!N? COUNT ~'ATE NORMALIZATION IN 015 'ZONE::.' TOP NORMAbIZlNG WINDOW (FT){ ... ~ASE ~ORMALIZING WINDOW (FT)~ nLUgT,INE COUPT RAT~ SCAbE$ SET BY FIE.~D ENG.IN'~ER CoU. LOW (C,S), · TOnb STANDOFF (IN)t R~aRKS~ TIE-IN SW$ LwD CD~ DATED 14-AUG-lED4.=' · 6NG DFPTH DRIFTS WRT THE CDR-TOWAR.D.THE BOTTOM..SO.THg'~OG ~A$ TIED-IN AT THE CENTER -OF.THE EXPECTED. PE'RF$.~O:600".. bOG RUN B~FORE WEL~ WAS PERFORATE'D.~ $ b?8 FOR.AT DATA LIS TaPe veri.'ficatlon Listing SChlumberger AlasKa ¢omputin~ Center DATA FORMAT SPECIFICATION RECORD mmmmmmmm~m~mmmmmmmmmmm.mmm~N~ T~PE REPR CODE VALUE I 66 0 2 66 0 3 73 76 4 66 5 66 6 73 7 65 8 68 0.5. 9 65' FT 12 68 13 66 0 14 65 FT 15 66 68 16 66 0 66 mmmmmmemmmmmmmmmmmmem~meem#'e#! : : ~* 8ET TYPE - CHAN ~ .......... · ...... : ........ ' .......................... ::::::::::::::::::::::::: '.. TO . .nRDER # bOG'TYPE CLASS MOO- NUM.~. :~A~P .... ";L.;M:.' .... '.....' .'.CODE.- ' "(.HEX.') '... FT 619044 O0 000 O0 0 6 '1 'I 4 68 .0000000000 ' 0000.000000 pu 619044 oo 619044 O0 CPS 619044 .00 CPS 619044 O0 CPS 619O44 O0 CPS 61~044 O0 pU 619044 O0 pl.{ 619044 O0 619044 O0 619044 O0 PU 619044 O0 CPS 619044 O0 CPS 619044 O0 CPS 610044 O0 CPS 619044 O0 GAP! 619044 O0 bB 619044 O0 000 O0 000' O0 000 O0 000 O0 000 00. 000 0'0 000 O0 000 '00 000 O0 000 O0 000 O0 000 O0 000 O0 000 O0 000 O0 000 00. 000 O0 0 6 O. 6 0 0 .0 0 0 0 0 0 0 0 0 0 0 0 6 "' .1. O' 6 1' 1 1 ~.. t '. 1 " 1 1 1 1 .4 4' 4 4 4 4' 4 '4 4~ '' 4' 4 4 68 0000000000" 6.8 '0000000000 6.8' . 0'00000'0.000 68 000.0'000.00'0 68 0000'000.'000 68 0000000'000 68 00.0.000000'0 68' 000000000'0 68 00.0'0000000 68 .000000-0000 6.8. 00'00000:'000 68 000000'0.0'00 6g .000.0000.00.0 68. 0000'000000 68 000000000.0 68 0000000000 68. .: 0000000000, , D~PT EMPH PS.2 EMRa PS2 CFEC P$2 CNE~ P$2 RCEF P$2 RCE" PS~ NPHT T~P" PS2 TNRI NPOn P$2 RCNT P$2 RCFT C~?C CFTC G~ P$2 TENS P$2 ~:.:$chlumberc~er Alaska Computlnd Center ?-NOV":Ig94 15:24 DEPT. 10695.500 ENPH'.PS2 30.'610 ;~ C~EC'.PS2 2749.277 aCer. PS2 57~o380 i:.:! T~p~.Ps2 31.560 TN~A..P82 ~.406· ~'i ~C~T P$~ t741.3~7 ~cr~.es~ 49~.~9. i:~ G~:PS2 80o000 T~NS.~P$2 2'0~5°.~vO :.. ..,- ::.! D~P~. 10600.000 ENPH,PS2 31,?75' :~: C~EC,P$2 2930.922 RCEF,P82 592'.698 " ~P~eP&~ 23.224 TNRA,P82 ' ,:~ 2..-.842 .. ~ ~C~oP$2 2038°545 ~CrT:.P82 654:'641= : ..i GP.P~2 31.875 TE~$,P~2 2970,000 DEPT, 10400,000 E~PH,P$2 C~EC,PS~ 2818,718 RCEF-,P82 RC~?oPS2 1985.493. ecrT..P$2 G~.ps2 23.b25 TENS,P~2 DrP~ 10260.500 ENPH,Pg2 C~EC:PS? ~796.3.89 RC£F,P&2 T~p~.p$2 33.064 T~RA.iP$2 RCNT,PS2 1842,528 nCrT',PS2 G~.PS2 141.125 SERVICE : WbIC VER$IO~ : O0~CO1 DiTF : 94/i!/ 7 M~X REC SIZ~ ~ 1024 FY~ TYPE ~ LO .EN"A~D$.2 RCE'N.~P82' R~NR-'~P82 . CN TC'~,~ P82 CCh ~P82. ENRA~iP82" "RCEN~ P62 'RTNR!!P82. CNTC~;P82 CCh P'$2" ~8.1' .- 47' · . 586.749 'RCEN~P82: 3..325 R.~NR~P82. 466,·459 ·CNT¢~P82' 2?85.000 .CCb'!~eS2 -4.;.724 'CFEC..PS2 '2622~.797 N.PH~:.,P$2 "3,479 NPOR,'P$2 181.7,8.79 .CFTC,,P$2 -0',007 ' ' · :2:,79T NPOR..PS2 ;2135.;805 .CfTC,PS2 ..0.~046 ..... '4;5.95 · '20~6:i. 295 'Ct?C-PS2 :.'0.,046 ' · · .283.2~974 NPH'Z*PS2 .--.-.:.3~-1-49 NPOR,PS2 · i~.70~.62~' CfTC,PS2. :'-0'~O07 ~3}'~560 '544'.,392 :26,236 23,340 -6i3,;43-6 "26~.9'46 ~35,052 29V8·~8 525a;592 FILr ~A~E : EDIT .o07 SERVICE = FbIC V~R$ION : 00lC01 F~b~ T¥~E : b~$? rIbE : FTLF HEADER FIL~ HUmBeR 7 CURVES ., .~.... . Curves and log header data ~or each pass In separate' · :taw' baetcqround pass in-Zest'.'~i LIS ~a~e Verification Llstlno Schlumberger AlasKe Computino Center ?-~ov-~994 l·S: 24 PASS NUMBER= D~PTH I~CRE~E?TI # FTL~ SUmmARY VENDOR TOOL CODE START DEPTH CNTG 5 ~OG H~ADER DATA ~ATE SOFTWARE VERSION= TI~E LOG~ER ON SOTTO~: · D DRILLER (FT): TD TOP [,OG INTERVAL (FT):TF ' POTTO~ ~OG INTERVAL LO~GIHG SPE~D ~EPT}-{ CO~TPOL USED (YES/NO): TOOL ST~ING (TOP TO BOTTOm} V~NDO~ TOOL CODE TDOL TYPE COLI, AR LOCATO'R TELEMETRY CARTR~DG~ GA~A RAY CO~PEHSA~ED NEUTRON C~TG CqTG C~TG CNTG $ ROREHOLE AND CASING DATA OPEN HOLE BIT SIZE DRTLLE~S C~LIN~ DEPTH (FT)~ tO~G~RS CASING DEPTH 80~EHObE FLUID TYPE~ FLUTD DENSITY (LB/G)~ - SURFACE TEmPErATUrE CDEGF)~ B~TTO~ HOLE T~MPERATURE (DEGF)~. FLUID SALINITY .(PP~)~ F~UIQ LEVEL CFT)~ Ff, UID RAIE AT WELLHEAD ~ATER CUTS·(PCT)~ GAS/OI& R~TIO: C~OKE ~TET..]~'mON TOOL TOO[, TYPE ¢~PITHERAAB OR THERMAL)~- RAT~IX DEWSITY: HOL~ CORRECTION (TN): 40.2 ' 1447 ' 27'AU~94 !0.?18,0 ·10675,0 '.1'030'0.~0' -':1.067. l.,0 .~25'0'0~-0 "TOOL :NUMBER.- "¢A~..¥A 229 Tee B'840 '-SOO. SA"59 -'~gX · ~:C'B'C 86 ;'.CBS 160' 2'8.0 ..:SEAWATER.." .: .. :-'.SANDSTONE .-2:.65 PAGE-~ ..:..22 · . ,. .. 'LIS ?ape Verification Llsttna 'Schlumheroer Alaska Computing Center BI'.,UEbTNE COIJ~T RATE] NORMALIZATION IN O!b. ZONE PLIIEI, INE COUNT R~TF SCALES SET BY FIELD ENGINEER ' CO, T RATE bo ,, SCALE (CPS).: ' FA~ COI~NT RATE H~GH SCALE. ~EAR COUNT ~ATE HiGH SCALE (CPS ~'OOh &TANDOFF (IN): RF~aRKS= T~E-iN SWS ~WO CD~ DATED 19-AUG-i9'94, ' bOG DFPTH D~IFTS WRT THE N~S TIfD-IN AT THE CEnTeR OF TIlE EXPECTED bog ~[!N BEFORF WEbb WAS PERFORATED.' L~S FORMAT DATA ** DATA VOR~AV SPFCIFICATIO. ~ECO~D ** SET TYPE - T¥'P~ R~P~.CODE. VALUE mmmmmmmmmmmmmmmmmmmmmeeeeeeeem ! 66 0 2 66 0 3 73 76 4 66 ! 5 66 6 73 7 65 9 65 · 1.~ 66' 13 1~ 68 1~ 66 0 14 65 PT 15 66 68 16 66 0 66 ! ** SET TYPE - CHAN ** . .. .................... NA~E S~RV UNIT SE~V~C~ API AP! .A-PI API FI.bE NUMB' - NUMB '$~ZE REP.R' :PROCESS TO ORDER # bOG TYPE C.LA&8 MOD NUMB- 'SA~'P...Eb~ .... ' ·.'...CODE (.HEX) ....... DEPT FT 610044 O0 oOO O0 0 7 ! I' '4 68 .00000000.00 E~pH P$3 PU ~1q044 O0 0O0 00 Om 7 ! 1'' 4 68' 00000'00000 E~!R~ PSt ~19044 O0 000 O0 0 7. ! I 4 68 ..0000000000 LIS TaPe ver~.ficatton I, Xstina Schlumberger Alaska Co~putln& Center TD CFEC P$3 CPS C~EC PS3 CPS RCE~ PS3 CPS RCE~ P$~ CPS 619 NPHT P~ PU 6~9 T~P~ PS~ PU 619 T~R~ P~3 619 R?NP P~ 619 NPO~ P~ PU 619 RC~ P~3 CPS 6~9 ~CFT PS~ CPS CNTC P$3 CP~ 619 G~ P$3 GAPI 619 COL P$3 V mmmmmmmmmmmmmmm~mm~!~.mmm~ ~ERVTCF AP1 APT APl. APl F ORDER # hOG TYPE CEA~S ~OD N ~mm~mm~m~m~m~m~mm~w~ 610044 O0 000 OO 0 7 ~19644 O0 000 O0 0 7 619944 O0 000 O0 0 7 044 O0 000 O0 0 -? 044 O0 000 O0 0 7 044 O0 000 O0 0 7 044 O0 000 O0 0 7 044 O0 000 O0 .0 7 044 00 000 00 0 7 044 O0 000 O0 0 7 044 O0 000 O0 0 7 044 O0 000 O0 0 7 044 O0 000 O0 0 7 044 O0 000 O0 0 7 044 O0 000 O0 0 7 0 ILE NUMB. F!UMB ,SIZE 'REPR ' 'PROCE85 UMB SAM.P.. 'EI~E'M . CODE- -' · CHEX) I. 1 1 1 1 1 1' 1 1 1 4' 68 0000000000 4 68 00000.00000 4 68 0000000000 4 68 OOO0000000 4 68 0000000000 4'. 68 0000000000 4 68 0000000000 4 '68 00'00000000 4 68 000000000.0 4 68 0000000000 .4 68 000-0000000 4 68 '0000000000 4' .68 '000.000.0.000 ~ ~ 0000.000000 ' 0000'00000.0 44 O0 000 O0 O. ? ',.1 .... .. I ..- .4 ...... 68 .... 00.00000'000 :. DATA DEP? 106g0.500 CNEC.:PS3 2879.049 TNPP.PS3 97,869 RCN?.PS] 1742.660 Gn.PS3 74.688 DFPT. 10600.000 CMEC,PS] 2869°300 Trg,.PS] 25.845 G~.P$3 ~2.344 D~Pq' 10400.000 C EC~.PS3 2818.772 T~P~.P$3 2t.~48 RCNT.PS] {.92 .441 G~.P$3 ?7,000 D~p? 102~3.O00 CNEC:PS] 2736,205 T~p~.~S] ]8.727 RCNT.P$] 1540.606 NPH '.:P$3 31.740 C~F,:P$3 56g'3i8 TNRA~.P83 3'164 RCFT.PS3 531. 9'9 ?EN$,P$3 2t40..'000 Z~PH'PS3 '29, g97 ~C.EF,PS3 607.888 NRA,PS3 2.90~ ICFT..P$3. . 691.48 TE~IS.PS3 2900.000 RCEFi. PS3 61.3, RCFT.