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177-057
7. Property Designation (Lease Number): 1. Operations Performed: 2. Operator Name: 3. Address: 4. Well Class Before Work:5. Permit to Drill Number: 6. API Number: 8. Well Name and Number: 9. Logs (List logs and submit electronic data per 20AAC25.071): 10. Field/Pool(s): Susp Well Insp Install Whipstock Mod Artificial Lift Perforate New Pool Perforate Plug Perforations Coiled Tubing Ops Other Stimulate Fracture Stimulate Alter Casing Pull Tubing Repair Well Other: Change Approved Program Operations shutdown 11. Present Well Condition Summary: Casing Length Size MD TVD Burst Collapse Exploratory Stratigraphic Development Service 14. Attachments (required per 20 AAC 25.070, 25.071, & 25.283) 16. Well Status after work: 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. OIL GAS WINJ WAG GINJ WDSPL GSTOR Suspended SPLUG Authorized Name and Digital Signature with Date: Authorized Title: Contact Name: Contact Email: Contact Phone: PBU 01-11 Convert Injector to Producer Hilcorp North Slope, LLC 3800 Centerpoint Dr, Suite 1400, Anchorage, AK 99503 177-057 50-029-20268-00-00 11010 Conductor Surface Intermediate Production 9434 85 2682 10981 10395 20" 13-3/8" 9-5/8" 8900 32 - 117 31 - 2713 29 - 11010 32 - 117 31 - 2713 29 - 9435 unknown 520 2670 4760 10395 1530 5380 6870 10238 - 10601 5-1/2" 17# & 5-1/2" 17# x 4-1/2" L-80 & N-80 28 - 9701 & 9894-10024 8765 - 9077 Structural 5-1/2" HES TNT No SSSV Bo York Operations Manager Dave Bjork David.Bjork@hilcorp.com 907.564.4672 PRUDHOE BAY / PRUDHOE OIL Total Depth Effective Depth measured true vertical feet feet feet feet measured true vertical measured measured feet feet feet feet measured true vertical Plugs Junk Packer Measured depth True Vertical depth feet feet Perforation depth Tubing (size, grade, measured and true vertical depth) Packers and SSSV (type, measured and true vertical depth) 12. Stimulation or cement squeeze summary: Intervals treated (measured): Treatment descriptions including volumes used and final pressure: 13a.Representative Daily Average Production or Injection Data Oil -Bbl Gas-Mcf Water -Bbl Casing Pressure Tubing Pressure Prior to well operation: Subsequent to operation: 15. Well Class after work: Exploratory Development Service StratigraphicDaily Report of Well Operations Copies of Logs and Surveys Run Electronic Fracture Stimulation Data Sundry Number or N/A if C.O. Exempt: ADL 0028329 28 - 8308 & 8471 - 0 785 0 55258 0 4868 0 0 0 1002 323-089 13b. Pools active after work:PRUDHOE OIL 9617 / 8237 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS Sr Pet Eng: Sr Pet Geo: Form 10-404 Revised 10/2022 Submit in PDF format to aogcc.permitting@alaska.gov Sr Res Eng: Due Within 30 days of Operations 9617 8237 12.6# Digitally signed by Bo York (1248) DN: cn=Bo York (1248) Date: 2023.08.17 14:28:21 -08'00' By Grace Christianson at 9:02 am, Aug 18, 2023 WCB 4-8-2024 DSR-8/18/23 RBDMS JSB 082423 ACTIVITYDATE SUMMARY 7/23/2023 Well start up check list complete. Copy filed at drill site in well folder and copy given to DSL. Well should be good to BOL. Daily Report of Well Operations PBU 01-11 7. If perforating: 1. Type of Request: 2. Operator Name: 3. Address: 4. Current Well Class:5. Permit to Drill Number: 6. API Number: 8. Well Name and Number: 9. Property Designation (Lease Number):10. Field: Abandon Suspend Plug for Redrill Perforate New Pool Perforate Plug Perforations Re-enter Susp Well Other Stimulate Fracture Stimulate Alter Casing Pull Tubing Repair Well Other: Change Approved Program Operations shutdown What Regulation or Conservation Order governs well spacing in thes pool? Will planned perforations require a spacing exception?Yes No 11. Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD: Effective Depth TVD: MPSP (psi): Plugs (MD): Junk (MD): PRESENT WELL CONDITION SUMMARY Perforation Depth MD (ft): Perforation Depth TVD (ft):Tubing Size: Tubing Grade: Tubing MD (ft): Packers and SSSV Type:Packers and SSSV MD (ft) and TVD (ft): Casing Length Size MD TVD Burst Collapse Exploratory Stratigraphic Development Service 12. Attachments: 14. Estimated Date for Commencing Operations: 13. Well Class after proposed work: 15. Well Status after proposed work: 16. Verbal Approval: 17. I hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approcal. Proposal Summary Wellbore schematic BOP SketchDetailed Operations Program OIL GAS WINJ WAG GINJ WDSPL GSTOR Op Shutdown Suspended SPLUG Abandoned ServiceDevelopmentStrastigraphicExploratory Authorized Name and Digital Signature with Date: Authorized Title: Contact Name: Contact Email: Contact Phone: AOGCC USE ONLY Commission Representative: Conditions of approval: Notify Commission so that a representative may witness Sundry Number: Location ClearanceMechanical Integrity TestBOP TestPlug Integrity Other: Post Initial Injection MIT Req'd? Spacing Exception Required?Yes Yes No No Subsequent Form Required: Approved By:Date: APPROVED BY THE AOGCCCOMMISSIONER PBU 01-11 Convert Injector to Producer Hilcorp North Slope, LLC 3800 Centerpoint Dr, Suite 1400, Anchorage, AK 99503 177-057 50-029-20268-00-00 ADL 0028329 11010 Conductor Surface Intermediate Production 9434 85 2682 10981 10395 20" 13-3/8" 9-5/8" 8900 32 - 117 31 - 2713 29 - 11010 2400 32 - 117 31 - 2713 29 - 9435 unknown 520 2670 4760 10395 1530 5380 6870 10238 - 10601 L-80 & N-80 28 - 9701 & 9894-100248765 - 9077 Structural 5-1/2" HES TNT No SSSV 9617 / 8237 Date: Bo York Operations Manager David Bjork David.Bjork@hilcorp.com 907.564.4672 PRUDHOE BAY 3/15/2023 Current Pools: PRUDHOE OIL Proposed Pools: PRUDHOE OIL STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 Comm. Comm.Sr Pet Eng Sr Pet Geo Sr Res Eng Form 10-403 Revised 10/2022 Approved application is valid for 12 months from the date of approval.Submit PDF to aogcc.permitting@alaska.gov 5-1/2" 17# & 5-1/2" 17# x 4-1/2" 12.6# By Samantha Carlisle at 12:47 pm, Feb 13, 2023 323-089 Digitally signed by Bo York (1248) DN: cn=Bo York (1248), ou=Users Date: 2023.02.13 11:32:19 -09'00' MGR13FEB23 DSR-2/13/23 DLB 02/14/2023 10-404X GCW 02/16/23JLC 2/16/2023 2/16/23Brett W. Huber, Sr. Digitally signed by Brett W. Huber, Sr. Date: 2023.02.16 14:26:35 -09'00' RBDMS JSB 022123 CAUTION: This email originated from outside the State of Alaska mail system. Do not click links or open attachments unless you recognize the sender and know the content is safe. From:Wallace, Chris D (OGC) To:AOGCC Records (CED sponsored) Subject:FW: NOT OPERABLE: Injector 01-11 (PTD #1770570) will lapse on 4-year MIT-IA Date:Tuesday, January 17, 2023 8:29:31 AM From: PB Wells Integrity <PBWellsIntegrity@hilcorp.com> Sent: Sunday, January 15, 2023 3:44 PM To: Wallace, Chris D (OGC) <chris.wallace@alaska.gov> Cc: Regg, James B (OGC) <jim.regg@alaska.gov>; Oliver Sternicki <Oliver.Sternicki@hilcorp.com>; Ron Phillips - (C) <Ron.Phillips@hilcorp.com>; PB Wells Integrity <PBWellsIntegrity@hilcorp.com> Subject: NOT OPERABLE: Injector 01-11 (PTD #1770570) will lapse on 4-year MIT-IA Mr. Wallace, Injector 01-11 (PTD #1770570) is due for its required AOGCC 4-year MIT-IA by the end of February. Currently there are no plans to put the well online and it will lapse on the MIT-IA. The well will now be classified as NOT OPERABLE for tracking purposes. Please respond with any questions. Andy Ogg Hilcorp Alaska LLC Field Well Integrity andrew.ogg@hilcorp.com P: (907) 659-5102 M: (307)399-3816 The information contained in this email message is confidential and may be legally privileged and is intended only for the use of theindividual or entity named above. If you are not an intended recipient or if you have received this message in error, you are herebynotified that any dissemination, distribution, or copy of this email is strictly prohibited. If you have received this email in error, pleaseimmediately 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 theonward transmission, opening, or use of this message and any attachments will not adversely affect its systems or data. No responsibilityis accepted by the company in this regard and the recipient should carry out such virus and other checks as it considers appropriate. MEMORANDUM State of Alaska Pretest Alaska Oil and Gas Conservation Commission 15 Min 30 Min 45.1in 60.Min DATE: Wednesday, January 23, 2019 TO: Jim Re I t % ' e IlZ4' y, 181 P.I. Supervisor SUBJECT: Mechanical Integrity Tests 2059 BP EXPLORATION (ALASKA) INC. 3U9 01-11 FROM: Jeff Jones PRUDHOE BAY UNIT 01-1I Petroleum Inspector IA 34 - Src: Inspector Reviewed By: P.I. Supry JY>,Q- NON-CONFIDENTIAL Comm Well Name PRUDHOE BAY UNIT 01-11 Insp Num: mitJJ190118140817 Rel Insp Num: API Well Number 50-029-20268-00-00 Inspector Name: Jeff Jones Permit Number: 177-057-0 Inspection Date: 1/8/2019 - Packer Well 01-11 Type Inj I w TVD PTD 1770570 Type Testj SPT ITest psi Bs.1 BBL Returned: BL PuTped-. Intervall 4YRTST P/F Notes: I well inspected; no exceptions noted Depth Pretest Initial 15 Min 30 Min 45.1in 60.Min S23- Tubing 181 181 Iso I:0 2059 IA 3U9 2502 - 2488 2151 3.7 OA IA 34 - 35 76 P T5} cote sic -a- 5"ce Qwk- Pr6y- CIC'e" �Ca 1-tT-r 1/+I Zd l el CRYA e,LACLS V¢(1g) Wednesday, January 23, 2019 Page I of 1 0 Wallace, Chris D (DOA) • From: AK, GWO Well Integrity Engineer <AKGWOWellSiteEnginee@bp.com> Sent: Friday, January 4, 2019 9:11 AM To: Wallace, Chris D (DOA); AK, OPS EOC Specialists; AK, OPS FS1 DS Ops Lead; Ak, OPS FS1 Facility PTL; Ak, OPS FS1 Field PTL; AK, OPS FS1 OSM; AK, RES GPB East Wells Opt Engr; AK, RES GPB West Wells Opt Engr; AKOpsProdEOCTL, Brown, Don L.; G GPB FS1 Drillsites; Oestgaard, Finn; Vandergon, Mark A Cc: Regg, James B (DOA); 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; Dickerman, Eric; Hibbert, Michael; Janowski, Carrie; Montgomery, Travis J; Munk, Corey; Obrigewitch, Beau; O'connor, Katherine; Sternicki, Oliver R; Tempel, Joshua; Worthington, Aras J Subject: OPERABLE: Injector 01-11 (PTD #1770570) ready to be POI, will need AOGCC MIT -IA All, Injector 01-11 (PTD #1770570) was made Not Operable for tracking purposes after it lapsed on its 4 -year AOGCC MIT -IA. The well is now ready for injection and is classified as OPERABLE. Once the well is thermally stable, an AOGCC MIT -IA will be performed. Please respond with any questions. Andrew Ogg SCANNED JAN 0 7 2019 Well Integrity Engineer BP Global Wells Organization - Alaska Office: 907-659-8110 From: AK, GWO Well Integrity Engineer Sent: Tuesday, January 1, 2019 4:05 PM To: 'chras.waIla ce@alaska.gov' <chris.waIlace@alaska.gov>; AK, OPS EOC Specialists <AKOPSEOCSpecialists@bp.com>; AK, OPS FS1DSOps Lead <AKOPSFS1DSOpsLead@bp.com>; Ak, OPS FS1 Facility PTL <akopsfslfacilityptl@bp.com>; Ak, OPS FS1 Field PTL<akopsfslfieldptl@bp.com>; AK, OPS FS1 OSM <AKOPSFS10SM@bp.com>; AK, RES GPB East Wells Opt Engr <AKRESGPBEastWelisOptEngr@bp.com>; AK, RES GPB West Wells Opt Engr <AKRESGPBWestWellsOpt2@bp.com>; AKOpsProdEOCTL <AKOPSPCCEOCTL@bp.com>; Brown, Don L. <browd2@BP.com>; G GPB FS1 Drillsites <ggpbfsldrillsites@BP.com>; Oestgaard, Finn <Finn.Oestgaard@bp.com>; Vandergon, Mark A <Mark.Vandergon@bp.com> Cc:'Regg, James B (DOA) (jim.regg@alaskagov)' <jim.regg@alaska.gov>; AK, GWO Completions Well Integrity <AKDCWLCompletionsSupt@bp.com>; AK, GWO DHD Well Integrity <AKD&CDHDWelllntegri@bp.com>; AK, GWO Projects Well Integrity<AKDCProjectsWe I I I ntegrityE ngi nee r@ bp.com >; AK, GWO SUPT Well Integrity <AKDCWelllntegrityCoordinator@bp.com>; AK, GWO Well Integrity Well Information <akgwowellintegritywe@bp.com>; AK, OPS FF Well Ops Comp Rep <AKOPSFFWeIIOpsCompRep@bpcom>; AKIMS App User <akimsuser.service@bp.com>; Cismoski, Doug A <CismosDA@BP.com>; Daniel, Ryan <Ryan.Daniel@bp.com>; Dempsey, David G <David.Dem pseyl@bp.com>; Dickerman, Eric <Eric.Dickerman@bp.com>; Hibbert, Michael <Michael.Hibbert@BP.com>; Janowski, Carrie <Carrie.Janowski@bp.com>; Montgomery, Travis J <Travis.Montgomery@bp.com>; Munk, Corey <Corey. M unk@bp.com>; Obrigewitch, Beau <BEAU.OBRIGEWITCH@bp.com>; O'connor, Katherine <Katherine.O'connor@bp.com>; Sternicki, Oliver R <Oliver.Sternicki@bp.com>; Tempel, Joshua <Joshua.Tempel@bp.com>; Worthington, Aras J Wallace, Chris D (DOA) From: AK, GWO Well Integrity Engineer <AKGWOWellSiteEnginee@bp.com> Sent: Tuesday, January 1, 2019 4:05 PM To: Wallace, Chris D (DOA); AK, OPS EOC Specialists; AK, OPS FS1 DS Ops Lead; Ak, OPS FS1 Facility PTL; Ak, OPS FS1 Field PTL; AK, OPS FS1 OSM; AK, RES GPB East Wells Opt Engr; AK, RES GPB West Wells Opt Engr; AKOpsProdEOCTL; Brown, Don L.; G GPB FS1 Drillsites; Oestgaard, Finn; Vandergon, Mark A Cc: Regg, James B (DOA); 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; Dickerman, Eric; Hibbert, Michael; Janowski, Carrie; Montgomery, Travis J; Munk, Corey; Obrigewitch, Beau; O'connor, Katherine; Sternicki, Oliver R; Tempel, Joshua; Worthington, Aras J Subject: NOT OPERABLE: Injector 01-11 (PTD #1770570) overdue for 4 -year AOGCC MIT -IA All, Injector 01-11 (PTD # 1770570) is currently shut in for surface repairs. The well was due for its 4 -year AOGCC MIT -IA by the end of December and the repairs are not expected to be completed in a timely manner. The well is now classified as NOT OPERABLE for tracking purposes. When the surface repairs are complete, an AOGCC witnessed MIT -IA will be scheduled. Please respond with any questions. Andrew Ogg Well Integrity Engineer BP Global Wells Organization -Alaska Office: 907-659-8110 JAN 3 1919 Wallace, Chris D (DOA) From: AK, D&C Well Integrity Coordinator <AKDCWellIntegrityCoordinator@bp.com> Sent: Wednesday, December 31, 2014 9:57 PM To: AK, OPS FS1 OSM; AK, OPS FS1 Facility OTL; AK, OPS FS1 DS Ops Lead; AK, OPS PCC EOC TL; AK, D&C Well Services Operations Team Lead; AK, D&C Wireline Operations Team Lead; Cismoski, Doug A; Daniel, Ryan; AK, RES GPB East Wells Opt Engr; AK, RES GPB West Wells Opt Engr; AK, OPS FS1 DS1 Operator; G GPB FS1 Drillsites; Oestgaard, Finn; Regg, James B (DOA); Wallace, Chris D (DOA) Cc: AK, D&C DHD Well Integrity Engineer; AK, D&C Projects Well Integrity Engineer; AK, OPS FF Well Ops Comp Rep; Sternicki, Oliver R Subject: OPERABLE: Injector 01-11 (PTD #1770570) Regulatory Compliance Testing due Attachments: image001jpg SCANNED JAN 0 6 2015 All, Water Injector 01-11 (PTD #1770570) had a passing AOGCC witnessed MIT -IA on December 13, 2014 while online. Subsequent monitoring of the well has shown pressure fluctuations consistent with thermal and injection rate changes. Per conversations with the AOGCC, the well will be returned to Operable status. Should the well develop anomalous pressure trends, the AOGCC will be notified and appropriate action taken. Please call with any questions. Thank you, Laurie Climer (Alternate: Jack Disbrow) BP Alaska - Well Integrity Coordinator GW�'r:,xm ! 'Ne s Organszat:on WIC Office: 907.659.5102 WIC Email: AKDCWeIIIntegrityCoordinator@BP.com From: AK, D&C Well Integrity Coordinator Sent: Tuesday, November 11, 2014 10:46 PM To: AK, OPS FS1 OSM; AK, OPS FS1 Facility OTL; AK, OPS FS1 DS Ops Lead; AK, OPS PCC EOC TL; AK, D&C Well Services Operations Team Lead; AK, D&C Wireline Operations Team Lead; Cismoski, Doug A; Daniel, Ryan; AK, RES GPB East Wells Opt Engr; AK, RES GPB West Wells Opt Engr; AK, OPS FS1 DS1 Operator; G GPB FS1 Drillsites; Oestgaard, Finn; 'Regg, James B (DOA) (jim.regg@alaska.gov)'; 'chris.wallace@alaska.gov' Cc: AK, D&C DHD Well Integrity Engineer; AK, D&C Projects Well Integrity Engineer; AK, OPS FF Well Ops Comp Rep; AK, D&C Well Integrity Coordinator; Sternicki, Oliver R; Parks, Kevin D Subject: UNDER EVALUATION: Injector 01-11 (PTD #1770570) Regulatory Compliance Testing due All, Water Injector 01-11 (PTD # 1770570) had wellwork completed December 03, 2011 to replace tubing with known impairments. A passing MIT -IA was performed on December 02, 2011, demonstrating competent well barriers downhole. Due to surface equipment issues, the well was not brought online immediately after the rig workover. At this time, the remedial work has been completed and the well is reclassified as Under Evaluation to aid in regulatory compliance testing. The well previously operated under AA 04E.011 for slow IAxOA while online. The AA was cancelled April 26, 2010 when the well failed a MIT -IA. Evaluation of the previously seen IAxOA will also be performed. A copy of the original sundry approval has been included with this email, which in which the standard compliance MIT -IA to at least 2,500 psi is required. Plan Forward: 1. Operations: Put well on injection 2. DHD: Once thermally stable, perform pre -MIT -IA 3. Fullbore: Perform AOGCC witnessed MIT -IA 4. DHD: Perform MIT -OA and warm OART for diagnostics Use prudence when bringing the well online, as the annuli are fluid packed and will be sensitive to thermal expansion. A copy of the wellbore schematic and a copy of the drilling summary approval has been included for reference. Please call with any questions. Thank you, Laurie Climer (,-Ilternate: Jack Disbrow) BP Alaska — Well Integrity Coordinator G� /f; r G!ObaI Wei Is W y Organi2a1w WIC Office: 907.659.5102 WIC Email: AKDCWellintegrityCoordinator@BP.com MEMORANDUM TO: Jim Regg P.I. Supervisors( FROM: Chuck Scheve Petroleum Inspector State of Alaska Alaska Oil and Gas Conservation Commission DATE: Wednesday, December 17, 2014 SUBJECT: Mechanical Integrity Tests BP EXPLORATION (ALASKA) INC 01-11 PRUDHOE BAY UNIT 01-11 Src: Inspector Reviewed By: P.I. Supry J�(� NON -CONFIDENTIAL Comm Well Name PRUDHOE BAY UNIT 0 1 -11 API Well Number 50-029-20268-00-00 Inspector Name: Chuck Scheve Permit Number: 177-057-0 Inspection Date: 12/13/2014 Insp Num: mitCS141214153434 Rel Insp Num: Packer Depth Pretest Initial 15 Min 30 Min 45 Min .60 Min Well' 01-11 Type Inj W -TVD 8237 " Tubing 380 380 380 380 TD 1770570 Type Test SPT Test psi 2059 IA 320 2705 2685 2679 Interval INITAL P/F P OA 418 641 701 745 Notes: Initial test post rig workover. SCANNED JAN 0 6 2015 Wednesday, December 17, 2014 Page I of 1 Wallace, Chris D (DOA) From: AK, D&C Well Integrity Coordinator<AKDCWellIntegrityCoordinator@bp.com> Sent: Tuesday, November 11, 2014 10:46 PM To: AK, OPS FS1 OSM; AK, OPS FS1 Facility OTL; AK, OPS FS1 DS Ops Lead; AK, OPS PCC EOC TL; AK, D&C Well Services Operations Team Lead; AK, D&C Wireline Operations Team Lead; Cismoski, Doug A; Daniel, Ryan; AK, RES GPB East Wells Opt Engr; AK, RES GPB West Wells Opt Engr; AK, OPS FS1 DS1 Operator; G GPB FS1 Drillsites; Oestgaard, Finn; Regg, James B (DOA); Wallace, Chris D (DOA) Cc: AK, D&C DHD Well Integrity Engineer; AK, D&C Projects Well Integrity Engineer; AK, OPS FF Well Ops Comp Rep; AK, D&C Well Integrity Coordinator; Sternicki, Oliver R; Parks, Kevin D Subject: UNDER EVALUATION: Injector 01-11 (PTD #1770570) Regulatory Compliance Testing due Attachments: 01-11 Wellbore Schematic.pdf; Injector 01-11 Rig Sundy Approval 05-20-11.pdf; image003jpg W1 Water Injector 01-11 (PTD # 1770570) had wellwork completed December 03, 2011 to replace tubing with known impairments. A passing MIT -IA was performed on December 02, 2011, demonstrating competent well barriers downhole. Due to surface equipment issues, the well was not brought online immediately after the rig workover. At this time, the remedial work has been completed and the well is reclassified as Under Evaluation to aid in regulatory compliance testing. The well previously operated under AA 04E.011 for slow IAxOA while online. The AA was cancelled April 26, 2010 when the well failed a MIT -IA. Evaluation of the previously seen IAxOA will also be performed. A copy of the original sundry approval has been included with this email, which in which the standard complianceM T--[A`f6 at"least 2,500 psi is required. Plan Forward: 1. Operations: Put well on injection 2. DHD: Once thermally stable, perform pre -MIT -IA "Men NOY 13 2014, 3. Fullbore: Perform AOGCC witnessed MIT -IA 4. DHD: Perform MIT -OA and warm OART for diagnostics Use prudence when bringing the well online, as the annuli are fluid packed and will be sensitive to thermal expansion. A copy of the wellbore schematic and a copy of the drilling summary approval has been included for reference. Please call with any questions. Thank you, Laurie Climer (Alternate: Jack Disbrow) BP Alaska — Well Integrity Coordinator Gwbal Wells Organiaaten WIC Office: 907.659.5102 WIC Email: AKDCWelllntegrityCoordinator@BP.com TREE = 6-3/8" CNV WELLHEAD = GRAY ACTUATOR = BAKER C KB. ELEV = 73' BF. ELEV = 6 KOP = 3200' Max Angle = 47'@6000' Datum MD = 10364' Datum TV D = 8800' SS 20" CONDUCTOR, 94#, H-40, IS 13-3/8" CSG, 72#, N-80 BTRS, ID = 12.347" 2713' Minimum ID = 3.759" @ 9964' 4-1/2" BKR R LANDING NIPPLE 1 5-1/2" TBG, 17#, L-80 TC -11, .0232 bpf, ID = 4.892" 1-1 9701' 5-1/2" TBG -NPC, 17#, N-80_0232 bpf, ID = 4.892" 4-1/2" TBG -NPC, 12.6#, N-80, 0152 bpf, ID = 3.958" 9894' 10024' PERFORATION SUMMARY REF LOG: BHCS ON 10/26/77 ANGLE AT TOP PERF: 32° @ 10238' Note: Refer to Production DB for historical perf data SIZE SPF INTERVAL Opn/Sqz DATE 2-7/8" 6 10238 - 10264 O 08/13/01 2-7/8" 1 6 10270 - 10276 O 08/13/01 2-7/8" 6 10286 - 10320 O 08/13/01 2-7/8" 6 10330 - 10354 O 08/13/01 3-3/8" 4 10370 - 10380 O 06/14/94 3-3/8" 4 10380- 10394 S 01/14/94 3-3/8" 1 10420 - 10425 C 09/12/90 3-3/8" 1 10438 - 10440 C 09/12/90 NA 0 10450 - 10462 C 02/04/78 3-3/8" 4 10462 - 10472 C 06/04/93 3-3/8" 4 10482 - 10495 S 11/13/89 3-3/8" 4 10495 - 10513 S 06/05/94 3-3/8" 4 10517 - 10520 S 11/13/89 3-3/8" 4 10530 - 10535 S 11/13/89 3-3/8" 4 10535 - 10545 S 06/05/94 3-3/8" 4 10545 - 10555 S 11/13/89 3-3/8" 4 10555 - 10570 S 06/26/93 3-3/8" 4 10575 - 10585 S 06/26/93 3-3/8" 4 10591 - 10601 S 06/26/93 a-5/8" CSG, 47#, N-80/RS-95 BTRS, .0733 bpf, ID = 8. "10988' TD 11010' 01 11 SAFETY NOTES: 2206' -15-1/2" HES X NIP, ID = 4.562" 2338' 9-5/8° FOC 246T 9-518" FOC 9585' 45-1/2' HES X NIP, ID = 4.562- 961T 9-5/8" X 5-1/2" HES TNT PKR, ID = 4.791" 9653' 5-1/2" HES X NIP, ID = 4.562" J684' 1--15-1/2" HES XN NIP, ID = 4.455" 9701' -j 5-1/2" WLEG, ID = 4.892" 8847' BKR SCOOP HEAD GUIDE, ID = 5.625" 9894' 9-5/8" X 5-1/2" BKR SAB PKR, ID = 3.875" 9923' 5-1/2" X 4-1/2" XO, ID = 3.958" 9964' 4-1/2" BKR "R" NIP, ID = 3.759" 10024'-�4-1/2" WLEG, ID=3.958" 10020' ELMD TT LOGGED 10132' 1--19-5/8" MARKER JOINT 'i?? 1-i4-1/2" WRP BLOWN DOWN HOLE (11/06/10 10395' TOP OF CEMENT (15') 10410'—iTOPOF SAND (125') 10535' PBTD DATE REV BY COMMENTS DATE REV BY COMMENTS 11/04/77 ROW 35 INITIAL COMPLETION 12/03/11 D16 IRWO 12/06/11 PJC DRLG DRAFT CORRECTION 12/08/11 MMc/ PJ FINAL DRLG CORRECTIONS PRUDHOE BAY UNIT WELL: 01-11 PERMIT No: 1770570 API No: 50-029-20268-00 SEC 8, T1 ON, R1 5E, 889' FNL & 778' FWL BP Exploration (Alaska) PTh 1770 5 Regg, James B (DOA) From: AK, D &C Well Integrity Coordinator [AKDCWeIllntegrityCoordinator @bp.com] 2c'- 4-1311 Z Sent: Friday, April 13, 2012 3:25 PM j 7 To: Regg, James B (DOA); Schwartz, Guy L (DOA); AK, OPS FS1 OSM; AK, OPS FS1 Facility OTL; AK, OPS FS1 DS Ops Lead; AK, OPS FS1 DS5 Operator; AK, OPS PCC EOC TL; AK, D &C Well Services Operations Team Lead; AK, D &C Wireline Operations Team Lead; Cismoski, Doug A; Daniel, Ryan; AK, RES GPB East Wells Opt Engr; AK, RES GPB West Wells Opt Engr; G GPB FS1 DS; Youngmun, Alex Cc: AK, D &C Well Integrity Coordinator; King, Whitney; Wills, Shane M; LeBaron, Michael J; Arend, Jon (NORTHERN SOLUTIONS LLC) Subject: NOT OPERABLE: Seawater Injector 01 -11 (PTD #1770570) Shut In Until Flowline Repaired Attachments: Injector 01 -11 (PTD #1770570) TIO and Injection Plot.doc All, Injector 01 -11 (PTD #1770570) had a leak on the flowline during the initial start up of seawater injection on 04/10/2012. As the well has not yet passed it's AOGCC MIT -IA, the well is reclassified as Not Operable. At such time as the surface equipment is ready to resume injection, the well will be reclassified accordingly. A copy of the TIO and Injection plot are included for reference. «Injector 01 -11 (PTD #1770570) TIO and Injection Plot.doc» Please call if you have any questions. Thank you, Gerald Murphy (alt. Mehreen Vazir) Well Integrity Coordinator Office (907) 659 -5102 7 20 Cell (907) 752 -0755 �' " "�� Pager (907) 659 -5100 Ext. 1154 From: AK, D &C Well Integrity Coordinator Sent: Tuesday, April 10, 2012 3:08 PM To: 'Regg, James B (DOA)'; 'Schwartz, Guy L (DOA)'; AK, OPS FS1 OSM; AK, OPS FS1 Facility OTL; AK, OPS FS1 DS Ops Lead; AK, OPS FS1 DS5 Operator; AK, OPS PCC EOC TL; AK, D &C Well Services Operations Team Lead; AK, D &C Wireline Operations Team Lead; Cismoski, D•..g A; Daniel, Ryan; AK, RES GPB East Wells Opt Engr; AK, RES GPB West Wells Opt Engr; G GPB FS1 DS Cc: AK, D &C Well Integrity Coordinator; King, Whitney; Wills, Shane M; LeBaron, Michael 3 Subject: UNDER EVALUATION: Seawater Injector 01 -11 (PTD #1770570) Flowline Choke Replace •nd Ready to Resume Injection All, The work to replace the inline choke has been completed for se- ater Injector 01 -11 (PTD #1770570). The well is reclassified as Under Evaluation to begin seawater injection. o nce the well is thermally stable, an AOGCC witnessed MIT -IA will be required for the well. Please call if you have any questions. Thank you, Gerald Murphy (alt. Mehreen Vazir) Well Integrity Coordinator 1 • PBU 01 -11 PTD #1770570 4/13/2012 TIO Pressures Plot Wa! 01 -01 4.000 3,000 Tbq -6- IA 2,000 - GAA -4.- 000A 0n i 1,000 01/14/12 01/21/12 01/28/12 02/04/12 02/11/12 02/18/12 02/25/12 03/03/12 03/10/12 03/17/12 03/24/12 03)31/12 04/07/12 Injection Plot Wan: 01 -11 - 10000 2200 ,0(0 3,000 2 1.800 - I - 8000 1,800 ) 7000 1,400 AT -0000 _ SIP 1,200 - Poi 5,000 3 -MI 1 - GI 4,000 ° - 0 On 800 3.000 600 - 2000 400 200 1.OW t 01/14/12 01/21/12 01/28.12 02/04/12 02/11/12 02/18/12 02/25/12 03/03/12 03/10/12 03/7/12 03/24/12 03/31/12 04/07/12 • • Pit 177 0570 Regg, James B (DOA) PBtC p`_ From: AK, D &C Well Integrity Coordinator [ AKDCWelllntegrityCoordinator @bp.com] j�� -- 4/ z j i z— Sent: Tuesday, April 10, 2012 3:08 PM '' `` (l To: Regg, James B (DOA); Schwartz, Guy L (DOA); AK, OPS FS1 OSM; AK, OPS FS1 Facility OTL; AK, OPS FS1 DS Ops Lead; AK, OPS FS1 DS5 Operator; AK, OPS PCC EOC TL; AK, D &C Well Services Operations Team Lead; AK, D &C Wireline Operations Team Lead; Cismoski, Doug A; Daniel, Ryan; AK, RES GPB East Wells Opt Engr; AK, RES GPB West Wells Opt Engr; G GPB FS1 DS Cc: AK, D &C Well Integrity Coordinator; King, Whitney; Wills, Shane M; LeBaron, Michael J Subject: UNDER EVALUATION: Seawater Injector 01 -11 (PTD #1770570) Flowline Choke Replaced and Ready to Resume Injection Attachments: 01 -11. pdf All, The work to replace the inline choke has been completed for seawater Injector 01 -11 (PTD #1770570). The well is reclassified as Under Evaluation to begin seawater injection. Once the well is thermally stable, an AOGCC witnessed MIT -IA will be required for the well. Please call if you have any questions. Thank you, Gerald Murphy (alt. Mehreen Vazir) Well Integrity Coordinator Office (907) 659-5102 0 Cell (907) 752 -0755 From: AK, D &C Well Integrity Coordinator Sent: Thursday, February 16, 2012 8:56 PM To: 'Regg, James B (DOA)'; 'Schwartz, Guy L (DOA)'; AK, OPS FS1 OSM; AK, OPS FS1 Facility OTL; AK, OP Si DS Ops Lead; AK, OPS FS1 DS5 Operator; AK, OPS PCC EOC TL; AK, D &C Well Services Operations Team Lead; AK, D &C Wireline Operations Team Lea. • ismoski, Doug A; Daniel, Ryan; AK, RES GPB East Wells Opt Engr; AK, RES GPB West Wells Opt Engr; G GPB FS1 DS Cc: AK, D &C Well Integrity Coordinator; King, Whitney; Wills, Shane M; LeBaron, Michael . Subject: NOT OPERABLE: Seawater Injector 01 -11 (PTD #1770570) Shut In Until •wline Choke Replaced All, Seawater Injector 01 -11 (PTD #1770570) was placed • water injection on 02/03/2012. On 02/10/2012 the choke that governs the water supply for the injection washed o internally allowing water injection to increase from 7000 to 10000 barrels per day. Injection has been discontinued • the well until the choke for the governing of water injection is replaced. As the well has not yet passed it's AP CC MIT -IA, the well is reclassified as Not Operable. At such time as the surface equipment is ready to resume inj= tion, the well will be reclassified accordingly. A copy of the TIO and Injection plot are cluded for reference. d f` Please call if you have any questions. Thank you, 1 • TREE = 6 -3/8" CM/ • ' WELLHEAD = GRAY 0 1 - 1 1 SAFETY NOTES: ACTUATOR = BAKER C KB. ELEV = 73' j I BF. ELEV = KOP = 3200' 2206' -1 5 -1/2" HES X NIP, ID = 4.562" I Max Angle = 47° @ 6000' Datum MD = 10364' 2338' H9-5/8" FOC I Datum TV D = 8800' 5S = I 2467' H9-5/8" FOC I 120" CONDUCTOR, 94 #, H-40, IS = 19.124" I 80' 1 13 -3/8" CSG, 72 #, N-80 BTRS, ID = 12.347" H 2713' I� a 9585' H5-1/2" HES X NIP, ID = 4.562" I Minimum ID = 3.759" @ 9964' 4 -1/2" BKR R LANDING NIPPLE Z �1 I 9617' I- 19-5 /8 " x5- 1/2 " HES TNT PKR, ID= 4.791" I 1 1 ( 9653' 1-15-1/2" HES X NIP, ID = 4.562" I 1 1 ( 9684' H5-1/2" HES XN NIP, ID = 4.455" I 5 -1/2" TBG, 17 #, L -80 TC-11, .0232 bpf, ID = 4.892" H 9701' I— r " ( 9701' H5 -1/2" WLEG, ID = 4.892" 3847' H BKR SCOOP HEAD GUIDE, ID = 5.625" I > 9894' H9-518" X 5 -1/2" BKR SAB PKR, ID = 3.875" I 1 5 -1/2" TBG -NPC, 17 #, N -80, .0232 bpf, ID = 4.892" H 9894' I--- \ / 9923' H5 -1/2" X 4 -1/2" XO, ID= 3.958" I 4 -1/2" TBG -NPC, 12.6 #, N-80, --I 10024' .0152 bpf, ID = 3.958" 1 9964' H4-1/2" BKR "R" NIP, ID = 3.759" I PERFORATION SUMMARY REF LOG: BHCS ON 10/26/77 1 10024' H4 -112" WLEG, ID = 3.958" I ANGLE AT TOP PERF: 32° @ 10238' 1 10020' I—) ELMD TT LOGGED ? ? / ? ? / ?? I Note: Refer to Production DB for historical pert data SIZE SPF INTERVAL Opn /Sqz DATE 2 -7/8" 6 10238 - 10264 0 08/13/01 2 -7/8" 6 10270 - 10276 O 08/13/01 ' 10132' 1- 19 -5/8" MARKER JOINT I 2 -7/8" 6 10286 - 10320 0 08/13/01 1 2 -7/8" 6 10330 - 10354 0 08/13/01 3 -3/8" 4 10370 - 10380 0 06/14/94 3 -3/8" 4 10380 - 10394 S 01/14/94 ' 3-3/8" 1 10420 - 10425 C 09/12/90 1141! ' 1 ? ?? H4 -1/2" WRP BLOWN DOWN HOLE (11/06/10) I 3 -3/8" 1 10438 - 10440 C 09/12/90 NA 0 10450 - 10462 C 02/04/78 Toy vo . + .., 10395' I-1 TOP OF CEMENT (15') 1 3 -3/8" 4 10462 - 10472 C 06/04/93 ••• • it��� ,ii , 3 -3/8" 4 10482 - 10495 S 11/13/89 3 -3/8" 4 10495 - 10513 S 06/05/94 3 -3/8" 4 10517 - 10520 S 11/13/89 3 -3/8" 4 10530 - 10535 S 11/13/89 3 -3/8" 4 10535 - 10545 S 06/05/94 3 -3/8" 4 10545 - 10555 S 11/13/89 3 -3/8" 4 10555 - 10570 S 06/26/93 1 10410' H TOP OF SAND (125') I 3 -3/8" 4 10575 - 10585 S 06/26/93 3 -3/8" 4 10591 - 10601 S 06/26/93 I 10535' H PBTD I 9 -5/8" CSG, 47 #, N- 80/RS -95 BTRS, .0733 bpf, ID = 8.68 f' 10988' P"t . rt " • 1 I 11010' , TD I DATE REV BY COMMENTS DATE REV BY COMMENTS PRUDHOE BAY UNIT 11/04/77 ROW 35 INITIAL COMPLETION WELL: 01 -11 12/03/11 D16 RWO PERMIT No: '1770570 12/06/11 PJC DRLG DRAFT CORRECTION API No: 50 -029- 20268 -00 12/08/11 SMMc/ PJCFINAL DRLG CORRECTIONS SEC 8, T10N, R15E, 889' FNL & 778' FWL BP Exploration (Alaska) PT 177x570 Regg, James B (DOA) From: AK, D &C Well Integrity Coordinator [ AKDCWelllntegrityCoordinator ©bp.com] eye 2/17 // Z Sent: Thursday, February 16, 2012 8:56 PM To: Regg, James B (DOA); Schwartz, Guy L (DOA); AK, OPS FS1 OSM; AK, OPS FS1 Facility OTL; AK, OPS FS1 DS Ops Lead; AK, OPS FS1 DS5 Operator; AK, OPS PCC EOC TL; AK, D &C Well Services Operations Team Lead; AK, D &C Wireline Operations Team Lead; Cismoski, Doug A; Daniel, Ryan; AK, RES GPB East Wells Opt Engr; AK, RES GPB West Wells Opt Engr; G GPB FS1 DS Cc: AK, D &C Well Integrity Coordinator; King, Whitney; Wills, Shane M; LeBaron, Michael J Subject: NOT OPERABLE: Seawater Injector 01 -11 (PTD #1770570) Shut In Until Flowline Choke Replaced Attachments: Injector 01 -11 (PTD # 1770570) TIO & Injection Plot.doc; 01- 11.pdf AII, Seawater Injector 01 -11 (PTD #1770570) was placed on water injection on 02/03/2012. On 02/10/2012 the choke that governs the water supply for the injection washed out internally allowing water injection to increase from 7000 to 10000 barrels per day. Injection has been discontinued on the well until the choke for the governing of water injection is p replaced. As the well has not yet assed it's AOGCC MIT-IA, the well is reclassified as Not Operable. At such time as P Y the surface equipment is ready to resume injection, the well will be reclassified accordingly. A copy of the TIO and Injection plot are included for reference. «Injector 01 -11 (PTD # 1770570) TIO & Injection Plot.doc» Please call if you have any questions. Thank you, Gerald Murphy (alt. Mehreen Vazir) cry W Well Integrity Coordinator E-� Office (907) 659 -5102 Cell (907) 752 -0755 Pager (907) 659 -5100 Ext. 1154 From: AK, D &C Well Integrity Coordinator Sent: Monday, January 09, 2012 9:12 AM To: 'Maunder, Thomas E (DOA)'; AK, OPS FS1 OSM; AK, OPS FS1 Facility OTL; AK, OPS FS1 DS Ops Lead; AK, OPS FS1 DS5 Operator; AK, OPS PCC EOC TL; AK, D &C Well Services Operations Team Lead; AK, D &C Wireline Operations Team Lead; Cismoski, D. - -, Daniel, Ryan; AK, RES GPB East Wells Opt Engr; G GPB FS1 DS; Youngmun, Alex; 'Regg, James B (DOA)' Cc: Walker, Greg (D &C); Clingingsmith, Mike J; Olson, Andrew; Reynolds, C - es (Alaska) Subject: UNDER EVALUATION: Seawater Injector 01 -11 (PTD #1770 1) Passed MIT -IA Post RWO All, Seawater Injector 01 -11 (PTD #1770570 sassed an MIT -IA to 4000 psi after completion of a rig workover to repair tubing and packer integrity. The passing to confirms two competent barriers in the well. The well is reclassified as Under - h Evaluation so it can be placed on • ection. Once stabilized, an AOGCC witnessed MIT IA will be scheduled. «01- 11.pdf» -` Thank you, 1 . • PBU 01 -11 PTD # 1770570 2/16/2012 TIO Pressures Plot Well: 01 -11 4,000 3.000 +► 1bg - f - IA 2,000 —a- OA 00A —41-- 0004 On 1,000 12/17/11 12/24/11 12/31/11 01/07/12 01/14/12 01/21/12 01/28/12 02104/12 02/11/12 Injection Plot Well: 01 -11 500 - 10,000 480 460 - 440 - 0,000 420 _ 400 II 380 1 - B4ODU 360 340 / - 7,000 320 300 4J — WHIP - 6,000 - 280 I SW 260 . _ PW 240 - 5,000 — MI 220 o — Ot 200 - 4,000 180 On 160 140 3,000 120 100 - 2,000 80 • 60 - 1,000 40 20 12/17/11 12/24/11 12/31/11 01/07/12 01/14/12 01/21/12 01/28/12 02/04/12 02/11/12 TREE = 6 -3/8" CIW WELLHEAD = GRAY 01 -1 1 SAFETY N• . ACTUATOR = BAKER C KB. ELEV = 73' il II 1 BF. ELEV = KOP = 3200' I 2206' H5-1/2" HES X NIP, ID = 4.562" I Max Angle = 47° @ 6000' Datum MD = 10364' .