~.'PS3 * 1 TE~S;P$3 2805.000 ~NPH.',P$3 40'54? Ta~A.P$3 3.8'28 ~CFTe. P83 396.671 TEaS.P83 2?45-000 RCEN'~PS3 RTNR~P.S3 "CNTC.~.P83 ~.TNR:~PS3 CNTC~PS3 CCb*..PS3 RCEN'~PA3 RTNRg!P83- CN?C~-PS3 .COb%PS3 RCEN~:P&3. CNTC*:.PS3 CCb"P$3: :. 4,838 .CFE¢.~:.PSi' · 2746~..600 N'P..H'I.,~P'SI.: ...'J3~'232- NPOR,-P6 ' 18.~9a281 CrTC.,PS :'0.,0.05 2'?.04~024 '~2~'939 NP. OR.P$3 ..2.1~2~04 ,Cr. TC,'P~3' :.'0.O1.0 .2694,.632 :.'-2~9~2 20'I1~639 '-'0,.002 '..3-93'1 15'72.154 -0.054 CFEC.,P$3 NPHI~.P$3. NPOR-,P63'' CfTC.PS3 CFE¢.~PSi NPOR~P&~ "586~*'.'727 -':27,.392 '~23~667 '.756i'~05 ..~23,634 44,208 4t5.'915 END 0~' DATA :iLI8 ?at~e verification Listing · $¢hlu~beroerll Alaska ¢omPotino ~ente'r **** FILE TRAILER **** Fr~K NA~E : EDIT ,007 5~RVICE : FbIC DITF : q4/ll/ 7 MAX REC $IZ~ : 1024 F/LF TYPE : LO LaST FILE : **** TAPE TRAILER SFRVICE NAME : EDIT D~TF ~ 94/1J/ 7 TAP~ MA.E : 9431g pREVIOUS TAPE : · E.~T ~ ~RCO ALADK~ INCo, **** R~EL TRAILER DwRVICE NAME : EDIT D~TF : 94/11/ 7 REEl. NAME ~ q4319 CONTInUaTIOn! # : P~EViOu$ REEh PRUD,OF_, BAli'..D~ .9.37I, 5002922451. .. .. ; ARCO A[.,ASK/~. INC., PRUDHOE. BAY,, :DS .-9-37.T, 5002922451 .. -.. PAOEi ,2s. I$ Tape 'Verfff~cet!o. Listln~ cblumberqer Alaska Computino Ce.ter 26-0CT-]9~ 21:52 : aRCO &L, ASNa !;,~., D.$, 9-371, P~{~[:Ht)E BAY, 50-02g-2~451-00 **** TaPF~ HEA E,~TR **** DaTF : o4!i~1 3 O~IC;[~d : F;ulC CO~E~,~T : .5. RCO ALASKa f~C.. P.S, 9-37I, PRI~DHOE BAY. 50'029-22451-00 APl N;~,4~gm; L~(;C IH(; CO~4oAMY: T~PF CR~ATIO~ DATE 8!.'~ ~.~C E DOCnTTO~ FSL: 'OERRTCK WFLI,,, CAS!~G RECORD ~ST ST~I~!G ALASKA, IgC 3-0CT-9~ 04318 Si~RONS REYNObDS 10 15 JAN 0 5 1995 Alaska Oil & Gas Cons. commission 20~. 4962 46.30 45 3¢) 2 o: 7 6 OPE~! HOLE CASI~G D~IbLMRS CASING ~!T SIZE {IN) SIZE (!M) DEPTH (FT) WEIGHT (LB/FT) 0,750 28.(') 45.50 ~6.~2s 353o.0 5,500 10804.0 17' 0 # PAGE: I$ ?aDc ver!f~.cation chlumberger Alask:a Cotr, puti.nc Center 26-0C~-1904 2~ :52 #mmmmmmmmmmmmm .......... E~)~)IVRL~i:~:T U,'~SHIFTEP ~F, PTH .......... PE~, ~P KS: ;~;F! ..... OP~'h HnL~: ..... ~ASE TOOL WAS AVAILABLE TO DEPTH CORR Tr4E 3 F~SSES OF TnTP. INSTEAD PASS ~1. WAS USED TO DWPT~ CO~ECT TI)Tm PASSES 2 AND 3. FILE NA.q~ : FOIT ,Onl SFRVICE ~ ~LIC VER$IO~ : O01COi D~T~ : 94/!0/ 3 ~X RFC SIZE FYLw TYPE : LO FYLF ~E~D~R EDITED CURVES DePth shifted and cl~Pped curves for each pass ~n separate ~],,le$, P~8S ND~BFR: I DFPTH INCPE~E~T: 0.5000 FILF LDWG TOOL CODE START DgP!rN STOP DEPTH "'"'"'"'" .... .... *DTP ~, it) , 0 $ CURV~] SglFT D~TA - ~ASS TO ~A~S(~4E, ASURE ..... DEPTg) B~SEI:,I~E CURVE FOR 5MIFTS P~SS ...... o .... T ~.ASE[,INE U~.rm~'~ Dq'P gRCH D .... ~,.~. C,.~RRt, C{,IO~,~6 ~.,~ERE APPLIED TO TD~'P PASS chlUmberaer AlasKa Co~'pt]tin~ Center 26-nCT-19o4 21:52 SbT$ FORu,,;-~T DAT~: PAGE: ] ..........................................C~'' ARC~''~.~A SKA, T_NC.' ...... ' ................... Company ~ame. '''''''''''''''. ...... PRUDH.OE BAY Field Name F~ API'~ 50 62~-~2451-00- SFC? TO~~ iO ~ RA~C 15 E COU~ aO~ ~LOPE ~T~'~ REY~OLDS/JO~SUN S~N 50054~ ~T APO FT 46,3 E~S ~T 46,3 EPF ~T 45,3 ECL ~T 20 7 TLI VT i0300o D~T ~EA WATER TI, A~ I0:25 31-Ai}G-94 Well Name APl Serial Number Field Location Section Township Ranoe Countv State or Province Nation Witness ~ame Service Order Number Permanent datum Elevation of Permanent Datum Log Measured From Auove Permanent Datum Elevmtion of Derr c Flo~r Elevation ~f Gro~md bevel Total De~th - Driller Bottom Log Interval, To? Log Interval Orllli..g Fluid Type Time bo~Qer at BOttom .............. .... . .... .................................... D r~ h~P? [~e t S%Gr: Sigma (i'~eutron Capture Croms Section) S!GC TPAv TCAF TC~ TCFP Sigma Correction Correcte~ aorehole Sigma Standard deviation of ~oreho!e ~lqma' t~,~ear de~ector ~orehole S~a - far detector TOT Porosity ~ation Total ~ear to Far counts Total counts a~alyzed - ~ear oetector (TDTP) Total coust$ analyzed -far d~tector (TDTP) Total capture counts - Near detector Total, capture Counts -far dectector IS ?ane Veri.~lcat.ion T,istln,~ ChlUpherger Alaska Comput!n~ Center 2g-0C~-~9~4 21:52 D~FT ~ ~,'ot . Se!ecte~ Cou s to . T$C~ Total Se~ecteo Counts - Far Detector I~;P Inelastic cour)t rate - near detector !~!FD Inelastic couat rate I far detector BaCY nack~round Count Rates - t'~ear Detector T~AC gsck~roumO Coumt Rate - Far Detector GPCM Camma ~av ~n Ca$lnQ TF{~S Surface Teas!on PAGE: ** 9,.,'%.TA FOR?AT SP~.CTF!CATIO~' RECORD 2 66 0 3 73 4 66 5 66 6 73 7 65 ~ 68 0,5 9 65 PT 1~. 66 12 12 68 13 66 0 15 66 68 16 66 0 6~ 0 ** 8ET TYPE - CHAM ** ID ORDER ~ LOG TYPE CbA$S "OD NO"B SA~P ELE~ CODE (HEX} D~PT FT K00540 00 000 00 0 i I ! 4 68 0000000000 SIGC TDTP STBN TDTP SDS? TDTP $~HF TOT? TP~! TDTP T~AT TDTP TCA~ TDTP ~AF TDTP CU 500540 O0 000 O0 0 Cu 5OO540 O0 000 O0 0 CU ~00540 O0 000 O0 Cu 5005~0 O0 000 00 0 CU 500540 OO 00o O0 0 CU 500540 O0 00o O0 0 PT,)-$ 500540 O0 000 O0 0 500540 O0 000 O0 0 CPS 500540 O0 000 00 0 CPS 500540 O0 000 O0 0 1 ! I 4 68 0000000000 I 1 1 4 68 0000000000 1 I 1 4 68 0000000000 1 I 1 4 68 0000000000 I I 1 4 68 0000000000 I l 1 4 68 0000000000 1 l t 4 68 0000000000 I 1 1 4 68 0000000000 I I I 4 68 0000000000 1 1 1 4 68 0000000000 IS ~a~e V~riflcat]on I-ist~n~ chlUm~eroer Alaska Comput!n~ Center 26-0CT-19~4 21:52 PAGE': ID ORDER # bOG TYPE CbASS ~OD NLI~B SA~P EbEM CODE (HEX) '~'~[~ ....................... CPS 500540 oO o~ .................. O0 0 I 1'' ........................... 1 4 6~ 0000000 TCFD TD?F CPS 50o5~o oD o00 O0 0 1 ~ ~ 4 68 0000000000 T$Cw TDT? CPS KU05~O 0O 000 00 T$Cw TDTP CP$ g0m540 O0 000 O0 I~ND TDTP CPS 500540 O0 OuO O0 INFD TOTP CD~ 500540 O0 OOO O0 BAC~ TDTP CP& 500540 00 000 00 TPaC Tp~p CPS g005~0 0o 000 00 0 1 ! 1 4 68 0000000000 0 1 1 ~ 4 68 0000000000 0 1 1 I 4 68 0000000000 0 1 1 ~ 4 68 0000000000 0 1 I ~ 4 68 0000000000 0 i ~ ~ 4 68 0000000000 ** DaTa ** DFpT. 10668.000 snSI.TOTP 0.561 TPAT.TDTP 1.874 TCFD.T~P 42v0.469 INFD.TOTP 370.737 SIG~.TDTP 37.015 SlGC,TDTP 1.017 $IB~.TD~P 45.695 ~B~N.TDTP 43.863 SBNF,TDTP 737,326 TPHI.TDTp 45:,7~8 TC~.I.TDTP 64041.14~ TCAF TDTP 17.45.332 TCND TDTP 173~0!~336 .. ~ , · ~ - .. · ~ ..... (~.TDTP 2!71 688 TSCF,TDTP 636.473 INND.TDTP 1809,738 BACK,TDTP !.28.734 TB~C.TDTP 3~.995 GRCM.TDTP -999,250 DFPT. 10300.000 SDSI.TDT~ 0.6~9 TPAT.TOTP 2.029 TCFD.TDTP 33~a3'547 INFD.TOTP 391o530 TFNS,TDTP ~410,000 SICi~'T~T~ 44.700 SIGC:'TDTP 0,000 SIBH.TDTP 54.'576 ~ ~ '~ ' · ,. oB~. TDTP 47.778 SB ~,TDTP 4~,628 TPHI TDTP 64.051 TCAN,TDYD 66826'~19 TCAF*TDTP I5~3~,145 TCND.TDTP 15003,441 TSC~]~. TDTP 1418,669 TSCF,TDTP 327.969 INND.TDTP ~845'208 BACK.TD~P 195,493 TBAC,TDTP 32-466 G~CH.TDTP 66'438 DATA **** FIbE TRAILER F~LF ~A~: ! EDIT .OOl SFRvIC!{ : FhTC ¥~RStO~'~ ~ O01CO1 D~T~ : 94/10/ ~X RFC $!Z~ : !024 FILW TYPE t LO L~ST FII,~ : IS Tane V~riflcatlon 5istino chlnmberger AlasKa Comput~Do Center 26-OCT-1994 21.:52 FTLF N^~S : ~O~f .002 SF~VIC~ ~ FbIC V~IO~ : n01CO~ D~'r~ : 94110/ 3 E~ITED ~eDtb shifte~ and cl~PDed curves ~or each pass DFPT!! I~CqE~E~T: 0.5000 FILF LDWG ToOL CODE START DEPTH STOP DEPT~ · P !06 . 10300.0 ~Rri~ 10655.0 10300,0 C!!RVE S~{IPT ~T~ - PASS TO PAS6(aEASU~ED DEPTH) ~ASELI~E CURVE FOR S~IFTS PASS ~U~BFR: 1 BASEI,I~!E DEPTM 1(t616.0 10616.5 )0614,0 1 06()~, ~ 10607.5 ~ 0596.5 ~ 0597.0 ~ 058~,0 ~ 0582.5 ~0579.0 10579.5 ~0575,o 10575.5 I0567,0 1. O56~.5 0557.5 !055g.0 ~O556.0 I0556,0 !,055!.,o i0551.5 I(.)54~.0 1054g.5 .... ------EQUIVALENT UNSHIFTED DEPTH---------- TDTP GRCH IS Tane .Veri£~!cat~on L. ist.lp~, ChlU,tberoer AlasKa Co,~puti~ Center 26-SCT-19q4 21:52 PAGE: ~ 05!