---- 2338' 1--19 -5/8" FOCI Datum WD = 8800' SS T y--- -I 2467' H 9 -5/8" FOC 120" CONDUCTOR, 94 #, H-40, IS = 19.124" I 80' L (13 -3/8" CSG, 72 #, N-80 BTRS, ID = 12.347" H 2713' s a I 9585' 1— I 5 -1/2" HES X NIP, ID = 4.562" I Minimum ID = 3.759" @ 9964' 4 -1/2" BKR R LANDING NIPPLE Z ZJ I 9617' I- 19-5/8 " X5- 1 /2 " HES TNT PKR,ID= 4.791" I 1 a I 9653' H5-1/2" HES X NIP, ID = 4.562" 1 i , I 9684' H5-1/2" HES XN NIP, ID = 4.455" I 5-1/2" TBG, 17 #, L -80 TG-11, .0232 bpf, ID = 4.892" H 9701' I— / N I 9701' H5-1/2" WLEG, ID = 4.892" I 9847' HBKR SCOOP HEAD GUIDE, ID = 5.625" I g ., L 9894' I- -19 -5/8" X 5 -1/2" BKR SAB PKR, ID = 3.875" I 1 5 -1/2" TBG -NPC, 17 #, N-80, .0232 bpf, ID = 4.892" H 9894' 1----- \ / 9 23' I— I5 -1/2" X 4 -1/2" XO, ID = 3.958" 4-1/2" TBG -NPC, 12.6 #, N-80, --I 10024' I 9 .0152 bpf, ID = 3.958" 9964' H4 -1/2" BKR "R" NIP, ID = 3.759" 1 PERFORATION SUMMARY REF LOG: BHCS ON 10/26/77 10024' H4 -1/2" WLEG, ID = 3.958" 1 ANGLE AT TOP PERF: 32° @ 10238' 10020' H ELMD TT LOGGED ? ? / ? ? / ?? I Note: Refer to Production DB for historical perf data SIZE SPF INTERVAL Opn /Sqz DATE 2 -7/8" 6 10238 - 10264 O 08/13/01 , 2 -7/8" 6 10270 - 10276 0 08/13/01 10132' H9 -5/8" MARKER JOINT 1 2 -7/8" 6 10286 - 10320 0 08/13/01 I 2 -7/8" 6 10330 - 10354 0 08/13/01 3 -3/8" 4 10370 - 10380 0 06/14/94 I 3 -3/8" 4 10380 - 10394 S 01/14/94 3 -3/8" 1 10420 - 10425 C 09/12/90 ih I 1 ? ?? I--14 -1/2" WRP BLOWN DOWN HOLE (11/06/10) 1 3-3/8" 1 10438 - 10440 C 09/12/90 NA 0 10450 - 10462 C 02/04/78 voy.v '. ws 10395' I--I TOP OF CEMENT (15') I 3 -3/8" 4 10462 - 10472 C 06/04/93 . A. A +A•i ii 3 -3/8" 4 10482 - 10495 S 11/13/89 3 -3/8" 4 10495 - 10513 S 06/05/94 3 -3/8" 4 10517 - 10520 S 11/13/89 3 -3/8" 4 10530 - 10535 S 11/13/89 3 -3/8" 4 10535 - 10545 S 06/05/94 3 -3/8" 4 10545 - 10555 S 11/13/89 3 -3/8" 4 10555 - 10570 S 06/26/93 I 10410' 1—ITOP OF SAND (125') I 3 -3/8" 4 10575 - 10585 S 06/26/93 3 -3/8" 4 10591 - 10601 S 06/26/93 10535' H PBTD I 9 -5/8" CSG, 47 #, N- 80/RS -95 BTRS, .0733 bpf, ID = 8.68#" 10988' rf* +' 1 '�'�, ' 1 TD H 11010' DATE REV BY COMMENTS 1 DATE REV BY COMMENTS PRUDHOE BAY UNIT 11/04/77 ROW 35 INITIAL COMPLETION WELL: 01 -11 12/03/11 D16 RWO PERMIT No: 1770570 12/06/11 PJC DRLG DRAFT CORRECTION API No: 50- 029 - 20268 -00 12/08/11 SMMc/ PJCFINAL DRLG CORRECTIONS SEC 8, T10N, R15E, 889' FNL & 778' FWL BP Exploration (Alaska) • • PEc.( 0 l -( Regg, James B (DOA) Pit 17 7 0 570 From: AK, D &C Well Integrity Coordinator [ AKDCWelllntegrityCoordinator @bp.com] !7 ` lI c / Z Sent: Monday, January 09, 2012 10:57 AM l� To: Regg, James B (DOA) Cc: Brooks, Phoebe L (DOA) Subject: RE: UNDER EVALUATION: Seawater Injector 01 -11 (PTD #1770570) Passed MIT -IA Post RWO Attachments: MIT -IA PBU 01 -11 12- 02- 11.xls Jim, Please see attached per your request. The MIT -IA was performed by the rig after completion of the workover prior to rig departure. Thanks, S EVE13 (; 8 ti : Mehreen Vazir BPXA Well Integrity Coordinator From: Regg, James B (DOA) [mailto:jim.reagOalaska.gov] Sent: Monday, January 09, 2012 10:10 AM To: AK, D &C Well Integrity Coordinator Subject: RE: UNDER EVALUATION: Seawater Injector 01 -11 (PTD #1770570) Passed MIT -IA Post RWO Please send MIT report Jim Regg AOGCC 333 W. 7th Ave, Suite 100 Anchorage, AK 99501 907 - 793 -1236 From: AK, D &C Well Integrity Coordinator [ mailto: AKDCWellIntegrityCoordinator .com] Sent: Monday, January 09, 2012 9:12 AM To: Maunder, Thomas E (DOA); AK, OPS FS1 OSM; AK, OPS FS1 Facility OTL; AK, OPS FS1 DS Ops Lead; AK, OPS FS1 DS5 Operator; AK, OPS PCC EOC TL; AK, D &C Well Services Operations Team Lead; AK, D &C Wireline Operations Team Lead; Cismoski, Doug A; Daniel, Ryan; AK, RES GPB East Wells Opt Engr; G GPB FS1 DS; Youngmun, Alex; Regg, James B (DOA) Cc: Walker, Greg (D &C); Clingingsmith, Mike J; Olson, Andrew; Reynolds, Charles (Alaska) Subject: UNDER EVALUATION: Seawater Injector 01 -11 (PTD #1770570) Passed MIT -IA Post RWO All, Seawater Injector 01 -11 (PTD #1770570) passed an MIT -IA to 4000 psi after completion of a rig workover to repair tubing and packer integrity. The passing test confirms two competent barriers in the well. The well is reclassified as Under Evaluation so it can be placed on injection. Once stabilized, an AOGCC witnessed MIT -IA will be scheduled. «01- 11.pdf» Thank you, 1 • • Mehreen Vazir (Alternate Gerald Murphy) Well Integrity Coordinator BP Alaska Drilling & Wells Well Integrity Office: 907.659.5102 Email: AKDCWelllntegrityCoordinator @BP.com From: NSU, ADW Well Integrity Engineer Sent: Thursday, December 31, 2009 8:18 PM To: NSU, ADW Well Integrity Engineer; 'Regg, James B (DOA)'; 'Maunder, Thomas E (DOA)'; GPB, FS1 DS Ops Lead; GPB, FS1 OTL; GPB, Area Mgr East (FS1 /2 /COTU /Seawater); NSU, ADW Well Operations Supervisor; Rossberg, R Steven; Engel, Harry R; GPB, Wells Opt Eng; GPB, EOC Specialists; GPB, Optimization Engr; 'Schwartz, Guy (DOA)'; 'Brooks, Phoebe L (DOA)' Cc: Seltenright, Ana Maria Subject: NOT OPERABLE: 01 -11 (PTD #1770570) Failing MITIA All, Well 01 -11 (PTD #1770570) failed an MITIA on 12/31/09 after gland nuts were tightened to mitigate a wellhead leak. The failing test indicates that at least one of the barriers has been compromised. The well has been reclassified as Not Operable and needs to be shut -in as soon at it has been freeze protected. The plan forward is to secure the well with a downhole plug. Please call with any questions or concerns. Thank you, Torin Roschinger (alt. Anna Dube) Well Integrity Coordinator Office (907) 659 -5102 Cell (406) 570 -9630 Pager (907) 659 -5100 Ext. 1154 From: NSU, ADW Well Integrity Engineer Sent: Wednesday, December 30, 2009 9:05 PM To: 'Regg, James B (DOA)'; 'Maunder, Thomas E (DOA)'; GPB, FS1 DS Ops Lead; GPB, FS1 OTL; GPB, Area Mgr East (FS1 /2 /COTU /Seawater); NSU, ADW Well Operations Supervisor; Rossberg, R Steven; Engel, Harry R; GPB, Wells Opt Eng; GPB, EOC Specialists; GPB, Optimization Engr; 'Schwartz, Guy (DOA)'; 'Brooks, Phoebe L (DOA)' Cc: Seltenright, Ana Maria Subject: UNDER EVALUATION: 01 -11 (PTD #1770570) Eval IAxOA communication post gland nut repair All, Well 01 -11 (PTD #1770570) is a sea water injection that has an AA for IAxOA communication. On 12/29/09, an AOGCC witnessed MITIA failed for compliance testing. During the test four gland nuts were noticed leaking on the inner casing spool. On 12/30/09, the gland nuts were tightened mitigating the leak. The well has been reclassified as Under Evaluation to perform an MITIA while online to evaluate integrity after the leaking gland nuts were tightened. 2 • • The plan forward is as follows: 1. Wellhead: Tighten gland nuts - DONE 2. DHD: MIT -IA to 2500 psi, LLR if fails 3. DHD: AOGCC witnessed MITIA to 2500 psi Please call with any questions or concerns. Thank you, Torin Roschinger (alt. Anna Dube) Well Integrity Coordinator Office (907) 659 -5102 Cell (406) 570 -9630 Pager (907) 659 -5100 Ext. 1154 3 • • STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION Mechanical Integrity Test Submit to: jim.reaonalaska.gov; doa. aogcc.prudhoe.bavnalaska.gov; phoebe.brooks(alaska.gov: tom.maundernalaska.00v OPERATOR: BP Exploration (Alaska), Inc. 1(1(17, FIELD / UNIT / PAD: Prudhoe Bay / PBU / DS -01 N.. l `f DATE: 12/02/11 OPERATOR REP: Ken Miller AOGCC REP: Not Witnessed Packer Depth Pretest _ Initial 15 Min. 30 Min. 45 Min. 60 Min. Well 01 -11 ' Type Inj. N - TVD 6,237 Tubing 1700 2300 ' 2290 2250 - Interval 0 P.T.D. 1770570 ' Type test P ' Test psi 2059.25 Casing 4090' 4020 - 3990' P/F P Notes: OA MIT -IA performed by ri after completion of workover to repair tubing x inner annulus communication 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 TYPE TEST Codes INTERVAL Codes D = Drilling Waste M = Annulus Monitoring I = Initial Test G = Gas P = Standard Pressure Test 4 = Four Year Cycle I = Industrial Wastewater R = Internal Radioactive Tracer Survey V = Required by Variance N = Not Injecting A = Temperature Anomaly Survey T = Test during Workover W = Water D = Differential Temperature Test 0 = Other (describe in notes) Form 10-426 (Revised 06/2010) 2011 1202_MIT_PBU 01 - 11 • I TREE= 6 -3/8" CW • WELLHEAD = GRAY SAFETY NOTES: ACTUATOR = BAKER C O • • KB. ELEV = 73' I. J I BF. ELEV = KOP = 3200' I 2206' I-15-1/2" HES X NIP, ID = 4.562" I Max Angle = 47° @ 6000' Datum MD = 10364' 2338' I--19 -5/8" FOCI Datum TV D = 8800' SS ... = I 2467' H9-5/8" FOC 120" CONDUCTOR, 94 #, H-40, IS = 19.124" I 80' 13 -3/8" CSG, 72 #, N-80 BTRS, ID = 12.347" H 2713' 1 , I 9585' H5-1/2" HES X NIP, ID = 4.562" I Minimum ID = 3.759" @ 9964' 4 -1/2" BKR R LANDING NIPPLE Z .! L 9617' H9-5/8" X 5-1/2" HES TNT PKR, ID= 4.791" I 9653' H5-1/2" HES X NIP, ID = 4.562" I 1 ( 9684' 1-15-1/2" HES XN NIP, ID = 4.455" I 5 -1/2" TBG, 17 #, L -80 TC-11, .0232 bpf, ID = 4.892" I-1 9701' I / \ I 9701' I- 15 -1/2" WLEG, ID = 4.892" I ........ 9847' H BKR SCOOP HEAD GUIDE, ID = 5.625" I \ / 9894' H9 -5/8" X 5 -1/2" BKR SAB PKR, ID = 3.875" 1 15 -1/2" TBG -NPC, 17 #, N-80, .0232 bpf, ID = 4.892" H 9894' I-25 ` / 9923' H5 -1/2" X 4 -1/2" XO, ID= 3.958" I 4-1/2" TBG -NPC, 12.6 #, N-80, —I 10024' .0152 bpf, ID = 3.958" ( 9964 1-14 -1/2" BKR "R" NIP, ID = 3.759" I r PERFORATION SUMMARY REF LOG: BHCS ON 10/26/77 I 10024' H4 -1/2" WLEG, ID = 3.958" I ANGLE AT TOP PERF: 32" @ 10238' Note: Refer to Production DB for historical perf data I 10020' H ELMD TT LOGGED ? ? / ? ? / ?'? SIZE SPF INTERVAL Opn /Sqz DATE 2 -7/8" 6 10238 - 10264 0 08/13/01 , 10132' I 19 -5/8" MARKER JOINT I 2 -7/8" 6 10270 - 10276 0 08/13/01 2 -7/8" 6 10286 - 10320 0 08/13/01 1 2 -7/8" 6 10330 - 10354 0 08/13/01 1 3 -3/8" 4 10370 - 10380 0 06/14/94 3 -3/8" 4 10380 - 10394 S 01/14/94 3-3/8" 1 10420 - 10425 C 09/12/90 1111 I ? ?? I- -14 -1/2" WRP BLOWN DOWN HOLE (11/06/10) I 3 -3/8" 1 10438 - 10440 C 09/12/90 NA 0 10450 - 10462 C 02/04/78 .�.� .� . � . l .�. � .�.�. � 10395' 1-1 TOP OF CEMENT (15') I 3 -3/8" 4 10462 - 10472 C 06/04/93 � tAA•IA OA I 3 -3/8" 4 10482 - 10495 S 11/13/89 3 -3/8" 4 10495 - 10513 S 06/05/94 3 -3/8" 4 10517 - 10520 S 11/13/89 3 -3/8" 4 10530 - 10535 S 11/13/89 3 -3/8" 4 10535 - 10545 S 06/05/94 3 -3/8" 4 10545 - 10555 S 11/13/89 3 -3/8" 4 10555 - 10570 S 06/26/93 I 10410' I-I TOP OF SAND (125') I 3 -3/8" 4 10575 - 10585 S 06/26/93 3 -3/8" 4 10591 - 10601 S 06/26/93 I 10535' I--1 PBTD I 19 -5/8" CSG, 47 #, N- 80/RS -95 BTRS, .0733 bpf, ID = 8.e& 10988' I li■ lt" ' 4 1 TD H 11010' 1 ,VAA V � � �� � A � A A � � ♦ � DATE REV BY COMMENTS DATE REV BY COMMENTS PRUDHOE BAY UNIT 11/04/77 ROW 35 INITIAL COMPLETION WELL: 01 -11 12/03/11 D16 RWO PERMIT No: 1770570 12/06/11 PJC DRLG DRAFT CORRECTION API No: 50- 029 - 20268 -00 12/08/11 SMMc/ PJCFINAL DRLG CORRECTIONS SEC 8, T10N, R15E, 889' FNL & 778' FWL BP Exploration (Alaska) STATE OF ALASKA 4 ALAS IL AND GAS CONSERVATION COMMIAN RECEIVED REPORT OF SUNDRY WELL OPERATIONS DEC 2 2 2011 1. Operations Performed: Alaska Gil & Gas Los. LomrniSSi0I? ❑ Abandon IN Repair Well ❑ Plug Perforations ❑ Stimulate ❑ Re -Enter Susrfarlatengle ❑ Alter Casing ® Pull Tubing ❑ Perforate New Pool ❑ Waiver ❑ Other ❑ Change Approved Program ❑ Operation Shutdown ❑ Perforate ❑ Time Extension 2. Operator Name: 4. Well Class Before Work: 5. Permit To Drill Number: BP Exploration (Alaska) Inc. ❑ Development ❑ Exploratory . 177 - 057 3. Address: ® Service ❑ Stratigraphic 6. API Number: P.O. Box 196612, Anchorage, Alaska 99519 - 6612 50 - 029 - 20268 - 00 - 00 7. Property Designation: 8. Well Name and Number: ADL 028 PBU 01 -11 9. Field / Pool(s): Prudhoe Bay Field / Prudhoe Bay Oil Pool 10. Present well condition summary Total depth: measured 11010' feet Plugs (measured) 10395' feet true vertical 9434' feet Junk (measured) Yes, Unknown Depth feet Effective depth: measured 10395' feet Packer: (measured) 9617' & 9894' feet true vertical 8900' feet Packer: (true vertical) 8237' & 8471' feet Casing Length Size MD TVD Burst Collapse Structural Conductor 120' 20" 120' 120' 1530 520 Surface 2713' 13 -3/8" 2713' 2713' 4930 2670 Intermediate Production 10988' 9 - 5/8" 10988' 9414' 6870 4760 Liner Perforation Depth: Measured Depth: 10238' - 10380' True Vertical Depth: 8765' - 8887' Tubing (size, grade, measured and true vertical depth): 5 17# L - 9701' 8308' 5 17#x4 12.6# N - 80 9847' - 10024' 8431' Packers and SSSV (type, measured and true vertical depth): 9 - 5/8" x 5 HES 'TNT' packer 9617' 8237' 9 - 5/8" x 5 - 1/2" Baker 'SAB' packer 9894' 8471' 11. Stimulation or cement squeeze summary: Intervals treated (measured): tr,'1 Treatment description including volumes used and final pressure: JAN 2; 3 ZU i2 12 Representative Daily Average Production or Injection Data Oil -Bbl Gas -Mcf Water -Bbl Casing Pressure Tubing Pressure Prior to well operation: Subsequent to operation: 13. Attachments: ❑ Copies of Logs and Surveys run 14. Well Class after work: ❑ Exploratory ❑ Development " ® Service ❑ Stratigraphic ® Daily Report of Well Operations ® Well Schematic Diagram 15. Well Status after work: ❑ GINJ ❑ Oil ❑ SUSP ❑ WDSPL ❑ Gas ❑ GSTOR ❑ SPLUG ❑ WAG "' ® WINJ 16. 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: Contact David Bjork, 564 -5683 311 - 171 Printed Name Terrie Hubble G Title Drilling Technologist Signature /J � «G��� Phone 5 64 -462 Date Prepared Bye 6 4- 4 2 g k ,�� ll T e rrie Hubble, 564 -4628 Form 10 -404 Revised 10/2010 RBDMS DEC 2 7 2011 Original Only • North America - ALASKA - BP Page 1 of 16 Operation Summary Report Common Well Name: 01 -11 AFE No Event Type: WORKOVER (WO) Start Date: 11/17/2011 End Date: X4 -00TMX (2,177,000.00 ) Project: Prudhoe Bay Site: PB DS 01 Rig Name /No.: DOYON 16 Spud Date/Time: 11/15/2011 12:00:OOAM Rig Release: Rig Contractor: DOYON DRILLING INC. UWI: Active Datum: 19 : 11 10/9/1977 00:00 @73.00ft (above Mean Sea Level) Date From - To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (ft) 11/17/2011 22:00 - 00:00 2.00 RIGD P PRE "RIG RELEASE AT 2200 FROM L -205" BRIDAL DOWN TOP DRIVE - SECURE DERRICK -CLEAN AND SECURE CELLAR -BLOW DOWN RIG LINES - SECURE PITS AND REMOVE SLOP TANK - SECURE RIG FLOOR 11/18/2011 00:00 - 07:00 7.00 MOB P PRE MOVE OFF OF L -205 AT 0100 WITH BP WSL, TOOLPUSHER AND PAD OPERATOR PRESENT - GATHER RIG MATS AND EQUIPMENT FROM CELLAR -MOVE RIG EQUIPMENT TO DS1 - INSTALL BOOSTER TIRES -CLOSE OUT L -205 PERMIT WITH PAD OPERATOR 07:00 - 08:00 1.00 MOB P PRE MOVE FROM L PAD TO L PAD ACCESS ROAD 08:00 - 17:00 9.00 MOB N RREP PRE RIG BROKE DOWN DUE TO REAR BOOSTER WHEEL MALFUNCTION - REMOVE REAR BOOSTER WHEEL AND CONTINUE DOWN L PAD ACCESS ROAD. - CONTINUE MOVE DOWN SPINE TO MOBILE PAD. 17:00 - 20:00 3.00 MOB N RREP PRE STAND BY FOR REAR BOOSTER WHEEL REPAIR AT MOBILE PAD. 20:00 - 00:00 4.00 MOB P PRE MOVE RIG FROM MOBILE PAD TO EAST KUPARUK RIVER BRIDGE. 11/19/2011 00:00 - 05:30 5.50 MOB P PRE MOVE RIG FROM EAST OF KUPARUK RIVER BRIDGES TOWARD DS 1VIA K PAD ROAD. 05:30 - 00:00 18.50 MOB N RREP PRE REAR OFF - DRILLERS SIDE MIDDLE TIRE RUPTURED DURING MOVE WITH RIG IN BETWEEN E PAD AND G PAD ON THE "K" PAD ROAD. TRACTION # 3995293 REMOVE REAR BOOSTER WHEELS AND SPREADER BEAM. REPLACE RUPTURED TIRE. INSTALL SPREADER BEAM AND REAR BOOSTER WHEELS. 11/20/2011 00:00 - 03:00 3.00 MOB N RREP PRE CONTINUE TIRE REPAIR 25 GALLON FRESH WATER RELEASE FROM FROZEN VALVE RUPTURE IN MEZZANINE LEVEL OF THE CELLAR, AT THE TEST PUMP STATION. SRT NOTIFIED 03:00 - 07:00 4.00 MOB N WAIT PRE STAND BY FOR NORDIC RIG TO COMPLETE RIG MOVE ON THE SPINE ROAD, PER SECURITY Printed 12/12/2011 11:41:17AM li plorthAmerica - ALASKA - BP Page 2 of 16 Operation Summary Report Common Well Name: 01 -11 AFE No Event Type: WORKOVER (WO) Start Date: 11/17/2011 End Date: X4 -00TMX (2,177,000.00 ) Project: Prudhoe Bay Site: PB DS 01 Rig Name /No.: DOYON 16 Spud Date/Time: 11/15/2011 12:00:OOAM Rig Release: Rig Contractor: DOYON DRILLING INC. UWI: Active Datum: 19 : 11 10/9/1977 00:00 @73.00ft (above Mean Sea Level) Date From - To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (ft) 07:00 - 10:00 3.00 MOB P PRE START MOVING EAST ON 'K' PAD ROAD (BETWEEN E AND G PAD) TURN SOUTH ONTO WEST DOCK ROAD AND TRAVEL TOWARD DS-1. 08:05 HRS: INFORMED 659-5700 'BP SPILL REPORTING' THAT RIG HAS MOVED OFF THE LEAK AREA AND THE WSL WOULD REPORT BACK FROM THE SITE WHEN HE/SHE ARRIVES. WITH THE RIG MOVED OFF THE LEAK SITE, WSL'S INSPECTED A 9 SQ/IN AREA CONTAINING HYDRAULIC FLUID. REPORT FINDING TO 659 -5700. C.J. INSTRUCTED THE WSL TO CLEAN IT UP AND RETURN TO WORK. 10:00 - 18:00 8.00 MOB P PRE CONTINUE RIG MOVE FROM WEST DOCK ROAD TO DS1 PULL ONTO DS 1 ACCESS ROAD AT 1800 AT 1755 —10 GAL BLACK WATER SPILL FROM DOYON 16 AUXILLARY CAMP. -CAUSE ATTRIBUTED TO IMPROPERLY MADE UP CONNECTION WHEN RIGGING UP CAMP ON DS 1 -LEVEL 0 NOTIFICATIONS MADE -AREA FLAGGED FOR SRT TO REMEDIATE AFTER CAMP MOVES OFF LOCATION - TRACTION #: 3996180 18:00 - 21:00 3.00 MOB P PRE REMOVE BOOSTER TIRES - DERRICK INSPECTION COMPLETE -PICK UP BOP STACK AND SECURE ON STAND IN CELLAR NOTIFIED AOGCC OF UP COMING BOP TEST AT 1830. JOHN CRISP WAIVED WITNESS FOR THE NEXT 24 HOURS. CALL BACK IF TESTING WILL BEGIN AFTER 24 HOURS FROM NOW. 21:00 - 00:00 3.00 MOB P PRE PJSM FOR STEERING RIG THROUGH TIGHT SPOTS AND CORNERS ON THE PAD. -MOVE RIG AROUND BACKSIDE OF DS 1 - CONFIRM TREE VALVES CLOSED -SPOT OVER WELL AT 11:30. DOYON TOOL PUSHER AND BP WELL SITE LEADER PRESENT 11/21/2011 00:00 - 07:30 7.50 RIGU P PRE PJSM -SHIM RIG -RAISE DERRICK, BRIDLE DOWN -R/U FLOOR EQUIPMENT -SPOT AND HOOK UP ALL AUXILIARY UNITS, MOTOR SHED, PUMP ROOM, FUEL TANK, CHANGE ROOM, ETC. -BRING ON 8.5 PPG SEAWATER "ACCEPT RIG AT 0600"" 07:30 - 08:00 0.50 RIGU P PRE HOLD RIG EVAC DRILL -AAR WITH WSL AND TP PRESENT 08:00 - 09:00 1.00 WHSUR P WHDTRE REMOVE TREE CAP -PICK UP DSM LUBRICATOR -IA= 0 PSI -OA= 0 PSI Printed 12/12/2011 11:41:17AM forth America - ALASKA - BP Page 3 of 16 • Operation Summary Report Common Well Name: 01 -11 AFE No Event Type: WORKOVER (WO) Start Date: 11/17/2011 End Date: X4 -00TMX (2,177,000.00 ) Project: Prudhoe Bay Site: PB DS 01 Rig Name /No.: DOYON 16 Spud Date/Time: 11/15/2011 12:00:OOAM Rig Release: Rig Contractor: DOYON DRILLING INC. UWI: Active Datum: 19 : 11 10/9/197700:00 @73.00ft (above Mean Sea Level) Date From - To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (ft) 09:00 - 20:30 11.50 WHSUR N SFAL WHDTRE DSM INSPECTING ACTUATOR ON SSV NOTICED PINS SHEARED IN OPEN POSITION AND UNABLE TO FUNCTION VALVE - COMMUNICATE WITH BP RWO TEAM IN ANCHORAGE TO REMOVE FAILED VALVE AND INSTALL A DRY -HOLE TREE. -DSM REMOVE FAILED SSV AND INSTALL DRY -HOLE TREE ON TOP OF EXISTING MASTER. AT 1800 GAVE AOGCC BOP TEST UPDATE. - JOHN CRISP WAIVED WITNESS 20:30 - 21:30 1.00 WHSUR P WHDTRE PJSM -RU AND PRESSURE TEST DSM LUBRICATOR AND NEW TREE BREAKS AGAINST MASTER VALVE TO 250 LOW, 4000 HIGH FOR 5 CHARTED MIN 21:30 - 22:30 1.00 WHSUR P WHDTRE PIJI 1 BPV AND RD DSM LUBRICATOR_ - TUBING ON VACUUM 22:30 - 00:00 1.50 WHSUR P WHDTRE PJSM FOR CIRC OUT - FINISH RIGGING UP FOR CIRCULATION - PRESSURE TEST SURFACE LINES TO 250 LOW AND 4000 PSI HIGH FOR 5 MIN 11/22/2011 00:00 - 01:00 1.00 WHSUR P WHDTRE PRESSURE TEST LINES IN CELLAR AND HARDLINE TO TIGER TANK TO 250 LOW AND 4000 HIGH FOR 5 MIN 01:00 - 01:30 0.50 WHSUR P WHDTRE REVERSE 60 BBLS OF 8.5 PPG SEAWATER DOWN IA AT 4 BPM TAKING DIESEL RETURNS TO THE TIGER TANK -TURN AROUND AND PUMP DOWN TUBING AT 5 PBPM AND 260 PSI - PRESSURE GRADUALLY DROPPED AND THEN FELL TO 60 PSI WITH 260 BBLS AWAY. -SHUT DOWN PUMP AND CHECK FOR SURFACE LEAKS - SI AT ANNULUS VALVE AND TUBING TO TEST SURFACE LINES TO 600 PSI, HELD PRESSURE 01:30 - 07:00 5.50 WHSUR P WHDTRE MAKE -UP 10 BBL HI-VIS SWEEP WITH RED DYE TO DETERMINE IF A WASHOUT HAD OCCURED IN THE TUBING. - CIRCULATE DOWN THE TUBING AT 4 BPM AT 20 PSI 07:00 - 08:00 1.00 WHSUR P WHDTRE PU & MU DSM LUBRICATOR, PT TO 250 LOW AND 4000 HIGH FOR 5 CHARTED MIN EACH - INSTALL THE 5 -1/8" GRAY BPV & TEST DART 08:00 - 12:00 4.00 WHSUR P WHDTRE TEST OA TO 250 PSI LOW AND 2000 PSI HIGH FOR 30 CHARTED MIN. LOSING TOTAL OF 100 PSI OVER THE ENTIRE 30 MIN. - TESTED COMBO T X IA PRESSURE TEST TO 4000 PSI FOR 30 CHARTED MIN, LOST 0 PSI IN THE FIRST 15 MIN, AND LOST 15 PSI IN THE SECOND 15 MIN, TEST WAS PEROFORMED TWICE TO VERIFY RESULTS. - CALLED RWO WELLS TEAM LEAD, FOR APPROVAL TO PROCEDE. - VERIFY WELL FOR NO FLOW, 12:00 - 13:30 1.50 WHSUR P WHDTRE RU & TEST THE THE "K" BPV & DART - TEST FROM ABOVE TO 250 PSI LOW AND 4000 PSI HIGH FOR 5 CHARTED MIN., BOTH TESTS GOOD Printed 12/12/2011 11:41:17AM a[arth America - ALASKA - BP Page 4 of 16 Operation Summary Report Common Well Name: 01 -11 AFE No Event Type: WORKOVER (WO) Start Date: 11/17/2011 End Date: X4 -00TMX (2,177,000.00 ) Project: Prudhoe Bay Site: PB DS 01 Rig Name /No.: DOYON 16 Spud Date/Time: 11/15/2011 12:00:OOAM Rig Release: Rig Contractor: DOYON DRILLING INC. UWI: Active Datum: 19 : 11 10/9/1977 00:00 @73.00ft (above Mean Sea Level) Date From - To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (ft) 13:30 - 16:00 2.50 WHSUR P WHDTRE BD LINES , CHOKE, DRAIN TREE AND GAS BUSTER. - NO LEAKS ABOVE THE BPV - INSTALL A LOW PERSSURE GUAGE ON THE IA TO MONITOR DURING ND AND NU PROCESS. 16:00 - 18:30 2.50 BOPSUR N RREP WHDTRE TP NOTIFIED WSL THAT THE AUDIBLE ALARMS SYSTEM WAS DOWN & THEY WERE TROUBLE SHOOTING THE ISSUE - NOTIFIED RWO SUPT ABOUT THE ISSUE WITH THE SAFETY CRITICAL EQUIPMENT. WAS DECIDED THAT WE WOULD NOT BE PROCEDING WITH THE REMOVAL OF THE TREE UNTIL THE AUDIBLE ALARMS WERE FIXED. 18:30 - 21:30 3.00 WHSUR P WHDTRE SAFETY CRITICAL ALARMS BACK IN SERVICE - N/D TREE & ADAPTER - INSPECT / PREP WELLHEAD AND DART - FUNCTION LDS ( LDS IN= 3.125 " / OUT= 4 ") 21:30 - 00:00 2.50 WHSUR P WHDTRF N /11 BOP'S - INSTALL NEW AIR BOOTS ON RISER 11/23/2011 00:00 - 02:30 2.50 BOPSUR P WHDTRE CONTINUE TO N/U BOPS 02:30 - 10:00 7.50 BOPSUR P WHDTRE TESTING 13 -5/8" BOPE TEST BOPE PER WELL PLAN AND AOGCC REGS. -RAMS TESTED TO 250 PSI LOW AND 4000 PSI HIGH. - HYDRIL TESTED TO 250 PSI LOW AND 3,500 PSI HIGH / �I L -TEST USING 5 V J 2" AND 4" TEST JOINTS. I - PRESSURE TEST FOR 5 CHARTED MIN. -ALL TEST WITNESSED BY BP WSL / DDI TP. �l - ALL TEST FOLLOW TESTING CRITERIA U/ DOCUMENTED IN CRT- AK -10 -45 -AOGCC STATE INSPECTOR JOHN CRISP WAIVED STATES RIGHT OF WITNESS. 10:00 - 11:00 1.00 BOPSUR P WHDTRE DRAIN STACK - CAMERON WELLHEAD TECH RETRIEVE TEST DART 11:00 - 12:00 1.00 BOPSUR P WHDTRE PU DUTCH RISER AND DSM LUBRICATOR QUICK TEST SUB AND THAW OUT FOR USE. 12:00 - 14:30 2.50 BOPSUR P WHDTRE PJSM - PRESSURE TEST DSM LUBRICATOR AND QUICK TEST SUB TO 250 PSI LOW AND 3500 PSI HIGH FOR 5 CHARTED MIN - REMOVE FLUID FROM BOPS AND PULL DART WITH T -BAR -TEST DSM LUBRICATOR BREAK AT QUICK TEST SUB TO 250 LOW AND 3500 PSI HIGH FOR 5 CHARTED MIN -PULL BPV -RIG DOWN LUBRICATOR AND DUTCH RISER 14:30 - 16:00 1.50 FISH P DECOMP PJSM -MAKE UP SPEAR (BULLNOSE, 4 -5/8" SPEAR PACK -OFF, 4" DOUBLE GRAPPLE) -FILL GAS BUSTER 16:00 - 17:30 1.50 FISH P DECOMP PJSM - CAMERON WELLHEAD TECH BOLDS - SPEAR TUBING HANGER -DRAIN BOPS -BLOW DOWN KILL LINE Printed 12/12/2011 11:41:17AM S port America - ALASKA - BP ill Page 5 of 16 Operation Summary Report Common Well Name: 01 -11 AFE No Event Type: WORKOVER (WO) Start Date: 11/17/2011 End Date: X4 -00TMX (2,177,000.00 ) Project: Prudhoe Bay Site: PB DS 01 Rig Name /No.: DOYON 16 Spud Date/Time: 11/15/2011 12:00:OOAM Rig Release: Rig Contractor: DOYON DRILLING INC. UWI: Active Datum: 19 : 11 10/9/1977 00:00 @73.00ft (above Mean Sea Level) Date From - To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (ft) 17:30 - 21:00 3.50 FISH P DECOMP PJSM -35 PSI ON IA, SUSPECTED WELL OUT OF BALANCE FROM THERMALS OR FREEZE PROTECT - DISCUSS PLAN FORWARD WITH RWO ENGINEER IN ANCHORAGE - INFORM NS SUPT OF PLAN FORWARD - CAMERON WELLHEAD TECH RILDS - RELEASE SPEAR -RIG UP TO REVERSE SURFACE TO SURFACE (650 BBLS) - REVERSE SURFACE TO SURFACE THROUGH THE GAS BUSTER AT 6 BPM AT 460 PSI -8.5 PPG FLUID IN 8.4 HEAVY OUT DURING CIRCULATION -0 BBLS LOST DURING CIRCULATION -BLOW DOWN THE CEMENT LINE AND DRAIN BOP - MONITOR WELL FOR 30 MIN WITH 5 PSI ON IA -DRAIN 17 BBLS FROM THE IA, IA MAINTAINED 5 PSI 21:00 - 00:00 3.00 FISH P DECOMP RIG UP TO CIRCULATE DOWN THE TUBING THROUGH CHOKE AND GAS BUSTER -PUMP 20 BBL HI-VIS SWEEP ATTEMPTING TO FLUSH OUT ANY DIESEL HUNG UP IN THE IA -PUMP SURFACE TO SURFACE (650 BBLS) DOWN THE TUBING AT 650 PSI, 7 BPM -8.5 PPG FLUID IN AND OUT DURING CIRCULATION -0 BBLS LOST DURING CIRCULATION - MONITOR WELL, 5 PSI ON IA -BLEED 25 BBLS OF 8.5 PPG FLUID FROM THE IA AND THEN FLOW STOPPED FROM THE IA -IA PRESSURE = 0 PSI 11/24/2011 00:00 - 01:00 1.00 FISH P DECOMP - MONITOR WELL, 5 PSI ON IA - ATTEMPT TO BLEED IA TO TRIP TANK, BUT NOT ENOUGH PRESSURE TO PUSH FLUID UP TO THE TANK -BLEED 25 GAL OF 8.5 PPG FLUID FROM THE IA AND THEN FLOW STOPPED FROM THE IA -IA PRESSURE = 0 PSI 01:00 - 01:30 0.50 FISH P DECOMP BLOW DOWN LINES -LOWER TOP DRIVE TO WARM UP IBOP 01:30 - 02:00 0.50 FISH P DECOMP , RUN IN SPEAR - CONFIRM LATCHED IN WITH 10K OVERPULL -2 GRAPPLES ON SPEAR ARE 8.75 FT AND 6.5 FT BELOW HANGER, PACK OFF 10.5 FT BELOW HANGER - CAMERON WELLHEAD TECH BOLDS -PULL TUBING HANGER AT 255K LBS (70K LBS OVER PULL) 02:00 - 03:00 1.00 FISH P DECOMP CIRCULATE BOTTOMS UP (425 BBLS) -7 BPM AT 500 PSI -8.5 PPG FLUID IN, 8.4 PPG FLUID OUT -0 BBLS LOST DURING CIRCULATION Printed 12/12/2011 11:41:17AM *art America - ALASKA - BP Page 6 of 16 Operation Summary Report, Common Well Name: 01 -11 AFE No Event Type: WORKOVER (WO) Start Date: 11/17/2011 End Date: X4 -00TMX (2,177,000.00 ) Project: Prudhoe Bay Site: PB DS 01 Rig Name /No.: DOYON 16 Spud Date/Time: 11/15/2011 12:00:OOAM Rig Release: Rig Contractor: DOYON DRILLING INC. UWI: Active Datum: 19 : 11 10/9/1977 00:00 @73.00ft (above Mean Sea Level) Date From - To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (ft) 03:00 - 05:00 2.00 FISH P DECOMP PJSM FOR LAYING DOWN TUBING - SCHLUMBERGER TERMINATE CONTROL LINES - RELEASE SPEAR FROM TUBING - U- TUBING FLUID - PUMP 15 BBL 9.5 PPG DRY -JOB - RELEASE SPEAR -LAY DOWN TUBING HANGER - VERIFY TUBING THREADS, 8 RD LTC 05:00 - 06:00 1.00 FISH P DECOMP BREAK OUT AND LAY DOWN SPEAR BHA - LAYDOWN LANDING JOINT 06:00 - 09:00 3.00 PULL P DECOMP PULL AND LAYDOWN THE 5 -1/2" 8RD LTC, TUBING FROM 9,703' - SLB SPOOLED CONTROL LINES FROM 2,208' - LAYDOWN TUBING TO PIPE SHED 09:00 - 09:30 0.50 PULL P DECOMP KICK WHILE TRIPPING DRILL: - DRILL WAS CONDUCTED WITH THE ASSISTANT DRILLER ON THE BRAKE, FIRST Y THE WSL AND THE DRILLER PULLED THE FLOW PADDLE TO SHOW AN INCREASE IN FLOW %. THE AD FOLLOWED THE SHUT IN PROCEDURE FOR A FLOW INCREASE, BY SHUTTING DOWN THE CIRCULATION AND FLOW CHECKING THE WELL, THERE WAS NO FLOW SHOWING , HE CONFIRMED THIS WITH THE PIT WATCHER. - WE LET THE CREW PULL 5 MORE JOINTS AND HAD THE PIT WATCHER ADD FLUID TO THE TRIP TANK. THE AD AGAIN FOLLOWED THE SHUT IN PROCEDURE AND SECURED THE WELL, WE TOLD HIM TO SIMULATE SHUTTING THE ANNULAR AAR: WAS DISCUSSED THAT THE AD AND CREW FOLLOWED THE SHUT IN PROCEDURES CORRECTLY AND IN A TIMELY MANNER. WHAT COULD HAVE GONE BETTER WAS THE AD NEEDED TO ANNOUNCE LOUDER WHAT WAS GOING ON WITH THE WELL AND WHAT HE WANTED THEM TO DO 09:30 - 10:30 1.00 PULL P DECOMP CONTINUE POH LAYING DOWN 5 -1/2" TUBING WITH CONTROL LINES - POOH WITH 81 JNTS, TO 2,208' , TERMINATED CONTROL LINES - LAY DOWN THE SLB SPOOLER 10:30 - 14:00 3.50 PULL P DECOMP RIG CREWS LEAVING THE RIG FOR THANKSGIVING - SECURED THE WELL WITH SAFETY VALVE. - CONTINUOUS HOLE FILL ACROSS THE TOP - DRILLER STAYED ON THE RIG TO MONITOR. 