&.5 lo517.0 1u513.0 1,05~3.0 10505.5 10a97,~ !.0497,0 10489.5 1.048~,5 104~.0 !04S9,5 ~047~,0 ~047~.5 10467,5 ~0467,5 ~0450,0 ~0459.5 ~045~.5 ~0459,0 10a27,5 ~042a,0 ~0424,5 10~.0g.5 !.0a09.5 10363,0 !0363,0 10360.~ 0357 5 1.0357.5 .034015 ~034t,0 ~031~,0 !.0318,0 ~O~OO.~ 10300.5 10309,5 10297.0 10297.5 !00.0 ~UO.5 100,5 THIS FILE CONTAINS CLIPPEg, DEPTH CORRECTED DATA OF TQTP P~$$ #2, PASS ~2 GA~A RAY WAS DEPT~ CORRECTED T~ mASS ~ GA~ P~Y. PASS #2 ~IGM WAS DEPTH CORRECTED TO PASS ~1 SIG~ CARRYING A:bb TDTP CMANNEbS, $ LIS FOIz~.~ZAT r~ATA 'iF U ~'~; l V A [, U D E F I · · , ~ ARCO AbASKA INC Company Name ~M PRUDH:~E BAY Field ~ame ~:i~' D ~ g - 37I Well Name API~! 5~-629-2~451-00 API Serial Number FL 20I' FSL & 4962' FEL Field Location SECT i Section TO~ lO N Township R~G 15 E Range Ca~i~ )~Tti SbOPE County S~ ALASKA State or Province N~Tt USA Nation WIT~ REYNOLDS/JO~NSO~ Witness Name So~ 50054.0 Service Order Number PDAT MSL Permanent dat~ EPO ~T O. Elevation of Permanent L~F KB bog Measured From ADD FT 46,3 A~ove Peri, anent Datum Datum IS ~ane V~rif!cation Listl. t'~.o ChlUm~erc~r ~{~as~a Co~pt]tJhn Cen~er 26-OCT-1994 21:52 ........EWe. ~':.,. ............................... 4~3 ' ..... '''' .... ' ....... Elevation''''' ...... of Kelly'' ........ SUSh:l,r!Cl"'' ..... EDP PT 45,] EGb Pi 20.7 TOD P'T 10~04. ~!,I WY 10o6~. TI~I PT 10300. DFT SE~ ~TER TbA~ 10:25 31-AUG-94 Elevation of Derrick Floor Elevation o~ Ground bevel Total DeDth - Dr~ller Bottom Loo Interval ToD Loo Interval Drill, lnq Fluid Type Time Lo~er at Dottom TAb!E TYP~ : CUEV STG~ Siqma ¢~;eutron Capture Cross Sectlom) 8IGC Si~ia Correction SYS~ Corrected Borehole S~D~? ~orebole Siqma - Near detector S~Hw ~orehole Siq~a - far detector TPhT ~'t)~ Porosity TPAT ~atlon Total ~ear to Far counts TCA~ Total counts a~alvzed - near detector (TDTP) TCA? Total counts a~alyzed - far detector (TDTP) TC~ Total capture counts - ~ear detector TCFD Total camture Counts- far dectector ~,~e.lected Counts ~ear Detector TSCw Total Selecte~ Counts - Far Detector IMN['~ InelaStic count rate - near detector IMED Ii)elastic count rate - ~ar detector BAC~: BacK,round Count Rates - ~ear Detector F~A~ Fackqroun. d Count Rste - Far Detector G~C~ Ca~a Pay in Casln~ TF~$ Surface Tens~on ** DAT~ FORMAT ,~PMCTFICAT!UN PECORD ** ** SET TYPE - 64EB ** TYP~ ~ V.~b!JE · 1 66 0 2 6b 0 3 73 84 4 66 5 66 rave Verification l.,isrino ChlUmberqer Al. asEa Co,,put. lno Center 26-OCT-1994 21:52 7 65 S 68 o.5 9 65 FT 17 l! ~6 0 14 65 FT 15 66 68 1~ 66 0 6b 1 ' ...... .............. [ .......... ........... F ~' ERV L!hiT SE~V CE APl AP AP1 ~PI ORDE~. ~ LOG TYPE CBA$S MOD N ~ .., 500 0 00 00 0 $IGu TD~P C~ 50O540 O0 000 OO o 9 STGo q'DTP CU 50~.540 O0 000 OU 0 2 SIBH TOTP CU 500540 ~0 000 O0 '0 2 SDSI TDTP CU 500540 0() 000 O0 0 ~ 6~H~': TDTP Clt 500540 00 000 00 0 ~ SBHF TDTP CU 500540 O0 ()00 OO 0 ~ TPH? TDTP PI)-S 500540 O0 000 O0 0 ~ TPA? TDTP 5005~0 O0 000 O0 0 2 TC A~; ~LTTP CPS 500540 O0 000 00 0 9 , ~.., ~. CPc . o 500540 o 0 000 00 0 2 TCF~ q'[)~F CP$ 500540 O0 000 00 0 2 ~, ~.~' CPS ~00540 oo 00() O0 0 2 TSCF TDTP CP6 500540 O0 000 O0 0 2 I~Vn T~?P C°S 500540 O0 000 O0 0 3 INFD TI)TP CPS 500540 O0 000 O0 0 ~ [.,,CW:~ Tt.,TP CPS 5005.40 O0 000 O0 o 2 FBAC TDTP CPS 500540 O0 000 O0 0 2 G~C~ TUTP G~.PI 500540 O0 000 )0 0 2 T~NS TDTP ~B 500540 O0 O00 O0 0 ~ · mm .... m'mm~mmmmmmmmmmmm~.~mmmm~,mmmmm#m~m~mmm ILE NUMB NUMB SIZ REPR PRO. S UMB SAMP E[~E~ CODE (HEX) 1 1 4 6800000000 O0 I 1 4 68 0000000000 1 1 4 68 0000000000 1 I 4 68 0000000000 I 1 4 68 0000000000 1 1 4 68 0000000000 1 1 4 68 0000000000 I I 4 6~ 0000000000 1 1 4 68 0000000000 1 1 4 68 0000000000 1 1 4 68 0000000000 1 1 4 68 0000000000 I I 4 68 0000000000 1 1 4 68 0000000000 I 1 4 68 0000000000 1 I 4 68 0000000000 1 I 4 68 0000000000 I i 4 68 0000000000 1 1 4 68 0000000000 1 ! 4 68 0000000000 I ! 4 68 0000000000 D.:pr 1¢)66~ 000 $IGiq'T..D.'~'o 36.463 SIGC'TDTP 1.391. SIBH TDTP SBSI..'rI)TP 0,642 giI~I:t,i.TDTP 43.470 SBHF:-TDTP 34 992 TPBI.TDTP . . ,,. TDT,D 59724.000 TCAF.TDTP !6095.313 TC~D.TDTP TCFD. Ti)!'P ~:.4~71 .666 ~SC~i.TDT'P.~ ,. ,~... 2~27.6~0 TSCF,TDTP 602,852 INND.TDTP INFD.TOTF 370.0!2 ACK,T.....~)lP [q5.996 FB~C,TDTP 59.672 G :Cl( TDTP ~a~ TO P ~615.00,J 44.802 47.698 17035'238 ~8.31.,,407 999~250 AlasKa Comu,!tin~ Center 2f,-rlCT-!99,~ 21, :':32 PAGEI 10 **** FILE HEADER **** FlbP' t~A~g : EOIT .003 ,jERVICE : FalC D~T'P : 94/10/ 3 ~X ~C S!ZF t 1074 F'IL~ TYPE : LO L~ST ~ILE : Depth sihitted an~ clipoed curves ior each pass in separate illes. P~SS NU~FR: 3 DEPTH INC~E~T: 0.5000 FILE SU~aRY !..,DWG TOOL CODE START DEPT~ STOP DEPTH GRCH 10655.0 10300.0 Ct~RVE SHIFT DATA - PASS TO PASS(~i~ASURED DEPTa) ~ASELI~E C~RVE FOR SHIRTS bO~ CURVE CODE: CRCH PASS ~U~R: I BASEI~I~E DEPTH 10662.5 ~0652.0 0 ~ 0647.0 10645. - .... -----EQUIVALENT Utl6HiFTED DEPTH---------- TDTP GRCH !.0662.0 ~0650.5 ~0647.0 1,0645,0 IS Ta~e Ver~!catiom Listin~ Cblumber<~er Alarums Comoutin~ Center 26-OCT-1994 21:52 11 10~3~ n ~0~3~.0 10638 0 10616.5 !0616.5 106!4.g t0597,0 10597,0 10582,5 10571,~ 10571,5 ~0563,5 10563.5 10K57,5 10557,5 ~0551,5 !055t,5 ~0549,5 ~U549,5 ~0K43,5 1052t .0 ~052! ,0 10520.5 10520,5 ~0517,0 ~0517.0 ~0~97,5 ~048~,~ t. 048~,5 ~.0486,5 10486,5 ~0476,5 ~.0476,5 ~0475.0 10475,0 90465,5 ~0465,5 ~.042~,0 10428:6 ~o~7,5 10387,5 ~0307:5 ~O~07'$ ~.o~o4'o ~o~o4,o ~.030~,0 10304,0 THIS FILE CONTAINS CLIPPED, DEPTH CORRECTED TDTP .DATA OF PASS ~3 PASS #3 GAaP. MA RAY WAS DEPTH CORRECTED TO PASS #i GA.~%MA RAY, PASS #3 SIGH W~$ DEPTH C.OR~ECTED TO P~$~ ~1 StG~ CARRYING A[,,L TDTP CHANNEl, S, ' bis FORe, AT DAmA T~BLE TYPE : C0~3S TUN! VALU DEFI C~ A~CO AI~SKA, Z~,!C. Company Name FN PRUDMOE BaY Field Name IS Tare Verification List!,no chlumberger Alaska comput~.no Center 26-0CT-1994 2!:52 PAGE: !,2 T T~ ~.! T V A L U DEF ! Well Name P 201' FSL & 4962' ~EL C~O~ NORTh SLOPE STA? ALASKA N~T! bSA ~iT~? R~¥NOLDS/JO~NSON SnN 50054O p~AT L'F KR APD FT ~6,3 EK~ rT 46,3 E~F ~T 45,3 F 20 7 TDD rT 10~04. TI.~I FT 103nO, DFT SEA ~ATER AP1 Serial Number Field Location Section Township ~anQe County State or Province Nation Witness Name Service Order Number Permanent datum Elevation o~ Permanent Datum Log ~easured From AbOve Permanent Datum Elevation of Kelly ~ushi,~ ~levatlon of Derrzc, Floor Elevation of Ground Level Total Depth - Driller Bottom Log Interval TOp Log Interval Drilling Fluid Type Time bog~er at Bottom T~.~,!,E TYPE ~ CLi~V D~F! D~pT Depth SIG~ Sigma (~eutron Capture Cross Section) S!GC Si~a Correction S!6~ Corrected Boreho!e SiGma SDST Standard deviation of $t~ma SR.H~ ~orehole $]~gma - Near detector S~MF Porehole $iqma - far detector TPH? TDT Porosity TPAT Pstion Total Near to Far counts TCA~.! Total, counts analyzed near detector (TDTP) rCA? Total counts analyzed ~ far detector (TDTP) TCND Total capture co~]nts - Near detector TC~D Total. capt~re Counts -far dectector TSC~ Total Selected Counts - Meat Detector TSCF Total Selected Counts - Far Detector I~ND Inelastic count rate - near detector IMFD Inelastic count rate - far detector BACK gackground Count Rates - Near Detector FMAC Sackeround Count Rate - Far Detector GRC~ Ca~ma PaV ~n Casing ChlUm~erger AlasKa Computing Center 26-0CT-1994 2!:52 PAGE: 13 TYPE REP.. CODE V~LUE t 66 0 2 66 0 4 66 5 66 6 73 8 68 0.5 !! 66 12 i~ 68 1! 66 0 15 66 68 I6 66 0 6~ ** SET TYPE - CgA~ ** N ~ ~EPR Naa $~ v 0~,i~., . s, a. PI AP1 F U .UMB SIZE ID ~RDE~ # LOG TYPE CL~8S ~OD NUMB SAMP EhEM CODE (HEX) OFPT ET 500540 0O 000 00 0 3 I I 4 68 $!G*~ TOTE CU 5Gn540 O0 00O O0 0 3 I 1 4 68 S%GC TOTE Ctl 5005~0 t)0 000 00 0 3 1 I 4 68 6IB~ TDTP C!! 5005~0 O0 000 O0 0 3 I 1 4 68 SD$~ TDTP Ct{ 500540 00 000 00 0 3 I I 4 68 $~H~ TD~P CU 5005a0 O0 000 O0 0 3 1 1 4 68 8~H~ TD~ CU 500540 00 000 00 0 3 i 1 4 68 TPMI TDTP PU-$ 50©540 00 000 O0 0 3 1 I 4 68 TPAT TDTP 50054,0 O0 TCA~ TOT~ CPS 500540 00 000 O0 0 3 1 1 4 68 TCA~ T~TP CPS 500540 00 000 00 0 3 1 i 4 68 TCND T~P CPS 5005.40 00 000 00 0 3 1 i 4 68 TCFD TDTP CPS 500540 00 000 00 0 ~ ~ I 4 68 T$C~ TD~P CPS 500540 00 TSCF TDTP CPS 50o5a0 00 000 00 0 3 t 1 4 68 I~D TI}WP C~S 500540 O0 000 00 0 INF~ TDTP CE5 500540 O0 OOO O0 0 3 1 I 4 68 B,ICK TDTP CPS 500540 O0 0o0 F~AC TDTP CPS 500540 0() 000 O0 0 3 i 1 4 68 0000000000 0000000000 0000000000 0000000000 0000000000 00O0000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 I$ ~a~e ver~.f~.catlon !,istina CblUmberger A]as~a Ce~putfno Center 26-OCT-],994 21,:52 DVPT. lO068.000 SIG~q. TPTP 37.~37 SIGC.TDTP SDS?.TDTP O.~d~ ~DHiq.TDTP 43.~3~ SBHF.TDTP TP~T.TDTP 1.b85 TCA~.TDY~ 5~595.85g TCAF.TQTD TCF~.TDTP ~052.b~7 ~SCN.T~TD 2047.112 TSCF.TDTP i~.TO~ 375.531 gACk. TD~D ~16.098 FBAC.TDTP 1.~9~ SIB~.TDTP 37.956 TP~f.TDTP 15865.70g TCND.TDTP 588.497 IN~D.TDTP 45.61] GRC~.TDTP 45.622 16778.0~3 1880.612 -999.250 14 **** FTLM ~4 E:A L,~ M.R **** FTL~ ~,'~'~i~ ; EDIT ,004 SErvICE : FbIC VERSIO?~ : O01, CO1 DATF : 94/10/ 3 FTLF TYnE : T..,O L~ST FILE : F~LM HEADER FILM Compensated ~leutron: arithmetic average of edited passes for all curves. Pulse~ ~eutron~ Unavera~ed edited Pass ! Gamma Ray and bac~rouDd counts; arithmetic average of edited static baseline passes ~or all ot~er curves, DFP~M I~C~E~T 0,5000 P~$SE8 I~!CL!,!DED IM ~VERAGE LDWG TOOL CODE PASS NUMBERS ~,, ~, 3, D~APKS: T~IS FiLE CONThIN$ ARITMM~TIC AVERAGE OF 3 PASSES OF T~TP DATA, LIS FORMAT DATA IS Wane ver~ficatio~ T,istino ChlUmheroer alaska Computing Center 26-~CT-~994 21:52 PAGE: 15 TU ~'~ ? VAL U DEF! ......................................C" ' ~ .......~LA. SKA:':~:'''' ........... Company''''''''''''''''~ame .... '''''' .... P~H~E BAY Field Na~e FN Ft, 20i' F~L & 4962' FEL SFC~ 1 R~ 15 K C~Ut,! NORTH SLOPE S~AT ALASKA NATT USA W~T~ REYNOLDS/JOHNSON SON 500540 FT A~D ~i 46,3 EKB FT 46,~ EDF PT 45,3 EGL FT 20 7 TDD ~T 10~04, BLI FT ~0~68, TLI mT 10300,T DFT SEA TLA~ 10:25 31-AUG-94 Well Name APl Serial Number Field I,ocation Section Township Range Cou6tv State or Province Nation Witness Name Service Order ~umDer Permanent datum Elevation o~ Permanent Datum 5o~ ~easured From Above Permanent Datum Elevation of Kelly Bushing Klevatlon of Derric~ Floor Elevation of Ground Level Total Depth - Driller Bottom Loq Interval Top Log Interval Drilling Fluid Type Time ~oqqer at Bottom TABLE TYPF : CU~V ............... . ...... ... ..... ................. SIGu SioI~a (~'~eutron Capture Cross SeCtion) Sigma Correction Corrected Borehole Sigma Standard dev~,atio~ of Sigma Borebole Sigma - ~ear detector Porehole S!Qma - far detector TnT Porosity Pation Total ~ear to Far counts Total counts analyzed - near detector (TDTP) Total counts analyzed - far detector (TDTP) Total capture co~3nts - Near detector Total caDt~re Co%~nts - far dectector Total Selected Counts - Near Detector Total Selected Coumts - Far Detector Inelastic count rate - near detector Inelastic count rate - ~ar deteCtor Background Count Rates - Near Detector' ~ackorou~ Count Rate - war Detector IS Va~e v~z'.ificatlo~,~ !.,istin~ chlUmberger AlasKa Comuutinc Center 26-0C?-1994 21:52 PAGE= 16 DATA F~R~Am SPeCIFICaTION ~ECO~D ** T¥O~ R~P~ CODE YALUE I 6~ 0 2 66 0 4 66 5 66 6 73 7 65 8 68 0.5 9 65 l! 66 12 68 13 66 I4 65 FT 15 66 68 16 66 0 66 ** SET TYPE - CHA~ ** N~F S~RV UNIT SER'VIC~ bPI ~PI APl bPI FILE NOMB NUMB SIZE REPR PROCESS Ii} ORDER # LOG TYPE CbAMS ~OD NUMB SAMP E~EM CODE (HEX) '~'' ...... ~'''''''''''~500540 ..... O00'''''''''''"''''''i'''''''"''''"''''''''''~ggg~ggg~g''O0 0 4 ! .4 6" $!G~ P~AV CU 500540 O0 000 O0 0 4 1 i 4 68 0000000000 SIGC SIBU SDS! P~AV TCA~ TCAF DNAV TCND PNAV ~CFD PN~V T$CM TSCW INFD PNAV BACW Ct.! 50054,0 CU 500540 O0 Cu 500540 O0 C[~ 500540 oO C~ 5005~0 O0 pu-$ 500540 O0 500540 OO CP~ 500540 O0 CPS ~00540 O0 CPS 500540 O0 CPS 50054{) O0 CPS 500540 O0 CPS 500540 O0 CPS 5(~0540 O0 CPS 500540 O0 CPS ~0o540 O0 000 O0 0 000 O0 0 000 O0 0 000 O0 0 000 O0 0 000 O0 0 000 O0 0 000 O0 0 000 O0 o 0o0 Oo 0 000 O0 0 OOO O0 0 000 O0 0 000 O0 o 000 O0 0 000 O0 o 68 68 68 68 68 68 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 O000000oO0 0000000000 0000000000 00o0000000 0000000000 0000000000 0000000000 o000000000 0000000000 IS Tape Verification Listin.q chll~mberqer ;~!aska Co~,putin~ Center 26-0CT-1994 2! :52 PAGE: t7 ~i~ ~ER ~ bOG TYPE CLASS ~OD NUMB SA~P ELEM CODE (HEX~ ~. CPS 5 40 O0 000 0 ! 1 4 0000000 O0 G~C~ P~V G~PT ~0~540 O0 000 O0 0 4 1 I 4 68 0000000000 DFPT. 10668.000 TPAT.PNaV 1.890 TCF~.PN~V 41.64.5Ol IMFD,P~¥ 372.0K6 $IGM.PNAV 37,00~ SlGC.PNAV 1 900 8IBH,PNAV 45 368 Sb~.P~AV ~3.717 ~BHF,PNAV 36~754 TPHI.PNAV 461617 TC~i~,PNAV 60780,g22 TCAF,PNAV ~6567.~29 TCND,PNAV 17042,8~8 wSCt,.i.P~AV 2~11.936 TSCF,P~AV 609,213 INND.PNAV 1840,402 BACK.P~!AV ~.2~.734 FBAC,PMAV 32,995 GRCM.PNAV -999.250 FIL~ ~A~E : EO'!T .004 8~RVICE : ~bIC V~RSIO~ : O0~COl **** FTLE ~E~DMR **** FILr ~E : EDIT ,005 S~RVlCg : ¥~RSIOb~ : O0~COI D~T~ : 94/i0/ 3 FILE TYmE : L~ L~ST Fi[,E : FILE ~.~ ~ ~ i:~ g E 5 . Curves a~d lo,~ ~'~eader data 'for eacr. pass in separate ~iles, raw backoroun~ pas~ In Ia~t, fl D~PT~..t I ~C~E~'~E?,~T: 0,5000 VE~:~i}Ot~l TOOI~ CODE STUART DEPTH STOP DEPTH ;~;, P ...... ''''''" 7~g;~7;'''' ''''''''''~0300,0 IS Ta~e ver~f~cati, on ListJno chlUF~v, erg~r AlasKa Computino Center 26-eCT-~ 994 2],:52 18 LmG HP~n~P ~ATA SOFTWARE V~R$in:,i: TD LOGGE~(FT~: =OTTO~ LOG I~T~RvAI, fFT): T.,OCG!N~ SPFE~ (FPM~): ~fPT~ COU'fR[]L U5~O ~1-AUG-94 CPSC.2 1025 ~03on.n !066~.o 600.0 31-AUG-g4 t' .. TP TmTP TDTP TnT~ TOTP YF~DO~ TOOL CODE TOOL TYPE TDTP THERMAL DEC~Y TM£RM~L DECAY T~EP~L DEC~Y THERMAL D~CAY THERMAL DMCAY T~E~MAL DECAY THERMAL DMCAY TOOL NUMBER TNC-P 50 TND-P 78 TNG-P 2! ~INITRON 8496 ATC 1163 CAb-U 597 AT~-AO 283 9OPE'HOLE AND CASII~iG DATA D~I!LLED~$ CA~ING DgPT~ (FT): LOGGERS CASING DEPTH (FY): BOPEHOLE CO~,~PIWlOh8 FLUIO TYPE: FLUID DENSITY SURFACE TF~FERATURE (DEGF) ~OTTO~ HO!~E ~I'E~ERATU~E (DEGF): FLUID 3Ab!NITY FL;~ID LEVEL CFT) FLUID RATE ~T ~T~R CUTS (PC%): GAS/OIL RATIO: CHOKE (DEG) ~,TPlX: M~.TDIX D~]N~!TY: i~I,t.~ML!~. COUNT RATE N~R~,~AI, IZATION iN OIL MC)NE TOP MO~a~LIZING WINDOW (PT): PL"~L!WE. COU~-~T ~ll ~.CAh~S ~.=~,.., BY FIEbD ~NGIMEER AR CO~,;l~ RATE LOW SCALE CCPS): ~AR C[l ~:~ ~.~ m 10804.0 SEA WATER THERMAL SANDSTON~ 2.65 IS Tare verification [~istJnq ChlU~,berger Alaska Co.,p~utfna Center 26-nC~-!.gq4 21:52 PAGEt lg F~ PRUDH9£ BAY ~N D.S. o . 