14:00 - 14:30 0.50 PULL P DECOMP SERVICE AND GREASE THE RIG - CREWS MAKING SURE THINGS DID NOT FREEZE UP DURING THE SHUT DOWN. 14:30 - 17:30 3.00 PULL P DECOMP CONTINUE PULLING AND LAYDOWN THE 5 -1/2" 8RD LTC TUBING FROM 7,495' - POH FROM 7,495' TO 6,091', 54 JNTS 17:30 - 18:00 0.50 PULL P DECOMP KICK WHILE TRIPPING DRILL - DRILLER CALLED THE DRILL AND THE CREWS RESPONDED BY STABBING THE 1 SAFETY VALVE, DRILLER SIMULATED SHUTTING THE ANNULAR & OPENING THE HCR TO A CLOSED CHOKE. Printed 12/12/2011 11:41:17AM allporth Arrierica - ALASKA , BP Page 7 of 16 Operation Summary Report Common Well Name: 01 -11 AFE No Event Type: WORKOVER (WO) Start Date: 11/17/2011 End Date: X4 -00TMX (2,177,000.00 ) Project: Prudhoe Bay Site: PB DS 01 Rig Name /No.: DOYON 16 Spud Date/Time: 11/15/2011 12:00:OOAM Rig Release: Rig Contractor: DOYON DRILLING INC. UWI: Active Datum: 19 : 11 10/9/1977 00:00 @73.00ft (above Mean Sea Level) Date From - To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (ft) 18:00 - 20:30 2.50 PULL P DECOMP CONTINUE PULLING AND LAYDOWN THE 5 -1/2" 8RD LTC TUBING FROM 6091' TO 3935' 20:30 - 21:00 0.50 PULL P DECOMP UNANNOUNCED KICK WHILE TRIPPING DRILL -AAR WITH WSL AND TP - MOTORMAN ON THE BREAK FOR DRILL, DETECTED PIT GAIN QUICKLY AND NOTIFIED CREW, ALL CREW MEMBERS RESPONDED PER ROLES AND RESPONSIBILITIES DURING WEL CONTROL EVENT AND COMMUNICATED OVER THE GAI- TRONICS - LESSONS LEARNED: DRILLER SHOULD GIVE HARMONY TO WHOMEVER IS ON THE BRAKE SO PROPER NOTIFICATIONS CAN BE MADE - DISCUSSED NEXT STEPS IF THIS HAD BEEN A REAL WELL CONTROL INCIDENT (NOTIFICATIONS, DATA NEEDED, ACTION ITEMS FOR CREW MEMBERS) 21:00 - 00:00 3.00 PULL P DECOMP CONTINUE PULLING AND LAYDOWN THE 5 -1/2" 8RD LTC TUBING FROM 3935' TO 2094' 11/25/2011 00:00 - 02:30 2.50 PULL P DECOMP CONTINUE PULLING AND LAYDOWN THE 5 -1/2" 8RD LTC TUBING FROM 2094' TO SURFACE. -360 TOTAL JOINTS RECOVERED PLUS CUT JOINT -FLARE ON CUT JOINT 6.0" -CUT JOINT 12.11 FT 0 BBLS LOST DURING POH 02:30 - 04:00 1.50 PULL P DECOMP CLEAN AND CLEAR RIG FLOOR -PULL TUBING OUT OF PIPE SHED -LOAD BHA INTO PIPE SHED. -RUN WEAR RING (8- 15/16" ID) 04:00 - 06:00 2.00 FISH P DECOMP MAKE UP FISHING BHA FOR TUBING STUB (8.5" HMX SHOE, 8 -1/8" MCP, 8 -1/8" BOWL WITH BASKET GRAPPLE FOR 5 -1/2 ", 8 -1/8" 4FT EXTENSION, TOP SUB, 6" BUMPER SUB, 6" OIL JARS, 9 EACH 6 -1/4" DC, 6" ACCELERATOR JARS, PUMP -OUT SUB) 06:00 - 17:30 11.50 FISH P DECOMP PU DRILL PIPE FROM PIPE SHED FROM SURFACE TO 7910' - 0 BLLS LOST DURING TRIP IN HOLE 17:30 - 18:00 0.50 FISH P DECOMP FIRE DRILL - SIMULATE FIRE IN BOILER ROOM - AAR WITH CREW 18:00 - 20:00 2.00 FISH P DECOMP CONT. RIH FROM 7910' TO 9648' PUW 200K, SOW 160K TAG FISH AT 9709' MD EST. MILLING PARAMETERS - PUW =200K, SOW =160K, ROT. WT. =175K -FREE TORQUE =6K -SPR'S MP #1 =30SPM (2.5 BPM) @ 80PSI, 40 SPM (3.4 BPM) @150 PSI -SPR'S MP #2 = 30SPM (3BPM) @ 80 PSI, 40 SPM (4 BPM) = 190 PSI - PUMP 3 BBL MIN © 120 PSI Printed 12/12/2011 11:41:17AM forth America - ALASKA - BP Page 8 of 16 Operation Summary Report Common Well Name: 01 -11 AFE No Event Type: WORKOVER (WO) Start Date: 11/17/2011 End Date: X4 -00TMX (2,177,000.00 ) Project: Prudhoe Bay Site: PB DS 01 Rig Name /No.: DOYON 16 Spud Date/Time: 11/15/2011 12:00:OOAM Rig Release: Rig Contractor: DOYON DRILLING INC. UWI: Active Datum: 19 : 11 10/9/1977 00:00 @73.00ft (above Mean Sea Level) Date From - To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (ft) 20:00 - 22:30 2.50 FISH P DECOMP PJSM WITH BAKER AND RIG CREW ON MILLING, FISHING AND BULLHEADING -MILL TUBING STUB @ 6 -7K TORQUE FOR 2 MIN -WORK MILL OVER CUT 4 TIMES - CONTINUE DOWN SWALLOWING TUBING STUB IN OVERSHOT EXTENSION WITH GRAPPLE - ENGAGE PACK -OFF AROUND TUBING STUB AT 4.5 FT OF SWALLOW AND SEE PRESSURE INCREASE ON PUMP FROM 120 TO 260 PSI -SHUT DOWN PUMP AND BLEED OFF - CONTINUE IN HOLE TO FULL SWALLOW OF 7.5 FT OVER TUBING STUB -OVER PULL 20K TO ENSURE LATCHED - ATTEMPT TO RELEASE " K" ANCHOR BY TURNING TO THE RIGHT WITH GRAPPLE LATCHED INTO TUBING STUB AND 20K OVER PULL -WORK TO PIPE UP AND DOWN WITH 13K TORQUE - RELEASE TORQUE AND COMPARE TURNS TO SEE IF LOOSING ROUNDS INDICATING BACK -OFF -NEVER LOST TURNS - CONTINUE WORKING WITH 10K OVER PULL - NO PROGRESS 22:30 - 00:00 1.50 FISH P DECOMP PRE - JARRING DERRICK INSPECTION PER DDI JARRING PROCEDURE -WSL PERFORMED AUDIT OF MAN -RIDER PERMIT AND DERRICK INSPECTION EQUIPMENT AND CHECKLIST -CLEAR RIG FLOOR DURING JARRING -BEGIN JARRING ON SBR WITH 200K PUW - 5 JAR LICKS AT 45K OVER PULL - 5 JAR LICKS AT 60K OVER PULL -5 JAR LICKS AT 80K OVER PULL - 20 JAR LICKS AT 100K OVER PULL -20 JAR LICKS AT 125K OVER PULL 11/26/2011 00:00 - 00:30 0.50 FISH P DECOMP PJSM WITH NEW CREW ON TOUR FROM TOWN - REVIEW FISHING AND BULLHEADING PLAN - PERFORM DERRICK INSPECTION PER DDI JARRING PROCEDURE 00:30 - 01:30 1.00 FISH P DECOMP CONTINUE JARRING ON TUBING STUB AT 125 -150K C)VFRPIII 1 -1.5 JAR LICKS/MIN OVER TIME INTERVAL -NO DEPTH GAIN ON THE DRILL PIPE FROM FISHING Printed 12/12/2011 11:41:17AM *orth America - ALASKA - BP Page 9 of 16 Operation Summary Report Common Well Name: 01 -11 AFE No Event Type: WORKOVER (WO) Start Date: 11/17/2011 End Date: X4 -00TMX (2,177,000.00 ) Project: Prudhoe Bay Site: PB DS 01 Rig Name /No.: DOYON 16 Spud Date/Time: 11/15/2011 12:00:OOAM Rig Release: Rig Contractor: DOYON DRILLING INC. UWI: Active Datum: 19 : 11 10/9/1977 00:00 @73.00ft (above Mean Sea Level) Date From - To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (ft) 01:30 - 03:00 1.50 FISH P DECOMP WELL LOST 10 BBLS FLUID - SI ANNULAR AND BULLHEAD DOWN KILL LINE 50 BBLS AT 7 BPM, 2600 PSI -OPEN ANNULAR TO SEE FLUID DROPPING IN ANNULUS - ESTABLISH LOSS RATE FOR 10 MIN, 83 BPH -HOLE FILL SET AT 60 BPH - DISCUSS FLUID LEVEL IN TUBING AND PUMPING OPTIONS WITH BOT FISHING HAND -SI ANNULAR AND BULLHEAD 50 BBLS DOWN THE TUBING AND ANNULUS AT 8 -10 BPM AND 2300 PSI (2500 PSI LIMIT FOR FISHING BHA PACK -OFF) - OPEN ANNULAR TO SEE FLUID DROPPING IN BACKSIDE 03:00 - 04:00 1.00 FISH P DECOMP CONTINUE JARRING TUBING STUB AT 150 -175K OVER PULL - 1.5 JAR LICKS/MIN OVER TIME INTERVAL -NO FOOTAGE GAINED ON DRILL PIPE FROM FISHING -30 MIN LOSS RATE ESTABLISHED, 85 BPH - HOLE FILL SET AT 60 BPH 04:00 - 04:30 0.50 FISH P DECOMP DERRICK INSPECTION PER DDI JARRING PROCEDURE 04:30 - 05:30 1.00 FISH P DECOMP CONTINUE JARRING TUBING STUB AT 150 -175K OVER PULL - 1.5 JAR LICKS/MIN OVER TIME INTERVAL -NO FOOTAGE GAINED ON DRILL PIPE FROM FISHING AT 0500 CALL TOWN RWO ENGINEER -PLAN FORWARD TO ATTEMPT LEFT HAND _ BLIND BACK OFF OF TUBING JOINT BETWEEN JET CUT AND WRP STATIC LOSS RATE DROPPED TO 30 BPH 05:30 - 06:00 0.50 FISH P DECOMP PU TO 205K (5K OVER PULL) -9 -1/2 LH TURNS, STALL OUT AT 6K TORQUE - 220 -175K WORK TORQUE OUT OF PIPE -PU TO 205K - 12 -1/2 LH TURNS -PULL UP FREE AT 200K PUW -DROP BALL TO OPEN CIRC SUB 06:00 - 06:30 0.50 FISH P DECOMP BULLHEAD 75 BBLS DOWN TUBING AND ANNULUS @ 10 BPM WITH 1360 PSI 06:30 - 08:30 2.00 FISH P DECOMP CIRCULATE BOTTOMS UP THROUGH CHOKE - 6 BPM @ 500 PSI - PERFORM POST JARRING INSPECTION PER DDI PROCEDURE 08:30 - 09:30 1.00 FISH P DECOMP MONITOR WELL - LOSS RATE = 108 BPH - BLOW DOWN CHOKE AND TOP DRIVE 09:30 - 15:30 6.00 FISH P DECOMP POOH FROM 9709' TO 4928' - CIRCULATE BOTTOMS UP THROUGH GAS BUSTER 6 BPM @ 580 PSI - MONITOR WELL FOR 10 MIN= NO FLOW - CONTINUE FILLING WELL @ 6 BPH 15:30 - 17:00 1.50 FISH P DECOMP CONTINUE POOH FROM 4928' TO 2463' -FILL WELLBORE 98 BBLS 17:00 - 18:00 1.00 FISH P DECOMP CONTINUE POOH FROM 2463' TO 1421' - FILL WELLBORE 40 BBLS Printed 12/12/2011 11:41:17AM forth America - ALASKA - BP Page 10 of 16 Operation Summary Report Common Well Name: 01 -11 AFE No Event Type: WORKOVER (WO) Start Date: 11/17/2011 End Date: X4 -00TMX (2,177,000.00 ) Project: Prudhoe Bay Site: PB DS 01 Rig Name /No.: DOYON 16 Spud Date/Time: 11/15/2011 12:00:OOAM Rig Release: Rig Contractor: DOYON DRILLING INC. UWI: Active Datum: 19 : 11 10/9/1977 00:00 @73.00ft (above Mean Sea Level) Date From - To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (ft) 18:00 - 18:30 0.50 FISH P DECOMP CONTINUE POOH FROM 1421' TO 284' 18:30 - 19:00 0.50 FISH P DECOMP FILL WELLBORE WITH 40 BBLS - CIRCULATE BOTTOMS UP AT 6 BPM, 340 PSI FOR 40 TOTAL BBLS CIRCULATED - MONITOR THE WELL -BLOW DOWN LINES - CONTINUE TO FILL HOLE AT 60 BPH 19:00 - 20:00 1.00 FISH P DECOMP POH TO DRILL COLLARS -FILL WELLBORE WITH 30 BBLS - MONITOR FOR 10 MIN BEFORE BRINGING NON - SHEARABLES THROUGH THE STACK, LOSSES CONTINUE - REVIEW BP /DDI BRIDGING DOCUMENT FOR NON - SHEARABLES ACROSS THE STACK -HAVE SAFETY JOINT READY ON SKATE 20:00 - 22:00 2.00 FISH P DECOMP PJSM FOR LAYING DOWN BHA -STAND BACK 9 DRILL COLLARS -LAX DOWN BAKER FISHING TOOLS TO GRAPPLE AND DRESS -OFF MILL WITH CUT JOINT 22:00 - 00:00 2.00 FISH P DECOMP PJSM FOR TRAPPED PRESSURE POTENTIAL IN FISH, REVIEW PROCEDURE -RIG UP 5 -1/2" TUBING EQUIPMENT -PUNCH TUBING ABOVE AND BELOW WRP PER DDI PROCEDURE, NO GAS PRESENT -LAY DOWN CUT JOINT ON BAKER GRAPPLE/OVERSHOT -LAY DOWN 5 -1/2" TUBING FISH. 135 TOTAI FEET RECOVERED CUT JOINT = 14.32' JOINT WITH WRP AND SLIDING SLEEVE ON BOTTOM = 30.57' JOINT = 28.34' JOINT WITH LANDING NIPPLE ON BOTTOM = 28.82' JOINT WITH TOP SUB OF SBR ON BOTTOM = 32.52' 11/27/2011 00:00 - 01:00 1.00 FISH P DECOMP CALL ANCHORAGE RWO ENGINEER TO DISCUSS PLAN FORWARD -SEND PHOTOS OF BOTTOM OF FISH - DECIDED SINCE LOOKING UP IN WELL IS A CLEAN, BEVELED ENTRY TO THE PRODUCING ZONE OF THE WELL, CAN PROCEED TO SCRAPING CASING FOR PACKER PICK UP OVERSHOT GRAPPLE -BACK OFF LIFT SUB AND LAYDOWN 01:00 - 02:30 1.50 FISH P DECOMP CLEAN AND CLEAR RIG FLOOR - HOUSEKEEPING AROUND RIG 02:30 - 04:30 2.00 CLEAN P DECOMP PJSM -MAKE UP SCRAPER BHA (BULLNOSE, DOUBLE PIN SUB, 9 -5/8" CASING SCRAPER, 2 BOOT BASKETS, BIT SUB, BUMPER JAR, X -O, 9 DC, X -O, 2 STRING MAGNETS, PUMP OUT SUB WITH DART, X -O -RIH TO 328' HOLE FILL AT 60 BBLS /HR Printed 12/12/2011 11:41:17AM ,orth America - ALASKA - BP Page 11 of 16 • Operation Summary Report Common Well Name: 01 -11 AFE No Event Type: WORKOVER (WO) Start Date: 11/17/2011 End Date: X4 -00TMX (2,177,000.00 ) Project: Prudhoe Bay Site: PB DS 01 Rig Name /No.: DOYON 16 Spud Date/Time: 11/15/2011 12:00:OOAM Rig Release: Rig Contractor: DOYON DRILLING INC. UWI: Active Datum: 19 : 11 10/9/1977 00:00 @73.00ft (above Mean Sea Level) Date From - To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (ft) 04:30 - 06:30 2.00 CLEAN P ■- DECOMP PJSM - SLIP AND CUT DRILLING LINE -JOINT OF DP ACROSS STACK 06:30 - 11:30 5.00 CLEAN P DECOMP RIH FROM 368' TO 9614' - SPR MUD PUMP #1: 30 SPM (2.5 BPM) @90 PSI, 40 SPM (3.4 BPM) © 140 PSI MUD PUMP #2: 30 SPM (3 BPM) @100 PSI, 40 SPM (4 BPM) @ 230 PSI -PUW = 205K, SOW = 155K, ROTATING WEIGHT = 180K 11:30 12:00 0.50 CLEAN P ■- DECOMP SCRAPE FROM 7503' 9621' 3 TIMES AT 11.5 BPM AND 1750 PSI -BLOW DOWN TOP DRIVE 12:00 - 13:30 1.50 CLEAN P DECOMP RIH TO TAG TOP OF SBR AT 9845' 13:30 - 14:00 0.50 CLEAN P DECOMP FILL WELLBORE WITH 26 BBLS OF SEA WATER AND MONITOR FOR 10 MIN BEFORE PULLING OUT OF HOLE - FLUID LEVEL DROPPING IN THE WELL - MAINTAIN HOLE FILL AT 60 BPH 14:00 - 18:00 4.00 CLEAN P DECOMP PJSM -POH FROM 9845' TO 336' - MONITOR THE WELL FOR 10 MIN BEFORE BRINGING BHA THROUGH STACK - SAFETY JOINT READY ON SKATE 18:00 20:00 2.00 CLEAN P ■- DECOMP PJSM -LAY DOWN COLLARS AND BOT SCRAPER BHA 20:00 - 20:30 0.50 CLEAN P DECOMP CLEAN AND CLEAR RIG FLOOR 20:30 22:00 1.50 DHB P ■- DECOMP PJSM WITH HES FOR RBP MU AND SETTING -M -MU HES RBP -RIH TO 304' 22:00 - 22:30 0.50 DHB P DECOMP SERVICE /GREASE TOP DRIVE 22:30 - 00:00 1.50 DHB P ■- DECOMP CONTINUE TO RUN IN THE HOLE FROM 304' TO 3431' - MAINTIAN 60 BPH HOLE FILL 11/28/2011 00:00 - 01:00 1.00 DHB DECOMP PJSM/ WEEKLY SAFETY MEETING - REVIEW RBP SETTING PLAN WITH CREW COMING ON TOUR - SERVICE RIG 01:00 - 05:00 4.00 DHB __— DECOMP RIH WITH RBP FROM 3431' TO —9500' 05:00 - 05:30 0.50 DHB --_ DECOMP PJSM FOR SETTING AND TESTING RBP WITH RIG CREW, BP WSL AND HES REPS. 05:30 - 06:00 0.50 DHB DECOMP PICKUP 5 MORE JOINTS OF 4" DP -PUW = 184K, SOW = 148K -RIH TO SETTING DEPTH OF 9624 -TURN TO THE LEFT 2 TURNS, SETTING CENTER OF RBP ELEMENT AT 9623.5' -SET DOWN 15K ON PLUG -PICK UP TO 15K OVERPULL (199K) TO CHECK PLUG SET -1/2 TURN OUT TO RELEASE FROM RBP -RACK 2 STANDS BACK AND LAY DOWN 2 JOINTS 06:00 - 07:30 1.50 DHB P -_ DECOMP RIG UP TO PRESSURE TEST CASING - BLOW DOWN KILL AND FILL LINES Printed 12/12/2011 11:41:17AM orth America - ALASKA - BP Page 12 of 16 ` Operation Summary Report Common Well Name: 01 -11 AFE No Event Type: WORKOVER (WO) Start Date: 11/17/2011 End Date: X4 -00TMX (2,177,000.00 ) Project: Prudhoe Bay Site: PB DS 01 Rig Name /No.: DOYON 16 Spud Date/Time: 11/15/2011 12:00:OOAM Rig Release: Rig Contractor: DOYON DRILLING INC. UWI: Active Datum: 19 : 11 10/9/1977 00:00 @73.00ft (above Mean Sea Level) Date From - To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (ft) 07:30 - 09:00 1.50 DHB P DECOMP PRFSSl1RF TFST CASING TO 4000 PSI - HART FOR 30 MINS -CALL WTL TO VERIFY PRESSURE TEST RESULTS, PERMISSION TO PROCEED WITH WELL PLAN - BLEED OFF PRESSURE - MONITOR WELL FOR 10 MINUTES - BLOW DOWN KILL AND FILL LINES 09:00 - 11:00 2.00 DHB P DECOMP PJSM - P/U RTTS - PUW= 173k, SOW = 145K - SET RTTS 1 STAND BELOW ROTARY TABLE AT 99' - POOH 1 STAND - LAY DOWN RTTS RUNNING TOOL - PRESSURE TEST RTTS FOR 5 MIN TO 1000 PSI - R/D TEST EQUIPMENT - BLOW DOWN KILL AND FILL LINES 11:00 - 13:30 2.50 EVAL N WAIT DECOMP INCIDENT AT NORDIC 1 - STAND DOWN CALLED FROM TOWN -WAIT FOR FURTHER INSTRUCTIONS 13:30 - 15:00 1.50 BOPSUR P DECOMP PJSM -N /D BOPS 15:00 - 17:30 2.50 WHSUR P WHDTRE PJSM - NIPPLE DOWN TBG SPOOL AND PACKOFF 17:30 - 20:00 2.50 WHSUR P WHDTRE INSTALL NEW TUBING SPOOL AND PACKOFF - CAMERON TEST PACKOFF 250 PSI 5 MIN - 3500 PSI 30 MIN. 20:00 - 00:00 4.00 WHSUR P WHDTRE PJSM - N/U BOPS - INSTALL DOUBLE CASING VALVE ON VA TUBING SPOOL - TEST BOP BREAK 250 PSI / 4500 PSI 5 MIN. CHARTED 11/29/2011 00:00 - 01:00 1.00 WHSUR P WHDTRE PJSM - CHANGE OUT RISER ON BOP - INSTALL 8 -3/4" WEAR RING 01:00 - 03:00 2.00 WHSUR P WHDTRE PICK UP RTTS RUNNING TOOL AND RIH 1 STAND TO 99' - INSTALL TIW VALVE -LATCH INTO RTTS TO OPEN VALVE ON PLUG -OPEN TIW VALVE AND SEE FLOW - INSTALL PRESSURE GAUGE ABOVE TIW WITH 150 PSI ON GAUGE - CALL DAY WSL -KELLY UP TOP DRIVE TO READ DP PRESSURE OFF OF CHOKE PANEL AND BE READY TO PUMP IF NECESSARY -NO PRESSURE ON CHOKE PANEL WHEN KELLY HOSE, STAND PIPE AND MUD MANIFOLD FILLED WITH FLUID - RELEASE RTTS AND MONITOR WELL FOR 10 MIN 03:00 - 03:30 0.50 WHSUR P WHDTRE BLOW DOWN TOP DRIVE - POH ONE STAND -LAY DOWN RTTS RUNNING TOOL AND PLUG Printed 12/12/2011 11:41:17AM *oft America - ALASKA - BP Page 13 of 16 Operation Summary Report Common Well Name: 01 -11 AFE No Event Type: WORKOVER (WO) Start Date: 11/17/2011 End Date: X4 -00TMX (2,177,000.00 ) Project: Prudhoe Bay Site: PB DS 01 Rig Name /No.: DOYON 16 Spud Date/Time: 11/15/2011 12:00:OOAM Rig Release: Rig Contractor: DOYON DRILLING INC. UWI: Active Datum: 19 : 11 10/9/1977 00:00 @73.00ft (above Mean Sea Level) Date From - To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (ft) 03:30 - 04:30 1.00 WHSUR P WHDTRE PJSM -RIH 3 STANDS -SPR: #1 MUD PUMP 30 SPM (2.5 BPM) 90 PSI, 40 SPM (3.5 BPM) 160 PSI #2 MUD PUMP 30 SPM (3 BPM) 120 PSI, 40 SPM (4 BPM) 200 PSI -PUW = 184K, SOW = 148K -SET DOWN 15K ON RBP AT 9624', OVERPULL 20K -FULL TURN TO THE RIGHT TO RELEASE -SEE FLUID LEVEL DROP IN ANNULUS INDICATING PLUG EQUALIZED -LET PLUG ELEMENTS RELAX -START PULLING UP IN INCREMENTS TO FULLY RELEASE PLUG -PLUG CAME FREE AT 60K OVERPULL 04:30 - 07:00 2.50 WHSUR P WHDTRE CIRCULATE BOTTOMS UP THROUGH THE CHOKE AT 6 BPM 320 PSI - NOTIFICATION OF WEEKLY BOP TEST TO AOGCC INSPECTOR LOU GRIMALDI 07:00 - 07:30 0.50 DHB P -_ INTERV MONITOR WELL, ESTABLISH LOSS RATE, 84 BPH. 07:30 12:00 4.50 FISH P ■- DECOMP POOH W/ 4" DP. - POOH F/ 9624' TO SURFACE, LAY DOWN RBP. 12:00 - 14:30 2.50 DHEQP P -_ OTHCMP PJSM. LOAD & STRAP HWDP. - M/U BHA, SCOOP / OVERSHOT ASSY. 14:30 16:30 2.00 DHEQP P ■- OTHCMP ' PJSM. RIH W/ SCOOP /OVERSHOT ASSY ON. 4 4" DP. - RIH TO 4847'. 16:30 - 17:00 0.50 DHEQP P OTHCMP SPILL DRILL & AAR. 17:00 - 19:30 2.50 DHEQP P OTHCMP CONTINUE TO RIH W/ SCOOP / OVERSHOT ASSY. - RIH TO 9400', ESTABLISH PARAMETERS. - UP WT = 182K, DOWN WT = 152K. - BRING ON PUMP @ 6 1/2 BPM / 700 PSI. - SLACK OFF & SET DOWN @ 9846', SET DOWN 5K. - PICK UP, NO OVERPULL, SET BACK DOWN TO 142K, (10K). - PICK UP, NO OVERPULL OBSERVED. PUT 4 ROUNDS TO THE RIGHT IN PIPE. - SET DOWN AND SEE SCOOP POP OVER AND SWALLOW 2' MORE. - OBSERVE PUMP PRESSURE UP TO 800 PSI @ 6 1/2 BPM. - SET DOWN 15K, PICK UP AND SEE 10 - 15K OVERPULL / BOBBLE. - SET BACK DOWN (2) MORE TIMES TO 127K, (25K ON IT). - PICK UP EACH TIME, OBSERVE NO OVERPULLS. 19:30 - 20:00 0.50 DHEQP P -_ OTHCMP B/D TOP DRIVE. MONITOR WELL. - LINE UP HOLE FILL, 60 BPH. 20:00 - 00:00 4.00 DHEQP P -_ OTHCMP PJSM. POOH & UD 4" DP. - CONTINUOUS HOLE FILL • 60 BPH. Printed 12/12/2011 11:41:17AM •orth America - ALASKA = BP Page 14 of 16 • Operation Summary Report Common Well Name: 01 -11 AFE No Event Type: WORKOVER (WO) Start Date: 11/17/2011 End Date: X4 -00TMX (2,177,000.00 ) Project: Prudhoe Bay Site: PB DS 01 Rig Name /No.: DOYON 16 Spud Date/Time: 11/15/2011 12:00:OOAM Rig Release: Rig Contractor: DOYON DRILLING INC. UWI: Active Datum: 19 : 11 10/9/1977 00:00 @73.00ft (above Mean Sea Level) Date From - To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (ft) 11/30/2011 00:00 - 09:00 9.00 DHEQP P OTHCMP CONTINUE TO POOH & UD 4" DP. - CONTINUOUS HOLE FILL © 60 BPH. - LAY DOWN OVERSHOT RUNNING TOOL - WORKED AS DESIGNED 09:00 - 09:30 0.50 BOPSUR P RUNCMP CLEAN AND CLEAR RIG FLOOR 09:30 - 10:00 0.50 BOPSUR P RUNCMP PJSM AND PULL WEAR RING AND INSTALL TEST PLUG 10:00 - 18:30 8.50 BOPSUR P RUNCMP PJSM - R/U TO PERFORM WEEKLY BOPE l 12,,f It TEST/ TEST - BOPE TO 250 / 4000 PSI FOR 5 Jw CHARTED MINUTES - TEST ANNULAR TO 3500 PSI 4 — - TEST WITNESSED BY AOGCC INSPECTOR, LOU GRIMALDI 18:30 - 23:00 4.50 RUNCOM P RUNCMP PREP FLOOR FOR RUNNING 5 1/2" TCII , COMPLETION. - RIG UP ELEVATORS, POWER TONGS, COMPENSATOR. - RIG UP TORQUE TURN EQUIPMENT. 23:00 - 23:30 0.50 RUNCOM P RUNCMP PJSM ON RUNNING COMPLETION. - EMPHASIS ON HAND PLACEMENT - EMPHASIS ON GOOD COMMUNICATION. 23:30 - 00:00 0.50 RUNCOM P RUNCMP RIH W/ COMPLETION ASSEMBLY. - BAKER LOC ALL CONNECTIONS BELOW PACKER. - MAKE UP HALLIBURTON TNT PACKER. - CONTINUOUS HOLE FILL, 60 BPH - SEAWATER. 12/1/2011 00:00 - 06:00 6.00 RUNCOM P RUNCMP CONTINUE TO RIH W/ 5 1/2" TCII COMPLETION STRING. - USING JET LUBE SEAL GUARD PIPE DOPE. - TORQUE TURNING ALL CONNECTIONS TO 5500 FT /LBS. - USING COMPENSATOR ON ALL CONNECTIONS. - CONTINUOUS HOLE FILL @ 60 BPH SEAWATER. - FILL HOLE, MONITOR WELL AND ESTABLISH CURRENT LOSS RATE. - ESTIMATE 120 BBLS / HR / SEAWATER LOSS RATE. - CHANGED OUT COLLAR ON JT #12. 06:00 - 21:30 15.50 RUNCOM P RUNCMP CONTINUE TO RUN 5 1/2" TCII COMPLETION STRING. - CONTINUOUS HOLE FILL @ 60 BPH / SEAWATER. - REPLACED JTS NUMBER DUE TO IMPROPER MAKE UP, (SHOULDERING UP TOO HIGH). - UP WT = 186K, DOWN WT = 158K. 21:30 - 22:00 0.50 RUNCOM P RUNCMP PJSM. M/U HANGER, LAND TUBING AND RILDS. 22:00 - 23:00 1.00 RUNCOM P RUNCMP RIG UP SURFACE LINES TO PUMP DOWN VA. - PRESSURE TEST LINES, 250 / 4000 PSI, 5 MIN EACH. 23:00 - 00:00 1.00 RUNCOM P RUNCMP SPOT AND PLUMB IN VAC TRUCK W/ CORROSION INHIBITED SEAWATER. - SPOT LITTLE RED UNIT. 12/2/2011 00:00 - 01:00 1.00 RUNCOM P RUNCMP WAIT ON 2ND TRUCK TO ARRIVE WITH REST OF INHIBITED SEAWATER. Printed 12/12/2011 11:41:17AM • orth America - ALASKA - BP Page 15 of 16 Operation Summary Report Common Well Name: 01 -11 AFE No Event Type: WORKOVER (WO) Start Date: 11/17/2011 End Date: X4 -00TMX (2,177,000.00 ) Project: Prudhoe Bay Site: PB DS 01 Rig Name /No.: DOYON 16 Spud Date/Time: 11/15/2011 12:00:OOAM Rig Release: Rig Contractor: DOYON DRILLING INC. UWI: Active Datum: 19 : 11 10/9/1977 00:00 @73.00ft (above Mean Sea Level) Date From - To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (ft) 01:00 - 01:30 0.50 RUNCOM P RUNCMP PRE JOB WITH ALL PARTIES INVOLVED IN BULLHEADING OPERATION. - EMPHASIS ON GOOD COMMUNCATION AND MONITORING FLUIDS. 01:30 - 03:30 2.00 RUNCOM P RUNCMP COMMENCE BULLHEADING CORROSION INHIBITED SEAWATER DOWN VA. - PUMP 76 BBLS @ 5 BPM, NO PRESSURE. - SEE INITIAL PRESSURE OF 70 PSI AFTER PUMPING 76 BBLS. - PUMPED 175 BBLS, 5 BPM / 370 PSI FCP. - LINE UP ON 2ND TRUCK AND PUMP 175 BBLS CORROSION INHIBITED SEAWATER. - 350 BBLS TOTAL PUMPED, 5 BPM / 370 PSI FCP. 03:30 - 04:00 0.50 RUNCOM P -_ RUNCMP PJSM AND STAGE LRS TO PUMP FREEZE PROTECT 04:00 - 05:00 1.00 RUNCOM P RUNCMP PRESSURE TEST LINES TO 500 / 1500 - GOOD 05:00 - 06:00 1.00 RUNCOM P -_ RUNCMP BULLHEAD 90 BBLS OF 80 DEGREE DIESEL DOWN IA 06:00 - 07:00 1.00 RUNCOM P -_ RUNCMP BULLHEAD 50 BBLS 80 DEGREE DIESEL DOWN TBG 07:00 - 07:30 0.50 RUNCOM P RUNCMP BLEED OFF PRESSURE AND MONITOR WELL 07:30 - 08:00 0.50 RUNCOM P -_ RUNCMP PU LANDING JOINT - DROP BALL AND ROD -LD LANDING JOINT 08:00 - 08:30 0.50 RUNCOM P RUNCMP FILL TBG W/ 26 BBLS 08:30 - 11:00 2.50 RUNCOM P RUNCMP PRESSURE UP TUBING - PACKER SET AT 2050# - CONTINUE TO PRESSURE UP TO 4000# FOR TUBING TEST. PACKING GLAND LEAKING ON TUBING SPOOL LOCK DOWN SCREW - BLEED DOWN AND REPAIR - PRESSURE UP TO 4000# AND HOLD FOR 30 MINUTES - PASS TEST - BLEED TUBING DOWN TO 1500# AND PRESSURE UP IA TO 4000 - HOLD FOR 30 MINUTES - PASS TEST - CALL WTL AND GET PERMISSION TO PROCEED (CHART IS ATTACHED TO THE REPORT) 11:00 - 11:30 0.50 RUNCOM P RUNCMP BLEED OFF PRESSURE AND MONITOR WELL 11:30 - 12:30 1.00 RUNCOM P -_ RUNCMP CLEAR FLOOR AND RU DUTCH RISER AND DSM LUBRICATOR 12:30 - 13:30 1.00 RUNCOM P -_ RUNCMP PT DSM LUBRICATOR TO 250 / 1500 FOR 5 MINUTES 13:30 - 14:00 0.50 RUNCOM P -_ RUNCMP SET TWC - CHECK STOPPED ON SEVERAL LEDGES WHILE PASSING THROUGH STACK 14:00 - 14:30 0.50 RUNCOM P RUNCMP LD LUBRICATOR AND DUTCH RISER 14:30 - 15:30 1.00 RUNCOM P -_ RUNCMP PRESSURE TEST TING TO 4000# FOR 5 MINUTES - PASS TEST 15:30 17:00 1.50 RUNCOM P ■- RUNCMP RIG DOWN DSM LUBRICATOR. - BLOW DOWN ALL CIRC LINES, DRAIN STACK. 17:00 - 19:00 2.00 RUNCOM P RUNCMP RIG DOWN CIRC LINES / SQUEEZE MANIFOLD. - R/D HARD LINES IN CELLAR. PREP PITS FOR MOVE 19:00 21:00 2.00 BOPSUR P ■- RUNCMP PULL RISER / MOUSE HOLE / TURN BUCKLES. -OP OPEN N DOORS, INSPECT / CLEAN. - REMOVE BLINDS & 3 1/2" X 6" PIPE RAMS. Printed 12/12/2011 11:41:17AM "forth America - ALASKA - BP Page 16 of 16 . ` Operation Summary Report Common Well Name: 01 -11 AFE No Event Type: WORKOVER (WO) Start Date: 11/17/2011 End Date: X4 -00TMX (2,177,000.00 ) Project: Prudhoe Bay Site: PB DS 01 Rig Name /No.: DOYON 16 Spud Date/Time: 11/15/2011 12:00:OOAM Rig Release: Rig Contractor: DOYON DRILLING INC. UWI: Active Datum: 19 : 11 10/9/1977 00:00 @73.00ft (above Mean Sea Level) Date From - To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (ft) 21:00 - 22:30 1.50 BOPSUR P RUNCMP PJSM. N/D BOPE. - START TO PREP RIG FOR MOVE. 22:30 - 00:00 1.50 WHSUR P WHDTRE PJSM. N/U 135/8" 5M X 7" 5M ADAPTER FLANGE. 12/3/2011 00:00 - 01:30 1.50 WHSUR P WHDTRE CONTINUE TO N/U ADAPTER FLANGE. TEST - TEST TBG HANGER SEALS & VOID / 500 PSI / 30 MIN. GOOD TEST. 01:30 - 03:30 2.00 WHSUR P WHDTRE PJSM. N/U TREE. 03:30 - 05:00 1.50 WHSUR P WHDTRE PJSM. PT TREE TO 5000 PSI / 5 MIN. GOOD TEST. 05:00 - 06:00 1.00 WHSUR P WHDTRE SECURE WELL AND CLEAN CELLAR. RIG RELEASED @ 06:00. Printed 12/12/2011 11:41:17AM • • ✓ 01 -11, Well History (Pre Rig Workover) Date Summary 06/13/11 INITIAL T /1 /O= 600/500/300 PSI. LRS PUMPED 5 BBL METH SPEAR, 250 BBL 1% KCL, 58 BBL 60/40 BEFORE RIH. 5.5" WRP SET AT 9708.4', TOP OF PLUG= 9706.4'. FINAL T /I /O= 470/500/300 PSI. 06/14/11 T /1 /O= 550/ 400/300 Pump 30 bbls meth down TBG, 15 bbls meth down IA to achieve a test pressure of 4000 Psi. 1st 15 min loss of 30 psi and 3 psi, 2nd 15 min loss of 13 psi and 3 psi, 3rd 15 min loss of 15 psi and 4 psi. Call PE, CMIT results are inconclusive. Bleed pressures back. Pumped 1.4 bbls crude down OA to achieve test pressure of 2000 psi, 1st 15 min loss of 98 psi, 2nd 15 min loss of 27 psi. MIT OA Passed, bleed pressure back. IA OA OTG FWHP= 500/200/250 06/16/11 T /I /0= 320/180/240 CMIT TxIA Failed to 1000 psi. First test T/I pressured up to 1000/1020 psi with 3.5 bbls diesel. T/I lost 360/50 psi in first 15 minutes. Second test - T/I pressured up to 1000/1020 psi with .8 bbls diesel. T/I lost 360/50 psi in first 15 minutes and 120/50 psi in second 15 minutes. For a total of 480/100 psi in 30 minutes. 06/17/11 CMIT TxIA Failed to 1000 psi. Third test T/I pressured up to 1000/1000 psi with 3.5 bbls diesel. T/I lost 180/40 psi in first 15 minutes and 160/40 psi in second 15 minutes. For a total of 340/80 psi in 30 minutes. Bled pressure down. FWHP's= 300/260/240 Operator notified of valve positions. 06/16/11 WELL SHUT IN ON ARRIVAL. JET CUT 5 1/2 TBG @ 9703' W/ 4.15 OD TBG CUTTER IN 1ST JOINT ABOVE WRP. FINAL T/I/0 750/550/225 JOB COMPLETE -- LEFT WELL S/I -- NOTIFIED DSO OF WELL STATUS. 07/02/11 Rig up. Pressure test surface equipment. Pump 10 bbls meth spear, verify TxIA communication. Pump 1006 bbls of 100 °F 1% KCL down tubing taking returns up IA and down 01 -18 flowline. Pump 67 bbls of 140 °F diesel down tubing for freeze protect. Freeze protect hard line with 11 bbls diesel. U -tube TxIA for 1 hr. Bleed well head psi. DSO notified of well condition upon departure. FWHP's= 0/0/0. 10/30/11 T /I /O= SSV /0 /0 Temp =Sl PPPOT-T (PASS) PPPOT -IC (PASS) (Pre RWO) PPPOT -T : RU 1 HP BT onto THA 0 bled to 0 psi. Pressured to 5000 psi for 30 minute test, 5000/ 15 min, 5000/ 30 min, bled void to 0 psi. RD test equipment re installed Alemite cap. Cycle and torque LDS "Standard" (1") all were in good working and visual condition. PPPOT -IC : RU 2 HP BT onto IC test void 0 bled to 0 psi. Flushed void until clean returns achieved, pressured to 3500 psi for 30 minute test, 3500/ 15 min, 3500/ 30 min. RD test equipment re installed Alemite cap. Cycle and torque LDS "Standard" (1") all were in good working and visual condition. Alignment pin's cycled with no problems. Page 1 of 1 TREE = 0 6 -3/8" OW WELLHEAD = GRAY 0 1 ...1 1 I SAFETY: ACTUATOR = BAKER C KB. ELEV = 73' I 1 BF. ELEV = KOP = 3200' 1 2206' H5 -1/2" HES X NIP, ID = 4.562" I Max Angle = 47° @ 6000' Datum MD = 10364' 2338' H 9 -5/8" FOC I Datum TV D = 8800' SS 2467' H 9 -5/8" FOC I 120" CONDUCTOR, 94 #, H -40, IS = 19.124" 1 80' 1 13 -3/8" CSG, 72 #, N -80 BTRS, ID = 12.347" H 2713' 9585' H5 -1/2" HES X NIP, ID = 4.562" I Minimum ID = 3.759" @ 9964' 4 -1/2" BKR R LANDING NIPPLE ►m• ►i∎ 9617' H 9-5/8" X 5-1/2" HES TNT PKR, ID= 4.791" 1 9653' H5 -1/2" HES X NIP, ID = 4.562" 1 9684' H5_1/2" HES XN NIP, ID = 4.455" I 1 5 -1/2" TBG, 17 #, L -80 TC-11, .0232 bpf, ID = 4.892" I--I 9701' 9701' H 5-1/2" WLEG, ID = 4.892" 1 9847' 1-1 BKR SCOOP HEAD GUIDE, ID = 5.625" I A 9894' 1 -19 -5/8" X 5 -1/2" BKR SAB PKR, ID = 3.875" I 1 5 -1/2" TBG -NPC, 17 #, N -80, .0232 bpf, ID = 4.892" H 9894' 4 -1/2" TBG -NPC, 12.6 #, N -80, --1 10024' 9923' 1- I 5 -1/2" X 4 -1/2" X0, ID = 3.958" 1 .0152 bpf, ID = 3.958" 1 9964' H4 -1/2" BKR "R" NIP, ID = 3.759" I PERFORATION SUMMARY REF LOG: BHCS ON 10/26/77 10024' H4 -1/2" WLEG, ID = 3.958" I ANGLE AT TOP PERF: 32° @ 10238' Note: Refer to Production DB for historical perf data 1 10020' H ELMD TT LOGGED ??/??/?? I SIZE SPF INTERVAL Opn /Sqz DATE 2 -7/8" 6 10238 - 10264 0 08/13/01 2 -7/8" 6 10270 - 10276 0 08/13/01 ' 10132' 1-19-5/8" MARKER JOINT I 2 -7/8" 6 10286 - 10320 0 08/13/01 ' 2 -7/8" 6 10330 - 10354 0 08/13/01 I, 3 -3/8" 4 10370 - 10380 0 06/14/94 3 -3/8" 4 10380 - 10394 S 01/14/94 3-3/8" 1 10420 10425 C 09/12/90 ' 1 ? ?? I--I -1/2" WRP BLOWN DOWN HOLE (11/06/10) I 3 -3/8" 1 10438 - 10440 C 09/12/90 NA 0 10450 - 10462 C 02/04/78 �.�.�.�. �.�.�.�.�.�. � 10395' 1-ITOP OF CEMENT (15') 1 3 -3/8" 4 10462 - 10472 C 06/04/93 IvA••∎•∎•• ■• ■■•AvA 3 -3/8" 4 10482 - 10495 S 11/13/89 3 -3/8" 4 10495 - 10513 S 06/05/94 3 -3/8" 4 10517 - 10520 S 11/13/89 I 3 -3/8" 4 10530 - 10535 S 11/13/89 3 -3/8" 4 10535 - 10545 S 06/05/94 3 -3/8" 4 10545 - 10555 S 11/13/89 3 -3/8" 4 10555 - 10570 S 06/26/93 1 10410' H TOP OF SAND (125') 1 3 -3/8" 4 10575 - 10585 S 06/26/93 3 -3/8" 4 10591 - 10601 S 06/26/93 1 10535' H PBTD I 19 -5/8" CSG, 47 #, N- 80/RS -95 BTRS, .0733 bpf, ID = 8.681" 10988' I: 1 TD H 11010 '�������������������� r, 1, DATE REV BY COMMENTS DATE REV BY COMMENTS PRUDHOE BAY UNIT 11/04/77 ROW 35 INITIAL COMPLETION WELL: 01 -11 '' 12/03/11 D16 RWO PERMIT No: F 1770570 ( 12/06/11 PJC DRLG DRAFT CORRECTION API No: 50- 029 - 20268 -00 I 12/08/11 SMMc/ PJCFINAL DRLG CORRECTIONS SEC 8, T10N, R15E, 889' FNL & 778' FWL BP Exploration (Alaska) • Page 1 of 1 Schwartz, Guy L (DOA) From: Bjork, David [David.Bjork @bp.com] Sent: Friday, September 30, 2011 10:16 AM To: Schwartz, Guy L (DOA) Subject: RE: PTD (177 -057) PBU 01 -111 sundry number 311 -171 scanned CBL log thanks! From: Schwartz, Guy L (DOA) [mailto:guy.schwartz @alaska.gov] Sent: Friday, September 30, 2011 10:13 AM To: Bjork, David Subject: RE: PTD (177 -057) PBU 01 -11i sundry number 311 -171 scanned CBL log Yes.. that is just fine. Very good looking bond below the tubing tail (can't even pick up the first arrival TT's!!) I don't see any reason to question the TOC based what I see on the log. A CBL during the workover will not be necessary. Guy Schwartz Senior Petroleum Engineer AOGCC 793 -1226 (office) `` 444 -3433 (cell) From: Bjork, David [mailto:David.Bjork @bp.com] Sent: Friday, September 30, 2011 10:00 AM To: Schwartz, Guy L (DOA) Subject: PTD (177 -057) PBU 01 -111 sundry number 311 -171 scanned CBL log Guy, Let me know if you think this will work. Regards, Dave 22 b From: bp [mailto:ancp 3@ p .com ] Sent: Friday, September 30, 2011 10:57 AM To: Bjork, David Subject: Attached Image 9/30/2011 COMPANY: BP EXPLORATION (ALASKA), INC , . Oil Der_isit Run 1 Run 2 Ru _ Water Salinity WELL: D.S. 1 - 11 itc Gas GraviV . . . •E 1/Bci FIELD: PRUDHOE BAY Bubble Point Pressure Bubble Point Temperature Solution GOR BOROUGH: NORTH SLOPE STATE: ALASKA maximum Devialion 48 deg _ — CEMENTING DATA 0 --:. CEMENT BOND LOG Primary/Squeeze Primary Casing String No _ 11) z j cr Schlumberier SSLT-GR Lead Cement Type — i < — — JULY Volume 28, 2001 ____ LL z Density _ o 0 w p 898' S & 772 E OF THE NW CORNER Elev.: K.B. 73 ft Water Loss 0 61 Additives _, Lu t- ,_ r , z AT SURFACE G.L. 34 ft co O " — ft 0 i i °t$ • a- D.F. 72 ft I— o co — a Tail Cement Type D E uj 0_ 0 Permanent Datum: MSL Elev.; 0 ft Volume 2 E $ 0 m 9 Log Measured From RKB 73.0 ft above Perm. Datum Density _ > 0 E c , Drilling Measured From: RKB Water Loss - D 0 ea 0 • • 1 . CX Additives -- _ cc 13 ' E API Serial No SECTION TOWNSHIP l RANGE 2 1 .§ i 8 50-029-20268-00 8 10N 15E Expected Cement Top ___ ___ 28-Jul-2001 _IN- glIg_i Date __Run Number 1 Run Number _ Depth Driller 10532 ft Depth Driller Schlumberger De_pth Schlumberger Depth - _ Bottom Log Interval 10285 ft Bottom Log Interval ___ To Log Interval 9670 ft Top Log Interval _ Casing Fluid Type KCL WATER Casing Fluid Type ___ — Salinity Salinity Density _ . Fluid Level Fluid Level BIT/CASING/TUBING STRING BIT/CASING/TUBING STRING __ _ _ Bit Size 12.250 in Bit Size From From _ To _ Casing/Tubing Size 9.625 In Casineubing Size _ _ Weight 47 Ibm/ft Weight Grade CASING Grade From ft From To 10988 ft To __ _ Maxim Recorded Temperatures 1 - MN Maximum RecordedTem_Reratures I __ Logger On Bottom I Time 28-Jul-2001 Logger On Boftom 1 Time Unit Number [ 2150 PRUDHOE BAY F Unit Number Location _ Recorded By S. DECKERT / M. LOPEZ _ Recorded By Witnessed By D. 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'a t Ti .1 ik 11111111111 X11111111111 11111111 :1 111111111111111111111111 111111111111 N 111111111111111111111111111111111111111111111111111111111111111111111111 11111111111111111111111111111111111 a 111111111111111 y 1111111111111111111111111111111111111111111111111111111111111111111111111111 1111111111111111111111111111111111 i 1111111111111111111111111111111111111111111111111111111111111111111111111111111111111111 1111111111111111111111111111111111111111111111111111111111111111111111111111111111111111111111111111111111111111 11111111111111111111111111111111111111111111111111111111111111111111111111111111111111111111111111111111111111111 11111111111111111111111111111111111111111111111111111111111111111111111111111111111111111111111111111111111111 11111 111111111111111111111111111111111111111111111111111111111111111111111111111111111111111111111111111111111111111 111 E 1 1111111111111111111111111111111111111111111111111111111111111111111111111111111111111111111111111111111111111 1111 111111111111111111111111111111111111111111111111111111111111111111111111111111111111111111111111111111111 U 1 111 Al2 $ o cc O T ` 111E11111111111111111111111111111111111111111111111111111111111111111111111111111111111111111111111111111111 111111111111111111111111111111111111111111111111111111111111111111111111111111111111111111111111111111111111111 111111111111111111111 11111 ! 1111111111111111111111111111111111111111111111111111111111111111111111111111111111111111111111111111 11111 11111111111111111111111111 1111111111111111111111111111111111111111111111111111111111111111111111111111111111111111 11111111 1151 i 11111111111111111111111111111111111111 11111111111111111111111111111111111111111111111 _.111111:11111111111111111111 � 111111111111111111111111111111111111111111111111111111111111111111 111 91111111111111111111111111111111 :11:11111 / 11111111111111111111111111111111111111111111111111111111111111111111111111111111111 \ /Rr' 111111`■ 11111111111111111111111111111111111111111111111 1111111111111111111111111111111111111111111111111111111111 11411111111111iiiiiiiii111 iiiiliiiiiiiiii1111111111111i1111111111111111111111111111111111111111111111111111111111111111 ' 1 01111111111 11:1111111!11111111191111111111 1141119111 11111111! 