371 aPl~ 50'629-7245!-00 FL 20i' FSL & 4962' FEL S~Cq~ 1 T~~ i0 ~ aak~g ~5 E CO~N NORTH SLOPE STAT ALASKA NtTT USA ~IT~ R~¥~OLDS/JO~NSON $O~ 50054~ PDA? MSL EPD FT LmF KB APb ~I' 46.3 EKB ~T 46,3 EDF ~T 15.3 ESL FT 20,7 T~D rT 10804. ~I..I FT Field Name Well Name AP1 Serial Number Field Location Section Township Range County State or Province ~ation Witness Name Service Order Number Permanent datum Mlevat!on of PerzaneDt Datum Log ~easured From Above Permanent Datum Elevation of Kelly Bushin~ ~levatlon of Derrtc~ Floor Elevation of Ground Level Total Depth - Driller 10668. Botto~ bo~ Interval T!.I WT 10300, ToD bo~ Tnt erVal P 10125 3 ~ US-94 I e b ,.~e[ t Botto~ TABLE TYPF ~ CU~V I)~FI D.,. FPT De~tb STG~ sigma (~eutrop Capture Cross Section) STDT Status of TPHT TOT Porosity SFFD Silica for~atior~ - far detector {TbTP) SW~P Siqma for~ati, o, -near detector (TDTP) IS Ta~e Yert~]cat].on [,ist~no chlumberger A].asKa Computlnq Center 26-oCW-19q4 2!.:52 PAGE: 2O or ol e S oma - r ~orehole $~O~a - Near detector Far TDT~ Count ~ate ~e~r TD~ Cou~t kate ~mnl~.tude ~or~tio~ -- ~ar detector (TDTD) ~c~ml~tude borehole -- Far detector (TDTP) A~HDl~tude formation - ne~r detector (TDTP) A~91~tud~ ~oreho!e -- near detector $ioma Correction Corrected gore~o!e SiGma ~,initron mode monitor ratio (TDTP) Ratio~ Total t~ear to Far counts Standard deviation of Sloma ~cK~roun~ Count Ra~es - Near Detector ~acK~roun~ Count Rate - Far Detector moral counts analyzed - meat ~etector {TDTP) moral counts analyzed - far detector (TDTP) Total capture counts - Near detector Total capture Counts - fiat dectector Total Selected Counts - Dear Detector Total Selecte~ Counts - Far Detector Inelastic count rate - near detector Tnelastic count rate - ~ar detector Raw Near 1st Gate ~aw ~!ear 2~d Gate Raw ~ear 3rd Gate ~aw !~!ear ~ta Gate ~aw ~ear 5t.~ Gate ~aw uear bth Gate Raw ~3ear 7th Gate Raw ~'ear 8tl~ Gate ~aw ~ear 9th Gate ~aw Near 10th Cate Baw ~ear l~th Gate ~aw ~!ear l~th Cate Raw ~e~r l]th Gate maw ~ear I~tb ~ate ~aw Meat IMth Gate ~aw Near t6th ~ate Ra:w Far ~.st ~ate Raw var 2nd ~ate Paw Far 3rd Gate Raw War 4th Gate ~aw Far 5th ~ate ~aw Far 6th Gate Raw Far 7th Gate Pa~ War Pth Gate Paw Far ~tb Gate Raw Far 10th Gate paw Far ~it~ Gate ~aw Far 12tn Gate ~aw Far ~3th Gate Raw ~ar ~4th Gate IS ~'ane ~mrlf~cat..f. on !.,isti. n~ chlu~bergmr Alaska C(;mp!lt]t)G. Center 26-0Cqr-t994 2~..:5~ RF15 ~aw ~ar ~5t~ Gate ~1~ ~aw war ]6th Gate G~ ~P!-Correcte~ Gamma ~av TF~s Surface Tensio~ CCL CCL ~Dlltude PAGE: ** ~A~A FOR~A~ SPEC~F7C~T!OW PECOPD ** 1 66 . 2 66 3 73 ~ 66 5 66 7 65 8 68 0,5 9 65 FI 11 66 3 IP 68 13 ~6 0 14 65 i5 66 16 66 0 66 ** SET T~PE - CNAN ** NA~,~ $~RV U~II? ~g~VICg AP1 API APl API FILE ~UMB NUMB SIZE REPR P~OCES8 TO ORDER ~ LOtS TYPE CLASS ~OD NUmB SAMP. ~SEM CODE (HEX) D~PT FT 500540 O0 000 O0 0 5 1 i 4 68 0000000000 ISH!! 8FF"D $~ PSi FTDT PS1 ~TDT PS1 ABFD ~F~ C~.~ 50054,0 O0 5005a0 O0 Pq 500540 O0 V 500540 oO CU 500540 CU 500540 O0 C~ 500540 oo CU 50~5~0 O0 C~$ 500540 CPS 500540 CPS 500540 O0 CPS 5on5,~0 OO CP~ 500540 O0 0o0 O0 0 5 000 O0 0 5 0o0 O0 0 5 1 000 O0 0 5 I 0o0 O0 0 5 1 000 O0 o 5 1 o00 O0 o 5 1 00o O0 0 5 000 O0 0 5 1 000 O0 0 5 000 O0 o 5 1 000 O0 0 5 1 0o0 O0 o 5 68 68 68 68 68 68 68 68 68 6.8. 68 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 00o0000000 0000000000 0000000000 0000000000 0o00000000 0000000000 0000000000 I8 Tame veriflcati, on [:istfno ChlUmherqer AlasKa Cor. put. in~ Center 26-0CT-~ 994 21:52 PAGE~ 22 '~;~ ..... S~Rv''''~rI? .... ~EavlCF ~; ....................... ~! apl APl FILE N~'~ ........... ~U~S SIZ~''~'''~~S .... A~ PS? 054O 0 000 oO 0 l 1 4 ~ 0000000000 ~TGC PS1 CI~ 50~549 O0 000 O0 0 5 1 1 4 6~ 0000000000 a~O~ PSI TPl? PS! SDST PS1 F~aC TCA~ PSI T~AF PS! T~N~ TCFD PS1 TSC~ PS! T$C~ ~$~ I~ PS! R~2 PS1 R~4 PS! RN5 PS! R~6 PSI R~7 PSl RN~ PS1, R~9 RNlO RNI! PS1, R~I.~ PSi RNI~ PSi. R~15 RN!6 RWl PS! RF2 PSI R~3 RF4 PS1. RF5 PSI RF6 PS1, RF7 RF8 P$I. R~9 RFiO PS1 RF!I PS1, ~17 PS1 RFi3 PS! R~14 PS1 R~I5 RFI6 PSi. GP PS! TFN~ COb PSI CI! 500540 5e0540 aG oho O0 500540 nO 000 00 Cn 500540 O0 000 O0 CPS 500540 O0 000 fig CPS 500540 O0 000 O0 CPS 500540 O0 000 O0 CPS 500540 O0 000 O0 CPS ~00540 O0 000 O0 CP6 500540 O0 000 O0 CPS 500540 O0 000 O0 CPS ~00540 O0 000 O0 CPS 500540 O0 000 O0 CPS 500540 O0 000 O0 CPS 500540 O0 000 OO CPS 500540 nO 000 O0 CPS 500540 O0 000 O0 CPS 500540 O0 OOO O0 CPS 500540 O0 000 O0 CPS 500540 oo 000 O0 CPS 500540 OO 000 O0 CPS 500540 O0 000 O0 CPS 500540 O0 000 O0 CPS 500540 O0 OOO CPS 500540 O0 000 O0 CPS 500540 O0 000 O0 CPS 50054(~ oO 000 O0 CPS 500540 O0 000 O0 CPS 500540 O0 000 O0 CPS ~00540 O0 000 O0 CPS 500540 O0 000 O0 CPS 500540 O0 000 O0 CPS 500540 O0 000 O0 CPS 500540 O0 CPS 500540 O0 CPS 500540 O0 CPS 500540 oo CPS 500540 O0 CPS 500540 O0 CPS 500540 O0 CPS 5O0540 O0 CPS 500540 O0 CPS ~00540 O0 CPS 500540 O0 CPS ~00540 O0 GAPI 500540 b~ 500540 O0 V 500540 O0 000 O0 000 O0 000 O0 000 O0 000 O0 000 O0 000 O0 000 O0 000 O0 000 O0 000 O0 000 O0 000 O0 000 000 O0 0 ~ 1 1 4 68 0000000000 0 5 i I 4 68 0000000000 0 5 1 1 4 68 0000000000 0 5 I I 4 68 0000000000 0 5 1 I 4 6~ 0000000000 0 5 1 t 4 6~ 0000000000 0 5 1 1 4 68 0000000000 0 5 1 1 4 68 0000000000 0 5 1. I 4 68 0000000000 0 5 1 1 4 68 0000000000 0 5 1 1 4 68 0000000000 0 5 1 1 4 6~ 0000000000 0 5 1 1 4 68 0000000000 0 5 1 I 4 68 0000000000 0 5 1 I 4 68 0000000000 0 5 I 1 4 68 0000000000 0 5 1 ! 4 68 0000000000 0 5 1 1 4 68 0000000000 0 5 1 1 4 68 0000000000 0 5 I 1 4 b8 0000000000 0 5 I t 4 68 0000000000 0 5 I 1 4 68 0000000000 0 5 1 1 4 68 0000000000 0 5 1 I 4 68 0000000000 0 5 1 I 4 68 0000000000 0 5 1 I 4 68 0000000000 o 5 I 1 4 68 0000000000 0 5 1 1 4 68 0000000000 0 ~ 1 1 4 68 0000000000 0 5 I i 4 68 0000000000 0 5 I 1 4 68 0000000000 0 5 I I 4 68 0000000000 0 5 ! 1 4 68 0000000000 0 5 I I 4 68 0000000000 0 5 I I 4 68 0000000000 0 5 1 I 4 68 0000000000 0 5 I I 4 68 0000000000 0 5 ! 1 4 68 0000000000 0 5 1 I 4 68 0000000000 0 5 i 1 4 68 0000000000 0 5 1 1 4 6~ 0000000000 0 5 I I 4 68 0000000000 0 5 1 ! 4 68 0o00000000 0 5 I I 4 68 0000000000 0 5 1 I 4 68 0000000000 0 5 i 1 4 68 0000000000 0 5 1 I 4 68 0000000000 0 5 i i 4 68 0000000000 0 5 1 i 4 68 0000000000 chlu~ber.cer A!asK...a. mo~put!l~g Cen~ter 26-0CT-1994 21:52 23 mmmmmmmmmmmmmm~mmmmmmmmm~mmmmmmmmmm~mmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmm~mmmm DFDT !06P6.O0n ~IGEi. PSl 1].589 STDT,P$1 66.000 TPHI.P$1 ISHU~PS1 39.4&~ SFWP.PS! 14.690 SFND.P$1 16.566 SBHF.P$! 6~:.P$1 39.2~0 FTDT.P$1 10.685 NTDT.PS~ 30.887 AFFD.P$! A~Fn.D$~ 118.206 AF~)D.PS1 3~g.368 AB~D,PS1 475.834 SIGC.P$~ S!b}-).PS! 39.2~0 UMOF,p$i 0.947 TRAT.PS1 ~.972 BaCW.PS~ ~7.729 FBaC,PS1 10.!36 TCAN'PS! ]9907,~8! TCAF.PS! TC~.PS! 265~1.!37 TCFD,PS1 8153.375 T$CN.PS! 8473.984 TSCF.P$1 IN,~n,m$1 ~6)6,u65 I~FO.P$~ 3~9.~61 RNI.PS1 942,235 PF,!3.PS~ 1074,$11 RNg.PSI 1529.356 RN5.PS1 1666.667 ~M6.P$1 ~N7.~S1 932.765 RN@.P$1 819.129 RNg,PSl 1761.364 RNiO.P$~ R~11.P$! ~220.644 Rf'J12.PS1 1974,432 RN].3.PS1 15~0.417 RN14.PS~ RM1K.P$~ 5!6.(}g8 Ri'~6'PS1 464.015 RF1,PS1 303,030 RF~.PS1 PFC.PS1 255.6~2 RFg. PSi ~83.5~3 RF5-PSi 359.848 RF6.PS! ~FT.mS~ 265.1~1 RP@.P$1 32~,g.0 RFg.P$1 416.667 RFiO.P$~. ~FI~.DS~ 558.712 ~F~2.PSI 46~.750 RF13,P$1 407.~97 RF~4.PS~ R~IK PS~ 156.250 RF16." · ... Poi ~4~.045 GR.P$1 98.68g TENS.PS! CCL. P8~ 0. DEPT. 10296.000 SIG~,P$1 4~.46~ STDT.PS! ISM;!.PSI 50.7gl SFFD,PSi 43.586 SFND,PSI $~{~.~.PS~. a7.935 ~TDT'*PS! 3.2~8 NTDT,PSl ABFD.P$1 97.3~b ~FND~PSI 414'955 ABND.P$i STB~.PS! 54.931 !~OF'PS1 ! 047 TRAT,PS1 TC~DoPS{ 14929o645 TCFD,iPSi 333~.407 T$CN,PSI I~ND.PS! ~64!o81i INFD-PSi 385.505 RNI'P$t · ~ . -., ~ t'~ P~ ~Sl t,~'~56:134 k,~4,P$1 1503.1~3 RNE.'P$1 ~j?. P$1. 810.1~5 RNS.P$1 ~52.141. RN9~PS1 R~!I~ .PS1. ~.973.389 Ri~12!'PS! 1660.880 R~!I~.PS1 509.259 RNi6,PS1 558'!,t9 ~F3.PSI 250,563 RF4-PSl 323,761 RF5..PSi ~FT.PS~. 164,696 RFa.P$1 320 946 RF9,PS1 RFII.PSt 4a6.227 RF12,PS1 40~[590 RF15.P$I 108.3~0 RFI6.P$1 1i~.243 GR.PS1 CCI,.P$1 0.000 DATA 66.000 TPHI.P$1 44.188 · GBHF PSi 13o733~ AFFDiP$! 141~.496 940.393 154B.03~ 1594.3~9 1187.:789 297.016 335.:022 402.590 274.493 63,188 TSCF.PS1 RN2,PS1 RN6.PS1 RNIO.PS1 R~14.P$1. RF2.PS~ RFIO.P$1 RF14.PS~ TENS.PS1 30.271 32-681 91.481 1.047 0,221 15568.813 3305.910 103,200 1638.257 1695,076 857,007 30.960 397 727 411:932 250 947 ~990:000 61.:,25o 44'779 81..399 0'3tO 0'540 149781,666 342,835 150'578 1507,523 '!539'352 651. i*.042 39*960 342-:061 3~9~9~I .159:'065 2520,000 **** FILE FILE ~:A~Z SERVICE : FLIC YERSIO~ : ~OICO1 DATP : 04/!n/ ~AX REC ~IZE FIL~ 'tYPE L5S~ FII,E IS Tame Verif~.catfon t.,istJno 2&-OCT-1994 21~52 PACE: 24 FTL~ ~A,E : ~OTY .OO~ SFRVIC~ : FLTC M~X ~C SIZM : FILW Tym~ : LO b~S· rI!~ : Curves anO log header data for each cass in separate TDTP TDTP TDTP TDTP TDTP T D T P TPTP $ DFPT~i i?,~C~E~,-~E,~.:,T: ~). 5000 YEr~[)Og TnOL CODE START DEPT~ mhTE LOGGED: TI~,~E LOGGE~ O!,, BOTTO~: TIJ DRILLER ~D LOGGEP(FT) TOp LOC INTERVAL nOTTO~'~ LOG I~.~3j'~RVAL [~OG(;!i~C ~PEED fFPHR) T~O[., ST~I~G (TOP TO BOTTOm) VF~DO~ TOOL CODE TOOL TYPE T~ERMAL D~CAY THERMAL DECAY THERMAL DEC.~Y T}{ER ~AL DECAY THER;4AL DECAY THERMAL DECAY THERMAL DEC~.Y ~OPEUCLE AND C~8INC DATA OPEi~! {qO!~g g!T STZE (IU): DRILLER6 CS$ING DEPTM fFT): [,OGGERS CASING D~PTH (FT): STOP DEPTM 10.00.o flles~ raw bac~orou~d pass in last ~i 3t-AUG-94 CP38.2 1,025 31-AUG-94 t. 0804.0 10300.0 600, TOOL NUMBER T~C-P 50 TND-P 78 TN~-? 21 ~INITRON :8496 ATE 1163 CAL-U 597 AT~-AB 283 10804.0 IS ~ane ver!f~catlon !~istino Chlu~ber~er AlasKa Computing Center z60CT-~gg4 21::52 TYPE (~P!q'HgPMAb OR THFR~AL)~ CORR~CTIO~ [TN.J: THERMAL SANDSTONE 2.65 BLUFLI?~E COt?.NT PATE NO.R~AI.,IZATiON iN OIL ZONE TOP NOPMAI~IZ!kG WI]qDD~,~' (~T): Pb!!E[~i~E COUF.:T RAT~ SCALES SET BY FIFbD ENGInEeR FA~ COUNT PATE LO~ SCALE (CPS)~ FAP CC'3UN? RATE HIGH scALE ~CP'):~ ~E~R CO~JT RATE LOW SCA~E CCP$): ~:E~R COUNT R~TE HIgH $CA!,E (CPS): TOOl.., 5TA~DOFW ¢1~3)~ R~i~R~S: COt;:~EI..,ATE[: TO SWS CBL DOG OF 27-AUG-Ig94,T :tHrEE PASSES I,OGGF. D C)N SA~NDTONE ~ATRIX h,. 600 FPH. FOR ~,~A ~, DATA PAGE: 25 TABI, E 'I...PF , C~ APCO AbA,BRA, !NC, F~," PRUDHOE BAY W~! D o 37I ADiN 56S-62~-~2451-00. FL 201' FSL & 4962' VEL SF'C~ TO ~.~ iO ~ R~, ~ m I5 E COUN NORTH STAT AI, ASK~ i~ ~.T! USA WTT~? REYNO!.,DS/jOH~$ON 8P?~ 500540 Pr~A~ K~ Compa. nv Name mield Name Well Name AP1 Serial Number Field Location Section Township ~anqe County State or'Province Nation Witness Name Service Order Number Permanent datum Elevation of Permanent Datum to~ ~easured From IS ma,ne veriflcatfo~ ChlUmbe,rger A].ask'a Compt]ti. DO 26-0CT-~994 21:52 PAGE: 26 !!~hT V~I,U DEFI APD ~'T 46'3 Above Permanent Datum E~F ~T 46.3 Elevation of Kelly BushlD~ 20 7 T~ ~ ~t~I ~T 10668, T[I ~? i0300, DFT S~A ~TER TLA~ I0:25 31-~UG-94 Mlevation of Derric~ Floor Elevation of Ground bevel Total Depth - Driller Bottom bog Interval ToD boo Interval Drillln~ Fluid Type Time boqoer at Bottom Ya~t,E TYP~' : COPV DeDth Sioma fSeutron Capture Cross Section) Status of TOm · 5~ ~orosit¥ TQT Shunt Current $io~a formatlom - far detector (TDTP) Sigma formation - near detector (T~?TP) ~orebole Sigma - far detector gore~o]e $~Oma - Near detector Far ~DTM Count Rate ~3ear T{~T Count Rate ~Qlit~de for{~ation -- far detector (TDTP) ~!Dl~tude borehole -- Far detector (TDTP) ~plitude formation - near detector (TDTP) ~mplltude gorebo~e -- near detector Sigma Correction Corrected gorebole ~lnItron mode ~onitor ratio (TDTP) Ration Total Near to Far cotlmts ~tandard deviation of Sigma Sackqro~)~d Count Rates - ~ear Detector' ~ac~rou~ Co~3~t Rate - Far Detector Total counts analyzed - near detector (TDTP) Total counts analyzed - far detector (TDTP) ~'ota! capture counts - ~!ear detector Total capture Counts - far dectector Total Selected Cot~nts - aear Detector Total Selecte~ Counts - Far Detector ]inelastic count rate - near detector Inelastic count rate - far detector Raw ~ear 1st Gate Raw ~ear 2nd Gate ~aw ~ear 3rd Gate ~aw h~ear 4th Gate Raw ~ear 5th Gate ~aw ~ear 6th Gate ~aw ~3ear 7tn Gate IS Ta~e verification chlUm~'erger .~,]asNa Com[.,.ut..{n~ Center 26-nCT-t994 21:52 PAGE~ 27 RN9 ~a~ ~lear 9tn Gate RMI~ Raw ,<~ear 10th Gate R~'~I ~aw ~ear llth ~ate R~I~ Paw ~!ear l~th Gate R~13 ~aw ~,ear 13th Gate R~i~ Raw r!ear 14th Gate ~;1.~ Paw ~ear ~Sth (;ate k~l~ ~aw ~ear 16th Gate RF! Paw ~ar 3St Gate RF2 Raw war ~d Gate RF3 ~aw ~ar 3rd Gate RW4 Pa~: Far ~th Cate RF5 ~aw Far 5th Cate RP6 Pa~ war 6th Gate RF7 Paw Far 7th ~ate RF8 Paw Far ~th ~at.e ~F9 Raw War Otb Gate RF1O Daw rat 10tb Gate RFit Paw rat ~lth (;ate RFI? ~aw ~ar 12th Gate RFi3 Daw ~ar 13tn Gate RFI~ Paw Far ~4th Gate NFl5 ~aw Far ~stn Gate RF16 ~aw Far ~6tD Ga're GR ~PI-Co~rected Gamma Ray ~FN~ Surface Tension CCL fC5 AmPlitude I 66 0 2 66 0 3 73 ~60 4 66 5 66 o 73 7 65 ~ 68 0,5 1,3 66 1~ 65 FT i5 66 6~ IS Te,~e verification L.tsti~q cblumberc!~r ~,laska eomputir,~ Cepter 2a-OCT-!904 21:52 ~v E T S ~'¥IC~ API ~ ~ AP1 hP~ BE MO~B NU P PROCES ID ~DE~ ~ hOG TYPE Ch~$$ ~OD NU~B SA~P ELEM CODE (HMX) ................... ............ g; .............. '"'""' ...... '"'""g'"'""g" DFP~ F~ ~ 5~ O0 000 o 6 1 I 4 6~ 00000000 STG~ rS? C!! 500540 O0 OOO O0 0 6 1 1 4 68 STD· PS~ 5005~0 O0 TO~I D52 Eli 500540 GO 000 O0 0 6 1 I 4 68 I$~U PS~ ¥ 500540 O0 000 O0 0 6 1 1 4 68 SFF~ PS? C~ ~005ao O0 O00 00 0 6 1 1 4 68 $~N~ PS? C~ 50054,0 00 000 00 0 6 1 1 4 68 $~W PS? C~ S00540 00 000 00 0 6 1 ! 4 68 $~ PS? C~} 500540 00 000 00 0 6 1 1 4 68 ~TQT PS~ CD~ 5005~0 O0 00O 00 0 6 1 1 4 68 NTOT P$~ CD~ 500540 00 000 00 0 6 AFF~ PS? CPS 500540 O0 000 O0 0 6 1 1 4 68 A~F~ PS2 CPS ~00540 O0 000 O0 0 6 1 I 4 6~ AF,NB PS? CPS 500540 OO 000 O0 0 6 ! ABND PS? CPS ~00540 O0 000 O0 0 6 1 I 4 68 (,_ P~2 Cu 500540 o0 000 O 0 6 I 1 4 68 $IB~ PS~ Cu 500540 O0 000 O0 0 6 1 1 4 68 M~O~ PS? 500540 O0 000 O0 0 6 I I 4 68 T~AT P$2 K00540 O0 000 O0 0 6 1 1 4 68 SDSI P$2 CU 500540 O0 000 O0 0 6 1 1 4 68 BIC~ PS? CPS 500540 O0 OOO O0 0 6 I I 4 6B FBAC PS~ CPS K00540 O0 000 O0 0 6 TCAN PS2 CPS 500540 O0 000 O0 0 6 1 1 4 68 TCAF PS? CPS 500540 O0 OOO O0 0 6 1 1 4 68 TCND PS~ CPS 500540 O0 000 O0 0 6 TCF~ PS2 CPS 500540 oO 000 O0 0 6 I I 4 68 TSC~ PS~ CPS 500540 O0 000 O0 0 6 T$C~ PS~ CPS 50054O O0 000 O0 0 6 ! 1 4 68 IMN9 P82 CoS 500540 I~FD PS~ CPS 500540 0O 00O 00 0 6 ! i 4 6~ ~'1 PS2 CPS 500540 OO 0o0 O0 0 6 1 I 4 68 RN2 PS2 CPS 50o540 O~ 000 oO 0 6 1 1 4 68 R~3 P$~ CPS 500540 O0 000 O0 0 6 1 1 4 68 R~4 P52 CPS 500540 O0 000 O0 0 6 ~5 PS? CoS ~00540 O0 000 O0 0 6 I 1. 