111111111111111111111111111111111111111111111 111111/ 11111111111111111111111111111111111111111111111111111111111a111111111111111111111111111111111111111111111111111111111111111111111111 Page 1 of 3 Schwartz, Guy L (DOA) From: Bjork, David [David.Bjork @bp.com] Sent: Thursday, September 29, 2011 4:21 PM To: Schwartz, Guy L (DOA) Subject: RE: PTD (177 -057) PBU 01 -11i sundry number 311 -171 Guy. I am working on getting the log copied. Unfortunately it is not stored electronically. The calculated TOC is 9,210ft, there were full returns during the cement job. The log was stopped at the original packer tail depth of 10,020. We are setting a new packer at - 9,674ft. thanks, Dave From: Schwartz, Guy L (DOA) [ mailto:guy.schwartz @ alaska.gov] Sent: Thursday, September 29, 2011 3:55 PM To: Bjork, David Subject: RE: PTD (177 -057) PBU 01 -11i sundry number 311 -171 Sounds good... can I get a copy of the log too? Or a scan of the area in question is good too. I concur with you as long as the primary cement job went as planned and TOC is well above the new packer depth. Guy Schwartz Senior Petroleum Engineer AOGCC„� 793 -1226 (office) ! r t 444 -3433 (cell) From: Bjork, David [mailto:David.Bjork @bp.com] Sent: Thursday, September 29, 2011 3:48 PM To: Schwartz, Guy L (DOA) Subject: PTD (177 -057) PBU 01 -11i sundry number 311 -171 Guy, I have located a CBL from this well that was ran on July 28th,2011 before the conversion to an injector. It was logged thru the 5 -1/2" tubing and appears to have good cement between 10,285 and 10,015 where they reached the tubing tail. If this log is acceptable I would like to forgo the USIT log we planned on running after removing the tubing during the RWO. Please call if you have questions. Regards, Dave Bjork 564 -5683 From: Schwartz, Guy L (DOA) [mailto:guy.schwartz @alaska.gov] Sent: Thursday, May 19, 2011 1:57 PM To: Bjork, David Cc: Reem, David C 9/29/2011 Page 2 of 3 • • Subject: RE: PTD (177 -057) PBU 01 -11i OK that makes sense ... thanks and good luck. Guy Schwartz Senior Petroleum Engineer AOGCC 793 -1226 (office) 444 -3433 (cell) From: Bjork, David [mailto:David.Bjork @ bp.com] Sent: Thursday, May 19, 2011 12:48 PM To: Schwartz, Guy L (DOA) Cc: Reem, David C Subject: RE: PTD (177 -057) PBU 01 -11i We will more than likely leave the tubing spool. If an upgrade is required we will set a second mechanical barrier like a storm packer, before ND. Regards, Dave From: Schwartz, Guy L (DOA) [ mailto:guy.schwartz @alaska.gov] Sent: Thursday, May 19, 2011 11:11 AM To: Bjork, David Cc: Hubble, Terrie L; Stewman, Sondra D; Barker, Elizabeth R (SAIC); Reem, David C Subject: RE: PTD (177 -057) PBU 01 -11i Dave, Thanks for the updated procedure. I think it's prudent to verify the cement top and quality in the casing since the packer is moving uphole even more from the original completion. This well never had a CBL run when it was completed as a producer. I noticed one other detail on the procedure.... Is the WRP the only mechanical barrier (+ KWF) when you swap the tubing spool out ?? You normally have two barriers. Guy Schwartz Senior Petroleum Engineer AOGCC 793 -1226 (office) 444 -3433 (cell) From: Bjork, David [mailto:David.Bjork @bp.com] Sent: Thursday, May 19, 2011 10:59 AM To: Schwartz, Guy L (DOA) Cc: Hubble, Terrie L; Stewman, Sondra D; Barker, Elizabeth R (SAIC); Reem, David C Subject: PTD (177 -057) PBU 01 -11i Guy, As we discussed, please update the application for sundry approval with the revised scope of work. I would also like to request a variance from, 20 AAC 25.412b. I would like to set the new production packer at 9,674ft MD which is 564ft MD above the upper most injection perforation. 9/29/2011 Page 3 of 3 • Please feel free to call me if you have any questions or concerns. Regards, Dave Bjork 564 -5683 20 AAC 25.412. Casing, cementing, and tubing of injection wells for enhanced recovery, disposal, and storage (b) A well used for injection must be equipped with tubing and a packer, or with other equipment that isolates pressure to the injection interval, unless the commission approves the operator's use of alternate means to ensure that injection of fluid is limited to the injection zone. The minimum burst pressure of the tubing must exceed the maximum surface injection pressure by at least 25 percent. The packer must be placed within 200 feet measured depth above the top of the perforations, unless the commission approves a different placement depth as the commission considers appropriate given the thickness and depth of the confining zone. 9/29/2011 • • 1 SEAN PARNELL, GOVERNOR ALASKA OIL AND GAS 333 W. 7th AVENUE, SUITE 100 CONSERVATION COM1IIISSION ANCHORAGE, ALASKA 99501 -3539 PHONE (907) 279 -1433 FAX (907) 276 -7542 David Reem Engineering Team Leader 0S7 BP Exploration (Alaska), Inc. P.O. Box 196612 'tdoiNE,0 MAY 2 0 201 Anchorage, AK 99519 -6612 Re: Prudhoe Bay Field, Prudhoe Bay Oil Pool, PBU 01 -11 Sundry Number: 311 -171 Dear Mr.Reem: 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 Commission grants for good cause shown, a person affected by it may file with the Commission 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, Daniel T. Seamount, Jr. Chair „- DATED this 4( day of May, 2011. Encl. STATE OF ALASKA , , t\ ALASKA AND GAS CONSERVATION COMMISSIW RECEIVED 5 APPLICATION FOR SUNDRY APPROVAL MAY 1 2 1-01' S 20 AAC 25.280 1 _ Type of Request Atom & Gas Cabe. it u1SM�f ❑ Abandon ❑ Plug for Redrill ❑ Perforate New Pool - ® Repair Well ❑ Change Approved ProgrV"n h ` " ❑ Suspend ❑ Plug Perforations ❑ Perforate , ® Pull Tubing ❑ Time Extension I ❑ Operations Shutdown ❑ Re -Enter Suspended Well ❑ Stimulate ❑ Alter Casing ❑ Other 2. Operator Name: 4. Current Well Class: 5. Permit To Drill Number BP Exploration (Alaska) Inc ❑ Development ❑ Exploratory 177 3. Address: 6_ API Number P.O. Box 196612, Anchorage, Alaska 99519 - 6612 ®Service ❑ Stratigraphic 50 20268 - 0000 - 7. If perforating, closest approach in pools) opened by this operation to nearest 8. Well Name and Number: property line where ownership or landownership changes: PBU 01-11 - Spacing Exception Required? ❑ Yes ® No 9. Property Designation: 10. Field / Pool(s): ADL 028329- Prudhoe Bay Field / Prudhoe Bay Oil Pool 11. PRESENT WELL CONDITION SUMMARY Total Depth MD (ft): Total Depth ND (ft): Effective Depth MD (ft): Effective Depth TVD (ft): Plugs (measured): Junk (measured): 11010' - 9434' - 10395' 8900' 10395' Yes, Unknown Depth Casing Length Size MD TVD Burst Collapse Structural Conductor 120' 20" 120' 120' 1530 520 Surface 2713' 13 -3/8" 2713' 2713' 4930 2670 Intermediate Production 10988' 9 10988' 9414' 6870 4760 Liner Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): 10238' - 10380' 8765' - 8887' 5 - 1/2", 17# x 4 - 1/2 ", 12.6# N 10024' Packers and SSSV Type: 9-5/8" x 5-1/2" Baker 'SAW packer Packers and SSSV 9894' / 8471' MD (ft) and TVD (ft): 12. Attachments: 13. Well Class after proposed work: IN Description Summary of Proposal 0 BOP Sketch ❑ Exploratory ❑ Development - ® Service ❑ Detailed Operations Program 14. Estimated Date for 15. Well Status after proposed work: Commencing Operations: June 1, 2011 ❑ Oil ® WINJ - ❑ WDSPL ❑ Plugged 16. Verbal Approval: Date: ❑ Gas ❑ GINJ ❑ GSTOR ❑ Abandoned Commission Representative: ❑ WAG ❑ SPLUG ❑ Suspended 17_ I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact David Biork, 564 -5683 Printed Name David Reem Title Engineering Team Leader . Prepared By NameRiumber Signature Phone 564 -5743 Date 5 /// /ZZ,/ Term Hubble, 564-4628 Commission Use Only Conditions of approval: Notify Commission so that a representative may witness ' —' 1 1 .�.,/ Sundry Number ❑ Plug Integrity ❑ BOP Test 170 Mechanical Integrity Test ❑ Location Clearance .1 L(Oov /3 2. 5d!° lest Other l�r l eS f (,.,2i n ?Z,SDO rSL ,r �I �f�, -n r�6 /p l6ic � q,,pp(Okf' �-L. z0 }' '' Z. y/ z. s J Subsequent Form Required: i u •- -7 ( t APPROVED BY /�� / 1 Approved By: �� , COMMISSIONER THE COMMISSION Date 5 Form 10-403 Rev-- -= S S MAY �'� S . / � // Submit In Duplicate 0 R f G f NA L 4,,r6 • • �bp 01 -1 1 i Expense Rig Workover Scope of Work: Pull 5 -'h" L -80 completion, Replace Casing Pack -offs and Tubing Spool, run 5 -1/2" L -80 completion. MASP: 2,381 -psi Well Type: Injector Estimated Start Date: June 1, 2011 Production Engineer: Bernhard Stechauner Intervention Engineer: David Bjork Pre -Ria Work Request: F 1 Fluid -pack wellbore and CMIT TxIA to 4,000 psi, MIT -OA to 2,000psi record LLR as necessary. If CMIT TxIA leaks we may have to re- secure the well. E 2 Power Jet cut 5 -1/2" L -80 tubing in the middle of the first full joint above the WRP at 9,737ft. F 3 Post cut CMIT -TxIA to 500 -psi. Circulate well with 8.6ppg seawater and freeze protect to 2000'. W 4 Check the tubing hanger lock down screws for free movement. Completely back out and check each lock down screw for breakage (check one at a time). PPPOT -T & IC. W 5 Set a BPV in the tubing hanger. O 6 Remove the wellhouse & flow line. Level the pad as needed for the rig. Proposed Procedure 1. MIRU. ND tree. NU 3 Preventer BOPE with annular, blind / shears, mud cross and 3 -1" x 6" VBR pipe rams. Pressure test Blind Rams and VBR's to 4,000 -psi, Annular to 3,500 -psi. 2. Circulate out freeze protection fluid and circulate well to clean seawater through the cut. 3. Pull and LD 5 - tubing string to the cut. 4. 4. Change 9 casing packoff and tubing spool. 5. RIH and recover the tubing stub. Scrape the casing and LDDP 6. Rig up SLB E -Line and run USIT log to verify top of cement. 7. Run 5 -1' L -80 completion with HES TNT packer. Position packer at -9,674' MD. 8. Displace the IA to packer fluid and freeze protect to 2,000' MD. 9. Set the Packer, test tubing and IA to 4,000 -psi. 10. Set BPV. ND BOPE. NU and test tree. RDMO. Post -da work: S 1 Pull Ball -n -Rod, pull RHC seat F 2 Post RWO AOGCC MIT -IA TREE= GRAY • ( SAFETY Me: I WELLHEAD= GRAY ACTUATOR = AXELSON 0 1 - 11 KB. ELEV = 73' BF.ELEV= I KOP = 3200' Max Angle = 48 © 6200' I 2208' 1-15-1/2" BKR PFV E SSSV NIP, ID = 4.562" I Datum MD = 10364' • Datum TVD = 8800' SS — —'I 2337' H 9 -5/8" FOC I 120" CONDUCTOR, 94 #, 1-1-40, IS = 19.124" I 80' - --I 2467' H9-5/8" FOC I 13 -3/8" CSG, 72 #, N-80 BTRS, ID = 12.347" H 2713' I I Minimum ID = 3.759" @ 9964' I 9737' I -15 -1/2" WRP (11/11/10) I ✓ 4 -1/2" BKR R LANDING NIPPLE I 9752' H5-1/2" BKR SLD SLV, 0 = 4.43" I II I 9812' H5-1/2" BKR R LANDING NIP, ID = 4.313" I 5-1/2" TBG NPC, 17 #, N-80, .0232 bpf, ID = 4.892" I J I 9894' I .. OM 9894' 1-19-5/8" X 5-1/2" BKR SAB PKR, ID = 3.875" I 9923' I- I5 -1/2" X 4 -1/2" XO, ID = 3.958" I • 11 964' H4 -1/2" BKR R LANDING NIP, ID = 3.759" I 4 -1/2" TBG -NPC, 12.6#, N-80, -i 10024' .0152 bpf, ID = 3.958" ■ 10024' H4_1/2" TUBING TAIL, ID = 3.958" I PERFORATION SUMMARY REF LOG: BHCS ON 10/26/77 I 10020' HELMD TT LOGGED DATE UNKNOWN? I ANGLE AT TOP PERF: 32 @ 10238' 10132' I -J9 -5/8" MARKER JOINT I Note: Refer to Production DB for historical pert data SIZE SPF INTERVAL Opn /Sqz DATE 2 -7/8" 6 10238 - 10264 0 08/13/01 ' 2 -7/8" 6 10270 - 10276 0 08/13/01 2 -7/8" 6 10286 - 10320 0 08/13/01 2 -7/8" 6 10330 - 10354 0 08/13/01 I 3 -3/8" 4 10370 - 10380 0 06/14/94 3 -3/8" 4 10380 - 10394 S 01 /14/94 3 -3/8" 1 10420 - 10425 C 09/12/90 R ' I ? ?? 1— I4 -1/2" WRP BLOWN DOWN HOLE (11/06/10) I 3 -3/8" 1 10438 - 10440 C 09/12/90 NA 0 10450 - 10462 C 02/04/78 ........vow 10395' I_J TOP OF CEMENT (15') I 3 -3/8" 4 10462 - 10472 C 06/04/93 . ...,MAWAtt 3 -3/8" 4 10482 - 10495 S 11/13/89 3 -3/8" 4 10495 - 10513 S 06/05/94 3 -3/8" 4 10517 - 10520 S 11/13/89 3 -3/8" 4 10530 - 10535 S 11/13/89 3 -3/8" 4 10535 - 10545 S 06/05/94 3 -3/8" 4 10545 - 10555 S 11/13/89 3 -3/8" 4 10555 - 10570 S 06/26/93 I 10410' H TOP OF SAND (125') I 3 -3/8" 4 10575 - 10585 S 06/26/93 3 -3/8" 4 10591 - 10601 S 06/26/93 I 10535' H PBTD I 1 9-5/8" CSG, 47 #, N- 80/RS -95, .0733 bpf, ID = 8.681" H 10988' , ,1,1 , 1 , 1,,,, , ,, t I TD 1-1 11010• .. ...* *.1� .. ..1 ..1 ....�1�.. ..141 DATE REV BY COMMENTS DATE REV BY COMMENTS PRUDHOE BAY UNIT ROW 35 ORIGINAL COMPLETION 08/26/10 MV /PJC SET WRP (07/14/10) WELL: 01 -11 08/13/01 ATD/TP ADD CMT / SAND DEPTHS 11/18/10 TAR/PJC SET WRP/ WRP BLOWN DH (11/11 1) PERMIT No: 1770570 08/13/01 ? /KAK ADPERFS API No: 50- 029 - 20268 -00 12/07/08 WK/SV CSG CORRECTIONS SEC 8, T10N, R15E, 1381.51' FEL & 4248.53' FNL 01/31/10 OPC/PJC SET WRP (01/12/10) 07/28/10 GTW /PJC PULL WRP (07/14/10) BP Exploration (Alaska) TREE= GRAY • 0 1_ 1 1 SAFETY NC I WEL LHEAD= GRAY ACTUATOR = AXELSON RWO Proposed KB. ELEV = 73' BF. ELEV = I KOP = 3200' Max Angle = 48 @ 6200' 2,200' H5-1/2" OTIS 'X' NIPPLE ID = 4.562" Datum MD = 10364' I Datum TV D = 8800' SS — I 2337' H9_5/8" FOC 20" CONDUCTOR, 94 #, H-40, IS = 19.124" I 80' --I 2467' H9-5/8" FOC I 13 -3/8" CSG, 72 #, N -80 BTRS, ID = 12.347" I--I 2713' I , Minimum ID = 3.759" @ 9964' 4 -1/2" BKR R LANDING NIPPLE 5 -1/2" TBG, 17 #, L -80, TC-II .0232 bpf, ID = 4.892"H 9,674' I 9,643' I -1/2" OTIS'X' NIPPLE ID= 4.562" I r pq -- I 9,674' I -19 -5/8" x 5 -1/2" HES TNT Packer I I 9,708' H5 -1/2" OTIS'X' NIPPLE ID= 4.562" I 9,780' H5 -1/2" OTIS'XN' NIPPLE ID = 4.455" I 4 -1/2" TBG -NPC, 12.6 #, N -80, H 10024' ∎�� IMt 9894' 1-19-5/8" X 5 -1/2" BKR SAB PKR, ID= 3.875" I .0152 bpf, ID = 3.958" 9923' 1-15-1/2" X 4 -1/2" XO, ID = 3.958" I PERFORATION SUMMARY 9964' H4 -1/2" BKR R LANDING NIP, ID = 3.759" REF LOG: BHCS ON 10/26/77 ANGLE AT TOP PERF: 32 © 10238' 10024' H4-1/2" TUBING TAIL, ID = 3.958" I Note: Refer to Production DB for historical perf data SIZE SPF INTERVAL Opn /Sqz DATE 4-.-- 10132' I- I9 -5/8" MARKER JOINT I 2-7/8" 6 10238 - 10264 0 08/13/01 ' SOP Per C t o 238 , 2 -7/8" 6 10270 - 10276 0 08/13/01 I 2 -7/8" 6 10286 - 10320 0 08/13/01 2 -7/8" 6 10330 - 10354 0 08/13/01 I 3 -3/8" 4 10370 - 10380 0 06/14/94 3 -3/8" 4 10380 - 10394 S 01/14/94 3 -3/8" 1 10420 - 10425 C 09/12/90 ' ? ?? I -14 -1 /2" WRP BLOWN DOWN HOLE (11/06/10) I 3 -3/8" 1 10438 - 10440 C 09/12/90 NA 0 10450 - 10462 C 02/04/78 ,• 10395' IHTOP OF CEMENT (15') I 3 -3/8" 4 10462 - 10472 C 06/04/93 i •∎i•••••• ∎••• ∎••• ∎i 3 -3/8" 4 10482 - 10495 S 11/13/89 3 -3/8" 4 10495 - 10513 S 06/05/94 3 -3/8" 4 10517 - 10520 S 11/13/89 3 -3/8" 4 10530 - 10535 S 11/13/89 3 -3/8" 4 10535 - 10545 S 06/05/94 3 -3/8" 4 10545 - 10555 S 11/13/89 3 -3/8" 4 10555 - 10570 S 06/26/93 10410' IHTOP OF SAND (125') I 3 -3/8" 4 10575 - 10585 S 06/26/93 3 -3/8" 4 10591 - 10601 S 06/26/93 I 10535' H PBTD I 9 -5/8" CSG, 47 #, N- 80/RS -95, .0733 bpf, ID = 8.681" I—I 10988' Plivtf,t't'f't • TD IH 11010' ,�����������������' A DATE REV BY COMMENTS DATE REV BY COMMENTS PRUDHOE BAY UNIT ROW 35 ORIGINAL COMPLETION 08/26/10 MV /PJC SET WRP (07/14/10) WELL: 01 -11 08/13/01 ATD/TP ADD CMT / SAND DEPTHS 11/18/10 TAR/PJC SET WRP/ WRP BLOWN DH (11/11 1) PERMIT No: 1770570 08/13/01 ? /KAK ADPERFS API No: 50- 029- 20268 -00 12/07/08 WK /SV CSG CORRECTIONS SEC 8, T10N, R15E, 1381.51' FEL & 4248.53' FNL 01/31/10 OPC /PJC SET WRP (01/12/10) 07/28/10 GTW /PJC PULL WRP (07/14/10) BP Exploration (Alaska) • . Page 1 of 2 Schwartz, Guy L (DOA) From: Schwartz, Guy L (DOA) Sent: Thursday, May 19, 2011 1:57 PM To: 'Bjork, David' Cc: Reem, David C Subject: RE: PTD (177 -057) PBU 01 -11i OK that makes sense ... thanks and good luck. Guy Schwartz Senior Petroleum Engineer AOGCC 793 -1226 (office) 444 -3433 (cell) From: Bjork, David [mailto:David.Bjork @ bp.com] Sent: Thursday, May 19, 2011 12:48 PM To: Schwartz, Guy L (DOA) Cc: Reem, David C Subject: RE: PTD (177 -057) PBU 01 -11i We will more than likely leave the tubing spool. If an upgrade is required we will set a second mechanical barrier like a storm packer, before ND. Regards, Dave From: Schwartz, Guy L (DOA) [mailto:guy.schwartz @alaska.gov] Sent: Thursday, May 19, 2011 11:11 AM To: Bjork, David Cc: Hubble, Terrie L; Stewman, Sondra D; Barker, Elizabeth R (SAIC); Reem, David C Subject: RE: PTD (177 -057) PBU 01 -11i Dave, Thanks for the updated procedure. I think it's prudent to verify the cement top and quality in the casing since the packer is moving uphole even more from the original completion. This well never had a CBL run when it was completed as a producer. I noticed one other detail on the procedure.... Is the WRP the only mechanical barrier (+ KWF) when you swap the tubing spool out ?? You normally have two barriers. Guy Schwartz Senior Petroleum Engineer AOGCC 793 -1226 (office) 444 -3433 (cell) From: Bjork, David [mailto:David.Bjork @bp.com] Sent: Thursday, May 19, 2011 10:59 AM To: Schwartz, Guy L (DOA) 5/19/2011 Page 2 of 2 1 110 • Cc: Hubble, Terrie L; Stewman, Sondra D; Barker, Elizabeth R (SAIC); Reem, David C Subject: PTD (177 -057) PBU 01 -11i Guy, As we discussed, please update the application for sundry approval with the revised scope of work. I would also like to request a variance from, 20 AAC 25.412b. I would like to set the new production packer at 9,674ft MD which is 564ft MD above the upper most injection perforation. Please feel free to call me if you have any questions or concerns. Regards, Dave Bjork 564 -5683 20 _ AAC _ 25.412. Casing, cementing, and tubing of injection wells for enhanced recovery, disposal, and storage (b) A well used for injection must be equipped with tubing and a packer, or with other equipment that isolates pressure to the injection interval, unless the commission approves the operator's use of alternate means to ensure that injection of fluid is limited to the injection zone. The minimum burst pressure of the tubing must exceed the maximum surface injection pressure by at least 25 percent. The packer must be placed within 200 feet measured depth above the top of the perforations, unless the commission approves a different placement depth as the commission considers appropriate given the thickness and depth of the confining zone. 5/19/2011 • • �b GP ) . _ ff./ ,9 1St' 01-11i Expense Rig Workover Scope of Work: Pull 5 -1/2` L -80 completion, Replace Casing Pack -offs and Tubing Spool, run 5 -1/2" L -80 completion. MASP: 2,381 -psi Well Type: Injector Estimated Start Date: June 1, 2011 Production Engineer: Bernhard Stechauner Intervention Engineer: David Bjork Pre -Rig Work Request: F 1 Fluid -pack wellbore and CMIT TxIA to 4,000 psi, MIT -OA to 2,000psi record LLR as necessary. If CMIT TxIA Teaks we may have to re- secure the well. E 2 Power Jet cut 5-1/2" L -80 tubing in the middle of the first full joint above the WRP at 9,737ft. F 3 Post cut CMIT -TxIA to 500 -psi. Circulate well with 8.6ppg seawater and freeze protect to 2000'. W 4 Check the tubing hanger lock down screws for free movement. Completely back out and check each lock down screw for breakage (check one at a time). PPPOT -T & IC. W 5 Set a BPV in the tubing hanger. O 6 Remove the wellhouse & flow line. Level the pad as needed for the rig. Proposed Procedure 1. MIRU. ND tree. NU 3 Preventer BOPE with annular, blind / shears, mud cross and 3 -1/2" x 6" VBR pipe rams. Pressure test Blind Rams and VBR's to 4,000 -psi, Annular to 3,500 -psi. 2. Circulate out freeze protection fluid and circulate well to clean seawater through the cut. 3. Pull and LD 5 -1/2' tubing string to the cut. 4. Change 9- casing packoff and tubing spool. 5. RIH and recover the tubing stub. Scrape the casing and LDDP 6. Rig up SLB E -Line and run USIT log to verify top of cement. 7. Run 5 - L -80 completion with HES TNT packer. Position packer at 9,674' MD. 8. Displace the IA to packer fluid and freeze protect to 2,000' MD. 9. Set the Packer, test tubing and IA to 4,000 -psi. 10. Set BPV. ND BOPE. NU and test tree. RDMO. Post -rig work: S 1 Pull Ball -n -Rod, pull RHC seat F 2 Post RWO AOGCC MIT -IA E 0 ALASKA SEAN PARNELL, GOVERNOR AJA►7KA OIL AND GALS333 W. 7th AVENUE, SUITE 100 M CONSERVATION COUSSION ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907)276-7542 Bernhard Stechauner Petroleum Engineer C /-7 BP Exploration (Alaska), Inc. ! �'f �-- 47 P.O. Box 196612 ! // Anchorage, AK 99519-6612 Re: Prudhoe Bay Field, Prudhoe Bay Oil Pool, PBU 01-11 Sundry Number: 310-304 Dear Mr. Stechauner: 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 Commission grants for good cause shown, a person affected by it may file with the Commission 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, Daniel T. Seamount, Jr. Chair DATED this 1.5 day of September, 2010. Encl. / C� /(.v A i19 STATE OF ALASKA • "A q', ALASKOIL AND GAS CONSERVATION COMMISSION 9�� APPLICATION FOR SUNDRY APPROVALS 90 AAc 95 9R0 1. Type of Request: Abandon ❑ Plug for Redrill ❑ Perforate New Pool ❑ Repair Well ❑ Change Approved Program ❑ Suspend ❑ Plug Perforations ❑ Perforate ❑ Pull Tubing ❑ Time Extension ❑ Operation Shutdown ❑ Re-enter Susp. Well ❑ Stimulate❑ Alter Casing ❑ -121 Other: seal-tite 2. Operator Name: 4. Current Well Class: 5. Permit to Drill Number: BP Exploration (Alaska), Inc. Development ❑ Exploratory ❑ Stratigraphic ❑ Service Q 177-0570 ' 3. Address: P.O. Box 196612 6. API Number: Anchorage, AK 99519-6612 50-029-20268-00-00 7. If perforating, closest approach in pool(s) opened by this operation to nearest 8. Well Name and Number: property line where ownership or landownership changes: Spacing Exception Required? Yes ❑ No ❑ PBU 01-11 9. Property Designation (Lease Number): 10. Field/Pool(s): ADLO-028329' PRUDHOE BAY Field / PRUDHOE BAY Pool 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): 11010 9433.61 10395 9000 10395 TOC 9945 01-12-2010 NONE Casing Length Size MD TVD Burst Collapse Structural Conductor 120 20" 94# H-40 SURFACE 120 SURFACE 120 1530 520 Surface 2640 13-3/8" 72# N-80 SURFACE 2713 SURFACE 2713 4930 2670 Intermediate Production 10915 9-5/V'47# N-80 SURFACE 10988 SURFACE 9414 6870 4760 Liner Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): SEE ATTACHED - - 5-1/2" 17# N-80 28 9923 - - 4-1/2" 12.6# N-80 9923 10024 Packers and SSSV TVDe: 5-1/2" Baker SAB Packer Packers and SSSV MD and TVD (ft): 9894 8471 12. Attachments: Description Summary of Proposal P] 13. Well Class after proposed work: Detailed Operations Program ❑ BOP Sketch ❑ Exploratory ❑ Development ❑ Service 2 - 14. Estimated Date for 15. Well Status after proposed work: Commencing Operations: 9/21/2010 Oil ❑ Gas ❑ WDSPL ❑ Suspended ❑ WINJ ❑✓ GINJ ❑ WAG ❑ Abandoned ❑ 16. Verbal Approval: Date: Commission Representative: GSTOR ❑ SPLUG ❑ 17. 1 hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Bernhard Stechauner Printed Name Bernhard Stechauner Title PE Signature Date �Phone 907-564-4594 9/13/2010 Prepared by Gary Preble 564-4944 COMMISSION USE ONLY Sundry Number: Conditions of approval: Notify Commission so that a representative may witness Plug Integrity ❑ BOP Test ❑ Mechanical Integrity Test Location Clearance ❑ Other: f, VE Subsequent Form Required: !( APPROVED BY Approved by: E2 rjOMM'SS'ONER THE COMMISSION Date: 3,/c) ....y�wv err 1''7`4 R I G I N A L� Y/ Yi-n Form 10-403 Revised 1/2010 Submit in Duplicate B 0 01-11 177-057 PERF ATTACHMENT Sw Name Operation Date Perf Operation Code Meas Depth Top Meas Depth Base Tvd Depth Top Tvd Depth Base 01-11 2/4/78 PER 10,450. 10,470. 8,947.36 8,964.51 01-11 2/4/78 PER 10,482. 10,520. 8,974.78 9,007.22 01-11 2/4/78 PER 10,530. 10,570. 9,015.77 9,050.06 01-11 7/11/87 APF 10,575. 10,585. 9,054.35 9,062.95 01-11 7/11/87 APF 10,591. 10,601. 9,068.11 9,076.73 01-11 11/13/89 SQZ 10,450. 10,601. 8,947.36 9,076.73 01-11 11/27/89 RPF 10,575. 10,585. 9,054.35 9,062.95 01-11 11/27/89 RPF 10,591. 10,601. 9,068.11 9,076.73 01-11 11/27/89 RPF 10,555. 10,570. 9,037.18 9,050.06 01-11 9/12/90 APF 10,420. 10,425. 8,921.55 8,925.86 01-11 9/12/90 APF 10,438. 10,440. 8,937.05 8,938.77 01-11 8/7/92 RPF 10,505. 10,517. 8,994.41 9,004.66 01-11 1/24/93 RPF 10,535. 10,545. 9,020.05 9,028.61 01-11 2/7/93 APF 10,470. 10,472. 8,964.51 8,966.22 01-11 2/7/93 RPF 10,462. 10,470. 8,957.66 8,964.51 01-11 3/6/93 RPF 10,495. 10,505. 8,985.88 8,994.41 01-11 5/26/93 SQZ 10,420. 10,601. 8,921.55 9,076.73 01-11 6/4/93 RPF 10,535. 10,545. 9,020.05 9,028.61 01-11 6/4/93 RPF 10,462. 10,472. 8,957.66 8,966.22 01-11 6/4/93 RPF 10,495. 10,517. 8,985.88 9,004.66 01-11 1/14/94 APF 10,376. 10,394. 8,883.55 8,899.09 01-11 6/5/94 SQZ 10,376. 10,601. 8,883.55 9,076.73 01-11 6/14/94 APF 10,370. 10,376. 8,878.38 8,883.55 01-11 6/14/94 RPF 10,376. 10,380. 8,883.55 8,887. 01-11 7/22/95 SQZ 10,370. 10,486. 8,878.38 8,978.2 01-11 9/2/95 RPF 10,370. 10,380. 8,878.38 8,887. 01-11 8/2/01 SPS 10,417. 10,529. 8,918.96 9,014.91 01-11 8/3/01 SQZ 10,395. 10,417. 8,899.95 8,918.96 01-11 8/13/01 APF 10,258. 10,264. 8,782.45 8,787.57 01-11 8/13/01 APF 10,270. 10,276. 8,792.68 8,797.8 01-11 8/13/01 APF 10,286. 10,306. 8,806.34 8,823.43 01-11 8/13/01 APF 10,306. 10,320. 8,823.43 8,835.42 01-11 8/13/01 APF 10,330. 10,354. 8,843.99 8,864.61 01-11 8/14/01 APF 10,238. 10,258. 8,765.43 8,782.45 01-11 12/24/01 FIL 10,392. 10,420. 8,897.36 8,921.55 01-11 1/12/10 BPS 10,394. 10,420. 8,899.09 8,921.55 AB ABANDONED PER PERF APF ADD PERF RPF REPERF BPP BRIDGE PLUG PULLED SL SLOTTED LINER BPS BRIDGE PLUG SET SPR SAND PLUG REMOVED FCO FILL CLEAN OUT SPS SAND PLUG SET FIL FILL I 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 • Date: September 9, 2010 To: C.Olsen/T.Norene, AK D&C Well Services Operations Team Lead J.Bixby/R.Liddelow, AK D&C Wireline Ops Team Leads From: Mehreen Vazir & Tiffany Quy Projects Well Integrity Engineer (659-5098, Harm #2418) Subject: 01-11 SealTite TxIA Repair Est. Cost: $120M AFE: APBD01 WL11 IOR: 200 Step Type Procedure 1 W Pump Seal-Tite; MIT -IA to 3000 psi, LLR if Fails. 2 S Pull WRP from 9945' to POI 4 DP AOGCC MIT -IA to 2500 psi (on line) Objective: This procedure is to repair IAxT communication at the production packer using Seal-Tite. S—e—a7ite Flo -Seal will be injected into the IA and allowed to tall to the production pacKer. Once the sealant is cured, the WRP will be pulled to put the well on injection. Once on line, an AOGCC MIT -IA will be performed and the well reclassified pending the MIT -IA results. Well Information: Current Status: IA Last Injection Rate Deviation: Min ID: Last DH operation: Last SBHPS: map SSSV: Last H2S: SWI — Secured with a WRP and Not Operable due to failed MIT - 10132 bwpd @ 437 psi & 54°F 47.50 @ 6200' M D 3.759" @ 9964'— Baker R -landing nipple WRP Diagnostics LDL 07/21/10 3261 psi @ 8800' TVD 08/21/05 or 3211-3264 psi from 2008 BHP No 03/28/01 @ 10 ppm. Injector — DSO is an H2S site Well Events Summary: Well 01-11 is a SWI classified as Not Operable. It is completed with the original 5.5" N-80 tubing from 11/04/77. This well provides the main injection support for 12-29 & 12-28 which are both lifted producers on the RWO schedule. Well 01-11 has a history of IAxOA communication manageable by bleeds and had AOGCC Administrative Approval to operate until a MIT -IA Failed 12/29/09. A PPPOT-T &-IC both passed 08/05/10 indicating there is no communication across the well head. A caliper run 09/09/10 indicates the tubing is in reasonable condition with the majority of the corrosion above 1500'. 0 r A TecWel LDL was performed on 03/04/10. Despite records of IAxOA communication, a tubing pressure response was seen when pumping down the IA with no OAP response. A second TecWel LDL was performed on 07/20/10. The leak at 18' did not repeat, however a temperature shift was again seen in the same region above the production packer at 9894' MD. A WRP was set below the packer 07/14/10. A CMIT-TxIA and MIT -T both passed to 3000 psi 08/16/10. A MIT -IA failed to 2500 psi. A IAxT LLR was established as 0.64 gpm @ 2640 psi for 38.5 gal. The passing MIT -Ts and CMIT-TxIA's indicate the plug and production casing have integrity and the packer has integrity to the formation. Based on the repeated temperature response in the LDLs, the leak is believed to be a one way IAxT leak at the production packer causing the MIT -IA's to fail. > 06/07/06: MIT -OA passed to 3000 psi > 12/18/06: AA request approved > 05/07/07: MIT -IA passed to 2500 psi. IAxOA waiver cancelled due to 2 competent barriers > 12/31/09: MIT -IA failed, LLR —0.4 gpm @ 2500 psi > 01/12/10: Caliper Tbg from 10030'293 jts 1-40%; set WRP @ 9935'; MIT -T passed to 3000 psi > 03/04/10: Tecwel LDL found temperature response at production packer & 18' below the tree > 04/26/10: AA for IAxOA comm cancelled > 05/22/10: IA-LLR of 0.36 gpm @ 2000 psi; T-LLR of 0.48 gpm @ 2000 psi >0711/10: CMIT-TAA passed to 2500 psi. > 07/14/10: Pulled and reset WRP @ 1012' SLM. CMIT-TxIA failed to 2500 psi. Pulled and reset WRP @ 9945' MD. CMIT-TAA passed to 2500 psi. > 07/21/10: Tecwel LDL found temperature response at production packer. MIT -T to 3000 psi passed. > 07/23/10: MIT -IA to 2500 psi failed. IA-LLR of 0.4 gpm @ 2380 psi. > 08/05/10: PPPOT-T & IC passed. > 08/16/10: MIT -T to 3000 psi passed. CMIT-TxIA to 3000 psi passed. MIT -IA to 2500 psi failed. IA-LLR of 0.64 @ 2640 psi. Please call Tiffany Quy or Mehreen Vazir (Projects WIE) with any questions on this work at 659-5098 or Harmony #2418. Cc: Well File AK, D&C Well Integrity Coordinator Mechanical Considerations: Capacities: • OA = 9-5/8" x 13-3/8" 0.0581 bpf • IA = 5-1/2" x 9-5/8" 0.0438 bpf • Tbg = 0.0232 bpf Fluids: • Tbg: Loaded w/ 1 % KCI & topped with 58 bbls 60/40 meth to 2500'MD per secure program • IA: Completed w/ 10.6 ppg inhibited CaCl2 and FP'ed w/ 15 bbls diesel. Diesel & meth have been pumped intermittently for MIT -IA's and LDL's increasing this volume since completion. • In order to achieve a satisfactory fall rate, Flo -Seal will be blended with 12.5 ppg CaBr2 (actual weight used can be adjusted slightly based on slope availability). Blend 5 bbls Flo -Seal @ 6-1 with CaBr2 to achieve a final sealant weight of -12.2 ppg. AnnComm Diagnostic history/discussion: • History of IAxOA communication manageable by bleeds. • The OA was arctic packed on completion. • AOGCC Administrative Approval to operate until a MIT -IA Failed 12/29/09. • PPPOT-T &-IC both passed 12/30/09 indicating well head integrity. • Caliper 01/12/10 shows tubing is in fair condition with a majority of the corrosion >1500'. • Secured with a WRP at 9945' MD on 01/12/10. Passed an MIT -T to 3000 psi. • TecWel LDL 03/04/10 showed questionable noise response suggesting a possible leak 18' into the first full joint of tubing. A temperature response was seen just above the production packer at 9894'. Despite records of IAxOA communication, a tubing pressure response was seen when pumping down the IA with no OAP response. An IA to T LLR of -0.4 gpm was established. • 2nd TecWe31 LDL run 7/21/10 showed a temperature response on the LDL from just above the landing nipple down to the packer region. • An MIT -IA was performed 05/22/10 with no pressure response seen in the fluid packed OA. The tubing pressure increased when pumping on the IA. An IA to T LLR of 0.36 gpm @ 2000 psi was established. A T to IA LLR of 0.46 gpm @ 2000 psi was also observed, but inconsistent with a passing MIT -T on 01/12/10. • WRP was pulled from below the packer on 07/13/10 and set at 1012' SLM. A CMIT- TxIA to 2500 psi failed. The WRP was pulled and reset below the packer at 9945' MD 7/14/10, and a CMIT-TxIA to 2500 psi passed. • A CMIT-TxIA and MIT -T both passed to 3000 psi 08/16/10. A MIT -IA failed to 2500 psi. A IAxT LLR was established as 0.64 gpm @ 2640 psi for 38.5 gal. • Diagnostics suggest a one way leak from IA to T causing the MIT -IA to fail. The passing MIT -Ts and CMIT-TxIAs indicate the plug and production casing have integrity and the packer has integrity to the formation. Based on the repeated temperature response in the LDLs, the leak is determined at the production packer. Risk/Uncertainty Discussion: • This will be the first time to attempt this type of repair in Alaska. Seal-Tite has a 80% success rate from varying other fields. • In Alaska we have a 86% success with IAxOA leaks with a average life of 1.4 years and a 100% TxIA success with a life of -0.5 years (one well treated and still on line). • Alaska does not have any experience with a bullhead displacement of Seal-Tite. • There has only been one packer leak Seal-Tite repair attempted in Alaska. There was a decrease of leak rate post treatment, but it did not pass a MIT -IA (K-09). However, 0 • the treated well had a different configuration where the leak was at the upper production liner packer. The program included multiple circulations and was very sensitive to fluid deployment and densities. The leak rate was also much greater, and the leak rate was inconsistent. • There is some uncertainty on the leak depth. The temperature signature repeated in the two LDL's, but the signal was small. A small anomaly was found in the first log near surface which was not repeatable in the second LDL. It could be that this anomaly was erroneous or there could be an intermittent leak near surface. • The temperature response on the LDL was from just above the landing nipple down to the packer region. The completion assembly from the landing nipple down has several connections and a 40' SBR - all of which could be potential leak points. The temperature response it is difficult to pin down a specific leak point, but TecWel (Joel Johns) gives an 85% confidence on a leak near the packer. After reviewing the logs and schematic of the completion assembly, the pill size was increased to 5 bbls (1 tote) to assure the entire region is covered. • This is not as proven of a repair option compared with a packer squeeze. A sealant repair option was chosen due to the minimal risk associated with the work, lower - expense, less intrusiveness, and the uncertainty associated with the leak. It is also desired to prove this deployment method in Alaska. Rig Up/Equipment Considerations: • Order 12.5 ppg inhibited NaBr2 brine from MI Swaco — 670-5252. Give them notice so they can batch mix the small brine order. • Support equipment: o Air compressor 0 2 heaters (request two trunks and two outlets on the heaters) o Bleed trailer o Triplex o Methanol source pup • Sealant will be pumped into the IA using the following Seal-Tite equipment o Diaphragm pump o SC pump o Injection cylinder • The Special Projects trailer will be required to keep sealant warm. Coordinate trailer use with the special projects PE's. • Spill containment in place for the trailer (either spill dike or line trailer with Herculite). • Note on PPE: Be sure to have goggles, chemical gloves, and ear protection on location. The pumps are loud. The Seal-Tite MSDS recommends gloves and goggles/face shield when in contact with the sealant. Use plastic or towel to cover the diesel reservoir. • Will require MSDS & Sundry on location for this program. Procedure: Well Head (W): 1. Load Seal-Tite mixing tote in the Special Projects trailer. 