4 68 R~6 PS~ CPS 500540 O0 000 O0 0 6 R~7 PS? CPS 500540 O0 000 O0 0 6 1 I ~ 68 R~{8 PS2 CPM 500540 oO 000 O0 0 6 1 1 4 6~ R~J9 PS~ CPS 500540 O0 000 O0 0 6 I i 4 68 RNIC PS? CPS 500540 nO 000 O0 0 6 R~I~ P$2 CPS 500540 O0 000 O0 0 6 I 1 4 68 R~i~ P$~ CPS 50~540 O0 000 O0 0 6 I I 4 68 R~13 P82 CPS 5005~0 O0 000 O0 0 6 ! 1 4 68 0000000000 0000oo0000 o000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 o000000000 o000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 000000000.0 0000000000 0000000000 0000000000 0000000000 0000000000 00000o0000 0000000000 0000000000 0000000000 0000000000 0000000000 o000000000 0000000000 0000000000 000000o000 0000000000 0000000000 o000000000 IS Tane V~.tificat.ton !_istino Chlumberqer AlasKa CompuSin~ center 26-0CT-19~4 21:52 29 m m ........ ........... R~I~ P82 CPS soo54o RNi~ PS2 C25 ~00540 RF1 P~2 CPS 5005{0 R~2 PS~ CPS K90549 RF3 PS2 CPS 5005a0 RF4 P52 CPS 500540 RF5 PS2 CPS 50054(~ RF6 mS2 CPS g00540 RF7 F$2 CPS 5uo540 RF8 ~S? CP6 500540 RWl~ ~52 CPS 500540 RFXt PS2 CPS ~00540 RPI? PS? CPS 500540 R~13 PS2 CPS 500540 RFI4 PS~ CPS 500540 RF1K PS? CPS 50r~540 RW16 PS2 CPS 500540 GR PS~ GAPI 5005a0 ~rF~ PS2 t,~ 500540 CCh PS2 ¥ 500540 mmmmmmmmmmmmmmmmmmm#mmmmm! m#m~'~mmmmmm mm~,mm,mmmmmmmmmmmmmmmmmmmm mmmm#m LOG TYPE CLASS ~{OO NUmB SA~P EbEN 0 000 O0 6 1 1 CODE ( HEX ) ............ 4 68 0000 ~ 000 n0 000 00 0 6 1 1 4 68 O000000000 o0 000 O0 0 6 1 1 4 68 0000000000 00 000 O0 0 6 1 1 4 68 0000000000 00 000 O0 n 6 1 1 4 68 0000000000 oO OeO O0 0 6 1 I 4 68 OOO0000000 O0 000 O0 n 6 1 I 4 68 0000000000 oO OOC O0 ~ 6 1 1 4 68 o000000000 O0 OeO O0 0 6 1 1 4 68 0000000000 DO 006 O0 0 6 1 1 4 68 0000000000 O0 000 O0 0 6 1 1 4 68 0000000000 00 000 O0 0 6 1 1 4 68 0000000000 DO 000 O0 O 6 ! I 4 68 0o00000000 ou 000 O0 0 6 1 1 4 68 0000000000 O0 uO0 O0 0 6 1 1 4 68 0000000000 O0 0o() O0 o 6 1 I 4 68 0000000000 O0 00() O0 0 6 1 1 4 68 0000000000 DO 000 O0 0 6 1 1 4 68 0000000000 00 000 O0 0 6 1 1 4 68 0000000000 oO DO0 O0 0 6 1 1 4 68 0000000000 O0 000 O0 0 6 1 I 4 68 0000000000 O0 000 O0 0 6 1 1 4 68 0000000000 DEPt. I06~a.500 $iai!,PS2 ISHU.PS2 42,563 SFFD*PS2 SBfi~,PS2 47,935 FTDT.PS2 A~FD.P$? q7.365 AFMO.PS2 ST~.P52 ~4.~31 MMOF.P$2 BICK.PS~ i~?.i09 F~,IC.PS2 TCN~.Pa? !.49P9.~45 TCFD,PS2 INND.PS2 18a1.,.~l ! D.PS2 PN3,PS2 1065.341 R~4.PS2 RNT.DS2 1.003.7~ R~8.PS2 RNI~,PS? 2267.902 R{~12.PS2 RM15.P82 !8i,250 'RN16-PS2 PFC,PS2 293,561 RFg.PS2 ~F7,PS2 539.7V3 RPS.PS2 RFI1 .PS2 b~l .$1$ RF1 2,PS2 RFlg. P69 a75'947 RF16°PS2 DEPT. 10277,50(} Ps~ 5o 2?0 BIC~.~6? 174.664 $I(;M'PS2 SFFD.PS2 AFrO.PS2 ~dOF.P82 FB.AC.PS2 4 4 41 3 333 38 150 205 q 0 34 70 I o5 3.462 3,586 3.2~ 4.955 1,047 4.505 2.4U7 5.505 0,947 7,007 0.1~9 4.356 7,~97 5.644 0 757 5 ~7~ ST.. ~ .PS2 66.000 I': HI.PS2 SFND,PS2 44,188 $BHF,PS2 g T D T :*PS 2 1 3 .. 7 3 3 A F F D. P S 2 ABND~P$2 440,035 TRAT*:PS2 1':974 TCA4,PS2 64126. 172 TCAF.DS2 TSCN'PS2 ~412'496 TSCF RN'I-P82 909.091 RN2~PS2 R~5,P82 t609. 848 R~6.PS~ RNg'PS2 1661.932 2 ~N13.PS2 1695,:076 RNI4.PS2 R F l ::, PS 2 28.4 *. 091 R F2. P S 2 RFS,PS2 482.955 RF6.PS2 RFg.PS2 46~.750 RF13,PS2 629,735 RFI .~.PS2 GR.PS2 257.000 4t.732 STDT.PS2 66 000 ~PHI.PS2 42.301 SFND,PS2 42:73! $BHF*PS2 3.8:98 NTDT:*PS:2 15,377 A~FD,PS2 414.072 ABN~.PS2 442 820 SIGC.P$~ 38.348 TCAN;:-PS2 59955.188 TCAF.P82 6t'250 4.4,779 81..399 0,310 0'540 14978'.666 342.835 2t6.720 !671.~401 1699'811 1017.'992 56, 182 6~ 553 19 000 4.1..398 14581,289 IS Tare Ver]fi. cat.~on chlumhergor [,laska ComF, utJnq Center 26-0CT-~904 21:52 PAGE~ 3O TC~P, P$2 155~,~.~% TCVg. P$2 I ~,~.:r~. P$2 18og. SPb T~:FD. PS2 PN3.PS2 1103.604 PN 7. P$~ [~75.971 R~'3R, PS2 R~I~ .P82 2053.772 ~1~ PS7 6~2 331 PF3, PS2 2aD, 3~u PF4, P.~2 PF7. PS~ 1o2. ~ 49 RF8 .P~2 RFI~ .DS2 5~9.4~0 PF12.PS2 RFI~,PSP 135,135 RF16,PS2 CCI., P6~ o. 359!.~41 TSC~.P$2 392.!.54 RM1,PS2 1462.763 RN5.PS2 83R.~64 RN9.PS2 1~11.~55 ~N13.PS2 675,61~ RFi,~S2 323,7OI RFS.PS2 32~.354 RFg. Ps2 ~16.66~ RFI3.PS2 152.027 GR.P$2 1635.57g TSCF,PS2 89~.67~ 1535.754 1638.513 335.867 RN14.PS2 1~B4.347 344.876 RF6,PS2 422 297 RFIO.PS2 320:g46 RF14eP$2 80.250 TE~S.PS2 418 789 184!353 1524 493 1585.022 826.295 32.367 347.691 3731029 188 626 2~951ooo SERviCE : FLIC VERSI~ : n01COl DAT~ : q4/!O/ 3 ~X R~C SIZ~ : ~U~4 F!LF TYPE : LO LAST PILE : **** FILE HEnOER **** FIL? DA*~E : EDIT .007 SERVICE ~ FL!C ~X aEC SIZE : 10~4 F~,t,E TYPE : LO LAST FILE PAS DFP CURVg$ Curves an~ TH INCRE~E~T: F VENDOR TOOL CODE LOG HFAPEP DATA ~ATE' L," 7 , SGFT!~'ARE VERSION nea. der data 3 0.5000 for each START DEPTH Pass in separate STOP DEPTH 31-AUG-94 CP38,2 files,, raw background pass IS Tame Verificati. ont. istin~ chl,.l~'~berger AlasKa ¢omputlno CeNter 26-0CT-1994 21:52 PAGE: 31 ?I:4~ LOG~ER ON bOTTU:,~: TU 4)PILLAR TO LOGGE~(~T): TOP LOC INTERVAL (F3'): BOTTO? bOG I~T~RVA~, tOCGTNG SPEED TOOL STPING TN~MAL DECAY TMEP~b DECAY THERMAL DECAY T~E~L DECAY THEP!4AL D~CAY T~ERMAL DECAY 1025 10~04.0 10300.o 10668.0 600.0 TOOL NUMBER TNC-P 50 TND-P 78 TNG-P 21 MINITRON 8496 ATC 1163 CAL-U 597 ATE-AB 283 DRIbLEtS CAST,IS DEPT~ (FT): LOGGERS CAS!~G DEPTH (FTC: ~OPEMO[,~ CONDITIONS FLUID TYPE: FI,UID DENSITY (LB/G3: ~{.]RFACE TE~PEPATU~E (DEGF): BOTTO~ ~OLE TEMPERATURE (DEGF): FLUID SALINITY (:PP~): ?Lf.!ID LEVEL (FT)~ FLUID RATE AT ~EbLH~AD ¼AT~R CUTS G~S/O!L C~OKE TOOL TYPf (EP!THER~AL :OR THERMAL): ~!~T~IX DE,:~iSTTY: H{?LK CORR~CTIO~ (IN): BLUELI~:4E COUNT PATE i:'~JORMALIZATIO~ IM Oil ZONE TOP NORMALIZING WINDOW BASE NORMALIZING WINDOW gD!!E~,INE C~ONT R~TE SCALES S~T BY FIELD ENGINEER FAR COI,IN~ RATE bO~ SCALE (CPS)~ WAR COUNT PAT~ HIGH $C,~LE (CPS): wE~R COUNT R~TK LOW SCALE ~!E&R CCU~T RATE MiGH SCAI.,E (CPS): 10804.0 SEA WATE~ THERMAL SANDSTONE 2.65 IS Tare ver~.f~catton l, ist!.n~. chlumber<jer Al. asKa Co~p,~tJ.n~ Ce,ret PAGE: ]2 TI)tiT VALb DEFI PRUDHOE B~¥ Field Name ~ D ~ ~ - 37I ~ ~,,, 5~- ~ 2 ~- ~ ~ ~ s ~.- o o SFC~' 1 T~~ I0 ~ C~O~' NORTH ST~T WIT~ R~¥NOLDS/JO~NSOM $0~: 50O54O PDAT EDD FT O. L~F KB APb MT EDF ~T 45.3 E~L ?T 20 7 TDD FT 10~04. BLI WI 10668. TY.,I FT 10300" T[,A~ 10:~5 31-AUG-94 well Name APl Serial Number Field Location Section Township County State or Province Marion Witness ~a~e Service Order Number Permanent datum Elevation of Permanent Datum Lo~ ~easured Above Permanent Datum Elevate. on of Kel,l,¥ Elevation of Derrlc~ Floor ~levatlon of Ground Level Total Depth - Driller Bottom Log Interval Top Log Interval Drilling flul~ Type Time Logger at BOttom TABLE TYP~ : CU~V D~F! S~G~ STD? FTDT NTDT AFFm $iama CI':eutron Capture Cross SeCtion) Status of TnT TD~ PorosttV TnT Shunt Current ~icma form~t, lon- far detector (TDTP) Sigma formatlom -near detector (TDTP) Borebo~.e S~,.g~a - far detector 8orebole 8.igma - Near detector Far ~D~-~ Count }::ate ~,~ear TOT Count kate ~mDl~t..]ae fore, at!on-- far ~etector (TPTP) IS vane verf. ff. cati. on CblUmberner ~lasKa Computin~ Center 26-DCT-1994 21:52 AB ~nl~ borehole r detector . DTP) ~,'aDl~.tUd~ formation - near oetector (TOTP) ~litude gorehole -- near detector ~i~ma Correction Corrected Borehole ~initron ~ode monitor ratio (TDTP) ~ation l'otal ~ear to Far counts StaDdard deviation of Backoround Count ~ates - ~ear Detector ~acKorOUD~ Count Rate - Far Detector Total counts analyzed - near detector (TDTP) Total counts analyzed - far detector ~otal capture counts - ~ear detector Total capture Counts - far dectector Total Selected Counts - Near Detector Total ~electe~ Counts - Far Detector Inelastic count rate - near detector Tnelastic count rate - far ~etector Raw ~ear 1st Gate paw ~ear 2Dd Gate Raw ~ear 3rd 6ate Raw ~ear gtn Gate Raw ~!ear 5tn Gate Raw Near 6t~ Gate ~aw Meat 7th Gate ~aw ~ear 8th Gate Raw ~ear 9t~ Gate Raw Near loth Cate ~aw Near ll'th Gate ~aw ~ear t~th Gate ~aw ~ear 13th Gate Raw ~!ear 14th Gate Raw Near 15th Gate Raw ~ear 16th Gate Raw Far !st Gate ~aw war 2nd Gate Paw Far 3rd Gate ~aw Far 4th ~ate ~aw Far 5th Gate ~aw Far 6th Cate ~aw war 7th Gate Raw ~ar 8th Gate Paw Far 9th ~ate ~aw Far ~lth 6ate paw Far ~2th Gate paw Far ~3th ~ate Pa~ Far ~gtb Gate Raw Par ~5t:h Gate Paw Far 16tn Gate API-Corrected Gamma Pay CC~ PAGE: 33 IS Tsv~e Yeriflcati_on Listinq ChlUm~e.r. qer AlasKa Co~put.ino Center 26-OCT-J. 994 2! :52 PAGE: 34 ! 