2. Transport trailer to MI to load the mixing tote with 5 bbls 12.5 ppg inhibited CaBr2. Spot trailer in spill containment on location @ 01-11. a. Make sure tote is loaded with the cam lock discharge near the access hatch near the rear of the trailer. b. Spot tote near the rear of the trailer so there is room for the rest of the rig up in the front of the trailer. c. Spot projects trailer so that wind does not catch the side door. This has been a problem in the past. 3. Rig up injection cylinder, diaphragm pump, and SC -pump in the projects trailer. Spot air compressor and heater(s). Heater(s) will be used to keep the trailer warm and warm the hose from the trailer to the IA to assure sealant does not freeze. QMI dieselI Injection cylinder SC pump Diaphragm pump Mixing tote 4. Pressure up the tubing to 500 psi and the IA with diesel to 2500 psi. Monitor and record IA and tubing pressure data for 45 minutes to re-establish baseline. Bleed IA and T to zero. 5. Blend 5 bbls NaBr2 with Flo -Seal @ 6-1 to achieve a final sealant weight of -12.2 ppg. a. Measure with mud scale to confirm actual brine weight. b. The IA was completed with 10.6 ppg inhibited CaC12, so the sealant needs to be at least 12.2 ppg to achieve a satisfactory fall rate. 6. Rig up injection cylinder discharge to IA casing valve. Rig up digital chart recorder to record IAP. Rig up a tee/manifold to bleed back IAP if needed. a. Load cylinder with Flo -Seal and pump entire 5 bbl Flo -Seal pill into IA. From past jobs, this method takes -1 bbl/hr to pump. b. Annular compressibility is -3.7 bbls, so it may take two compression/bleed cycles to inject all Flo -Seal into the IA. Wait a minimum of 1 hour before bleeding off the IA. Bleed down if IAP > 2000 psi when lubricating in sealant. c. Compressibility factor was confirmed in the last MIT -IA done 8/16/10 where it took -3.6 bbls to pressure up the IAP to 2500 psi. 7. Wait a minimum of 1 hour after Flo -Seal is pumped before bleeding IA. 8. Pressure up on the tubing at least 500 psi above the IAP and allow sealant to fall in the IA and collect at the packer without any losses to the tubing. 9. After at least 7 hours or overnight, pressure up on the IA to 2500 psi. a. Monitor and record IA and T data for 30 minutes. b. Compare to baseline for signs that sealant has reached leak site (not expected for at least 10 hours). c. Bleed the IA to 500 psi. 10. Repeat the above step every 3 hours. Once a change in the leakoff rate signals that sealant is reaching the leak location, wait an additional 2 hours before proceeding. 11. Once the sealant pill is has reached bottom, pressure up on IA with methanol and a triplex to 1500 psi. Bleed Tbg to 0 psi. 0 • a. Monitor IA pressure and LLR every 10 min. b. Calculate LLR from both straps and pressure fall off data as a check. Monitor leak -off rate closely to confirm if sealant has reached the leak location. c. Once IA pressure has stabilized, allow to cure for 2 hours. d. Increase IA pressure to 2000 psi. Allow pressure to stabilize and cure for 4 hours. e. If tubing builds up above 1500 psi, bleed back to <1000 psi. f. Continue increasing IA pressure in 500 psi increments with 4 hour cure periods between each stage up to 3000 psi. Once 3000 psi is reached, allow sealant to cure for 4 days. g. Monitor bleed volumes closely to assure the pill is not over displaced from the IA. If more than 1 bbl is bled off the tubing, plan to decrease IA pressure 500 psi to decrease the leak rate into the tubing. Slickline (SP): 12. Pull WRP from 9945' MD (pending successful Seal-Tite repair). DHD Post Sealtite treatment (DP): 13.AOGCC MIT -IA to 3000 psi (after well is POI). Establish LLR if fails. GRAY WELLHEAD= GRAY ACTUATOR= AXELSON KB. ELEV = 73' BF. ELEV = 6 KOP = 3200' Max Angie = 48 @ 6200' Datum MD = 10364' Datum TVD = 8800' SS 120" CONDUCTOR 94#, H-40, IS = 19.124" 80' 13-3/8" CSG, 72#, N-80 BTRS, ID =12.347" 2713' Minimum ID = 3.759" @ 9964' 4-1/2" BKR R LANDING NIPPLE 5-1/2" TBG -NPC, 17#, N-80, .0232 bpf, ID = 4.892" 4-1/2" TBG -NPC, 12.6#, N-80, H 10024' .0152 bpf, ID = 3.958" PERFORATION SUMMARY REF LOG: BHCS ON 10126/77 A NGLE AT TOP PERF: 32@10238* Note: Refer to Production DB for historical perf data SIZE SPF INTERVAL Opn/Sqz DATE 2-7/8" 6 10238 - 10264 O 08/13/01- 2-7/8" 6 10270 -10276 O 08/13/01 2-7/8" 6 10286 -10320 O 08/13/01 2-7/8" 6 10330 -10354 O 08/13101 3-3/8" 4 10370 - 10380 O 06/14/94 3-3/8" 4 10380 - 10394 S 01/14/94 3-318" 1 10420 - 10425 C 09/12/90 3-3/8" 1 10438 - 10440 C 09/12/90 NA 0 10450 - 10462 C 02/04/78 3-3/8" 4 10462 -10472 C 06/04/93 3-3/8" 4 10482 - 10495 S 11/13/89 3.3/8" 4 10495 - 10513 S 06/05/94 3-3/8" 4 10517- 10520 S 11/13189 3-3/8" 4 10530 - 10535 S 11113/89 3-3/8" 4 10535 - 10545 S 06/05/94 3-3/8" 4 10545 - 10555 S 11/13/89 3-3/8" 4 10555 - 10570 S 06/26/93 3.3/8" 4 10575 - 10585 S 06/26/93 3-3/8" 4 10581-10601 S 06/26193 9-5/8" CSG, 47#, N-80/RS-95,.0733 bpf, E) = 8.681" C 15-1/2" BKR PFVE SSSV NP. K) = 4.562" 2467' H9-5/8" Foc j 9752' H5-1/2" 9812' BKR SLD SLV, K) = ? 5-1 /2" BKR R LANDING NIP, ID = 4.472" 9$94' 9-5/8" X 5-1/2" BKR SAB WJ: ID = 3.875" 9923' 5-1 /2" X 4-112" XO, ID = 3.958" 9945' 4-112" WRP(01/12/10) 9964' 4-1/2" BKR R LANDING NIP, ID= 3.759" 10024' 4-1/2" TUBING TAL, ID = 3.958" 10020' ELMD TT LOGGED DATE UNKNOWN? 10132' 9-5/8"MARKERJoiNT Capacity: OA = 0.0581 bpf IA = 0.0438 bpf Tbg = 0.0232 bpf Fluids: IA: Completed w/ 10.6 ppg inhibited CaC12 and FP'ed w/ 15 bbls diesel to 343' MD Tbg: Loaded w/ 1% KCI & topped with 58 bbls 60/40 meth to 25001MD for secure program 10395' TOP OF CEMENT (15 10410' TOP OF SAND (125'j 10535' PSTD DATE REV BY COMMENTS DATE REV BY COMMENTS 11/04/77 ROW 35 ORIGINAL COMPLETION 08/13/01 ATD/TP ADD CMT / SAND DEPTHS 08/13/01 ?/KAK ADPERFS 12/07/08 WK/SV CSG CORRECTIONS 01/31/10 OPC/PJC SET WRP (01 /12/10) (t Rs. PDS Report Overview Body Region Analysis Well: 01-11 Survey Date: September 9, 2010 Field: Prudhoe Bay Tool Type: UW MFC Ext. 40 No. 217958 Company: BP Exploration (Alaska), Inc. Tool Size: 2.75 Country: USA No. of Fingers: 40 Analyst: C. Waldrop_ Tubing: Nom.OD Weight Grade & Thread Nom.ID Nom. Upset Upper ten. Lower len. 5.5 ins 17 ppf N-80 NPC 4.892 ins 5.5 ins 6.0 ins 6.0 ins Penetration and Metal Loss (% wall) penetration body metal loss body 250 -- 200 150 100 50 0 _ 'VE 0 to 1 to 10 to 1% 10% 20% in 20 to 40 to over 40% 85% 85% Number of joints analysed total = 370 pene. loss 11 148 161 233 135 2 48 2 0 0 0 0 Damage Configuration ( body) 150 100 50 0 isolated general line ring hole f poss pitting corrosion corrosion corrosion ible hole Number of joints damaged total = 138 137 1 0 0 0 Damage Profile (% wall) penetration body metal loss body 0 50 100 0 98 198 298 Bottom of Survey = 365.5 Analysis Overview page 2 • • tIcLiieiO>, j' No Drilling Report — Daily Weft tir ize SE?t'81 �Oep:l7 Last CSG Date �S Cont ,t t Depth ToCay DepL Yesterday PtOg.^esS Fotrna:EOn ``_ Operation at OG 0 Dairy Cost �d Accum_ Ccst !• a Accum. Mud Cast Mud -z Weighi S V Data V' , PV ,-Y.P. YGels, Ph. W.L. Cake Ch1_ Sand " SOI, Da Te„o Pit P,L, Pump Data No. & Type Litter Size SPM GPM P.S. Noz. Vel, A.V, • D.P. A,V, •D.C. Slow Pump Rate Bit No. Size Make Type SN ' Jets Depth-[ n Dell Out Feet Hts, RAM WT: M Condi-Ion BHA L'Jt- Mud D1ZLG Time Accum, Rot. Hrs. Torque Rot. Wt. P.U. Wt_ S.O- BHA 10T. - Afr /!S f •' ., ._..-.. SUOUnaAN PAINTiNO 0 s 4 "Mai-IOU�W+ .. iL&A. ir4Ky r{,rs ro.5d4 4.a`4 r 4 +sPr+i,47sIP. i .1Q7 -`•.—' RIfU1�4 1 if!` 131 MFW +s6G�tr i.:si3 +..715 tmm yPg - JJP' i .I(+ Sot Ale Im IUDI sTW 7PYJN , 44lYLQ LWO t5 P 1M i'f, 5 IR' i7! aY--@ b1CMRF : # J09Pf s," +.!'e �G7 } /herr 014. s,QS - sYiCr SiNg fJ7C�CJ ii` -+4 avax ,_ss WIVI 4-54 i G *I" ran twstg f fisc .Ikr I— 11111 t_alb 9.05 G.PIi 5,Jjs 4149® S,:Yl6 I.DY� l =.1Ga k49 5.PP0 �+'Sis t:r5vd 9 '� TOat9 AND N MIDWI �,,,.,trtrt s ++r IIs J.Y l.G-P0 76it{i ate. i. it �Mi} + it+tiYrt yrs it iBIMR+ 5 11!' Jit EChii +16.= t;am � { W 7,11 rmt a sanw ss -w ImIW Armu X12 11, Ms -m mx,.".lir 4a4 +R4iP/Wil?7tiR�KGi►4�f�►�Cq Pal . s tai• �;. w.n AYJtiI tiff sx Oaf+ IMss44s bees a-32 P4tr�R nmPc sut .rsaar rnm►sl- 4f'hH i41R riles 0.947 14 W" mmrr iIM97 lowe d ALM` Yet rlNt 40 ;[t "J" i�rOl it � + rt. cuac Li r �.as a It9' 49,4r le.p Puwrsz W+Ir: ;w31 me- P ..Im wo WIS MF Kers[ LX a "S 4 tir 1.S/ I" ]Pr5Q79 TWITS jo i r P +sPr+i,47sIP. .1Q7 -`•.—' RIfU1�4 1 if!` 131 MFW +s6G�tr P tmm yPg - JJP' i .I(+ Sot Ale Im IUDI sTW 7PYJN , 44lYLQ LWO 1M i'f, 5 IR' i7! aY--@ b1CMRF : # J09Pf � gyp} Shl" Aoo9 4.rIP X P ri. rim Oi/P.7N �G7 } /herr 014. Pal'dP +_is ! i-�e:(tkt w !6Y 4.mil 11i%i4 SHPIfi ^o-` sYiCr SiNg fJ7C�CJ ii` -+4 7 +'t t1JV. ,HP staKFooes WIVI 4-54 i G *I" ran twstg pamm 41' d O 7r !P `a.. � i,�=' Irr rFSP fit-Igll MP: J1Gi1' -e �,,,.,trtrt s ++r IIs J.Y l.G-P0 76it{i ate. i. it �Mi} + it+tiYrt yrs it iBIMR+ 5 11!' Jit EChii +16.= t;am � { W 7,11 rmt a sanw ss -w ImIW Armu X12 11, Ms -m mx,.".lir 4a4 +R4iP/Wil?7tiR�KGi►4�f�►�Cq Pal . s tai• �;. w.n AYJtiI tiff sx Oaf+ IMss44s bees a-32 P4tr�R nmPc sut .rsaar rnm►sl- 4f'hH i41R riles 0.947 14 W" mmrr iIM97 lowe d ALM` Yet rlNt 40 ;[t "J" i�rOl it � + rt. cuac Li r �.as a It9' 49,4r le.p Puwrsz W+Ir: ;w31 me- P ..Im wo WIS MF Kers[ LX a "S 4 tir 1.S/ I" ]Pr5Q79 TWITS jo ,` ~ il. PROAcrive DiAgnwsric SeevicES, INC. 01-11 BL / EDE • ~~ To: AOGCC Christine Mahnken 333 W. 7th Ave Suite 100 Anchorage, Alaska 99501 [907) 793-1225 RE : Cased Hole/Open Hole/Mechanical Logs and /or Tubing Inspection(Caliper / MTT) 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 Lastufka LR2-1 900 Benson Blvd. Anchorage, Alaska 99508 and ProActive Diagnostic Services, Inc. Attn: Robert A. Richey U -(~ ~~~ - ~$~ 130 West International Airport Road Suite C ~ ~ ~~ Anchorage, AK 99518 Fax: (907) 245-8952 1) Leak Detection - WLD 20zJu1-10 2) Signed Print Name: ~-`-- r: 50-029-20268-00 arxv , i~, . Date _ ,;~ PROACTIVE DIAGNOSTIC SERVICES, INC., 130 W. INTERNATIONAL AIRPORT RD SUITE C, ANCHORAGE, AK 99518 PHONE: (9071245-8951 FAX: (9071245-88952 E-MAIL : ~dsacechor~geCu~mem~rvlog.C©esi WEBSITE : www.mernonrloq.c®m Ci~Documenfs and Settings\Diane Williams\Desktop\Temp Trasmit\2010\07-7u1y\Ol-l l.docx • • ~~p~~ Oo ~ a~Q~f~a /,E..a~.~~o~.~. Bernhard Stechauner ~/ Pertroleum Engineer ~: ~ ~~~~_ ~J" ' J BP Exploration (Alaska), Inc. w r~~a~ ~~`~"~- ~~ P.O. Box 196612 ~~~~ ~~ Anchorage, AK 99519-6612 Re: Prudhoe Bay Field, Prudhoe Bay Oil Pool, PBU O 1-11 Sundry Number: 310-198 Dear Mr. Stechauner: 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 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 s DATED this ~ day of July, 2010. Encl. STATE OF ALASKA 0'~ ' ~ ALASK~ AND GAS CONSERVATION COMMISSI APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 6-~9-JO 1. Type of Request: Abandon ^ Plug for Redrill ^ Perforate New Pool^ Repair Well^ Change Approved Program ^ Suspend ^ Plug Perforations ^ Perforate^ Pull Tubing ^ Time Extension ^ Operation Shutdown ^ Re-enter Susp. Well ^ Stimulate^ Alter Casing ^ Other: TUBING PATCH ' 0 2. Operator Name: 4. Current Well Class: 5. Permit to Drill Number: BP Exploration (Alaska), Inc. Development ^ Exploratory ^ 177-0570 - 3. Address: P.O. Box 196612 Stratigraphic ^ Service ^ ~ 6. API Number: Anchorage, AK 99519-6612 50-029-20268-00-00. 7. If perforating, closest approach in pool(s) opened by this operation to nearest 8. Well Name and Number: property line where ownership or landownership changes: Spacing Exception Required? Yes ^ No ^ PBU 01-11 - 9. Property Designation (Lease Number): 10. Field/Pool(s): ADLO-028329 - 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): 11010 - 9433.61. 10395 9000 10395 TOC 9945 01-12-2010 NONE Casing Length Size MD ND Burst Collapse Structural Conductor 120 20" 94# H-40 SURFACE 120 SURFACE 120 1530 520 Surtace 2640 13-3/8" 72# N-80 SURFACE 2713 SURFACE 2713 4930 2670 Intermediate Production 10915 9-5/8" 47# N-80 SURFACE 10988 SURFACE 9414 6870 4760 Liner Pertoration Depth MD (ft): Pertoration Depth ND (ft): Tubing Size: Tubing Grade: Tubing MD (ft): SEE ATTACHED - - 5-1/2" 17# N-80 28 9923 - - 4-1/2" 12.6# N-80 9923 10024 Packers and SSSV Tvoe: 5-1/2" Baker SAB Packer Packers and SSSV MD and ND (ftl: 9894 8471 12. Attachments: Description Summary of Proposal Q 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: 7/2/2010 Oil ^ Gas ^ WDSPL ^ Suspended ^ 16. Verbal Approval: Date: WINJ Q- GINJ ^ WAG ^ Abandoned ^ Commission Representative: GSTOR ^ SPLUG ^ 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Bernhard Stechauner Printed Name ge hard Stechauner Title petroluem Engineer Signature/~ Phone Date 1/ ~' L. ' 907-564-4594 6/28/2010 Prepared by Gary Preble 564-4944 COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number: ~ ~,~~ Plug Integrity ^ BOP Test ^ Mechanical Integrity Test ~ Location Clearance ^ Other: ~~ ~ ~~~ (1 ,. i U N ~ ~ 2 010 Subsequent Form Required: Io _, ~ ~t1 ~~BS~(8 OE! ~t ~~;~ ~~(" CAC1~111~SS~ar~ fF ~~i1C)1tlf;3l~ APPROVED BY I ~ /~ v ~ / Approved by: COMMISSIONER THE COMMISSION Date: 1 RB ~~ a2 ~, O R I G I N ~~ ~.3o.,a --~~1~~ Form 10-403 Revised 1/ 10 Submit in Duplicate 0~-~11i Tubing Patch • by ~•: :•~ ~~~ ~~~ i~~:~',~ To: J. Bixby/C. Olsen GPB Well Ops Team Leaders Bernhard Stechauner Petroleum Engineer From: Josiah Igwe Wells Engineer Subject 01-11 i Tubing Patch Job Seauence~ •AFE# APBD01WL11 Memorandum Date: June 02, 2010 AFE: APBD01WL11-N Est. Cost: IOR: 200 1. S Pull Weatherford 4-1/2" WRP, Set 5-1/2" WRP 2. F CMIT-T x IA to 2500 si 3. S Pull 5-1/2" WRP 4. F Pum 290 bbls of hot 1 % KCL down the tubin 5. E Set Weatherford 5-1/2" Wide Pak / MITIA to 2,500 si Current Status: Shut in due to T X IA communication Last Well Test: 01/05/2010: In'ectin at 10,000 BWPD 437 si WHP Max Deviation: 48° at 6200' MD Minimum ID: 3.759" @ 9,964' MD in 4-1/2" BKR landing nipple Last Downhole Op: 03/4/10 E-Line LDL Last Drift & TD Tag: 03/03/10 E-Line tag TD @ 9945' SBHPlT: 08/21/2005: 3218 psi / 118 deg F Latest H2S Value: 03/28/2001 10 ppm Job Objective The objective of this procedure is to set the 5-1/2" tubing patch to seal the tubing leak at 39'. Histo Well 1-11i was converted to a produced water injector in August 2001 as part of the SWIPE FOR Pilot (UZI pilot). Since September 2001 the well was averaging about 10-11,000 BWPD in Zone 4A and 4B at 1100 psi WHP. The well was converted to sea water in October 2004. The average rate did not change, but the WHP declined dramatically to <100 psi. The rate had to be increased in order to keep the p-pilot from tripping. In April 2006 a down hole choke was installed to maintain the target rate without tripping the pilot and avoiding over injection/injecting out of zone. 1 01-11 177-057 PERF ATTACHMENT • Sw Name Operation Date Perf Operation Code Meas Depth Top Meas Depth Base Tvd Depth To Tvd Depth Base 01-11 2/4/78 PER 10,450. 10,470. 8,947.36 8,964.51 01-11 2/4/78 PER 10,482. 10,520. 8,974.78 9,007.22 01-11 2/4/78 PER 10,530. 10,570. 9,015.77 9,050.06 01-11 7/11/87 APF 10,575. 10,585. 9,054.35 9,062.95 01-11 7/11/87 APF 10,591. 10,601. 9,068.11 9,076.73 01-11 11/13/89 SQZ 10,450. 10,601. 8,947.36 9,076.73 01-11 11/27/89 RPF 10,575. 10,585. 9,054.35 9,062.95 01-11 11/27/89 RPF 10,591. 10,601. 9,068.11 9,076.73 01-11 11/27/89 RPF 10,555. 10,570. 9,037.18 9,050.06 01-11 9/12/90 APF 10,420. 10,425. 8,921.55 8,925.86 01-11 9/12/90 APF 10,438. 10,440. 8,937.05 8,938.77 01-11 8!7/92 RPF 10,505. 10,517. 8,994.41 9,004.66 01-11 1/24/93 RPF 10,535. 10,545. 9,020.05 9,028.61 01-11 2/7/93 APF 10,470. 10,472. 8,964.51 8,966.22 01-11 2/7/93 RPF 10,462. 10,470. 8,957.66 8,964.51 01-11 3/6/93 RPF 10,495. 10,505. 8,985.88 8,994.41 01-11 5/26/93 SQZ 10,420. 10,601. 8,921.55 9,076.73 01-11 6/4/93 RPF 10,535. 10,545. 9,020.05 9,028.61 01-11 6/4/93 RPF 10,462. 10,472. 8,957.66 8,966.22 01-11 6/4/93 RPF 10,495. 10,517. 8,985.88 9,004.66 01-11 1/14/94 APF 10,376. 10,394. 8,883.55 8,899.09 01-11 6/5/94 SQZ 10,376. 10,601. 8,883.55 9,076.73 01-11 6/14/94 APF 10,370. 10,376. 8,878.38 8,883.55 01-11 6/14/94 RPF 10,376. 10,380. 8,883.55 8,887. 01-11 7/22/95 SQZ 10,370. 10,486. 8,878.38 8,978.2 01-11 9/2/95 RPF 10,370. 10,380. 8,878.38 8,887. 01-11 8/2/01 SPS 10,417. 10,529. 8,918.96 9,014.91 01-11 8/3/01 SQZ 10,395. 10,417. 8,899.95 8,918.96 01-11 8/13/01 APF 10,258. 10,264. 8,782.45 8,787.57 01-11 8/13/01 APF 10,270. 10,276. 8,792.68 8,797.8 01-11 8/13/01 APF 10,286. 10,306. 8,806.34 8,823.43 01-11 8/13/01 APF 10,306. 10,320. 8,823.43 8,835.42 01-11 8/13/01 APF 10,330. 10,354. 8,843.99 8,864.61 01-11 8/14/01 APF 10,238. 10,258. 8,765.43 8,782.45 01-11 12/24/01 FIL 10,392. 10,420. 8,897.36 8,921.55 01-11 1/12/10 BPS 10,394. 10,420. 8,899.09 8,921.55 AB ABANDONED PER PERF APF ADD PERF RPF REPERF BPP BRIDGE PLUG PULLED 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 LF_Ai( STO STRADDLE PACK, OPEN OH OPEN HOLE 0~ ~ 11i Tubing Patch ~ ~AFE# APBD01WL11 The well was SI in April 2007 for corrosion in the 1-11 seawater line, after the line replacement the well was put back on injection in December 2008. In June 2009 the well was SI for the modification implementation of the UZI project in DS1. After POI in December 2009 the well failed the state MIT-IA. After WH remediation the well passed PPPOT-T & IC but failed MIT-IA with a LLR ~0.4 gpm at 2500 psi. TecWel LDL on March 2010 located IAxOA communication indicating leak at 39'. Due to the anomality and noisy character obtained in the TecWel LDL and also greatest PDS wall penetration at the SSSV (2191'), extra steps have been added to this program to verify the position of the actual leak. Well Events: > 08/13/99: DSE evaluating to put on PWI. No problems noted in AC database. Recent pressure observations indicate IAxOA communication. > 04/19/00: PPPOT-T & IC Passed, MITIA Passed, MITOA Passed > 07/17/01: MITIA Passed to 2500 psi > 07/22/01: PPPOT-IC Passed > 07/28/01: USIT Log > 08/02/01: CTU Sandback and cement cap > 08/06/01: SL tag top of cement @ 9996' > 09/16/01: MITIA Passed to 2500 psi > 12/09/02: Bled OA 1000>50 psi. Monitor BUR > 12.10/02: T1O=1150/950/620 > 12/15/02: MITIA Passed to 2500 psi > 12/26/02: PPPOT-T & IC Passed > 02/15/03: MITOA Passed to 2400 psi > 06/06/03: Notified Winton that the OA is tracking the IA. Winton said that notification is all we need to do at this time for a PWI with slow IA x OA. > 06/10/03: MITOA Passed to 3000 psi > 06/12/03: AOGCC MITIA Passed to 2500 psi > 06/12/04: MITOA Passed to 3000 psi > 06/19/04: MITIA Passed to 2500 psi > 06/24/04: MITIA Passed to 2500 psi state witnessed > 06/18/05: MITOA Passed to 3000 psi > 07/16/05: MITIA Passed to 2500 psi (AOGCC rejected IE 13bbls test vol) > 03/08/06: OARP BUR 150 psi/day > 06/07/06: MITOA Passed to 3000 psi > 07/16/06: AOGCC MITIA Passed to 2500 psi > 09/19/06: MITIA Passed to 3000 psi > 10/23/06: Well exhibits TxIA & IAxOA comm, but MITIA passes. APE to review with Wells Manager for AA or secure -Rossberg okayed pursuing AA > 12/09/06: AA request & TJ mailed > 12/18/06: AA request approved > 05/07/07: MIT-IA Passed to 2500 psi. IAxOA waiver cancelled due to 2 competent barriers > 11/20/08: MIT-IA Passed to 3000 psi > 12/18/08: MIT-IA to 2500 psi Inconclusive > 12/20/08: MIT-IA to 2500 psi Passed. Witnessed by Lou Grimaldi > 05/15/09: MIT-IA Failed, PPPOT-T &ID paased, PPPOT-IC Passed, cycled LDS 2 OT,'11i Tubing Patch • .AFE# APBD01WL11 > 05/16/09: MIT-IA Failed > 05/17/09: Tightened gland nut on tubing spool > 05/18/09: MIT-IA Passed to 3000 psi ~ > 12/25/09: MIT-IA Passed to 2500 psi ~ ` > 12/29/09: AOGCC MITIA Failed > 12/30/09: PPPOT-T & IC, PPPOT-IC > 12/31/09: MIT-IA Failed, LLR ~0.4 gpm @ 2500 psi / > 01/12/10: Caliper Tbg from 10030' 293 jts 1-40%; set WRP @ 9945'; MIT-T Passed to 3000 psi > 03/04/10: LDL found leak @ 18' below tree C3~i ~ ~~~ > 04/26/10: AA for IAxOA comm cancelled > 05/22/10: IA-LLR 0.36 gpm @ 2000 psi; LLR-TxIA 0.48 gpm @ 2000 psi Contacts: Bernhard Stechauner Production Engineer Office /Cell: 564-4594/360-7485 Josiah Igwe Wells Engineer Office /Cell: 564-4753/590-0610 Slickline 1. RU SL. 2. Pull Halliburton 4-1/2" WRP at 9,945' slm. 3. Set 5-1/2" WRP at 1000' 4. CMIT- Tx IA to 2500 psi. If it passes continue with Patch se ing program, but if it fails contact APE/WDE for new program to re-log LDL. 5. Pull 5-1/2" WRP ~ ,~P~fi' 1~, 6. Rig down move out. ~`..~ ~ ,~ ~ o ,~ G5~ 1~ Full Bore (E-Line and fullbore jobs to be run concurrently) 1. MU LRS pumping line to the tubing 2. Test line to the tree to 3000 psi 3. Bull head (hot) 290 bbls of 1 % kcl down the tubing • Pump at 2.0 bpm (intent is to warm the tubing prior to running patch) 4. Freeze protect lines with 50/50 meth and standby for E-Line F - 30~- z~ Patch Specs 5-1/2" Weatherford WidePak packer - L-80 Patch single run system. Use manufacturer's recommended setting procedure. Considering the fact that temperature at this depth is very low, Weatherford Wide Pack patch elastomer contains some nitrite which has been tested to with stand -30 degree F. 3 01~-11i Tubing Patch . Patch Depth • AFE# APBD01WL11 • Patch Setting Depth is 34' - 44' ELMD • Patch Length: 10' element to element. • Leaking depth at: 39' from PDS LDL 04t" March 2010. • Log referenced to Well bore schematics dated 31th January 2010. • Please carefully read and discuss the attached HARC for Perforations shallower than 200' document. E-line 1. RU E-Line. Conduct PJSM with the crew. 2. RIH w/ 10' Weatherford 5-1/2" WidePak Packer . 3. Log w/CCL and Set Packer at 34' - 44' elm per manufacturer's recommendations. POOH. • Tie-in to PDS LDL dated 04t" March 2010. 4. MIT-IA to 2500 psi. LLR if fails 5. RDMO 4 0 Arming explosive d~,~ Gun firing at suRace Personnel v m n a a° ~ 5 ~ s^ 3i ~ ~ Do not stand in the line of fire. ONLY Schlumberger personnel are a0owed to be in the vicinity of the gun arming area. ONLY the Schlumberger engineer/ specialist ran arm the gun. Gun must be armed elecViWlfy first arM then ballistically. Oo not stand in the line of fire. v ~, ~ j r Firing the Gun Shooting guns shallower then Personnel Maximum baded gun length is to De 10 feet The hde will De full of fluid. PO and Pump 2W q ~ which should help limit the shock. In Sub Are Minimum WHE Requirements. ``. e7 Wtll De conelate below 200 ft and work (heir '/ a .. way up the hole. The shallowest depth is 100 : I ~ .W ft. After shooting run in hole bebw 200 ft, o f ~ power down the unit and remove the safely j to a ke . Retrieval of Gun not fired or incomplete Personnel AJI safety rules mentioned above applies from Do riot eland in the line of fire. When the gun firing. 200 ft below the floor until gun Is at suAece and gun reach suRace or when disarming. confirmed fired. "AS per Schlumberger policy ~^, _ ' this rule applies even if There is positive g ~ ~ indication of gun firing. It al all the gun has riot ~, n g fired, check for Thermal event. disarm the gun ballisticalty first and then elecUicalry. x ~~° a ~ ~ COMMUNICATIONS Communications [o all concerned parties will De done in the tollowing manner: Harc discussed and approve by rig engineer and FSM then send to Rig Engineer . Engineer to disUibute to Co. man and confirm procedure. Safety toolbox meeting hold with all personnel involved in preparaCron of job. Toolbox meetings redone every crew change if required. Communications to newcomers will be done in the following manner: ~. Onboarding process -25 to - 20 Non operable: Evacuate the zone 8 or area/country -76 to -10 Intolerable: Do not take this risk - 9 to - 5 Y6110w Untlesirable: Demonstrate ALARP belore proceeding - 4 to - 2 Acceptable: Proceed carefully, with continuous improvement -t Negligible: Safe to proceed ~- ~. sr ~- cro A~ n • M~ l1J ~-~~--yy ~..J t--~ N 0 ~. _ H s/ Q' ~~ >v r~ ~' • HAZARD INITIAL RISK CONTROL MEASURES RESIDUAL RISK ~Ivm' Hazard Description and Worst Case Lto o / C $ ro List all Current and Plannetl Control Measures, taking into Account all Contributing and Escalating Factors Steps Consequences with no a ~ ry o ~ ' ~ c° _ Prevention or Mitigation Population t io Curtent and Planned Prevention ~ Curtent and Planned Mitigation ~ a Measures in Place Affected Y o m Measures to reduce Likelihood Measures to reduce Severity ~ o Radio Silence Radio transmdting Personnel All other operations to be stopped near the well Make announcement before operation. Transmitters while preparing fd tha run. Radio silence Review the Radio Silence procedures procedures to be reviewed antl signetl off by before proceetling. - Y the Slb engineer on board poor to the jo0. Use _ $ of SECURE detonator o a ri ~ U ~ t 4 Worksile Tripping and Falling Stray Personnel Check well area for haiards 8 coned when Make announcement before operation. _ Inspection 8 vdtage/ wrtenl '~ necessary. Install positive grounding cable ~ Preparation v n 3 from a-line unit to power pack. Install casing-rig . m ~ ~ vdlage monitor; make sure residual vdtage if ~ ~- ~ ~ any, is less than 0.25V. Install safety grounding '-` o a ~ ~,; cable between unit, rig and casing. j Gun firing acdtlenfally at surface Personnel Tum off AC generators. Tum off satery switch Do not stand in the line of fire. ~ and renwve key. The key MUST remain v m c .Q _ outside the unit until Ne gun is Debw 200n. ~, °i o° ° a m + ~ • O r Schlumherger SLB-QHSE-FOO4 Exemption Risk Control Form Oi'-11i Tubing Patch , .AFE# APBD01WL11 TREE _ ' ~ GRAY WELLHEAD = GRAY ACTUATOR = AXELSON KB. ELEV = 73' BF. ELEV = KOP = 3200' Max Angle = 48 @ 6200' Datum MD = 10364' Datum TV D = 8800' SS 20" CONDUCTOR, 94#, H-40, IS = 19.124" (-~ $0' 13-3/8" CSG, 72#, N-80 BTRS, ID = 12.347" 2713' Minimum ID = 3.759" @ 9964' 4-1 i2" BKR R LANDING NIPPLE 5-1/2" TBG-NPC, 17#, N-80, .0232 bpf, ID = 4.892" ~-I 9894' 4-1/2" TBG-NPC, 12.6#, N-80, ( 10024` .0152 bpf, ID = 3.958" PERFORATION SUMMARY REF LOG: BHCS ON 10!26/77 ANGLE AT TOP PERF: 32 @ 10238' Note: Refer to Production DB for historical perf data SIZE SPF INTERVAL Opn/Sqz DATE 2-7/8" 6 10238 - 10264 O 08/13!01 2-7/8" 6 10270 - 10276 O 08113!01 2-7/8" 6 10286 - 10320 O 08/13101 2-7/8" 6 10330 - 10354 O 08/13!01 3-3/8" 4 10370-10380 O 06/14!94 3-318" 4 10380 - 10394 S 01/14/94 3-3/8" 1 10420 - 10425 C 09!12/90 3-318" 1 10438 - 10440 C 09!12190 NA 0 10450 - 10462 C 02104/78 3-3/8" 4 10462 - 10472 C 06/04/93 3-3/8" 4 10482 - 10495 S 11!13/89 3-3/8" 4 10495 - 10513 S 06/05/94 3-3/8" 4 10517 - 10520 S 11/13/89 3-318" 4 10530 - 10535 S 11/13!89 3-3/8" 4 10535 - 10545 S 06/05/94 3-318" 4 10545 - 10555 S 11!13/89 3-3/8" 4 10555 - 10570 S 06/26!93 3-3/8" 4 10575 - 10585 S 06/26/93 3-318" 4 10591 - 10601 S 06/26!93 9-518" CSG, 47#, N-80/RS-95, .0733 bpf, ID = 8.681" I 01-11 2208'-j 5-112" BKR PFV E SSSV NIP, ID = 4.562" 233T 9-5/8" FOC 2467' 9-5/8" FOC 975_ 2~ -~5-1I2" BKR SLD SLV, ID =? 9812' S-1/2" BKR R LANDING NIP, ID = 4.472" 9894' 9-5/8" X 5-112" BKR SAB PKR, ID = 3.875" 9923' 5-112" X 4-112" XO, ID 3.95$" 9945' - 4-1/2" WRP(01/12/10 99~ 4-1/2" BKR R LANDING NIP, ID = 3.759" 10024' -+4-112" TUBING TAIL, ID = 3.958" I 10020' ELMD TT LOGGED DATE UNKNOWN? 10132' 9-5/8" MARKER JOINT 10395' -1 TOP OF CEMENT (15 10410' TOP OF SAND (125') 10535' PBTD DATE REV BY COMMENTS DATE REV BY COMMEMS 11/04/77 ROW 35 ORIGINAL COMPLETION 08/13!01 ATDITP ADD CMT 1 SAND DEPTHS 08!13/01 ?/KAK ADPFRFS 12!07/08 WK/SV CSG CORRECTIONS 01!31/10 OPGPJC SETWRP(01/12/10) PRUDHOE BAY UNIT WELL: 01-11 PERMfT No: 1770570 API No: 50-029-20268-00 SEC 8, T10N, R15E, 1381.51' FEL & 4248.53' FNL BP 6cploration (Alaska) ~~ial~C~ 0~ Q~Q~~Q /.~.~A.E..w~w.~ Bob Chiwis Petroleum Engineer BP Exploration (Alaska), Inc P.O. Box 196612 Anchorage, AK 99519-6612 ~, { e -~t>s~tl~" ,~: Re: Prudhoe Bay Field, Prudhoe Bay Oil Pool, PBU 01-11 Sundry Number: 310-165 Dear Mr. Chiwis: osn 1~ 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 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. '7yti Chair DATED this ~ day of June, 2010. Encl. ,~ ~i i~' U,C~~~ STATE OF ALASKA ' `~~~~ " ~~~,~~ b ALAS~IL AND GAS CONSERVATION COMMISSi~ APPLICATION FOR SUNDRY APPROVALS MAY 2 7 2010 6-~io 1. Type of Request: Abandon ^ Plug for Redrill ^ Perforate New Pool^ Repair Well Ch~ppqq DD ed Program ^ ~~ ~ Suspend ^ Ptug Perforations ^ Perforate^ Pull Tubing ^ Hi1G ~ii Time Extension ^ Operation Shutdown ^ Re-enter Susp. Well ^ Stimulate^ Alter Casing ^ 0 Other: SEAL TITE - 2. Operator Name: 4. Current Well Class: 5. Permit to Drill Number. BP Exploration (Alaska), Inc. Development ^ Exploratory ^ 177-0570 - 3. Address: P.O. Box 196612 Stratigraphic ^ Service ^ 6. API Number. Anchorage, AK 99519-6612 50-029-20268-00-00 - 7. If perforating, closest approach in pool(s) opened by this operation to nearest 8. Well Name and Number: property line where ownership or landownership changes: Spacing Exception Required? Yes ^ No ^ PBU 01-11 _ 9. Property Designation (Lease Number): 10. Field/Pool(s): ADLO-028329 PRUDHOE BAY Field / PRUDHOE BAY Pool 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): 11010 - 9433.61 - 10395 9000 10395 TOC 9945 01-12-2010 NONE Casing Length Slze MD TVD Burst Collapse Structural Conductor 120 20" 94# H-40 SURFACE 120 SURFACE 120 1530 520 Surface 2640 13-3/8" 72# N-80 SURFACE 2713 SURFACE 2713 4930 2670 Intermediate Production 10915 9-5/8" 47# N-80 SURFACE 10988 SURFACE 9414 6870 4760 Liner Perforation Depth MD (ft): Pertoretion Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): SEE ATTACHED - - 5-1/2" 17# N-80 28 9923 - - 4-1/2" 12.6# N-80 9923 10024 Packers and SSSV Type: 5-1/2" Baker SAB Packer Packers and SSSV MD and TVD (ftl: 9894 8471 12. Attachments: Description Summary of 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: 6/10/2010 Oil ^ Gas ^ WDSPL ^ Suspended ^ 16. Verbal Approval: Date: WINJ ~ - GINJ ^ WAG ^ Abandoned ^ Commission Representative: GSTOR ^ SPLUG ^ 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact BOB CHIWIS Printed Name BOB CHIWIS Titie PE Signature Phone Date .- 907-564-5412 5/27/2010 Prepared by Ga Preble 564-4944 COMMISSION USE ONLY C diti f l N tif i i th t ti it C t S d N b ~~ ~ r' on ons o approva : o y omm on so a represen ve may w ss a a ness un ry um er: Plug Integrity ^ BOP Test ^ Mechanical Integrity Test d Location Clearance ^ Other: Subsequent Form Required: X10 . tl/ fjL( APPROVED BY A d b COMMISSIONER CO pprove y: THE MMISSION Date: n~s~s fuK ro ~ ( 1 ~ I ~ A L b :~,., o Form 10-403 Revised 1/2010 ~ t-~' ~.~~ Submit in Duplicate `''.~` r~ 01-11 177-057 PERF ATTACHMENTS • C~ J Sw Name O eration Date Pert O erat(on Code Meas De th To Meas De th Base Tvd De th To Tvd De th Base 01-11 2/4/78 PER 10,450. 10,470. 8,947.36 8,964.51 01-11 2/4/78 PER 10,482. 10,520. 8,974.78 9,007.22 01-11 2/4/78 PER 10,530. 10,570. 9,015.77 9,050.06 01-11 7/11/87 APF 10,575. 10,585. 9,054.35 9,062.95 01-11 7/11/87 APF 10,591. 10,601. 9,068.11 9,076.73 01-11 11/13/89 SQZ 10,450. 10,601. 8,947.36 9,076.73 01-11 11/27/89 RPF 10,575. 10,585. 9,054.35 9,062.95 01-11 11/27/89 RPF 10,591. 10,601. 9,068.11 9,076.73 01-11 11/27/89 RPF 10,555. 10,570. 9,037.18 9,050.06 01-11 9/12/90 APF 10,420. 10,425. 8,921.55 8,925.86 01-11 9/12/90 APF 10,438. 10,440. 8,937.05 8,938.77 01-11 8!7/92 RPF 10,505. 10,517. 8,994.41 9,004.68 01-11 1/24/93 RPF 10,535. 10,545. 9,020.05 9,028.61 01-11 2/7/93 APF 10,470. 10,472. 8,964.51 8,966.22 01-11 217/93 RPF 10,462. 10,470. 8,957.66 8,964.51 01-11 3/6/93 RPF 10,495. 10,505. 8,985.88 8,994.41 01-11 5/26/93 SQZ 10,420. 10,601. 8,921.55 9,076.73 01-11 6/4/93 RPF 10,535. 10,545. 9,020.05 9,028.61 01-11 6/4/93 RPF 10,462. 10,472. 8,957.66 8,966.22 01-11 6/4/93 RPF 10,495. 10,517. 8,985.88 9,004.66 01-11 1/14/94 APF 10,376. 10,394. 8,883.55 8,899.09 01-11 6/5/94 SQZ 10,376. 10,601. 8,883.55 9,076.73 01-11 6/14/94 APF 10,370. 10,376. 8,878.38 8,883.55 01-11 6/14!94 RPF 10,376. 10,380. 8,883.55 8,887. 01-11 7/22/95 SQZ 10,370. 10,486. 8,878.38 8,978.2 01-11 9/2/95 RPF 10,370. 10,380. 8,878.38 8,887. 01-11 8/2/01 SPS 10,417. 10,529. 8,918.96 9,014.91 01-11 8/3/01 SQZ 10,395. 10,417. 8,899.95 8,918.96 01-11 8N3/01 APF 10,258. 10,264. 8,782.45 8,787.57 01-11 8/13/01 APF 10,270. 10,276. 8,792.68 8,797.8 01-11 8/13/01 APF 10,286. 10,306. 8,806.34 8,823.43 01-11 8/13/01 APF 10,306. 10,320. 8,823.43 8,835.42 01-11 8/13101 APF 10,330. 10,354. 8,843.99 8,864.61 01-17 8/14/01 APF 10,238. 10,258. 8,765.43 8,782.45 01-11 12/24!01 FIL 10,392. 10,420. 8,897.36 8,921.55 01-11 1/12/10 BPS 10,394. 10,420. 8,899.09 8,921.55 AB ABANDONED PER PERF APF ADD PERF RPF REPERF BPP BRIDGE PLUG PULLED 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 b i ~ To: J.Bixby&R.Liddelow, AK D&C Wireline Ops Team Leads C.Olsen&T.Norene, AK D&C Well Services Ops Leads From: Taylor Wellman & Tiffany Quy (cell 253-576-6153) Projects WIE (659-5098, Harm #2418) Subject: 01-11 Pull WRP pre-SeatTite TxIA repair May 26, 2010 Step Type Procedure 1 W Pump Seal-Tite 2 SP Pull WRP from 9945' to POI (Pending 7 day cure) 4 DP AOGCC MIT-IA to 2500 psi (on line) Objective: This is procedure is to repair tubing by inner annulus communication using Seal-rite. Seal-Tite Gel-Seal be pumped down the IA to mitigate the communication. Once the sealant is cured, the well will be unsecured and reclassified as Under Evaluation to put on seawater injection. Once thermally stabile, an AOGCC MIT-IA will be performed and the well reclassified pending the MIT-IA results. Well Stats: Well Status: SWI - SI and Not Operable due to failed MIT-IA Last injection rate: 10132 bwpd @ 437 psi Well Events Summary: > 06/07/06: MIT-OA Passed to 3000 psi > 12/18/06: AA request approved > 05/07/07: MIT-IA Passed to 2500 psi. IAxOA waiver cancelled due to 2 competent barriers > 12/29/09: AOGCC MITIA Failed > 12/30/09: PPPOT-T & IC, PPPOT-IC > 12/31/09: MIT-IA Failed, LLR ~0.4 gpm @ 2500 psi > 01/12/10: Caliper Tbg from 10030' 293 jts 1-40%; set WRP @ 9935'; MIT-T Passed to 3000 psi > 03/04/10: LDL found leak @ 18' below tree /' > 04/26/10: AA for IAxOA comm cancelled > 05/22/10: IA-LLR 0.36 gpm @ 2000 psi; LLR-TxIA 0.48 gpm @ 2000 psi Please call Tiffany Quy or Taylor Wellman (Projects WIE) with any questions on this work at 659-5098 or Harmony #2418. Cc: Well File AK, D&C Well Integrity Coordinator Procedure: 1. Run a LDL to evaluate leak location. Use results of log to define sealant volume and displacement parameters in the steps below. -DONE, Confirmed leak @ 18'below the tree, 0.4 gpm @ 2500 psi / 2. Confirm sustainable LLR down IA & down Tbg taking returns up the OA @ 2500 psi to confirm consistent infectivity -DONE, confirmed TxIA LLR .~ Well Head (W): 3. Rig up to pump diesel and Gel-Seal to IA casing valve. Using Fireball or triplex to increase IA pressure to 1800 psi with diesel. DO NOT use triplex to pump Seal-Tite as it has a history of setting up in these pumps. 4. Switch to Fireball and pump 1 bbl Gel-Seal to increase pressure to ± 2600 psi. Allow sealant to cure 1 hour. Pump additional 0.5 bbl Gel-Seal to increase pressure to 3000 psi. 5. Allow to cure for 7 days. 6. Bleed IA to 700 psi. Will want to maintain a IAP > Tbg pressure at all times if possible. Slick-line (S): 7. Pull WRP from 9945' MD. DHD Post Sealtite treatment (DP): 8. Reclassify well as Under Evaluation to put on injection for treatment. 9. AOGCC MIT-IA to 3000 psi. Establish LLR if fails. '` TRIB= = GRAY 120" COn1DUCTOR, 94#, #i-4o, IS = 19.124" H 80' 13-3/8" CSG, 72#, N-80 BTRS, ~ = 12:347" 2713' Minimum ID = 3.759" @ 9964' 4-1 /2" BKR R LANDING NIPPLE 15-112" T8G-NPC, 179(, N-80, .0232 bpf, ~ = 4.892" I 4-1/2" TBG-NPC, 12.6#. N-80, .0152 bpf, ~ = 3.958" PERFORATK3N SUMMARY REF LOG: BHCS ON 10/26/77 A NGLE AT TOP P~tF: 32 @ 10238' Note: Refer to Production DB for f~istoricai perf data SIZE SPF fNTERVAL Opn/Sqz DATE 2-718" 6 10238 - 10264 O 08113101 2-7/8" 6 10270 - 10276 O 08!13/01 2-7!8" 6 10286 - 10320 O 08/13101 2-718" 6 10330 - 10354 O 08/13/01 3-3±8" 4 10370 - 10380 O 06/14/94 3.318" 4 10380- 10394 S 01!14194 3-378" 1 10420 - 10425 C 09/12/90 3-318" 1 10438- 10440 ~O 09/12/90 NA 0 10450 - 10462 C 02/04/78 3-316" 4 10462 - 10472 C 06/04!93 3-318" 4 10482 - 10495 S 11(13/89 3-3/8" 4 10495 - 10513 S 06105194 3-318" 4 10517 - 10520 S 11!13189 3318" 4 10530 - 10535 S 11/13/89 3-3/8" 4 10535 - 10545 S 06/05/94 3-318" 4 10545 - @0555 S 11113189 3-318" 4 10555 - 10570 S 06/26/93 3-318" 4 10575 - 10565 5 06/26/93 3-318" 4 10591 - 10601 S 06/26193 I ~ 9-5/8" CSG, 47#, N-80/RS-95, .07331~pf. ~ = 8.681" h 109t3t3- r Tn ~ 11010' 01-11 +~. ~ 1A .k ~~' t ~ . 220$' S-112" BKR PFV E SSSV NIP, ID = 4.562" 9-5/8" FOC 9752' 1--15-112" BKR SLD SLV, ID = ? 9812' H 5-112" BKR R LAND~IG NIP, ID = 4.472" I g$g4' 9-518" X 5-112" BKR SAB R(R, ~ = 3.875" 8923' 5-1/2" X 4-112" XO, ID = 3.958" gg45• a-v2"wRP{ovlvlo} 9964` I'i 4-1 /2" BKR R LA ND~1G NIP, ID = 3.759" ~ 10024' H4-112" TUBING TAB, ID = 3.y5F1" I 10020' ELMD TT LOGGED DATE UNKNOWN? 10132' 9-518" MARKER JOB~1T Capacity: OA = 0.0581 bpf IA = 0.0438 bpf Tbg = 0.0232 bpf Fluids: IA: Completed w/ 10.6 ppg inhibited CaC12 and FP'ed wl 15 bbls diesel to 343' MD Tbg: Loaded w/ 1% KCI 8~ topped with 58 bbls 60140 meth to 2500'MD for secure program 10395` TOP OF CEMENT (1 S'} 10410' TOP OF SAND{125'}' 10535' ~ PBTD DATE REV BY COh>~4'~VTS DATE REV BY COMMENTS 1 UOd177 ROW 35 ORIGINA! GOWiPLETiON 08/13/01 ATDPfP ADD CMT 15AND tJEf'7'tiS 06713J01 ?1KAK ADPERFS 12707108 1JVK/SV CSG CORRECTK3NS 01(31110 OPC7PJC ~ wR!' j0'11'12/i 0) • • ~~Q~[~ 0~ Q~G1~~Q /,.....w~..oo~,~. ADMINISTRATIVE APPROVAL NO. AIO 4E.011 Mr. Steve Rossberg, Wells Manager Attention: Well Integrity Engineer, PRB-20 ~ o S BP Exploration (Alaska) Inc. ~ ~ / P.O. Box 196612 Anchorage, AK 99519-6612 RE: Cancellation of Administrative Approval AIO 4E.011 (Well PBU 01-11) Dear Mr. Rossberg: Pursuant to BP Exploration (Alaska) Inc. (BPXA)'s request dated March 17, 2010, the Alaska Oil and Gas Conservation Commission (Commission) hereby cancels Administrative Approval AIO 4E.011, which allows continued water injection in Prudhoe Bay Unit ("PBU") well 01-11. This well exhibited inner by outer annulus 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. The well recently failed a MITIA. BPXA has determined not to operate PBU O 1-11 until further diagnostics can be accomplished and a repair option determined. Consequently, Administrative Approval AIO 4E.011 no longer applies to operation of this well. Instead, injection into PBU 01-11 will be governed by provisions of the underlying AIO No. 4E. DONE at Anchorage, Alaska and dated Apri126, 2010. Alaska Oil and fount, Jr Chair f s ~ s; ~o~~ : ~ ~ ~ ~~ 4 /~ _: Commission Cathy . Foerster Com issioner K. N ~~ ~ 4' ;~ #~~~aL.9~ ~ iii 1 \~ ~ , } ~ (~ } .. ~ylY • BP Exploration (Afaa~ka) Inc. Attn: Weil Integrity Coordinator, PRB-ZO Post OtTtce Box 196612 Anchorage, Alaska 99519-6812 March 17, 2010 Mr. Daniel Seamount, Chaim~an Alaska Clil and Gas Conservation Commission 333 West 7~' Avenue Anchorage, Alaska 99501 APB ~~~ ~ zoo by ~iaska Gil ~ Gas (;QtIS. Omission Anchora4~ Subject: Prudhoe Bay Unit well 01-11 (PTO #1770570) Application for Cancellation of Administrative Approval 4E.011 Dear Mr. Seamount, BP Exploration (Alaska) tnc. requests cancellation of Administrative Approval number 4E.011 dated December 18, 2006. The administrative approval was for continued water injection into watt 01-11 with slow IA x OA communication. This well felted a MITIA for Administrative Approval compliance on Oecerrtber 31, 2009. The well is secured with a downhole mechanical plug. It is scheduled for further diagnostics to locate the depth of the leak to evaluate repair 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 Anna Dube Toxin Roschinger at 659-5102. Sincerely, R. Steven Rossberg BPXA, W®ils Manager Attachments: TIO Plot Cc: Bixby/Olsen Dube/Roschinger East Area Manager Ana Maria Seltenright Harry Engel CJ • 01-11 (PTD #1770570) TIO~ot ;_ Mi O1-11 A 000 3,000 z,ooo i.uoo + T~ -~ w -~ oa oa+ -+- ooon o~ ~ ~ WELL LQG S TRAAlSl19lTFAL PaoA~trive DiAynosnc SERVicES, ANC. To: AOGCC Christine Mahnken 333 W. 7th Ave Suite 100 Anchorage, Alaska 99501 (907) 793-1225 RE : Cased Hole/Open Hole/Mechanical Logs and /or Tubing Inspection(Caliper/ MTT) The technical data listed below is being submitted herewith. Please acknowledge receipt by returning a signed copy of this transmittal letter to the fallowing : BP Exploration (Alaska), Inc. Petrotechnical Data Center Attn: Joe Lastufka t 900 Benson Blvd. Anchorage, Alaska 99508 and ProActive Diagnostic Services, Inc. Attn: Robert A. Richey 130 West International Airport Road suite C Anchorage, AK 99518 Fax: (907) 245-8952 1) Leak Detection - WLD 04-Mar-10 01-11 2) Signed Print Name: C~~a~ 1 BL / EDE 50-029-20268-00 ~.` Date PROACTIVE DIAGNOSTIC SERVICES, INC., 130 W. INTERNATIONAL AIRPORT RD SUITE C, ANCHORAGE, AK 99518 PHONE: (907)245-8951 FAx: (907)245-88952 E-MAIL : _ ._____, _!' " __.__._ .___r WEBSITE ! _.~~ _~~ C:`,Document; and SzttingslDiane Williams~Desktop~Transmit_BP.docx MEMORANDUM To: Jim Regg P.I. Supervisor ~ ~ 1 ~ ~ f `'~ FROM: Jeff Jones Petroleum Inspector State of Alaska Alaska Oil and Gas Conservation Commission DATE: Tuesday, January 12, 2010 SUBJECT: Mechanical Integrity Tests BP EXPLORATION (ALASKA) INC O1-I1 PRUDHOE BAY UNIT 01-11 Src: Inspector NON-CONFIDENTIAL Reviewed By: P.I. Suprv Comm Well Name: PRUDHOE BAY UNIT 01-11 API Well Number: 50-029-20268-00-00 Inspector Name: Jeff Jones Insp Num: mitJJ100104135018 Permit Number: 177-057-0 Inspection Date: 12/29/2009 Rel Insp Num: Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. Well °1-11 Type Inj. ~' ~TVD sazl IA ~ - z19° zsoo ' zaoo z31o P.T.D l~zos7o TypeTest SPT Test psi ~ zllz OA 7s s6 a6 ss Interval REQvAR P/F F ~ Tubing aso aso a7o a7o NOtes• Repeat MIT: Operator notes slow IA x OA communication. 0.6 BBLS methanol pumped. Th is well failed to demonstrate the type of pressure stabilization the AOGCC expects and also fails BPXA's internal MIT policy. Tuesday, January 12, 2010 Page 1 of 1 MEMORANDUM To: Jim Regg ~~ ~ ~2t (i o P.I. Supervisor ~~ FROM: Jeff JOries Petroleum Inspector State of Alaska Alaska Oil and Gas Conservation Commission DATE: Tuesday, January 12, 2010 SUBJECT: Mechanical Integrity Tests BP EXPLORATION(ALASKA)INC 01-11 PRUDHOE BAY iJNIT O]-11 Src: Inspector NON-CONFIDENTIAL Reviewed By: P.I. Suprv ~~ Comm Well Name: PRUDHOE BAY UNIT 01-11 API Well Number: 50-029-20268-00-00 Inspector Name: Jeff Jones Insp Num: mitJJ100104134237 Permit Number: 177-057-0 Inspection Date: 12/29/2009 Rel Insp Num: Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. Well '. 01-11 ~Ype Inj. 1 w T~ sa71 IA ~ - --~ zoo ~ 2soo ~ --- z3so zz7o z19o P.T.D 1770570 TypeTest ~PT TCSt pSl 2117 A 37 93 79 78 78 Interval REQvAR P/F P / Tubing a7o a7o a7o a7o i aso Notes: Operator notes slow IA x OA communication. 3.9 BBLS methanol pumped. This well failed to demonstrate the type of pressure stabilization ~ the AOGCC expects and also fails BPXA's internal MIT policy. ;w~;,~~~ Tuesday, January 12, 2010 Page I of 1 AOGCC MITIA Forms for MPE~(PTD#1890170), MPE-07 (PTD#19100), 01-11 (P... Page 1 of 1 Maunder, Thomas E (DOA) From: NSU, ADW Well Integrity Engineer [NSUADWWeIIlntegrityEngineer@BP.com] Sent: Friday, January 01, 2010 11:30 AM To: Regg, James B (DOA); Maunder, Thomas E (DOA); Brooks, Phoebe L (DOA); Schwartz, Guy L (DOA) Cc: NSU, ADW Well Integrity Engineer Subject: AOGCC MITIA Forms for MPE-03 (PTD#1890170), MPE-07 (PTD#1910490), 01-11 (PTD#1770570), 01-24A (PTD#1921320), V-218 (PTD#2070400), Y-18 (PTD#1830290) Attachments: MIT MPU E-03 MPU E-07 12-11-09.x1s; MIT PBU 01-11 12-29-09.x1s; MIT PBU 01-24 12-16- 09.x1s; MIT PBU V-218 12-19-09.x1s; MIT PBU Y-18 12-14-09.x1s Hi Jim, Tom, Guy, and Phoebe, Please find the attached MITIA forms for the following wells: MPE-03 (PTD#1890170) MPE-07 PTD#19 0 01-11 #1770570)~dr- -24A (PTD#19 '~" V-218 (PTD#2070400) Y-18 (PTD#1830290) «MIT MPU E-03 MPU E-07 12-11-09.x1s» «MIT PBU 01-11 12-29-09.x1s» «MIT PBU 01-24 12-16-09.x1s» «MIT PBU V-218 12-19-09.x1s» «MIT PBU Y-18 12-14-09.x1s» Please let me know if you have any questions. Thank you, Toxin Roschinger (alt. Anna Dube) Well Integrity Coordinator Office (907) 659-5102 Cell (406) 570-9630 Pager (907) 659-5100 Ext. 1154 ~~°~~ ~° 4/26/2010 • 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: FIELD /UNIT /PAD: DATE: OPERATOR REP: AOGCC REP: BP Exploration (Alaska), Inc. Prudhoe Bay /PBU / DS-01 12/29/09 _ Taylor Wellman Jeff Jones Packer Depth Pretest Initial 15 Min. 30 Min. Well 01-11 Type Inj. W TVD 8,471' Tubing 470 470 470 470 Interval V P.T.D. 1770570 Type test P Test psi 2117.75 Casing 200 2,500 2,380 2,270 P/F F Notes: 1-year MITIA to 2500 psi for AA. OA 37 93 79 74 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 01-11 12-29-09 (2).xls UNDER EVALUATION: 01-11-~D #1770570) Eval IAxOA communion post glan... Page 1 of 1 Regg, James B (DOA) From: NSU, ADW Well Integrity Engineer [NSUADWWeIIlntegrityEngineer@BP.com] ~~~~~ ~Z,' ~ ~ ~ Sent: Wednesday, December 30, 2009 9:05 PM To: Regg, James B (DOA); Maunder, Thomas E (DOA); GPB, FS1 DS Ops Lead; GPB, FS1 OTL; GPB, Area Mgr East (FS1/2/COTU/Seawater); NSU, ADW Well Operations Supervisor; Rossberg, R Steven; Engel, Harry R; GPB, Wells Opt Eng; GPB, EOC Specialists; GPB, Optimization Engr; Schwartz, Guy L (DOA); Brooks, Phoebe L (DOA) Cc: Seltenright, Ana Maria Subject: UNDER EVALUATION: 01-11 (PTD #1770570) Eval IAxOA communication post gland nut repair All, s" Well 01-11 (PTD #1770570) is a sea water injection that has an AA for IAxOA communication. On 12/29/09, an AOGCC witnessed MITIA failed for compliance testing. During the test four gland nuts were noticed leaking on the inner casing spool. On 12/30/09, the gland nuts were tightened mitigating the leak. The well has been reclassified as Under Evaluation to perform an MITIA while online to evaluate integrity after the leaking gland nuts were tightened. The plan forward is as follows: 1. Wellhead: Tighten gland nuts -DONE 2. DHD: MIT-IA to 2500 psi, LLR if fails 3. DHD: AOGCC witnessed MITIA to 2500 psi Please call with any questions or concerns. Thank you, Toxin Roschinger (alt. Anna Dube) Well Integrity Coordinator Office (907) 659-5102 Cell (406) 570-9630 Pager (907) 659-5100 Ext. 1154 ~~~ ~ ~~~ 12/31/2009 UNDER EVALUATION: 01-1~PTD #1770570) for TxIA communicatj~n Regg, James B (DOA) Page 1 of 1 From: NSU, ADW Well Integrity Engineer [NSUADWWeIIlntegrityEngineer@BP.com] ~~~~r ~ (~ ~~ Sent: Tuesday, May 12, 2009 1:03 PM To: Regg, James B (DOA); Maunder, Thomas E (DOA); DOA AOGCC Prudhoe Bay; GPB, FS1 DS Ops Lead; GPB, FS1 OTL; GPB, Area Mgr East (FS1/2/COTU/Seawater); NSU, ADW Well Operations Supervisor; Rossberg, R Steven; Engel, Harry R; GPB, Wells Opt Eng; GPB, EOC Specialists; GPB, Optimization Engr Cc: Holt, Ryan P (ASRC); Seltenright, Ana Maria; Quy, Tiffany; NSU, ADW Well Integrity Engineer Subject: UNDER EVALUATION: 01-11 (PTD #1770570) for TxIA communication Attachments: 01-11 TIO 12-May-09.ZIP; 01-11.pdf All, Well 01-11 (PTD #1770570) is a sea water injection well that has shown signs of TxIA communication. On 05/09/09 the TIO's were 500/500/40 psi~an-d tTie f~pressure was bled to 240 psi. Overnight the lA pressure has increased to match injection pressure with TIO's of 500/510/40 psi. To check for thermal expansion causing the IA repressurization the IA was bled to 0 psi on 05/11/09. Again the IA pressure built to match the tubing injection pressure overnight, The well has been reclassified as Under Evaluation until an IT-IA can a con uc ed to confirm tubing integrity. Please shut in the well as soon as possible. The plan forward for the well is as follows: 1. Wellhead Techs: PPPOT-T & IC 2. Fullbore: MIT-IA to 3000 psi A TIO plot and wellbore schematic have been included below. «01-11 TIO 12-May-09.ZIP» «01-11.pdf» Please contact me with any questions. Thank you, Taylor Wellman filling in for Anna Dube/Andrea Hughes Office: 659-5102 ~i'"1~~ ~`~~-`` ~~ I~'~ ~' ~i f'vl Pager: 659-5100 x 1154 6/17/2009 PBU 01-11 PTD 177-057 5/ 12/2009 12 Month TIO Pressures a.ooD • 3A00 2,000 1,OOD f Tbg ~ IA -~- OA OOA ~ OOOA On • 05/19/0"0 06!19!08 07,'20/03 03:20108 09;20108 10121/08 11/21/08 12!22108 01!22/09 02.22109 03/25/09 04!25109 PBU 01-11 PTD 177-057 5/12/2009 6 Month TIO Pressures 4,~0 3,D00 2,OOD 1,000 ~ Tbg ^ IA +- OA ODA OOOA On • • 11/2210'0' 12106!0"o 12/20/0"a 01/03/03 O1/17/03 01131:03 02/14/09 02/2^0:03 03/14!03 0312oi03 04/11/09 04/25/03 05/03/03 TREE = GRAY 01-11 SAF OTES: WELLHEAD = GRAY ACTUATOR = AXELSON KB. ELEV = 73' BF. ELEV = KOP = 3200' Max Angle = 48 @ 6200' datum MD = 10364' datum TV D = 8800' SS 13-318" CSG, 72#, N-80, ID = 12.347" ~-f 2713' f Minimum ID = 0.75" a~? 9964' HES LIMITING CHOKE 5-112" TBG-NPC, 17#, N-80, .0232 bpf, ID = 4.892" TOP OF 4-1(2" TBG-NPC 9752' --~ 5-1/2" BAKER SLIDING SLV ( 9812' 5-112" BAKER R LANDING NIP, ID = 4.472" 9894' 9-5/8" X 5-1/2" BAKER SAB PV(R 9923' 5-112" X 4-1/2" XO 99$4' -~ 4-1/2" BAKER R LANDING NIP, ID = 3.759" I 9964' HES LIMITING CHOKE (04/17/06), ID = 0.75" 4-1/2" TBG-NPC, 12.6#, N-80, 10024' 10024' -~4-112" TUBING TAIL .0152 bpf, ID = 3.958" 1002p~ ELMD TT LOGGED DATE UNKNOWN? PERFORATION SUMMARY REF LOG: BHC5 ON 10/26/77 ANGLE AT TOP PERF: 32 @ 10238' Note: Refer to Production DB for historical perf data SIZE SPF INTERVAL Opn/Sqz DATE SEE PAGE 2 FOR PERF BREAKDOWN 10395' 10410' PBTD 9-518" CSC, 47#, N-80/RS-95, ID = 8.681" ~TD~ I 10535' I i 11010' i DATE REV 8Y COMMENTS DATE REV BY COMMENTS 11/04177 ORIGINAL COMPLETION 08/27/06 ???/TLH HES LIMffED CHOKE (04117!06) 11/04177 LAST WORKOVER 05/10/07 RDW/PAC WANERSFTY NOTE DELETED 03/16/01 RN/TP CORRECTIONS 12/07/08 WKiSV CSG CORRECTIONS 08!13/01 ATD/TP ADD CMT /SAND DEPTHS 08/13/01 ?/KAK ADPERFS 12!12/03 TJP/TLH WANER SAFEfY NOTE TOP OF CEMENT (15') I TOP OF SAND ! 125') PRUDHOE BAY UNIT WELL: 01-11 I PERMIT No: 1770570 'i API No: 50-029-20268-00 SEC 8, T10N, R15E, 1381.51' FEL & 4248.53' FNL BP Exploration (Alaska) 220$' -i 5-1/2" BAKER PFVE SSSV NIP, ID = 4.562" I 233T 9-5/8" FOC 2353' 9-518" FOC '~ a~ -7 ~ • PERFS PERFORATION SUMMARY REF LOG: BRCS ON 10/26/77 A NGLE AT TOP PERF: 32 @ 10238' Note: Refer to Production DB for historical pert data SIZE SPF INTERVAL Opn/Sqz DATE 2-718" 6 10238 - 10264 O 08/13/01 2-718'" 6 10270 - 10276 O 08/13/01 2-7/8" 6 10286 - 10320 O 08/13/01 2-7/8" 6 10330 - 10354 O 08/13!01 3-3/8" 4 10370 - 10380 O 06114(94 3-318" 4 10380 - 10394 S 01114!94 3-318" 1 10420 - 10425 C 09/12/90 3-3/8" 1 10438 - 10440 C 09/12/90 NA 0 10450 - 10462 C 02104(78 3-3/8" 4 10462 - 10472 C 06/04/93 3-318" 4 10482- 10495 S 11/13!89 3-318" 4 10495 - 10513 S 06/05!94 3-3/8" 4 10517 - 10520 S 11/13!89 3-3/8" 4 10530 - 10535 S 11/13/89 3-3/8" 4 10535 - 10545 S 06/05/94 3-318" 4 10545 - 10555 S 11/13!89 3-3/8" 4 10555 - 10570 S 06126/93 3-3/8" 4 10575 - 10585 S 06/26/93 3-3/8" 4 10591 - 10601 S 06/26/93 DATE REV BY COMMENTS DATE REV BY COMMENTS 11!04/77 ORIGINAL COMPLETION 08/27/06 ???/TLH HES LIMITED CHOKE (04/17106) 11/04/77 LAST WORKOVER 05/10/07 RDW/PAG WANERSFTY NOTE DELETED 03/16!01 RNlTP CORRECTIONS 12!07108 WKiSV CSG CORRECTIONS 08/13101 ATD/TP ADD CMT/SAND DEPTHS 08/13!01 ?/KAK ADPERFS 12!12/03 TJP/TLH WANER SAFETY NOTE PRUDHOE BAY UNff WELL: 01-11 PERMIT No: r'1770570 API No: 50-029-2026$-00 SEC 8, T10N, R15E, 1381.51' FEl. & 4248.53' FNL BP Exploration (Alaska) OPERABLE: 0-11 (PTD #1770570) Completed compliance testing Page l of 2 • Regg, James B (DOA) From: Grimaldi, Louis R (DOA) Sent: Sunday, December 21, 2008 4:26 PM To: Regg, James B (DOA) Subject: FW: OPERABLE: 0-11 (PTD #1770570) Completed compliance testing Attachments: MIT PBU DS1-11 12-18-08 LG.snp; MIT PBU DS1-11 12-20-08 LG.snp Hi Jim, Thought you might like to see these. The first test we pumped five barrels before the IA pressure started to rise. I spoke with the FuliBore rep (Ron Wilson) and asked him where he would be comfortable (pressure-wise} to leave the annulus to allow fluid/gas to swap. Ron said about 500 psi. I let them pump another barrel and the pressure was up to 400 psi and we stopped there. The welt was pretty cool and they said they would keep an eye on it for thermal effect. They bled the gas off the next day. The second test went fine with 3.9 bbl's pumped and ~~ approximately the same returned. Let me know if you have any questions, Lou From: NSU, ADW Well Integrity Engineer [mailto:NSUADWWeIIIntegrityEngineer@BP.com] Sent: Sunday, December 21, 2008 1:46 PM To: Regg, James B (DOA); Maunder, Thomas E (DOA); DOA AOGCC Prudhoe Bay; GPB, FS1 DS Ops Lead; GPB, FS1 OTL; GPB, Area Mgr East (FSl/2/COTU/Seawater); NSU, ADW Well Operations Supervisor; Rossberg, R Steven; Engel, Harry R; GPB, Wells Opt Eng; GPB, EOC Specialists; GPB, Optimization Engr Cc: Holt, Ryan P (ASRC); Seltenright, Ana Maria; Quy, Tiffany; NSU, ADW Well Integrity Engineer Subject: OPERABLE: 0-11 (PTD #1770570) Completed compliance testing Hi all, Well 01-11 (PTD #1770570} has been reclassified as Operable. The well passed an AOGCC witnessed MITIA for AA compliance testing on 12(20/08. The MITEA form will be sumitted to the AOGCC at the end of the manth. Please let us know if there are any questions. Thank you, Anna ~u6e, ~'.~. Well Integrity Coordinator GP13 Wells Group Phone: (907} 659-5102 Pager: (907) 659-5100 x1154 From: NSU, ADW Well Integrity Engineer Sent: Friday, November 21, 2008 2:04 PM a~?~~~~:~4, lvl ~`, n t ,~ `l_ ~l; To: 'Regg, James B (DOA)'; 'Maunder, Thomas E (DOA)'; 'DOA AOGCC Prudhoe Bay'; GPB, FSl DS Ops Lead; GPB, FSl OTL; GPB, Area Mgr East (FSl/2/COTU/Seawater); NSU, ADW Well Operations Supervisor; Rossberg, R Steven; Engel, Harry R; GPB, Wells Opt Eng; GPB, EOC Specialists; GPB, Optimization Engr Cc: Holt, Ryan P (ASRC); NSU, ADW Well Integrity Engineer; Seltenright, Ana Maria; Quy, Tiffany Subject: UNDER EVALUATION: 0-11 (PTD #1770570) to place well on injection for compliance testing Hi all, 2/25/2009 OPERABLE: 0-11 (PTD #1770570) Completed compliance testing Page 2 of 2 • • Well 0-11 {PTD #1770570) is currently approved for injection with IAxOA communication under AA 4E.011. This well has been shut-in since 4/18/07 waiting for repairs. As such, the well does not have a current AA compliance MITIA. The well has been reclassified as Under Evaluation and placed on a 28-day clock so that the well may be place on injection and an AOGCC witnessed MITIA can be obtained. The plan forward for the well is as follows: 1. Well Integrity Coordinator: Reclassify well as Under Evaluation -DONE 2. Operations: Place well on injection 3. Fullbore: AOGCC MITIA for AA compliance A wellbore schematic has been included for reference. Please call with any questions. Thank you, Well Integrity Coordinator GPB Wells Group Phone: {907} 659-5102 Pager: {907} 659-5100 x1154 2/25/2009 MEMORANDUM ~ ~ State of Alaska Toy Jim Regg P.I. Supervisor Alaska Oil and Gas Conservation Commission DATE: Saturday, December 20, 2008 SUBJECT: Mechanical Integrity Tests BP EXPLORATION (ALASKA) INC FROM: LG Petroleum Inspector OI-il PRUDHOE BAY iJNIT O]-11 Src: Inspector NON-CONFIDENTIAL Well Name: PRUDxoE BAY tllvrr o1-11 API Well Number: so-029-zozb8-oo-0o Inspector Name: LG Insp Num• mitLG081220134131 Permit Number 177-057-0 Inspection Date 12/20/2008 Rel Insp Num: Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. 01-11 Well ~ ---- Type Inj. ~' TVD sa71 IA~ zso zslo 2465 ~ zabo P.T.DI l~~os~o TypeTest SPT ~Test psi zslo pA ao bo bo I so - Interval Other (describe in per, Pass `~ Tubing -__.___-_ zao zao zao zao n .. Notes: Retest of well due to large volume pumped _____ . last test (see mitLG08'1218110427). Bled gas pressure from where left (400 psi) to 250 and got fluid back. This test went very well Saturday, December 20, 2008 Page 1 of 1 MEMORANDUM ~ ~ State of Alaska Alaska Oil and Gas Conservation Commission To~ Jim Regg P.I. Supervisor DATE: Thursday, December 18, 2008 SUBJECT: Mechanical Integrity Tests BP EXPLORATION(ALASKA)INC FROM: j,G Petroleum Inspector 01-11 PRUDHOE BAY UNIT 01-11 Src: Inspector NON-CONFIDENTIAL Well Name• PRUDHOE BAY UNIT O1-I 1 Insp Num• mitLG08 12 1 8 1 10427 Rel Insp Num: API Well Number: 50-029-20268-00-00 Permit Number 177-057-0 Inspector Name• LG Inspection Date 12/18/2008 Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. Well 01-11 yT pe Inj. w TVD say] -- IA 0 -- P.T.D 177os7o TypeTest SPT Test psi 2soo pA ao Interval Required by Variance p/ji Incomplete Tubing 600 Notes: 0 psi at surface, pumped 5 bbl's before IA pressure started to rise. Pumped 1 more bbl to raise 400 psi. Instructed Ron Wilson to let fluid/gas swap and bleed gas, will test later this week. Thursday, December 18, 2008 Page 1 of 1 MEMORANDUM To: Jim Regg / P.I. Supervisor ~`` I/ ~/ZL%c)~ State of Alaska • Alaska Oil and Gas Conservation Commission DATE: Monday, December 29, 2008 SLIBJECT: Mechanical lntegrity Tests BP F.XPLORA'IION (ALASKA) [NC 01-I1 PRUDHOE BAY UNIT OI -1 1 FROM: Lou Grimaldi Petroleum Inspector Well Name: PRUDHOE BAY UNIT Ol-I 1 Insp Num: mitLG081220134131 Rel Insp Num: NON-CONFIDENTIAL API Well Number: so-o29-20268-00-00 Permit Number: 177-057-0 Packer Depth Well of I I '- , . _ _ . ,_ i YPe In'. w ; TVD sail ~ IA _. P.T. ;` I~~os~o TYPeTest ~ sPT Test psi __ Zslo ~ OA . _.: g Interval orxi;R p/F P ~ Tubin NOteS: Rer,. test of well due to large volume pumped fast test (see mitLG08 t back. This test went very well. Pretest zso ao zao 218110427) Reviewed By: P.I. Suprv~J ~',fL- Comm Inspector Name: Lou Grimaldi Inspection Date: 12izoizoo8 Initial 15 Min. __ zslo ,' ,a6s 60 .. 60 _ -- 240 ,40_ Bled gas pressure from w ~, Monday, December 29, 2008 Src: Inspector 30 Min. 45 Min. 60 Min. _. 2460 ~` 60 240 here left (400 psi) to 250 and got fluid Page l of I MEMORANDUM To: Jim Regg I JZ ~ ~V~ P.I. Supervisor ~~~ I FROM: LOU Grimaldi Petroleum Inspector Well Name: PRUDHOE BAY UNIT 01-1 1 Insp Num: mitLG08 121 8 1 10427 Rel Insp Num: Packer _. _ _.. -- .Well ~ of-u Type Inj. W_. TVD 1770570 - ' P.T. TypeTest SPT Test psi Interval REQVAR p~F I _._ _. Notes: 0 Psi at surface, pumped 5 bbl's before IA pi swap and bleed gas, will test later this week. Monday, December 29, 2008 Src: Inspector Reviewed By: P.I. Suprv ~JQ-- Comm Inspector Name: Lou Grimaldi Inspection Date: 12/IS/zoos NON-CONFIDENTIAL API Well Number: so-oz9-2o2~s-oo-oo Permit Number: 177-057-0 Depth __ ._8471 /! IA zsoo .~ OA ~' Tubing' essure started to rise. P State of Alaska• Alaska Oil and Gas Conservation Commission DATE: Monday, December 29, 2008 S[JBJECT: Mechanical Integrity Tests BP EXPLORATION (ALASKA) INC 01-11 PRC!DHOF. BAY UNIT 01-I I Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. 0 _ _ ~. _ 40 _ amped 1 more bbl to raise 40U psi. Instructed Ron Wilson to let fluid/gas Page I of 1 UNDER EVALUATION: 0-11 (PTD #1770570) to place well on injection for compliance testing Page 1 of 1 • i Regg, James B (DOA) From: NSU, ADW Well Integrity Engineer [NSUADWWeIIlntegrityEngineer@BP.com] j ~ ~I~Z~(2~u~ Sent: Friday, November 21, 2008 2:04 PM Z , To: Regg, James B (DOA); Maunder, Thomas E (DOA); DOA AOGCC Prudhoe Bay; GPB, FS1 DS Ops Lead; GPB, FS1 OTL; GPB, Area Mgr East (FS1/2/COTU/Seawater); NSU, ADW Well Operations Supervisor; Rossberg, R Steven; Engel, Harry R; GPB, Wells Opt Eng; GPB, EOC Specialists; GPB, Optimization Engr Cc: Holt, Ryan P (ASRC); NSU, ADW Well Integrity Engineer; Seltenright, Ana Maria; Quy, Tiffany Subject: UNDER EVALUATION: 0-11 (PTD #1770570) to place well on injection for compliance testing Attachments: 01-11.pdf Hi all, Well 0-11 (PTD #1770570) is currently approved for injection with IAxOA communication under AA 4E.011. This well has been shut-in since 4/18/07 waiting for re ' s. As such, the well does not have a current AA compliance MITIA. The well has been reclassified as Under Evaluation and placed on a 28-day clock so that the well may be place on injection and an AOGCC witnessed MITIA can be obtained. The plan forward for the well is as follows: 1. Well Integrity Coordinator: Reclassify well as Under Evaluation -DONE 2. Operations: Place well on injection 3. Fullbore: AOGCC MITIA for AA compliance A wellbore schematic has been included for reference. «01-11.pdf» Please call with any questions. /' ~~~~~ ~~~`~ ~ ~ SOD 11/24/2008 TREE = GRAY WELLHEAD = GRAY ACTUATOR = AXELSON KB. ELEV = 73' BF. ELEV = KOP = 3200' Max Angle = 48 @ 6200' Datum MD = 10364' Datum TV D = 8800' SS 13-318" CSG, 72#, N-80, ID = 12.347" 2713' Minimum ID = 0.75" @ 9964' HES LIMITING CHOKE 5-112" TBG-NPC, 17#, N-80, .0232 bpf, ID = 4.892" j-j 9894' TOP OF 4-1;2" TBG-NPC 9895' 4-1/2" TBG-NPC, 12.6#, N-80, ~-~ X0024' .0152 bpf , ID = 3.958" PERFORATION SUMMARY REF LOG: BRCS ON 10!26177 ANGLE AT TOP PERF: 32 @ 10238' Note: Refer to Production DB for historical perf data SIZE SPF 9NTERVAL OpnlSgz DATE SEE PAGE 2 FOR PERF BREAKDOWN 2208' ~-'~ 5-1;2" BAKER PFVE SSSV NIP, ID = 4.562" E~ I I 9752-~ 5-1/2" BAKER SLIDING SLV 9$12' S-1t2" BAKER R LANDING NIP, ID = 4.472" 9894' 9-518" X 5-112" BAKER SAB PKR 9928' 5-1/2" X 4-112" XO M 9964' 4-112" BAKER R LANDING NIP, ID = 3.759" 9964' HES LIMITING CI-#OKE (04117106), ID = 0.75" 10024' 4-112" TUBING TAIL 10020' ELMD TT LOGGED DATE UNKNOWN? 10395' -i TOP OF CEMENT (15') 10410' TOP OF SAND {125') PBTD 10535 9-5/8" CSG, 47#; N-801RS-95; ID = 8.681" 109$$' TD 11010' DATE REV BY COMMENTS DATE REV BY COMMENTS 11!04!77 ORIGINAL COMPLETION 08!27106 ???lTLH HES LIMITED CHOKE (04!17!06) 11/04177 LAST WORKOV ER 05/10/07 RDW/PAG WA V ER SFTY NOTE DELETED 03/16/01 RN{TP CORRECTIONS 08/13/01 A TD/TP ADD CMT l SA ND DEPTHS 08i13i01 ?