66 0 2 66 0 3 73 560 4 66 1 5 66 6 73 7 65 8 68 0,5 9 65 1.1 66 12 68 ~] 66 14 65 PT 15 66 68 16 66 0 66 *% SET TYPE - CHAN ** NA~W SWRV UNIT SER¥ICE API APl AP! APl FILE NUmB NUmB SIZE ~EPR P~OC£SS ID ORDER ~ LOG TYPE CLASS NOD NUMB SAMP ~LEM CODE (HEX) D PT FT 500540 O0 000 00 0 7 ! ! 4 68 0000000000 STP? TPHT ISHIJ PS3 S~HW PS3 FTDT PS3 NTDW AFFD PS~ ABFD AFND PS3 S!GC PS~ 8IBN TPAT PS3 CU 50054u OO 500540 O0 PU 500540 V 50054o O0 CU 500540 O0 CU ~00540 00 C!I 5005~0 O0 CU 500540 O0 CP~ 500540 Oo CPS 500540 oo CPS 500540 O0 CPS 500540 O0 CPS 500540 CPS 500540 oo CU ~on54o CU 500540 500540 C~ 50n540 CP~ 500540 nO 000 00 0 7 1 00U oO 0 7 1 000 O0 o 7 On0 O0 0 7 1 000 0o 0 7 00o O0 0 7 1 000 O0 0 7 000 O0 0 7 1 00O OO 0 7 1 000 O0 0 7 i 000 O0 0 7 000 00 0 7 1 000 O0 0 7 000 00 o 7 I 0o0 00 0 7 1 000 O0 0 7 1 O00 O0 0 7 1 000 O0 0 7 1 aPO O0 o 7 1 000 O0 0 7 1 I 4 68 0000000000 1 4 68 0000000000 1 4 68 0000000000 I 4 68 0000000000 1 4 68 0000000000 1 4 68 0000000000 I 4 68 0000000000 I 4 68 0000000000 1 4 68 0000000000 ! 4 68 0000000000 1 4 68 0000000000 I 4 68 0000000000 I 4 68 0000000000 1 4 68 0000000000 1 4 68 0000000000 1 4 68 0000000000 1 4 68 0000000000 1 4 68 0000000000 I 4 6~ 0000000000 i 4 68 0000000000 Chlt]roberoer. AlasKa .c. om{;~uti~o Center 26-0CT-1994 21:52 PAGE; 35 FF:V ,~ T S RVICE A API APl ! FILE NO B NUMB SIZE EPR PROCES T(~ mRD~P ~ b~G TYPE CLASS ~OO NUmB SAMP EbEM CODE (HEX) FRAC P 3 .. O0 0 O0 0 . I 1 4 ~ 00000000 0 TCA*! m$3 CPS 500540 O0 000 O0 0 7 I 1 4 TCAF PS3 CPS 500540 90 000 O0 0 7 1 1 4 TCNP PS] CP~ 500540 O0 000 O0 0 ? 1 1 4 TCFn P$3 CPS K00540 O0 000 O0 0 7 i I 4 T$CV PS3 CPS 50n540 O0 000 oO 0 7 1 I 4 TFCF PS3 CPS 560540 O0 000 O0 0 7 1 I 4 INND PS3 C~$ 500540 OO 000 oO 0 7 1 1 4 INFP PS] CPS ~00540 O0 000 O0 0 7 1 ! 4 R~!i PS3 CPS 50054.0 O0 000 O0 0 7 I 1 4 RN2 PS3 C~S 500546 O0 000 O0 0 7 1 I 4 RN3 PS3 CPS 500540 nO 000 O0 0 7 I I 4 ~'4 PSI CPS 500540 O0 000 O0 0 7 1 I 4 NN5 PS3 CPS 5u05~0 O0 000 O0 0 7 1 I 4 RN6 PS] CPS 5~0540 oO 000 O0 0 7 1 I 4 RN7 PS3 CPS 5U0540 OD 000 O0 0 7 1 1 4 RN8 PS3 CPS 500540 OO 000 O0 0 7 I 1 4 R~9 PS3 CPS 500540 O0 000 O0 0 7 1 I 4 RN!o P$3 CPS 500540 O0 000 O0 0 7 I 1 4 ~li PS3 CPS 500540 Or) 000 O0 0 7 I 1 4 R~I~ PS3 CPS 5005~0 O0 000 O0 0 7 1 1 4 RN13 PSI C~$ ~0054© O0 000 oo 0 7 I I 4 RNI~ PS3 CP6 500540 O0 000 O0 0 7 I I 4 RN1B PS3 CPS 500540 O0 000 O0 0 7 I I 4 R~)16 PS3 C~S 5O0540 O0 000 O0 0 7 1 I 4 RF! PS3 CPS 500540 O0 000 O0 0 7 1 1 4 RF2 PS~ CPS 50054u O0 000 O0 0 7 1 1 4 RF3 PS3 CPS 5~0540 O0 000 O0 0 7 ! 1 4 RF4 P$3 CPS 5U05~0 O0 000 00 0 ? I i 4 ~F5 PS3 CPS ~()05~0 O0 000 O0 0 7 1 I 4 R~b P83 CPS 5005aU 00 000 00 0 7 1 i 4 ~t7 PS3 CPS 5t~0540 O0 000 O0 o 7 I 1 4 RF8 PS3 CPS 50A540 O0 000 O0 0 7 1 1 4 R~9 P63 CPS 5~0540 O0 000 O0 0 7 I 1 4 ~1o P$3 CPS 500540 00 000 O0 0 7 1 ! 4 RFI! P$3 CPS 500540 00 000 00 0 7 1 ! 4 RFI? PS3 CPS 500549 00 000 O0 0 7 1 1 4 RFI3 P$3 CPS 500540 00 090 00 0 7 I t 4 RFI~, PS3 CPS 500540 00 000 O0 0 7 1 I 4 RF15 P63 CPS 500540 00 000 O0 C 7 '! ! 4 RFI6 PS3 CPS 500540 O0 000 o0 0 7 I 1 4 GP PS3 GAFf 5(;054O O0 000 O0 0 7 1 1 4 TENS P$3 LB 5905g9 O0 000 O0 0 7 1 I 4 CCL PS~ V 50n540 O0 000 O0 0 7 I I 4 68 0000000000 68 0000000000 0000000000 68 0000000000 68 OOO0000000 68 0000000000 68 0000000000 68 0000000000 68 0000000000 0000000000 68 0000000000 68 0000000000 68 0000000000 68 0000000000 0000000000 68 0000000000 0000000000 60 0000000000 68 0000000000 68 0000000000 68 0000000000 68 0000000000 68 0000000000 68 0000000000 68 0000000000 68 0000000000 68 0000000000 68 0000000000 68 0000000000 68 0000000000 68 0000000000 68 0000000000 68 0000000000 68 0000000000 68 0000000000 68 0000000000 68 0000000000 0000000000 68 0000000000 68 0000000000 68 0000000000 68 0000000000 68 0000000000 IS Tane ver~ffcat!.on 5ist~!n~. ch].umherger AlagK~ Co.~[~ut~n~ Center ISHU.DS_! 40.375 SFFD.P$3 SB~'.DS~ 45.~5b FTDT.PS3 TCNP. PS3 15594. 164 TCFD, PS3 I~ND.DS] 1809.5~6 I,~[3.PS3 ~N3 .PS3 ! 098 ..~g5 a ~-~4, PS 3 PNv. PS ~ 1051. 130 R'~ 8. PS 3 R~I~ .PS3 ~234.~4~ P~'~ 2.PS3 g~.~ 15.PS3 833.333 ~! 6.P83 ~F3. PS3 255. 682 RF4.PS3 ~F7 .PS3 227.2~3 RES .PS3 R~I~ ,PS3 544.5o~ RF12.PS3 RWlS,PS3 179.9~4 PFIb.PS3 CC~., PS3 ~, 00(2 DEPt. I0296,0~0 SIC~.PS3 ISHU,PS3 44.5~ SFmD.PS3 S~.PS3 48,4~6 FTDT.PS3 A~FD.PS3 05.137 AFND.PS3 81~w,PS3 56,045 ~F,PS3 BAC~,P$3 182.135 WMAC.P$3 TCMD,P$3 16852,525 TCFD,PS3 %MNn.PS3 ~905,253 T~FD,PS3 N,PS ! 0~5,737 R~,!4.PS3 ~ig,PS3 854.70t R~8.PS3 R~i ~ ,PS~ 1957.799 RN12,PS3 R~IE.PS3 662.393 Ri'~16.PS3 PF3,PS3 257,746 RF4'PS3 PFT,DS3 i76,2~2 RFS,PS3 RF15'PS3 145-566 RF~6:,'~P83 C£I~,PS3 0,00O END OF DATA **** FILE TRAILE~ FILF NA~,C : EDIT .0~7 6MRViCE : FbIC V~iR$ION : 001C0i DnT~ : 04110/ 3 ~A× REC SIZE ! !.02~ FIL~ TYPE L~$q" FILE : 26-0C~-~9~4 2~:52 41.73P 8TDT,P$3 66.000 ~2.30! SFND-PS3 42.731 3.898 MTDr.P$3 15.377 414.072 ~BND.P$3 442.820 1.~20 TRA'!.PS3 1,974 38.3~8 TCAN,P$3 59955,188 3591.241 TSC~i,PS3 1635.578 392.154 RN1.P$3 937,500 i5a~.295 R~.!5,PS3 ~590.909 82~.598 RM9,PS3 1699,811 2059,65~ ~N13,PS3 1590.909 918.56~ RFI,P$3 293.56! 350,379 RFS,PS3 359.848 ~88,826 RFg,PS3 473.485 506,629 RF~3,P83 426.136 203.598 ~a 087 STDT,PS3 4.4[~35 8FNO.P$3 3.240 NTDT,P$3 405.726 ABND',PS3 ~..042 TRAT,PS3 ~1.327 TCAN,PS3 3318.792 T$CN*PS3 385,439 RNI*PS3 1489,049 RN5:,~PS3 804,049 RN9,PS3 1682,692 ~NI3*PS3 729o!~7 RF'l,P83 339,~0q RFS-PS3 320.5i3 RF9'P8~ 395,P99 RF~3*P8 ~68.269 GR.PS3 66,000 44.087 13,97] 432 362 6918~ 125~ 1533 120 1553,~52 12X2,:607 303 ~52 317 842 38? 286 ~7t 100 9~,3~ TPHI.PS3 SBhF.PS3 AFFD.PS3 SIGC.PS3 SDSI.PS3 TCAF,P$3 ~scr.~S~ ~N2,PS3 RN6.PS3 RN10,P63 RM14.PS3 RF2.PS3 RF6.P$3 RF10.P$3 RF14.P$3 TENS.PS3 TP~I.P$3 SBHF.PS3 AFFD.P$3 SIGC,PS3 SDSI.PS3 TCAF.PS3 TSCF'P$3 RN2.P$3 RN6ePS3 RNI0.PS3 R~14.P$3 RF2,P83 RF6,P8~ RFI4.P$3 TENS,PS3 PAGEI 36 56,306 41.398 85,007 0,427 0,486 14581:~89 418 89 216.720 1709.250 1614.583 1117.424 77.400 416,667 445.,076 274,6~! ~0~0.000 65,570 48,095 82,112 0.000 0,579 15987,568 333.624 181,890 1494~391 I526',442 759*882 38'700 332,532 380.'609 173.,6~1 ~400:~000 v~r {~fication T.,is t In,~ Alaska Com~ut~.nc CeNter 26-nCT-!gg4 21:52 37 GPI~IM : FLOC P~EVI~ig ~APE C~,i~E~,,~ : ~r!.~ A~,ASK~ %NC,, D,S, 9-37I~ PRUDHQE BAY, 50-029-22451-00 SFRv!c5 ~M : EDIT D~TF : ~4/10t 3 CO~"EHT : ~RCO A!~AgK~ INC., D.S, 9-371, PRT!DHOE BAY, 50-02g-~245~-00