(KAK ADPERFS 12'12!03 TJP/TLH WAIVER SAFETY NOTE PRUDHOE BAY UNff WELL: 01-11 PERMIT No: 1770570 API No: 50-029-20268-00 SEC 8, T1 ON, R15E, 1381.51' FEL & 4248.53' FNL BP Exploration (Alaska) . SAF Y NOTES: 01-11 • 01-11 • PERFS PERFORATION SUMMARY REF LOG: BRCS ON 10/26/77 ANGLE AT TOP PERF: 32 @ 10238' Note: Refer to Production DB for historical perf data SIZE SPF INTERVAL OpnlSgz DATE 2-718" 6 10238 - 10264 O 08113(01 2-718" 6 10270 - 10276 O 08/13/01 2-718" 6 10286 - 10320 O 08113f01 2-7/$" 6 10330 - 10354 O 08113/01 3-3f8" 4 10370 - 10380 O 06/14/94 3-3/8" 4 10380 - 10394 S 01!14!94 3-318" 1 10420 - 10425 G 09(12190 3-3f8" 1 10438 - 10440 C 09/12/90 NA 0 10450 - 10462 C 02104/78 3-318" 4 10462 - 10472 C 06!04!93 3-3/8" 4 10482 - 10495 S 11f13t89 3-3f8" 4 10495 - 10513 S 06!05;94 3-318" 4 10517 - 10520 S 11/13/89 3-318" 4 10530 - 10535 S 11/13!89 3-318" 4 10535 - 10545 S 06(05/94 3-318" 4 10545 - 10555 S 11!13/89 3-3l8" 4 10555 - 10570 S 06(26/93 3-3J$" 4 10575 - 10585 S 06126/93 3-318" 4 10591 - 10601 S 06(26193 DATE REV BY COMMENTS DATE REV 8Y COMMENTS 11/04177 ORIGINAL COMPLETION 08i27r06 ???ITCH HES LIMtTEDCHOKE{04117106} 11104177 LAST WORKOVER 05110107 RDW(PAG WANER SFTY NOTE DELETED 03!16(01 RN/TP CORRECTIONS 08/13!01 RTDtTP ADD CMT /SAND DEPTHS 08/13101 ?tKAK ADPERFS 12!12/03 TJPfTLH WANER SAFELY NOTE PRUDHOE BAY UNIT WELL: 01-11 PERMff No: 1770570 API No: 50-029-20268-00 SEC 8, T10N; R15E, 1381.51' FEL & 424$.53' FNL BP Exploration {Alaska) 01-11 (PTD #1770570) MITrA a.ns Regg, James B (DOA) . Page 1 of 1 From: Regg, James 8 (DOA) üïm.regg@alaska.gov] Sent: Tuesday, September 18,20078:18 AM To: NSU, ADWWelllntegrity Engineer Cc: AOGCC Prudhoe; Maunder, Thomas E (DOA) Subject: RE: 01-11 (PTD #1770570) MITIA Options 'R-r 1 q I/ø/ D 7 Since we get a monthly TIO plot for this well, it is acceptable to hold off on the MIT required per AIO 4E.011 until the well is returned to injection service and thermally stable. FYI, the due date for the MIT is December 18 according to the AA. Jim Regg AOGCC 333 W.7th Avenue, Suite 100 Anchorage, AK 99501 phone: 907-793-1236 fax: 907-276-7542 From: NSU, AOW Well Integrity Engineer [mailto:NSUAOWWellIntegrityEngineer@BP.com] Sent: Monday, September 17, 2007 10:57 AM To: Regg, James B (OOA) Subject: 01-11 (PTO #1770570) MmA Options SCANNED SE? 2 1 2007 Jim, Well 01-11 is under AA #4E.011 for IAxOA communication and is currently shut-in and will be shut-in until the end of summer 2008 when the new injection line is complete. The AA requires an annual MITIA which is due on 09/19/07. Would the AOGCC prefer a cold test to maintain compliance with the AA and a re-test upon returning to service or is one test when the well is brought back online acceptable within the standards of the AA? Please call with any questions or concerns. Thank you, Andrea Hughes Well Integrity Coordinator Office: (907) 659-5102 Pager: (907) 659-5100 x1154 9/18/2007 01-11 (PTD #1770570) Internal Waiver Cancellation - Normal Well . . 07 All, An internal waiver was issued for IAxOA communication on well 01-11 (PTD #1770570) on 11/24/03. The well passed an MITIA on 09/19/06 proving two comepentent barriers. Under the new WI System Policy set to take effect on June 1,2007, 01-11 will be Operable. The Administrative Approval for slow IAxOA 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 wellhouse. Thank you, Andrea Hughes Well Integrity Coordinator Office: (907) 659-5102 Pager: (907) 659-5100 x1154 &'~NED MAY 1 6 Z007 1 of 1 5/9/20073:30 PM - ~ - `_ - '- S~R,9H P~L/Al, GOIlERlVOR ~~ 333 W ?thAVENUE, SUITE 100 ~9 yy~~~~~w*~ ggp~AApp~~v~ ~y ~~®~ ~o~A~a'a1~9~56~18~®A~ ~® ~ ANCHORAGE, ALASKA 9950?-3539 y PHONE (907) 279-?433 SAX --(90T; 276-7542 ADMINISTRATIVE APPROVAL AIO 4E.011 titr. Steve Rossberg Wells Manager BP Exploration (Alaska) Inc. P.O. Box 196612 Anchorage, AK 99~ 19-6612 "~`~ ~ JfiN ~ 200 RE: PBU 01-11 (PTD 177-057) 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. PBU 01-11 exhibits slow IA x OA pressure communication when operating. AOGCC finds that BPXA has elected to perform no corrective action at this time on PBU O 1-11. The Commission fiuther fords that, based upon reported results of BPXA's diagnostic procedures, PBU O l -11 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 O 1-11 is conditioned upon the following: 1. Injection is Limited to water only. 2. BPXA shall record wellhead pressures and injection rate daily; 3. BPXA shall submit to the AOGCC a monthly report of well pressures and injection rates; 4. BPXA shall perform an annual NIIT-I a to 1.2 times the maximum anticipated well pressure, the anniversary date of which shall be this approval's effective date; ~. BPXA shall limit the well's OA pressure to 1000 psi; • AIO 4E.01 l December 18, 2006 Page 2 of 2 6. BPXA shall immediately shut in the well and notify the A®GCC if there is any change in the well's mechanical condition; and 7. After well shut in due to a change in the well°s mechanical condition, A~OGCC approval shall be required to restart injection. Please note that PBU O1-11's status remains 1 WINJ. As provided in AS 31.0.0$0, 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. at a e, Alaska and dated December 18, 2006. o an aniel T. Seamount, Jr. Commissioner .~ - . _ ,. ~ °s ti. e ~ r~} y ~ 1` j~~,~ - q. ~,: ~ ~ r , ~ -:~ 2r ~ , ~-. • ~.~ '~. { ~ F ~ _ 1 ~ ~~ ~ RE: 01-11 (PTD #1770570) . . Hi Jim. We are working on the AA, should have it in the mail later this week. Joe Anders, P.E. Well Integrity Coordinator, BP Exploration, (Alaska) Inc. Work: 1-907-659-5102 Mobile: 943-1154 Pager: 659-5100,x1154 Email: NSUADWWelllntegrityEn¡:¡ineertâ!bp.com 8CANNEÐ c From: James Regg [mailto:jim_regg@admin.state.ak.us] Sent: Monday, October 02,2006 11:43 AM To: Hughes, Andrea Cc: Winton Aubert (E-mail); Bob Fleckenstein (E-mail); N5U, ADW Well Integrity Engineer; Admin AOGCC Prudhoe Bay Subject: Re: 01-11 (PTD #1770570) PBU 01-11 This well has an interesting history and apparently not the first time it has been evaluated for IAxOA: 6/6/2003 - BP notified AOGCC that PBU 01-11 is exhibiting IAxOA communication; restricting to PWI only and 1000 psi in IA and OA; TIO pressure plot provided with email notice clearly shows the IA and OA equalized; source onA pressure unexplained 12/612003 - BP forwarded to AOGCC the BP internal waiver for PBU 01-11; well has slow TxIA, apparently passed MITIA and MITOA 9/1812006 - BP notified that PBU 01-11 is exhibiting repressurization (not clear if this was in response to periodic pressure bleeds or after well SI during August). When can we expect BP's request regarding a well integrity variance for injector PBU 01-11 (TxIA and IAxOA)? Jim Regg AOGCC --------------------------------------------------------------------------- lof2 10/24/2006 9: 13 AM nC. UI-IllP IV #11/0570) . . Hughes, Andrea wrote: Jim, Winton and Bob, Please see the attached MIT forms for the following wells. NGI-01 (PTD #1750480) MITIA and MITOA for variance, witness by AOGCC representative Chuck Scheve NGI-10 (PTD #1760690) MITIA and MITOA for variance, witness by AOGCC representative Chuck Scheve. The plan forward is to change out the tree and repeat the MITIA. 01-11 (PTD #1770570) MITIA for evallAxOA communication AGI-05 (PTD #1930020) MITIA for variance, witness by AOGCC representative Chuck Scheve NGI-13 (PTD #1780910) MITrA for variance, witness by AOGCC representative Chuck Scheve. The plan forward is to perform SSSV work, reset the IBP, and repeat the MITIA. P-03 (PTD #1972280) MITT and MITIA for eval TxlA communication. Both tests passed, indicating no communication to liquid. The plan forward is to pursue a variance for slow TxlA communication. «MIT PBU NGI-01, 10 09-18-06.xls» «MIT PBU 01-11 09-19-06.xls» «MIT PBU AGI-05 09-19-06.xls» «MIT PBU NGI-13 09-18-06.xls» «MIT PBU P-03 09-25-06.xls» Thank you, Andrea Hughes (Filling in for Anna Dube) Well Integrity Engineer Office: (907) 659-5102 Pager: (907) 659-5100 x1154 20f2 10/24/2006 9: 13 AM . . I"" \:'.1; " -'-/ u~.....,:-- ./'Î J Vi... . f . V 1.7/; /1 <'-.,'- . i " L 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 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION Mechanical Integrity Test OPERA TOR: FIELD / UNIT / PAD: DATE; OPERA TOR REP: AOGCC REP: BP Exploration (Alaska), Inc. Prudhoe Bay / PBU / OS 01 09/19/06 Joe Anders t17-0S7 Packer Depth Pretest Initial 15 Min. 30 Min. Well101-11 I Type Inj. I N TVD I 8,471' Tubing 2,290 2,360 2,360 2,360 Interval 0 P.T.D.11770570 I Type test I P Test psi! 2117.75 Casing 2,050 3,000 2.960 2,940 P/F/ P Notes; MITIA for evallAxOA communication. OA 650 820 840 840 Well' I Type Inj. TVD I Tubing Interval I P.T.D.I ! Type test I Test psi! Casing P/F! Notes: OA Weill I Type Inj.1 I TVD I Tubing I Interval I P.T.D.I I Type test I I Test psi Casing I P/F Notes: OA I Weill I Type Inj. I TVD I Tubing I I Interval p.T.D.1 I Type test I I Test psi Casing I I P/F Notes: OA I I Weill I Type Inj.1 TVD , Tubing Interval P.T.D.I I Type test I Test psi Casing I P/F Notes: OA TYPE INJ Codes D = Drilling Waste G = Gas ¡ :: Industrial Wastewater N " Not Injecting W = Water MIT Report Form BFL 9/1/05 TYPE TEST Codes M ::: Annulus Monitoring P " Standard Pressure Test R:::; Internal Radioactive Tracer SUNey 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) 2006-0919_MIT_PBU_01-11.xls U'J""'''VU "",U V 1 -. . \" "LJ . / I VJ / V} u," l'..c;-'eUllLdl1VIl Helloal!. Injection well 01-11 (PTD 1770570) is exhibiting indications of IA repressurization. Well pressures on 9/17/06 are 81/1700/500. /17-057 Planned actions: 1. F: MITIA to 3000 psi Attached is a wellbore schematic and annulus pressure plot. Please call with any questions. «01-11 Ann Press Plot.jpg» «01-11.pdf» Joe Anders, P.E. ~~~k':n~~g~ir-6~~~~~i~~tor, BP Exploration, (Alaska) Inc. ~CANNED SEP 2 l2' 2005 Mobile: 943-1154 Pager: 659-5100, x1154 Email: NSUADWWelllntegrityEngineer@bp.com Content-Description: 01-11 Ann Press Plot.jpg 01-11 Ann Press Plot.jpg Content-Type: image/jpeg Content-Encoding: base64 Content-Description: Ol-l1.pdf 01-11.pdf Content-Type: application/octet-stream Content-Encoding: base64 I of 1 9/22/2006 8:46 AM TREE = WELlHEA D = ACTUATOR = KB. ELEV = SF. ELEV = KOP= Max Angle = Datum MD = Datum TVD = GRAY GRAY AXELSON 73' 3200' 48 @ 6200' 10364' 8800' SS 13-3/8" CSG, 72#, N-80, 10 = 12.347" I Minimum ID = 0.75" @ 9964' "HE5LfMlTrNGCHOKE"-- 5-1/2'" TBG-NPC, 17#, N-80, .0232 bpf, 10 "4.892" , TOPOF 4-1/2" TBG-NPC I 4-1/2"' TBG-NPC, 12.6#, N-80, .0152 bpf. ID = 3.958" . SAFAoTES: ***SLOW IAxOA COMM. OPERATING LlMI_AX lAP == 2000 PSI, MAX OAP == 1000 PSI (11/24/03 WAIVER)*** 01-11 . 2208' -i 5-1/2" BAKER PFVE SSSV NIP, 10" 4.562" I 10024' I I 9752' 5-1/2" BAKER SLIDING SLV I 5-1/2" BAKER R LANDING NIP, ID = 4.472" 9894' -i 9-5/8" X 5-1/2" BAKER SAB PKR I 9923' -i 5-1/2"' X 4-1/2"' XO I 9964' -i 4-1/2" BAKER R LANDING NIP, ID" 3.759" I 9964' H HES LIMITING CHOKE (04/17/06). ID = 0.75" I 10024' - 4-112" TUBING TAIL I 10020' H ELMD TT LOGGED DA TE UNKNOWN? TO Pf5UDHOE SA Y UNrr WELL: 01-11 ÆRMrr No: ~I 770570 API No: 50-029-20268-00 SEC 8. T10N, R15E, 1381.51' FEL & 4248.53' FNL ÆRFORA TION SUMMARY REF LOG: BHCS ON 10/26/77 ANGLEATTOPÆRF: 32@ 10238' Note: Refer to Production DB for historical perf data SIZE SPF INTERVAL Opn/Sqz DA TE SEE PAGE 2 FOR PERF BREAKDOWN IPBTD 9-5/8" CSG, 47#, N-80/RS-95, ID = 8.681"' DATE REV BY COMMENTS 11/04/77 ORIGINAL COMPLETION 11/04177 LAST WORKOVER 03/08/01 SIS-MD FINAL 03/16/01 RN/TP CORRECTIONS 08/13/01 A TD/TP ADD CMT / SAND DEPTHS 08/13/01 ?/KAK ADPERFS 10395' --i TOP OF CBvlENT (15') I 10410' -j TOP OF SAND (125') I 11010' DA TE REV BY COMMENTS 12/12/03 TJP/TLH WANER SAFETY NOTE 08/27/06 ???/TLH HES LlMrrED CHOKE (04/17/06) BP Exploration (Alaska) PERFORA TON SUMMARY REF LOG: SHCS ON 10/26/77 ANGLE AT TOP PERF: 32 @ 10238' Note: Refer to Production DB for historical perf data SIZE SPF INTERV AL Opn/Sqz DATE 2- 7/8" 6 1 0238 . 10264 0 08/13/01 2-718" 6 10270· 10276 0 08/13/01 2-718" 6 10286 . 10320 0 08/13/01 2-7/8" 6 ,0330· 10354 0 08/13/01 3-3/8" 4 10370 - 10380 0 06/14/94 3-3/8" 4 10380 - 10394 S 01/14/94 3-3/8" 1 10420 - 10425 C 09/12/90 3-3/8" 1 10438 - 10440 C 09/12/90 NA 0 10450 - 10462 C 02/04/78 3-3/8" 4 10462 - 10472 C 06/04/93 3-3/8" 4 10482·10495 S 11/13/89 3-3/8" 4 10495-10513 S 06/05/94 3-3/8" 4 10517 - 10520 S 11/13/89 3-3/8" 4 10530 - 10535 S 11/13/89 3-3/8" 4 10535 - 10545 S 06/05/94 3-3/8" 4 10545- 10555 S 11/13/89 3-3/8" 4 10555 - 10570 S 06/26/93 3-3/8" 4 10575 - 10585 S 06/26/93 3-3/8" 4 10591 - 10601 S 06/26/93 01-11 PERFS . DATE REV BY COMMENTS DATE REV BY COMMENTS 11/04/77 ORIGINAL COMPLETION 12112/03 TJPfTLH WANER SAFETY NOTE 11/04/77 LAST WORKOVER 08/27/06 ???fTLH HES LlMrrED CHOKE (04/17/06) 03/08/01 SIS-MD FINAL 03/16/01 RNfTP CORRECTIONS 08/13/01 A TOfTP A DO CMT / SA NO DEPTHS 08/13101 ?/KAK A DP-cRFS . PRUDHOE SA Y UNrr WELL: 01-11 PERMrr No '1770570 API No 50-029-20268-00 SEC 8. T10N. R15E, 1381.51' FEL & 4248.53' FNL BP Exploration (Alaska) .~.. . ri 1))1) .CJ.- 171-057 e e STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION Mechanical Integrity Test 1 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: BP Exploration (Alaska), Inc. Prudhoe Bay / PBU / OS 01 07/16/06 Jack Winslow Packer Depth Pretest Initial 15Min. 30 Min. Well 01-11 Type Inj. I W TVD I 8,471' Tubing 710 720 720 720 Interva" V P.T.D. 1770570 I Typetest I P Test psi! 2118 Casing 200 2,470 2,420 2,400 P/FI P Notes: MITIA to 2500 psi for Waiver Compliance OA 90 350 360 360 Chuck Scheve declined to witness Weill I Type Inj. I I TVD I Tubing Interval I P.T.D.I I Type test I Test psil Casing P/FI Notes: OA Weill I Type Inj.1 TVD I I Tubing Interval I P.T.D.I I Type test I Test psi I Casing P/FI Notes: I OA Weill I Type Inj. TVD I Tubingl Interval I P.T.D.I I Type test I Test psi I Casing I P/FI Notes: I OA Weill I Type Inj.1 I TVD I Tubing I Interval I P.T.D.I I Type testl I Test psil I Casing P/FI Notes: OA TYPE INJ Codes D = Drilling Waste G = Gas I = Industrial Wastewater N = Not Injecting W = Water MIT Report Form BFL 9/1/05 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 01-11 07-16-06-1.xls Scblumbel'ger RECEIVED 06/05-06/06 JUN 0 8 Z006 NO. 3835 Alaska Data & Consulting Services 2525 Gambell Street, Suite 400 -,,;~<:~(; ;~;!. .? r> ~"ns C~mm~cn Anchorage, AK 99503-2838 .,<;;",~~..., - ~as 1,;", . ATTN: Be~ Anchcrag~ SC4\ð~NED ? ç., Company: State of Alaska Alaska Oil & Gas Cons Comm Attn: Christine Mahnken 333 West 7th Ave, Suite 100 Anchorage, AK 99501 ~ 7 Field: Prudhoe Bay t 77 - 0 ~ ."". WII J b# L D . f D BL CI CD e 0 og eSCflptlOn ate o or 17-13A fH:.L1 - n~C' 11001218 USIT 04/04/05 1 NK-65A AÜ"') -rJ(~~"::;. 11084270 SCMT 07/05/05 1 02~10B :Jtx)- (i (,., t... 10964140 LDL 04/06/05 1 01-11 ì'~~ - (')<Ç +. 11051039 INJECTION PROFILE &~ .:::>_, - r 0(' "' ,; ,,..j C. h1-5. /':'<' 04/29/05 1 01-D9A IC¡< - (Yi~ 10559825 INJECTION PROFILE / 07/31/03 1 01-11 !:}+ -I'"",,,,,--:j. 10662950 INJECTI~~ PROFILE Clop'" - ("Q..e..e\Ù~ :;) ¡¡X3iC-<;" 09/16/03 1 11-34 I O¡A..{ - /, -=? <;< 10687720 LDL 12/31/04 1 A-07 Î7~ -O~f 9153241 PRODUCTION'PROFILE <1.- 0, - r 02~... ;_J -iif~~fJ' 02/04/03 1 B-36 I q f /) - 00~ 10563182 LDL ('" ,"\, I-/" 0 (". ' '" j J e~ I J ;::J "'" / ñ "7?/ - 07/09/03 1 01:20 í7¡:-:).- J4/- 10687694 PRODUCTION PROFILE 07/16/04 1 K-D1 i1r..~-/,=J.1 11211415 SCMT 06/01/06 1 H-30 l "757f' - (.,~.::, 11217253 US IT 06/01/06 1 D.S:09-D6 )''7-(> i-.i..J-x- 11258699 USIT 04/13/06 1 e e Petrotechnical Data Center LR2-1 900 E. Benson Blvd, . _om,., AI,,,,, '9508 ,.f' /' (] .£t/,- Alaska Data & Consulting Services 2525 Gambeil Street, Suite 400 Anchorage, AK 99503-2838 ATTN: Beth .' MEMORANDUM ) State of Alaska ') Alaska Oil and Gas Conservation Commission TO: Jim Regg P.I. Supervisor í<e.¡'i 7Izb(û<? DATE: Wednesday, July 20,2005 SUBJECT: Mechanical Integrity Tests BP EXPLORATION (ALASKA) INC 01-1 I PRUDHOE BAY UNIT 01-11 \11~()'57 FROM: Jeff Jones Petroleum Inspector Src: Inspector Reviewed By: P.I. Suprv ~a-- Comm Well Name: PRUDHOE BAY UNIT 01-11 Insp Num: mitJJ050719154043 Rei Insp Num: NON-CONFIDENTIAL API Well Number: 50-029-20268-00-00 Permit Number: 177-057-0 Inspector Name: Jeff Jones Inspection Date: 7/16/2005 Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. Well 01-11 Type Inj. w TVD 8471 IA 0 2500 P.T. 1770570 TypeTest SPI Test psi 2117.75 OA 100 100 Interval OTHER P/F F Tubing 150 150 Notes: Waiver compliance: MIT failed because lA was not fluid packed. 13 BBLS methanol to pressure up lA. Operator rep. Indicated they will fill & re-test at a later date. SCANNED f\UG () 9 2005 Wednesday, July 20, 2005 Page I of I "-V " GRAY GRAY AXELSON 73' TREE = WELLHEA D = ACTUA TOR = KB. ELEV = SF. ELEV = KOP= Max Angle = Datum MD = Datum TVD = 3200' 48 @ 6200' 10364' 8800' SS ) 01-11 'ii¡I~:II: 13-3/8" CSG, 72#, N-80, 10 = 12.347" Ii. 2713' rJ Minimum ID = 3.759" @ 9964' 4·1/2" BAKER R LANDING NIPPLE 5-1/2" TBG-NPC, 17#, N-80, .0232 bpf, 10 = 4.892" l-i ITOP OF 4-1/2" TBG-NPC l-i 9894' 9895' I I I :8: \ :& ! I I 4-1/2"TBG-NPC, 12.6#, N-80, -i 10024' I .0152 bpf, 10 = 3.958" PERFORA TION SUMMARY REF LOG: BHCS ON 10/26/77 ANGLE AT TOP PERF: 32 @ 10238' Note: Refer to Production DB for historical perf data SIZE SPF INTERV AL Opn/Sqz DA TE SEE PAGE 2 FOR PERF BREAKDOWN PBTD l-i 9-5/8" CSG, 47#. N-80/RS-95. 10 = 8.681" l-i I TO l-i DATE REV BY COMMENTS 11/04/77 ORIGINAL COM PLETION 11/04/77 LAST WORKOVER 03/08/01 SIS-MD FINAL 03/16/01 RNlTP CORRECTIONS 08/13/01 A TD/TP ADD CMT 1 SA NO DEPTHS 08/13/01 ?/KAK A DPERFS 10535' 10988' 11010' I I ~ I ~ ~ ~ DA TE REV BY COMMENTS 10/31/02 KRIS/TP PERF CORRECTIONS 06/17/03 KB/KAK PERF CORRECTIONS 12/12/03 TJP/TLH WAIVERSAFEfY NOTE ) SAFElY NOTES: ***SLOW IAxOA COMM. OPERATING LIMITS: MAX lAP = 2000 PSI, MAX OAP = 1000 PSI (11/24/03 WAIVER)*** 2208' 1-1 5-1/2" BAKER PFVE SSSV NIP, 10 = 4.562" 1 9752' l-i 5-1/2" BAKER SLIDING SLV I 9812' l-i 5-1/2" BAKER R LANDING NIP, 10 = 4.472" 9894' l-i 9-5/8" X 5-1/2" BAKER SAB PKR 1 9923' l-i 5-1/2" X 4-1/2" XO I 9964' l-i 4-1/2" BAKER R LANDING NIP, 10 = 3.759" I 10024' l-i 4-1/2" TUBING TAIL 1 10020' l-i ELMO TT NOT LOGGED 10395' l-i TOP OF CEMENT (15') 1 10410' l-i TOPOFSAND(125') 1 PRUDHOE BA Y UNIT WELL: 01-11 PERMIT No: 1770570 API No: 50-029-20268-00 SEC 8, T10N, R15E, 1381.51' FEL & 4248.53' FNL BP Exploration (Alaska) STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION Mechanical Integrity Test ~é'4#) Email to:Winton_Auberi@admin.state.ak.us;Bob_Fleckenstein@admin.state.ak.us; Jim_Regg@admin.state.ak.~~ l \ ) ) OPERATOR: FIELD I UNIT / PAD: DATE: OPERATOR REP: AOGCC REP: BP Exploration (Alaska) Inc. Prudhoe Bay / PBU / 08-01 07/16/05 Rob Mielke .lpff Jonas 1\ \q\"D< \17~tJ57 31; fZ... 7/1~ l0ç' Packer Depth Pretest Initial 15 Min. 30 Min. well 01-11 I Type Inj. Is TVD I 8,471' TUbing 1001 1001 I Interval P;T.D. 1770570 . Type test P Test psi 2,500 Casing 0 2,500 P/F Notes: Annual MITIA for Waiver Compliance. Used 13 bbls to reach test pressure, test discontinued. Bleed IA to 1000 psi. o <.:..::- N [) T~r- we1l101-11 I Type Inj. Is I TVD I 8,471'1 TUbing 1501 1501 P.T.D. 1770570 Type test P Test psi 2,500 Casing 1000 2,500 Notes: Annual MITIA for Waiver Compliance. AOGCC Declined to Witness second test. 1501 150 'nterval 0 2,460 2,450 P/F P I,nterval P/F I,nterval P/F Ilnterval P/F weill Type Inj'l I T:~PSil I TUb~ngl P.T.D. Type test Casing Notes: weill Type Inj. I T:~PSil I TUb~ngl P.T.D. Type test Casing Notes: weill Type Inj. I T:~PSil I Tub~ng I P.T.D. Type test Casing 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 INTERV AL Codes I = Initial Test 4 = Four Year Cycle V = Required by Variance T = Test during Workover 0= Other (describe in notes) Notes: If the test was not AOGCC witnessed, leave the "AOGCC REP:" box blank. MIT Report Form Revised: 06/19/02 MIT PBU 01-11 07-16-05.xls MEMORANDUM . State of Alaska Alaska Oil and Gas Conservation Commission TO: Jim Regg P.I. Supervisor 'Zet1 7/1&, /04 DATE: Wednesday, June 30, 2004 SUBJECT: Mechanical Integrity Tests BP EXPLORATION (ALASKA) INC 01-11 PRUDHOE BAY UNIT 01-11 FROM: John Crisp Petroleum Inspector Src: Inspector NON-CONFIDENTIAL Well Name: PRUDHOE BAY UNIT 01-11 Insp Num: mitJCr040628091543 Rei Insp Num: API Well Number: 50-029-20268-00-00 Permit Number: 177-057-0 . - {))f~ - ì 77- ()S7 Reviewed By: P.I. Suprv :::5ßP- Comm Inspector Name: John Crisp Inspection Date: 6/24/2004 Packer Depth ~ Initial 15 Min. 30 Min. 45 Min. 60 Min. Well 01-11 Type Inj. P TVD 9394 IA ( 1030 ., 2510 2480 2470 P.T. 1770570 TypeTest SPT Test psi 2117.75 OA 950 1010 980 1030 Interval REQVAR P/F P Tubin~ 980 . ) 980 980 980 Notes: MIT required to continue injection. Safety notes on well, slow IA x ~ax lAP 2000 psi, MaxOAP 1000 psi. 11/24/03 waiver. " ~i~Bf --.--.. ... ... ...... .."AA7 - ., J':J:.A 1'-V"" . . -wM-AlUI<L- ~. >.....~.....<Jf.f~ tù:L\~..~ ~tX\ ~~l. l~f~ ~orr. SCANNED DEC 4 200tl VVednesday,June30,2004 Page I of 1 MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: Jim Regg P.I. Supervisor '(('11 71 a'l C4 DATE: Wednesday. June 30. 2004 SlIBJECT: tI.-1echanicallntegrity Tests BP EX'PLORA. TION I: ALASKA ì rNC 01-11 FROM: John Crisp Petroleum Inspector PRUDHOE BA Y UNIT 01-1 I Src: Inspector Re\'iewed By: P.I. SUpr\' .::Jß,L Comm NON-CONFIDENTIAL Well Name: PRUDHOE BAY UNIT 01-11 Insp Num: mitJCr040628091543 Rei Insp Num: API Well Number: 50-029-20268-00-00 Permit Number: 177-057-0 Inspector Name: John Crisp Inspection Date: 6/24/2004 Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. Well 01-11 Type Inj. P TVD 9394 IA 1030 2510 2480 2470 P.T. 1770570 TypeTest SPT Test psi :!I 1775 OA 950 1010 980 1030 Interval REQVAR P/F P Tubing 980 980 980 980 Notes: t\HT required to continue injection. Safety notes on well. slow IA x OA comm. Ma.x lAP 2000 psi. Max OAP 1000 p!">i. 11/24/03 waiver. Wednesday. June 30. 200..J Page I of I Schlumberger Alaska Data & Consulting Services 3940 Arctic Blvd, Suite 300 Anchorage, AK 99503-5711 ATTN: Beth 09/18/03 No. 2963 Company: State of Alaska Alaska Oil & Gas Cons Corem Attn: Lisa Weepie 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Field: Prudhoe Bay Color Well Job # Log Description Date Blueline Prints CD H-17A I c{ ~ ,I ~ MEM PROD PROFILE 08113/07 E-27A 'I ~ c~ -(~.~3~ MEM PROD PROFILE 08109/03 D.S. ~3-08A i~ ~-~-[~-~ GLS 09104/03 E-26 1 ~ '~'1 ~- ~ LDL 09/05103 D.S. 3-09 I~-~. "' (~ '~ ~ PSP PROD PROFILE 08105/03 D.S. t-1~ [-~ -~,~ c5~'~' INJECTION PROFILE 09116103 ,.0,c A-23 ~~'~:~-t'~ J-~ RST-C GRAVEL PACK 09/07103 D.S. 15-48A ~ "~-(~.~ PSP LEE 08~30~03 MPS-0'6 r.Y.).O ~-~ ..- I C")~-1 TEMPERATURE LOG 08130/03 -3510-25 -~ ~ ~ - [ _~/"j · PROD pROFILE/DEFT/GHOST 09/14/03 ~J-20B 23076 'OH EDIT MWD SLIMPULSE & ARC DATA 10114102 J-20B 23076 MD VISION RESISTIVITY 10/14/02 ~J-20B 23076 TVD VISION RESISTIVITY 10114102 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING ONE COPY EACH TO: BP Exploration (Alaska)Jnc. Petrotectnical Data Center LR2-1 900 E. Benson Blvd. R CEIVED Anchorage, Alaska 99508 Date Delivered: Schlumberger GeoQuest 3940 Arctic- Blvd, Suite 300 Anchorage, AK 99503-5711 ATTN: Beth STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION Mechanical Integrity Test Email to: Tom_Maunder@admin.state.ak.us; Bob_Fleckenstein@admin.state.ak.us; Jim_Regg@admin.state.ak.us OPERATOR: FIELD / UNIT / PAD: DATE: OPERATOR REP: AOGCC REP: BP Exploration (Alaska)Inc. Prudhoe Bay / PBU / DS-01 06/12/03 Joe Anders John Crisp - Declined to witness Welll01-11 P.T.D.11770570 Notes: WellI P.T.D.I Notes: WellI P.T.D.I Notes: WellI P.T.D.I Notes: WellI P.T.D.I Notes: ~ Packer Depths (ft.) ' I Pretest Initial 15 Min. 30 Min. Type lnj. I~ I~O~V~I ~'~'1 ~'~'~'1 Tubingl 12001 12001 12001 12001 Interval Typetestl P I Testpsil 21181 I Casin~ll 6001 25OO1 24501 24501 P/FI Type Inj. Type Inj. Type Inj, Type Inj 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 O = Other (describe in notes) MIT Report Form Revised: 06/19/02 2003-0612_MIT_PBU_01-11 .xls 'FYI: MITIA Forms Subject: Date: From: To: CC: FYI: MITIA Forms Thu, 12 Jun 2003 22:19:39 -0500 "NSU, ADW Well Integrity Engineer" <NSUADWWelllntegrityEngineer~,BP.com> "AOGCC Bob Fleckenstein (E-mail)" <Bob_Fleckenstein~admin.state.ak.us>, "AOGCC Field Inspectors (E-mail)" <AOGCC_Prudhoe_Bay@admin.state.ak.us>, "AOGCC Winton Aubert (E-mail)" <Winton_Aubert~admin.state.ak.us>, "AOGCC Jim Regg (E-mail)" <Jim_Regg~admin.state.ak.us> "Rossberg, R Steven" <RossbeRS~BP.com>, "Engel, Harry R" <EngelHR~BP.com>, "NSU, ADW Well Operations Supervisor" <NSUADWWellOperationsSupervisor~BP.com> Hello all. Attached are several MIT reports for recent 4-year MIT's conducted on injectors. All passed except 09-20, currently under evaluation. Note we've had email problems recently, some of these may have already been sent. Let me know if you have any questions. <<MIT PBU 01-11 06-12-03.xls>> <<MIT PBU 13-19 06-12-03.xls>> 14-27 06-12-03.xls>> <<MIT PBU 09-08,10,20 06-06-03.xls>> Joe Anders, P.E. / John Cubbon Well Integrity Engineer, BP Exploration, Work: (907) 659-5102 Mobile: (907) 943-1154 Pager: (907) 659-5100, x1154 Email: NSUADWWellIntegrityEngineer@bp.com (Alaska) Inc. <<MIT PBU ~[ , 1 Name: MIT PBU 01-11 06-12-03.xls Microsoft Excel ]~-~MIT PBU 01-11 06-12-03.xls:t Type: Worksheet (application/rna.ms-excel) i - Encoding' base64 ] Name: MIT PBU 13-19 06-12-03.xls ~_)MIT PBU 13-19 06-12-03.xlsI Type: Microsoft Excel Worksheet (application/vnd.ms-excel) ] ],Encoding~ base64 , ] Name: MIT PBU 14-27 06-12-03.xls I ~_)MIT PBU 14-2706-12-03.xlsIType:Microsoft Excel Worksheet (application/vnd.ms-excel) [ 11 Encoding' base64 ,[ Name: MIT PBU 09-08,10,20 06-06-03.xls ~_)MIT PBU 09-08,10,20 06-06-03.xlsI Type: Microsoft Excel Worksheet (applicatiordvnd.ms-excel) IiEncoding: base64 I of 1 6/25/2003 3:10 P MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: Cammy O Taylor~,~ DATE: September 16, 2001 Chairman ~01_~~U~ECT: M~han'cal Int~ri~ Tests THRU: Tom Maunder BPX P.I. Supervisor DS 1 C)~--% \~-o~- \ 1-11 FROM: Chuck Scheve PBU Petroleum Inspector Prudhoe Bay NON. CONFIDENTIAL ' 'j ' ' . Packer ~ Pmlest Initial 15 Min. 30 Min. ' ' ~ we#l ~-~ ITypeinj. I s I'T.V.D. la'fl I TuU.oI ~ I.. 12~ I 1~ I 12~ I1~1 4 ] P.T.D'I 1~7 ITy.~I . IT=.~I 2~S I~1 ~ I 2~ I 2~1 2~ [ .; ! q~ I ~: ~ve.~ ~ p~~ ~'inj~ .... - / wd, I," i P.T.D.I ,j , w,~,/ i . P.T:D.I Notes: wd~I ,, .P.T.D.I I~1~: IType'nj.l' IT:V.D.I ' ' I'Yuanol ' I "' I I ' 'l"r"'~l ' ITypetestl ITest~l '.. '1 c..~n~'l' ... I I ' I, , I P/F I , ITx~'i"j-i I T.V.D. !' ' ' I Tub~'l ' .I .I .. I '.I,rr.,,~'l ' ~ ITypetestl , I Test Ps*l I C~."g I I.. I ... I . I. P/F I. 1 .!T~,',ni.I ...' ', I T,.9.,D. I ," ' I Y~ar~ ~. '. '. I' ' I" ' i '" I'nt,~l / ITYpetest,! ITest,psil I. casing I ,I, , I' ' , I"I Pa: I1 / Type INJ. Fluid Codes F = FRESH WATER INJ. G = GAS INJ. S = SALT WATER INJ. N = NOT INJECTING Type Test M= Annulus Monitoring P= Standard Pressure Test R= Internal Radioactive Tracer Survey A= Temperature Anomaly Survey D= Differential Temperature Test Interval I= Initial Test 4= Four Year Cycle V-- Required by Variance W= Test during Workover O= Olher (describe in notes) Tsst's Dztails I traveled to BPXs Drill Site l and witnessed the initial MIT on ,well 1-11 since its conversion f~om producer to injector. The pretest tubing and casing pressures were observed and found to be stable. The casing was then pressured up and observed for 30 minutes with the' well.demonstrating,good mechanical integrity. M.I.T.'s performed: Attachments: Number of Failures: 0 Total Time during tests: I hour cc,: MIT report form 5112/00 L.G. MIT PBU 1-11 9-16-01 CS.xls 10/1/01 " STATE OF ALASKA (" ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: Operation shuidown_ Stimulate _ Plugging _ Perforate _X Pull tubing _ Alter casing _ Repair well _ Other _X (Conversion) 2. Name of Operator 5. Type of Well: 6. Datum elevation (DF or KB feet) BP Exploration (Alaska), Inc. Development_ RKB 73 feet 3. Address Exploratory__ 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 896' FNL, 4501' FEL, Sec. 8, T1 ON, R15E, UM (asp's 698114, 5940009) 01-1 li At top of productive interval 9. Permit number / approval number 3955' FNL, 1541' FEL, SEC. 8, T10N, R15E, UM (asp's 701165, 5937032) 177-057 / approv # 301-156 signed 8/29/2001 At effective depth 10. APl number 50-029-20268 At total depth 11. Field / Pool 4249' FNL, 1382' FEL, Sec. 8, T10N, R15E, UM (asp's 701331, 5936740) Prudhoe Bay Oil Pool 12. Present well condition summary Total depth: measured 11010 feet Plugs (measured) Tagged TOC @ 10395' MD on 8/05/2001. true vertical 9434 feet (Sand plug capped with cement) Effective depth: measured 10395 feet Junk (measured) true vertical 9000 feet Casing Length Size Cemented Measured Depth True Vertical Depth Conductor 120' 20" 30o Sx AS 120' 120' Surface 2640' 13-3/8" 5670 Sx PF II 2713' 2713' Production 10915' 9-5/8" s0o Sx Class G & 300 Sx PF II 10988' 9414' Perforation depth: measured 10238'- 10264'; 10270'- 10276'; 10286'- 10320'; 10330'- 10354'; 10370'- 10380'; (Isolated below sand plug / cement cap 10495' - 10517'; 10535' - 10545'). truevertica18766'-8788'; 8793'-8798'; 8806'-8835.5'; 8844'-8865'; 8878'-8887'; RECEIVED (Isolated below sand plug / cement cap 8986' - 9005'; 9020' - 9029'). Tubing (size, grade, and measured depth) 5-1/2", 17#, N-80 NPCT @ 9894' MD; 4-1/2", 12.6#, N-80 NPCT @ 10024' MD. , SEP 1 0 Packers & SSSV (type & measured depth) 9-5/8" X 5-1/2" BAKER SAB PACKER @ 9894' MD. 5-1/2" BAKER PFVE SSSV @ 2208' MD. Alaska Oil & Gas Cons. Commission 13. Stimulation or cement squccze summary Ai;c',;u,,=g~ Intervals treated (measured) (see attached) Treatment description including volumes used and final pressure 14. Representative Daily Averaqe Production or Injection D~.ta OiI-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation(4/06/2001) 1799 43625 4314 1333 Subsequent to operation 2000 950 15. Attachments 16. Status of well classification as: Copies of Logs and Surveys run __ Daily Report of Well Operations__X Oil m" Gas__ Suspended ~ Service Water Injector~ 17, I hereby certify that the foregoing is true and correct to the best df my knowledge. Signed Title: DS 1 Surveillance Engineer Date September 5, 2~O01 Deldre Taylor Prepared by Paul Rauf 564-&79.~ ~ Form 10-404 Rev 06/15/88 · "ORiGiNAL SUBMIT IN DUPLICATE ,. 01-11 i DESCRIPTION OF WORK COMPLETED CONVERSION FROM PRODUCER TO WATER INJECTOR Date Event Summar~ 4/1712001' 5/0612001' 7116/2001' 7/22/2001' 7/2812001' 8/01/2001' 8/02/2001: 8/05/2001: 8/13/2001 - 8/14/2001: 8/17/2001' 8/31/2001: Last day of oil production. Well shut in for conversion. RIH & tagged PBTD @ 10537' MD. MITIA to 2500 psi - passed. PPPOT-IC to 3000 psi - passed. Ran USIT/CET Log; good cement found between 10015' - 10285'. MIRU CTU. PT'd BOPE. Killed well w/2% Filtered KCl Water & dead Crude. RIH & tagged PBTD @ 10529' CTM. Pumped a gelled sand slurry containing 5300 lbs of 20/40 mesh Carbolite Sand to isolate the following perforations located at: 10495'-10517' MD (Zone3) Reference Log: BHCS 10/26/1977. 10535' - 10545' MD (Zone 2) Waited for I hr for sand to settle. Capped the sand plug with 1.5 bbls of Class G Cement. POOH w/CT. RIH & tagged TOC @ 10395' MD. MIRU ELU. PT'd equip to 3000 psi. RIH w/perf guns & performed tie-in. 'Shot 90' of add perforations f/: 10238' - 10264' MD (Zone 4B) 10270' - 10276' MD (Zone 4B) 10286' - 10320' MD (Zone 4B) 10330' - 10354' MD (Zone 4B) Used 2-7/8" carriers & all shots @ 6 SPF, random orientation, 60° phasing, & underbalanced press. POOH w/guns - ASF. RD ELU. MIRU CTU & APC Test Separator. PT'd equip. RIH & performed N2 lift to kick off well (temporarily produced well for cleanup of wellbore). RD CTU. Placed well on initial Produced Water Injection. Obtained representative injection data. A state witnessed MITIA is scheduled for the near future. .. Page 1 u1-11 MIItA (~'lu 1 Subject: 01.11 MITIA (PTD 177-057) Date: Sat, 11 Aug 2001 20:23:15-0500 From: "NSU, ADW Well Integrity Engineer" <NSUADWWelllntegrityEngineer@BP.com> To: "AOGCC Tom Maunder (E-mail)" <Tom_Maunder@admin.state.ak.us> Hi Tom. Well 01-11 passed an MITIA on 7/16/01. We pressured the IA to 2500 psi, lost 10 psi at 15 min, 10 psi total at 30 minutes. Once the well is placed on injection and the temperatures have stabilized, we will contact the slope Inspectors and schedule an AOGCC witnessed MITIA. Call if you have any questions. Joe Joe Anders, P.E. I Kevin Yeager Well Integrity Engineer BP Exploration, (Alaska)Inc. (907) 659-5102 email: NSUADWWelllntegrityEngineer@bp.com 1 of 1 8f17/01 2:26 PM Note to File PBU DS 1-11 (177-0157) BP has applied to convert this well to water injection service as a one well pilot project to investigate updip Xone 4 water injection. The effected area in the reservoir lies between the established periferal water flood and the original gas cap. Comparative core studies have been done in two wells, D-06^ and 13-06A. The wells are in the gravity drainage area and mature water flood areas respectively. The core studies indicated there may be substantial movable oil in the proposed project area. BP, supported by partner representatives, made a presentation regarding the project to the Commission on August 30, 2001. Their proposal outlined the possible oil reserves target, the monitoring of surrounding wells for water "break through" as well as production increases. BP stressed that the intent is to confine the injected water in Zone 4. If water production increases are seen in Sone 3 or Zone 2 wells to the north of the project area, the pilot would likely be terminated. If the water is successfully confined to Zone 4, BP estimates that it could take up to a year to see possible production increases although replacing voidage would have an overall pressure maintenance benefit. Following the presentation, it was the concensus of the staff present that their ,ncy,~dry application (301-156) should be approved. Tom Maunder, PE August 30, 2001 1. Type of request: Abandon_ STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS Suspend_ Operational shutdown _ Re-enter suspended well _ (Prod .> Water 2. Name of Operator Alter casing _ Repair well _ Plugging _ Change approved program _ Pull tubing _ BP Exploration (Alaska), Inc. 3. Address P. O. Box 196612 Anchorage, AK 99519-6612 4. Location of well at surface 896' FNL, 4501' FEL, Sec. 8, T10N, R15E, UM At top of productive interval 3955' FNL, 1541' FEL, SEC. 8, T10N, R15E, UM At effective depth At total depth 4249' FNL, 1382' FEL, Sec. 8, T10N, R15E, UM 12. Present well condition summary 5. Type of Well: Developroent Exploratory _ Stratigraphic Service_ (asp's 698114, 5940009) (asp's 701165, 5937032) (asp's 701331, 5936740).~__ Time extension _ Stimulate _ Variance Perforate _X 6. Datum elevation (DF or KB feet) 73 feet 7. Unit or Property name Prudhoe Bay Unit 8. Well number 01-11 9. Permit number / approval number 177-057 v/ 10. APl number 50-029-20268 V" ,, 11. Field / Pool Prudhoe Bay Oil Pool InJ Converalon) Other_X Total depth: measured true vertical Effective depth: measured true vertical Casing Length Size Conductor 120' 20" Surface 2640' 13-3/8" Production 10915' 9-5/8" 11010 9434 10537 9022 feet Plugs (measured) feet ~ feet Junk (measured) feet Cemented 3oo Sx AS 5670 Sx PF II 800 Sx Class G & 300 Sx PF II Tagged PBTD @ 10537' MD on 5/06/2001. Measured Depth True vertical Depth 110' 110' 2713' 2713' 10988' 9414' Perforation depth: measured 10370'- 10380'; 10495'- 10517'; 10535'- 10545'. true vertical 8878' - 8887'; 8986' - 9005'; 9020' - 9029'. Tubing (size, grade, and measured depth Packers & SSSV (type & measured depth) 13. Attachments RECEIVED ,..:: ?:i (.; ,.-.-.. Alaska 0il & [~,.,,.-, I:.',o,:~s. ~ommissio~ .Anchorage 5-1/2", 17#, N-80 NPCT @ 9894' MD; 4-1/2", 12.6#, N-80 NPCT @ 10024' MD. 9-5/8" X 5-1/2" BAKER SAB PACKER @ 9894' MD. 5-1/2" BAKER PFVE SSSV O 2208' MD. Description summary of proposal _~X Detailed operations program __ BOP sketch__ 14. Estimated date for commencing operation ~ of well classification as: June 18, 2001 ~ 16. If proposal was verbally approved 1 Oil _X Gas __ Suspended _ Name of approver ~ Date approved .LService ~'. i h-'~'~mby ~ t'~at t~e foregoing is true ~rect t'o e~ ~y knowledge.Questions? Call Deldre Taylor @ 564-5086. Signed "~.~ Deidre Title: DS 1 Surveillance Engineer Date June 7 2001 P~ Paul Rauf 564-5799 FOR C~ ONLY Conditions of approval: Notify Commission so representative may witness Plug integrity __ .B/OP Test _ Mechanical Integrity Test .~ Location clearance_ Subsequent form required 10- L[I~'~ Approved by order of the Commission Form 10-403 Rev 06/15/88 · Commissioner Cammy Oechsli ORIGIN,A[ .... Date SUBMIT IN TRIPLICATE WELLH~D= GRAY ACTUATOR= AXELSON KB. J"J_EV = 73' BF. ELEV = KOP = 3200' Max Angle = 48 @ 6200' Datum MD = 10364' Datum TVD= 8800' SS I 13-3/8" CSG, 72#, N-80, ID = 12.347" I~'~ 2713' ~-J Minimum ID = 3.759" @ 9964 4-1/2" Baker R Landing Nipple 5-1/2" TBG-NPC, 17#, N80, .0232 bpf, ID = 4.892" I~ 9894' ITOPOF 4-1/2" TBG-NPC I---~ 9895' 4-1/2" TBG-NPC, 12.6#, N80, I'~ 10024' I .0152 bpf, ID = 3.958" PERFORATION SUMMARY REF LOG: BHCS ON 10/26/1977 ANGLE AT TOP PERF: 32 @ 10233 Note: Refer to Production DB for historical perf data SEE SPF INTERVAL Opn/Sqz DATE 3 3/8 4 10370-10380 O 9/211995 4 10495-10517 O 6~/1993 4 10535-10545 O 6~/1993 r-~-.-~ 10535. 01-11 2208' 9752' 9812' 9894' 9923' 9964' 10024' SAFETY NOTES I~ 5-1/2"BAKERPFVESSSV NIP, ID=4.562 I I~1 ~-~,,~^~,,~,,~ I I~ 5-112" BAKB~RLANDING NIP, ID=4.472 I I~ ~-~-x~-~..~~.~c~ I I~ x°~-~" x~-~" I I~ 4-1/2" BAK~RLANDI~ NIP, ID=3.759 I 10020' I~ ELMI~q'F- LOGGED 9-5/8"CSG,47#,I~80/RS-95,.0732bpf,ID=8.681 I---~ 10988' r~-I ~o~o' i DATE REV BY COMMI~ITS PRUDHOE BAY UNIT 11/04/77 ORIGINAL COMPLETION WELL: 01-11 11/04/77 LAST WORKOVER PERMIT No: 77-057 03/08/01 SIS-MD FINAL APl No: 50-029-20288-00 03/16/01 RN/TP CORP, F_C~iONS SEC8 T10N R15E 1381.51 FEL 4248.53 FNL · BP Exploration (Alaska) · · bp June 7, 2001 BP Exploration (Alaska) Inc. 900 East Benson Boulevard P.O. Box 196612 Anchorage, Alaska 99519-6612 (907) 561-5111 Tom Maunder Alaska Oil & Gas Conservation Commission 333 West 7th Avenue Suite 100 Anchorage, AK 99501 Fax 276-7542 Dear Tom: RE: Sundry Notice for 01-11 Conversion from Producer to PW Water Iniection Service BP requests approval for recompletion of Well 01-11 from producer to Produced Water Injection Service. The procedure includes the following major steps: 1. S 2. C 3. C 4. E 5. O 6. O 7. O Drift and Tag Sandback to 10410' MD Cement cap to 10395' MD Add perfs (10238'- 10264'; 10270'- 10276'; 10286'- 10320'; 10330'- 10354') Flow back through APC for at least 24 hours Perform MIT prior to injection Turn well over to DSO for PWI injection. Current Status: Last Test: Deviation: Last TD Tag: Last Well Op: Completion: Min. Restriction: Latest H2S value: Shut in; scheduled to be converted to PWI '-6/17/01 4/06/01:1799 bopd/43625 mcfd/24249 GOR/71% WC 30° @ the perfs. Max. dev. is 48° @ 6200' MD 10532' ELM on 4/7/99 Ran CNL on 4/7/99 5-1/2" N-80 tubing from surface to 9894' MD 4-1/2" N-80 tubing from 9894 to 10024' MD 9-5/8" N-80 casing from surface to 10968' MD 3.759" @ 9964' MD (4-1/2" Baker R landing nipple) 4 ppm on 2/10/96 Well 1-11 is currently being converted to PWI for the SWIPE EOR pilot. The plan is to inject water into Zone 4 and provide pressure support for the down dip DS 12 producers. It is estimated there are 1.64 MMBO incremental reserves associated with this project. The recompletion program will prepare the well for injection into the desired interval, Zone 4. The well is currently completed in Zones 3 and 4A, with a sand plug @ 10535' MD isolating Zone 2 perforations. A sandback with cement cap is proposed to isolate Zone 3 and lower Zone Page 1 (' 4A from the injection interval. The existing upper Zone 4A perforations will remain open, and Zone 4B perforations will be added to maximize Zone 4 sweep efficiency. A 24 hour flowback period is recommended to clean up the perforations prior to injection. Once the well is successfully on injection, a tracer study will be implemented to confirm injection conformance, with an emphasis on proving the water is not migrating to nearby Zone 2 producers on DS 1. A mechanical integrity pressure test will be performed prior to water injection service. If you have any questions, please contact Deidre Taylor, DS 1 Surveillance Engineer, at 564- 5086 or by email at TaylorDA@ bp.com. Deidre Taylor DS 1 Surveillance Engineer Page 2 GeoQuest 500 W. International Airport Road Anchorage, AK 99518-1199 ATTN: Sherrie NO. 10237 ' Company: Alaska Oil & Gas Cons Comm Attn: Howard Oakland 3001 Porcupine Drive Anchorage, AK 99501 6/1 3/96 Field: Prudhoe Bay Anadrill Anadrill Anadrill Floppy Well Job # Log Description Date BL RF Sepia Survey Program Performance Disk .~,~. Calculation Letter D.S. 1-11 'il-el"? 96103 DUAL BURST TDT-P 960401 1 ~.S. 1-4 -'~t .~,(, PERFRECORD 960528 I 1 'D.S. 1-8 ?}--Zk INJEC PRORLE 96051 9 1 1 ~).S. 2-3A q)",~,l'7~' PROD PROFILE 960531 1 1 D.S. 2-3A ¢{~-.. ('~; DUAL BURSTTDT-P (BORAX) 960601 I 1 D.S. 2-18A ¢/~ l) ~ PROD PROFILE 96051 8 I 1 ~).S. 2-32 ¢JC tct GAS DETECTION 960530 I 1 'D.S. 2-35 ell . I,t9 LEAK DETECTION 960525 I 1 t~.S. 3-14 '~,/, 0;;. PERFRECORD 960526 1 1 ~).S. 3-36 '~5..6 I~' PERFRECORD 960523 1 1 ~;~-.S. 4-29A '1~'.19,~ PERFRECORD 96051 6 I 1 'D.S. 5-5A q'f- o'i 1, DUAL BURST TDT-P (BORAX) 960520 1 1 O.S. 5-11 '~, 0)~ CHEMICALCUTI'ER RECORD 960528 I 1 1~.S. 7-6A qF. Iff ? DUAL BURST TDT-P (BORAX) 960515 I 1 1~.S. 13-06 ~- I~.~ INJECPROFILE 960524 I I t~.S. 13-18 ~'~,- e);' INJECPROFILE 960527 1 1 D.S. 15-08A q}. t ~'~ LEAK DETECTION 960526 I 1 ,p.s. 15-28 ~J2..o~" LEAK DETECTION 960516 I 1 D.S. 15-32 ~,t O't ? PERF RECORD 960517 I 1 b.S. 17-21 ¢~Z. I,t~ LEAK DETECTION 960519 I 1 ~).S. 18-31 ~'.- loft DUAL BURST TDT-P (BORAX) 960521 I I Please sign and return one copy of this transmittal to Sherrie at the above address. Thank you. JUN 13 199; Anchorage L STATE OF ALASKA 'OI~, ALASKA .,-AND GAS CONSERVATION C ,,v,qSSlON REPORT OF SUNDRY Wi:LL , 1. Operations performed: operation shutdown Stimulate Plugging PerforateX "~/" /~ . Pull tubing Alter casing Repair well Other ~?///"~' -- __ __ __ 2. Name of Operator ARCO Alaska, Inc. 3. Address P.O. Box 100360, Anchorage, AK 99510-0360 4. Location of well at surface 898' FNL, 777' FWL, Sec 8, T10N, R15E, UM. At top of productive interval 1324' FSL, 1541' FEL, Sec 8, T10N, R15E, UM. At effective depth 1023' FSL, 1372' FEL, Sec 8, T10N, R15E, UM. At total depth 971' FSL, 1343' FEL, Sec 8, T10N, R15E, UM. 12. Present well condition summary 5. Type of Well Development X Exploratory Stratigraphic Service 6. Datum of elevation(DF or ~ 73' RKB %etl 7. Unit or Property Prudhoe Bay Unit 8. Well number 1-11 9. Permit number/approval number 77-57 10. APl number 50 - 029-20268 11. Field/Pool Prudhoe Bay Oil Pool Total depth: measured true vertical Effective depth: measured true vertical Casing Length Conductor 120' Surface 2640' Production 10915' 11010 feet 9394 feet Plugs(measured) Fill Tagged @ 10535' MD (7/30/95) 10535 feet 9020 feet Junk(measured) Size Cemented Measured depth 20" 300 Sx Arcticset 120' 13-3/8" 5670 Sx PF II 2713' 9-5/8" 800 Sx G & 300 Sx PF II 10988' True vertical depth 120' 2713' 9375' Perforation depth: measured 10370 - 10380'; 10495 - 10517'; 10535 - 10545' JAN 04 true vertical 8848 - 8857'; 8954 - 8973'; 8988 - 8997' Alaska Oil & Gas Cons. Commission Anchorage Tubing (size, grade, and measured depth) 5-1/2", 17#, L-80, NPCT @ 9894' MD; 4-1/2", 12.6#, L-80, NPCT Tail @ 10024' MD. Packers and SSSV (type and measured depth) Baker SAB Packer @ 9894' MD; 5-1/2" Baker PFVE SSSV @ 2208' MD. 13. Stimulation or cement squeeze summary 14. Intervals treated(measured) see Attached Treatment description including volumes used and final pressure Representative Daily Average Production or Injection Datn OiI-Bbl Gas-Mcf Water-Bbl Casing Pressure Prior to well operation 1680 20962 2603 -- Subsequent to operation 2067 29072 2252 15. Attachments 16. Status of well classification as: Copies of Logs and Surveys run Daily Report of Well Operations X Oil X Gas Suspended 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Service Tubing Pressure 1004 1219 Form 10-404 Rev 06/15/88 Title Engineering Supervisor Date ~ SUBMIT IN DUPLICATE 1-11 PERFORATING OPERATIONS DESCRIPTION OF WORK COMPLETED 7/30/95' RIH & tagged PBTD at 10535' MD. 9/2/95. MIRU & PT equipment. Reperforated: RIH w/perforating gun & shot 10' of reperforations as follows: 10370 - 10380' MD (Z4) Ref. Log: BHCS 10/26/77. Used a 3-3/8" carrier & shot 4 spf at 60 degree phasing at underbalanced pressure, POOH w/perf gun. Noted all shots fired. Rigged down, Returned the well to production & obtained a valid welltest, GeoQuest 500 W. International Airport Road Anchorage, AK 99518-1199 A'n'N: Sherrie NO. 9756 Company: 9/26/95 Alaska Oil & Gas Cons Corem Attn: Larry Grant 3001 Porcupine Drive Anchorage, AK 99501 Field: Well Job if Log Description Date BL Prudhoe Bay Floppy RF Sepia DIR MWD Disk D.S. 1-11 "~ ~ b~ rj PRODUCTION PROFILE 950914 I 1 D.S. 1-19--'r~[~ PERFO~NGRE~RD 950914 1 1 D.S. 6-17 ~ ~ ~~ BAKER INF~TABLE BRIDGE PLUG 950916 1 1 SIGNED: Please sign and return one copy of this transmittal to Sherrle at the above address. Thank you. REC VED Alaska 0il & Gas C0'ns. Commission ^,chorage GeoQuest 500 w. International Airport Road Anchorage, AK 99518-1199 A'I'rN: Sherrie NO. 9739 Company: 9/20/95 Alaska Oil & Gas Cons Comm Attn: Larry Grant 3001 Porcupine Drive Anchorage, AK 99501 Field: Prudhoe Bay Floppy Well Job # Log Description Date BL RF Sepia DIR MWD Disk D.S. 1-11 '7~ ~ 5'-~? PERF RECORD 950902 I 1 D.S. 1-10 -7~'" ~H_~ PROD PROFILE 950902 1 1 D.S. 1-20 ~t'"2..~ I ~ ~ PROD PROFILE 95 09 05 I 1 O.S. 1-22A ~' ~ ~ _.~"~' .BAKER INFLATABLE BRIDGE PLUG 950906 1 1 D.S. 5-6A ¢~,- (3 7L~ PERFRECORD 950905 1 1 O.S. 9-4A~,'~ O'2--~ RSTB/GR 950813 I 1 D.S. 11-28 ~C~ '~ CHEMICAL CUI'rER RECORD 950903 1 1 D.S. 13-34 ~i~"Z.- I ~ ~ LEAK DETECTION 95 0 9 04 1 1 D.S. 15-12~'[ ) ~ (~ BAKER INFLATABLE BRIDGE PLUG 950901 I 1 SIGNED: Please sign and return one copy of this transmittal to Sherrie at the above address. Thank you. STATE OF ALASKA . ALASKA( .AND GAS CONSERVATION C~" fiSSION REPORT'ui= SUNDRY WELL OPr'HATIONS 1. Operations performed: operation shutdown Stimulate Plugging Perforate Pull tubing Alter casing Repair well Other X 2. Name of Operator ARCO Alaska, Inc. 3. Address P.O. Box 100360, Anchorage, AK 99510-0360 4. Location of well at surface 898' FNL, 777' FWL, Sec. 8, T10N, R15E, UM At top of productive interval 1324' FSL, 1541' FEL, Sec. 8, T10N, R15E, UM At effective depth 1023' FSL, 1372' FEL, Sec. 8, T10N, R15E, UM At total depth 971' FSL, 1343' FEL, Sec. 8, T10N, R15E, UM 5. Type of Well Development Exploratory Stratigraphic Service X 6. Datum of elevation(DF or KB) 73 RKB 7. Unit or Property Prudhoe Bay Unit feet 8. Well number 1-11 9. Permit number/approval number 77-57 10. APl number 50 - 029-20268 11. Field/Pool Prudhoe Bay Oil Pool 12. Present well condition summary Total depth: measured 11010 feet Plugs(measured) true vertical 9394 feet Effective depth: measured 10600 feet AU{~ 0 8 1995 true vertical 9076 feet Junk(measured) ~JaS~ Dil & 6aS C011~, .~.~[011 Casing Length Size Cemented ' ' ~l~lepth True vertical depth Conductor 120' 20" 300 Sx Arcticset 120' 120' Surface 2640' 13-3/8" 5670 Sx PF II 2713' 2713' Production 10915' 9-5/8" 800 Sx CIG & 300 Sx PF II 10988' 9375' Perforation depth: measured 10495-10517'; 10535-10545' true vertical 8985-9004'; 9020-9028' Tubing (size, grade, and measured depth) 5-1/2", 17#, N-80, NPCT@ 9894' MD; 4-1/2", 12.6~, N-80, NPC tail @ 10024' Packers and SSSV (type and measured depth) Baker SAB packer @ 9894' MD; 5-1/2" Baker PFVE SSSV @ 2208' MD 13. Stimulation or cement squeeze summary Intervals treated(measured) See Attached 14. Treatment description including volumes used and final pressure Representative Daily Average Production or Injection Data OiI-Bbl Gas-Md Water-Bbl Casing Pressure Tubing Pressure Prior to well operation 1964 30003 1021 - 2014 Subsequent to operation 2237 8637 2464 1036 15. Attachments 16. Status of well classification as: Copies of Logs and Surveys run , Daily Report of Well Operations x Oil x Gas Suspended 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. FSiogr nme~0.40 R~ev 06/1~5/88 ~' Title Engineering Supervisor AJB cc: KZ, JWP Service Date SUBMIT IN DUPLICAt.~.I~ 1-11 DESCRIPTION OF WORK COMPLETED CTU CEMENT SQUEEZE FOR GAS SHUTOFF 7114195: RIH & tagged PBTD at 10514' MD. 7119195: RIH w/CT & pumped gelled sand slurry containing a total of 1500 lbs of 20/40 mesh sand, to place an isolation sand plug over the lower open perforation intervals located at: 10495 - 10517' MD (Z3) 10535 - 10545' MD (Z2) Ref. Log: BHCS 10/26/77. Made a final top of sand plug tag at 10480' MD. POOH w/CT. Rigged down. 7120/95 - 7121/95: Made dump bailer runs & spotted a CaCO3 Cap on top of the sand plug to 10486' MD. 7/22/95: A CTU Cement Squeeze for Gas Shutoff was performed as follows: MIRU CTU & PT equipment to 4000 psi. Loaded the wellbore w/Hot Seawater, then RIH w/CT to cement squeeze the open perforation intervals located above the sand plug located at: 10370 - 10380' MD (Z4) 10462 - 10472' MD (Z4) Ref. Log: BHCS 10/26/77. Pumped 34 bbls of Latex Acid Resistive cement & placed 16 bbls of cement behind pipe at 3500 psi max squeeze pressure & held for 1 hour. Contaminated cement w/biozan & jetted contaminated cement from wellbore down to 10486' MD. Could not jet past sand/cement interface at 10486' MD. POOH w/CT. Rigged down. 7/29/95: RIH w/CT Underreamer & reamed the cement/sand plug interface from 10484' to 10489' MD, then jetted a fill cleanout w/Nitrogen to 10557' MD, to uncover the lower open perforation intervals (above). POOH w/CT. Rigged down. 7130/95: RIH & tagged PBTD at 10535' MD. Returned well to production & obtained a valid production test, AUG 0 8 1995 Alas~ Oil a Gas Cons. Commi~on Anchorage GeoQuest 500 w. International Airport Road Anchorage, AK 99518-1199 ATTN: Sherrie REC-EIVED & Gas Cons. Anchorage NO. 9284 Company: 2/27/95 Alaska Oil & Gas Cons Comm Attn: Larry Grant 3001 Porcupine Drive Anchorage, AK 99501 Field: Prudhoe Bay Floppy Well Job # Log Description Date BL RFSepia Mylar Disk D.S. 1-11 PROD PROFILE 0212 95 I 1 D.S. 1-22A PERFRECORD 021295 1 1 D.S. 4-38 LEAK DETECTION 020995 1 1 D.S. 04-40 PERFRECORD 021 095 I 1 D.S. 09-42 'PERFRECORD 021 095 I 1 'D.S. 9-49 ~ PERF RECORD 020895 I 1 D.S. 11-04A DUAL BURST TDT-P 021195 I 1 D.S. 11-06 LEAK DETECTION 020995 1 1 D.S. 11-16ST1' PERF RECORD 020395 I 1 D.S. 14-4 PERF RECORD 02 07 95 I 1 D.S. 14-17 INJEC PROFILE 020795 I 1 D.S. 15-07A** 95069 DUAL BURST TDT-P 0411 94 1 D.S. 15-07A 95039 DUAL BURST TDT-P 122794 1 D.S. 15-40 95022 MWDGR 120294 1 D.S. 15-40 95021 VlWD GR 113094 1 D.S!~07A 95068 PDCGR 1 001 94 I *PLEASE NOTE: THESE PRINTS-REPLACE THE ONES SENT 2/22/95. THE WELL NAME (D.S. 11-16) WAS INCORRECT **PLEASE NOTE: THIS TAPE REPLACES THE ONE SENT 12/21/94. IT WAS NOT DEPTH SHIFTED; THIS ONE IS. SIGNED: DATE: Please sign and return one copy of this transmittal to Sherrie at the above address. Thank you. 1/19195 GeoQuest 500 W, International Airport Road Anchorage, AK 99518-1199 ATFN: Sherrle NO. 9204 ~(~'~ Company:. Alaska Oil & Gas Cons Comm Attn: Larry Grant 3001 Porcupine Drive An~ chorage, AK 99501 udhoe Bay ~ ~ ~ RR Sepia RF Sepia Floppy Well Job # Log Description Mylar Disk ' S. 1-3 -7~ ' I (o 94354 DUAL BURST TDT-P (10-23-94) (~, L~ D _'~ 1 ,.<S. 3-12 --~ cf. ~"oo' 94396 DUAL BURST TDT-P (11-24-94) - I~_L~ O~ . 1 D.S. 1..-4~ "2- ~ 94399 DUAL BURST TDT-P (4-20-94) (, L~0L[_ ' D.S, 1-05 ST 70'" ~/'~ 94399 DUAL BURST TDT-P (6-13-94)~_.~.~)~.~ 1 D.S. 1-06 "7' 5~ /..~ 94399 DUAL BURST TDT-P (6-13-94) 1 D.S. 1-11 '7 7'" ~- 7' 94399 DUAL BURST TDT-p/PRESSURE LOG (3-25-94) (j2 :~ c/~,, 1 D.S. 1-29 ~'~,-ioTT". 94399 DUAL BURST TDT-P (6-14-94) .~~c~ 1 D.S. 1-7A c/~.. ~Z.-_ 94399 DUAL BURST TDT-P (9-15-94)(~c~'7~ 1 D.S. 14-20 ~J'- 70 94399 DUAL BURST TDT-P (3-11-94) ~ [0 ~ 1 D.S. 18-4 ~ 2.- :2_o~// 94399 DUAL BURST TDT-P (6-11-94) ~ L~ (~.~ 1 D.S. 4-44 ~ L/'.-/O 94408 DUAL BURST TDT-P (12-13-94) ~('~ C/~(~ 1 D.S. 15-33 ~ ~7/~ ,2:~7/ 9501 1 PDC GR (10-1-94) (.~.L~ O ~' 1 D.S. 15-8A ~ :~---I~> ~ 94364 PDC GE (10-02-94) /= ~ (::)"7 I Please sign and return one copy of this transmittal to Sherrle at the above address. Thank you. / STATE OF ALASKA "ALASI" ~ _ AND GAS CONSERVATION C(~' .41SSlON REPORT SUNDRY WELL CPI-RATIONS 1. Operations performed: Operation shutdown Stimulate Plugging Perforate X Pull tubing Alter casing Repair well Other X 2. Name of Operator ARCO Alaska, inc. ,. 3. Address P.O. Box 100360, Anchorage, AK 99510-0360 4. Location of well at surface 898' FNL, 777' FWL, Sec. 8, T10N, R15E, UM At top of productive interval 1324' FSL, 1541' FEL, Sec. 8, T10N, R15E, UM At effective depth 1023' FSL, 1372' FEL, Sec. 8, T10N, R15E, UM At total depth 971' FSL, 1343' FEL, Sec. 8, T10N, R15E, UM 12. Present well condition summary Total depth' measured true vertical Effective depth: measured true vertical Casing Length Conductor 120' Sudace 2640' Production 10915' 5. Type of Well Development Exploratory Stratigraphic Service RECEIVED OCT -4 i994 0it & Gas Cons. Commission , ~ch0r[.,.e 6. Datum of elevation(DF or KB) 73 RKB 7. Unit or Property Prudhoe Bay Unit 8. Well number 1-11 9. Permit number/approval number 77-57 10. APl number 50 - 029-20268 11. Field/Pool Prudhoe Bay Oil Pool feet 11010 feet 9394 feet Plugs(measured) Sand Plug below 10600' MD 10600 feet 9076 feet Junk(measured) ORIGINAL Size Cemented Measured depth True vertical depth 20" 300 sx Arcticset 120' 120' 13-3/8" 5670 sx PF II 2713' 2713' 9-5/8" 800 sx Cl G & 300 sx PF II 10988' 9375' Perforation depth: measured 10370-10380'; 10462-10472'; 10495-10517'; 10535-10545' true Vertical 8848-8856'; 8956-8965'; 8985-9004'; 9020-9028' Tubing (size, grade, and measured depth) 5-1/2", 17#, N-80, NPCT @ 9894' MD; 4-1/2", 12.6#, N-80, NPC tail @ 10024' MD Packers and SSSV (type and measured depth) Baker SAB packer @ 9894' MD; 5-1/2" Baker PFVE SSSV @ 2208' MD 13. Stimulation or cement squeeze summary Intervals treated(measured) See attached. Treatment description including volumes used and final pressure 14. Re_oresentative Daily Average Production or Injection Data - Oil-Bbl Gas-Md Water-Bbl Casing Pressure Tubing Pressure Prior to well operation 1050 10571 3509 -- 720 Subsequent to operation 2128~' ....... 9043 3955 -- 862 15. Attachments Copies of Logs and Surveys run Daily Report of Well Operations 17. I hereby certify that the foregoing is true and correct . Signed ~'~'- ~" ~ Form 10-404 Rev 06/15/88 '~--~ 16. Status of well classification as: Oil x Gas Suspended Service 1221/14 AJB cc: KZ, JWP to the best of my knowledge. Title Engineering Supervisor SUBMIT IN DUPLICATE (' 1-11 DESCRIPTION OF WORK COMPLETED CTU CEMENT SQUEEZE FOR GAS SHUTOFF 1114194: Added Perforations: 10376 - 10394' MD (Z4) Ref. Log: BHCS 10/26/77. 611194: RIH & tagged PBTD at 10720' MD. 612194: RIH w/CT & pumped gelled sand slurry containing a total of 15,000 lbs of 20/40 mesh sand, to place an isolation sand plug over the lower open perforation intervals located at: 10462 - 10472' MD (Z4) 10495 - 10517' MD (Z3) 10535 - 10545' MD (Z2) Ref. Log: BHCS 10/26/77. Made a final top of sand plug tag at 10418' MD. POOH w/CT. Rigged down. 615194: An Acid Wash & CTU Cement Squeeze were performed for Gas Shutoff as follows: MIRU CTU & PT equipment to 4000 psi. Loaded the wellbore w/Hot Seawater & RIH w/CT to pump an acid wash across the open perforation interval located above the sand plug (listed above). Pumped 30 bbls 1% NH4Cl Water @ 2.0 bpm, followed by 10 bbls Xylene @ 1.9 bpm, followed by 35 bbls 12% HCI w/10% Xylene @ 2.1 bpm, followed by 27 bbls 6% HCl - 0.75% HF w/3% Acetic Acid @ 2.1 bpm, followed by 80 bbls 1% NH4CI Water Flush. Circulated 1 CT volume of 1% KCl Water, then switched to pumping cement. Pumped 15 bbls of Microfine Cement, followed by 21 bbls of Latex Acid Resistive cement & placed 6 bbls of Superfine cement & 2 bbls of LARC cement behind pipe at 3500 psi max squeeze pressure, held for 1 hour. Contaminated cement w/biozan & jetted contaminated cement from wellbore down to 10422' MD. Could not jet past sand/cement interface at 10422' MD. POOH w/CT. Rigged down. 6112194: RIH w/underreamer & reamed cement/sand plug from 10426' to 10445' MD. 6113194: RIH & tagged the sand plug top at 10443' MD. 6114194= Added Perforations 10370 - 10376' MD (Z4) Reperforated: 10376 - 10380' MD (Z4) Ref. Log: BHCS 10/26/7~'~s~'~ b~ & Gas Cons. C0ml~'tss't.oit Ref. Log: BHCS 10/26/77. 6119194: RIH w/CT & jetted a sand plug fill cleanout to 10445' MD. 6~20~94: RIH w/underreamer & reamed out sand plug to 10590' MD. 8128194: RIH w/CT & jetted a sand plug fill cleanout w/Nitrogen to 10600' MD, to uncover the open perforation intervals (listed above). Returned well to production & obtained a valid production test. ARCO Alaska, Inc. Date: June 21, 1994 Subject: ARCO Cased Hole Finals From/Location: John E. DeGrey/ATO-1529 Telephone: (907) 263-4310 To/Location: Distribution Number. (M-D-Y) .- Scale I'~ ! I, 1-06 6-13-94 I/' Dual Burst ~ 1, 5" Sch 1-11 J 6-14-94 j- Perf Record ! 1, 5" Sch 1-25 ! 6-10-94 ~ / Perf Record ~ ' 1, 5" Sch 1-29 { 6-14-94 i"" Dual Burst l 1, 5" Sch 1-30 I 6-08-94 t" CNL 1, 5" Sch 3-02 I 6-07-94 i.,' Tubing Cutter ! 1, 5" Sc'h 3-19 ! 6-05-94 ',~" Perf Record { 1, 5" , Sch , 4-36 ! 6-11-94 '"" Perf Record l 1, 5" Sc~ 4-41 I 6-12-94 ;-"Cutter Recc~rd i 1, 5" Sch 5-11 j 6-11-94 j / Dual Burst j 1,5" ' Sch 9-'~5 J 6-13-94 I / InjPmf f 1, 5" Sch 9-1,8 6-14:94 I / InjPmfl 1, 5" Sch 9-25 6-i4-94 i / injpr°f I 1, 5" . Sch 11-35 6-11-94 j ." Perf Record 1, 5" Sch 11-~36 ~ 6'-07-94 j -"'"'P;~rf Reco~;;d f 1, 5" Sc~ 13-31I 6-09-94 i /' Perf Record i 1, 5" Sch 13-35 I 6-09-94 1 / Perf Record ! 1, 5" Sc.h... J c~2.<~ 14-03 I 6-15-94 ! ~- ProdLo~] i 1,5" Sch i 14-03 f 6-15-94 / Duai Burst 1, 5" Sch " 16'23 i'6'13'94 ]~'Leak Detection 1, ~:: Sch 16-23 6-10-94 [. '~ Alpha Tubing 1, Sci~" ~7-02 6-6-94 1~' Prod Pmf f 1, 1" &5" Sch 18-02 6-12-94 / Perf RecOrd 1, 5" Sch 18-04 ! 6-12-94 I /' Dual Burst 1, 5" Sch 18-19 I 6-10-94t,"t-eak [~et~ction 1, 1" & 5" Sch * The correct APl # for 1-05ST is 50-029-20076-00 Number of Records: E. DeGrey Distribution: Central Files ANO-8 Geology Exxon Mobil Phillips BPX State of Alaska- ARCO Alasla~, Int.. Is a Subsidiary o! AllenlleRIr. hflelaContl3eny ARCO Alaska, Inc. Date: Apr 14, 1994 P.O. Box 100360,(''.. .,chorage, AK Transmittal #: 94034 99510.~ ~ Subject' ARCO Cased Hole Finals From/Location: Telephone: To/Location: John. E. DeGrey/ATO- 1529 (907) 263-4310 Distribution ~ Well E Nurrber c~ ~..~." 01-09A 01-11~ 01-33 03-01 03-02 03-19 03-29 03-31 !/04.43 .. c~-'~Si,/ 04-43 i'~D4'43 ~ 04-44 ! 04-45 i Log Date i Tool Type (M-D-Y)i 04-02-94 i,,' Perf Re~ord . 06-19 07-08 07-23 09-01 09-02 09-03 09-19 09-27 11-04 11-17 11-24A 12-06A i 13-20 -'57.. ~ 14-03 · .' 14-23 03-25-94 I TDT-P 03-27-94 03-22-94 !/ Leak Detection 03-22-94 .L, Bride 03-18-94 ~,' Leak Detection 03-27-94 03-27-94 03-29-94 ],/ TDT-P 03-29-94 03-10-94 ! ¢' USIT 03-13-94 03-29-94 J 03-14-94 Run, Scale 1 5" 1 5" 1 5" I 5" 1 2" 1 5" 1 5" 1 5" 1 5" 1 5" 1 5" 1 5" 1 5" 1 5" 1 5" 14-28 4-28 03-18-94 ?' Pe'.rf Record 04-03-94 [..-, Perf Record 03-21-94 i'/ Bride 03-30-94 i,,' Prod Profile 03-17-94 i./ Prod Profile 03-29-94 i/ Prod 04-01-94 ~v- Perf Record 03-16-94 i/ Prod Lo( 03-22-94 ~' Perf Record 03-16-94 ,,'Patch settin 03-29-94 ./ Perf Record 03-18-94 ~,. Prod Profile 1,5" 1, 1"&5" 1, 5" 1 "&5" 1,5" 1, 5" 1,5" 1, 5" 1,5" 1 "&5" Sch Sch Sch Sch Sch Sch Sch Sch Sch Sch Sch Sch I ~ '14--35 16-04A 16-18 [~.- ~oZ. i 16-28 03-15-94 '-' Leak Detection 03-28-94 l-' CNL 03-19-94 ! --- Prod Profile 03-15-94 i,,' Leak Detection 03-28-94 :v~ Patch .03-21-94 !-'_ Bridge Plug 03-17-94 i v,' CNL 03-15-94 i,,-- Perf Record 03-14-94 !,/' Leak Detection 03-14-94 ~ ,,- Perf Record 03-20-94 i'" TDT-P 1, 1 "&5" 1, 5" i 1, 1"&5" i 511 1 1, 5" 1,5" 1,5" 5II 1, 2"&5" 1, 5" 1,5" Sch Sch Sch Sch Sch Sch Sch Sch Sch Sch Sch Number of Records: 38 ~V ARCO Alask~ Ino. Is a Subsidiary of A~anticRIcMleldCompeny ARCO Alaska, Inc. Date: Subject: From/Location: Telephone: To/Location: i P.O. Box 100360, A~ '.~orage, AK Mar 15, 1994 Transmittal #: 94029 0~ AR e Finals c~(~:~ ~ John E. DeGrey/ATO-1529 (907) 263-4310 Distribution 99510~ ~k, I Well ~ Log Date Tool Type Run, Contractor Nurrbert (M-D-Y) Scale ~- ~ i 01-02 i ~-26-94 Prod/Spin/Temp/{~ 1,5" Schlumber -fo-- ~ 01-03 2-19-94 Prod~BS/Temp~'~ 1, 5" Schlumber ~{= ! ,01-09 3-0:1-94 Tubing Cutter ~' 1, 5" . $chlumber ~.o~.. ~-~ I 01-11 2-27-94 Prod Prof/Spin 1, 5" ,Schlumb,er ~-~- Z_=t ~ 01-18 2-23-94 Leak Detection 1, l"& 5" Schlumber ~7..-- '~'~ f 01-25 I 3-06-94 CNL ~.~ ~ ~'~33-2{~A' 2-1,7-.94 Perf ' 1, 5" Schlumber ~03-20A 3-03-94 Dual Burst '~ '~' ~-~--- ~I~- 03-32 2-26-94 LealdPr~'ss/Temp 1, 2" Schlumber ~'Z.'- I.~ 03-34A 2-24-94 Prod/Press/Temp 1,, 2"&5"' Schlumber . ' . 5'" Schlumber ~% 04-01 2-19-94 Prod ~* 04-24 [ ~-22-94 Prod ciA- t~ 04-40 2-22-94 Perf ' .,1, 5" Schlumb,er ~ ~_~,~ 04-46 , 2-16-94 Rope Perf , 1, 5" . Schlumber o1~_ ./~ =/04-47 2-18.~94 v Perf 1, 5" Schiumber ~ 04-47 '2-15-.94, ." CBT-GR 1, 5" Schlu,mber ~,04-47 2-15-94 v CET. GR =P~- ~O '= 05-06 2-11-94 Perf ct' ~ 05-14A 7-11-93 USiT/Cem&Corr =1~ 05-15A 05.15A cC~ C=N~GR't.~%U ~:~.- [t"~ 05-26 3'02-94 Dual Burst ~)_ ~,'2. /'06-15 2-21-94 Prod 1, 5" Schlumb..er \' 06-15 2-22-94 Comp Neutron 1 ~ ,, 06-22A 3-01-94 Perf Ilo 07-08 3'02-94 Prod~e~ I..~ 07-.2,3 '3-07-94 I~e~k/Spin/Temp~!~ 1, 5" Schlumb'er ~-![o¢~ ,, 09-34 2-21'94 Tubin~l Cutter ~.- ~ 11-02 2-10-94 Ini Pmf/~~, 5" SchlUmber ,~0-I ~ "/'11-04 2-20-94 Tubincj Cutter i~.-- ,5' Sch'lumb,er .'~11-04 2-17-94 Tubin~l ~ t- it~- 11-7ST 3-06-94 ",' Inj Pmf~Spin J~l~'~_ 1, 5" Schlumber 11- 2-25-94 LealdPress/Temp 1, 1"&5" Schlumber ~- ~ 16ST /Spin//~.~b D-"[,~ ~t~- ~ g~l 1-17 .2-2'0-94 . Leak 1, 5" .,,~11-17 3-08-94 Prod 1, ~o-- I[% 11-23 8-09-'91 " TMD 1, 5" Halliburton o~-~.. ~ /~11-24A 3-05-94 I~erf/GR/CCL 1, 5" S.chlumber J\l. 1;24A 2-22-94 Comp/Perf 1, ARCO Ala~ Inc.. I$ · 12-01 i 3-06-94 13-10 2-24-94 14-2B f 1-16-94 14-2B ! 1-16-94 14-2B i 1-16-94 14-2B i 1-16-94 14-2B [ 1-19-94 14-2B ! 1-23-94 .14-2B i 1-23-94 14-24 ! 2-19-94 Prod i 1, 1"&5" Perf ! 1', 5"" ' 2"&5" CNL/GR ~ 1 Sub-Sea i 1, 1"&2" BH~. Acoustiiocj j~¢. 1, 2"&5" Dual LatedoCJ/GR(~,~ 1, 5" Bond/GRIcc{l~ 1, 5" PFC/GFI/CCL i 1, 5" PFC/Collar i 1, 5" i 1, 5" 14-28 ! 3-05-94 Leak , 14-34 ~ 2-15-94 l'Prod/Press/Tempi 16-08 j 3-07-94 I Prod,Prof/Spin 17-21 i 2-24-94 t Perf 02-01 Inj/FBS/Temple¢{ Schlumber Schlumber Schlumber SchlUmb'er Schlumber Schlumber Schlumber Schlumber Schlumber Schlumber * Well 4-24 the 1, 1"&5" Schlumber 1, 2"&5" t Schlumber 1, 2"&5" "1 Schlumber 1, 2"&5" ! Schlumber 1, 5" ! Schlumber correct APl # is 50-029-21508-00 Number of Records: eGrey ' Distribution: Central Files Phillips Chevron ANO-8 Geology BPX Exxon iil.'~tate'.'i;0f ' Alaska .... Mobil Please acknowledge receipt by signing and returning a copy of transmittal. By: I I . ~~:~ ~'~ I Date:. RECEIVED ARCO Alaska, Inc. Date: Subject: From/Location: Telephone: To/Location: P.O. Box 100360, t." horage, AK Jan 28, 1994 Transmittal #: ARCO Cased Hole Finals John E. DeGrey/ATO-1529 (907) 263-4310 Distribution 94016 99510,~ ~, /? lWell Number '~--/~ I 1-3 ~'~' !~ql 1-22 c/0- 2.~ J 2-29A ;r¢-?.,q ~3-23'2 3-16 3-22 3-22 ,3-22 3-35 ~ 3-36 ;~-~,~ 4-13 5-35 5-35 9-13 ~ 9-30st 11-12 11-24 12-16A 15-7 15-7 17-13 18-1 Number of Records:24 ohn E. DeOrey PBOE Document Control i Log Date (M-D-Y) 1-14-94 ~ 1-14-94 ~ 1-13-94 i 1-18-94 I 1-19-94 11-15-94 I 1-10-94 1-19-94 [ 1-16-94 [ 1-10-94 I 1-21-94 [ 1-20-94 i 1-15-94 I1-18-94 [ 1-18-94 01-14-94 1-22-94 [ 1-19-94 1-17-94 ! 1-22-94 [ 1-17-94 1-8-94 1-20-94 Distribution: Tool Type i Run, {~0r..~v4 ~ .~ Scale Tubing Puncher' { 1, 5" Perf Record ~ 1, 5" ~ Bridge Plug ~j~ ¢~:1, 5" CNL~ 1, 5" Ih\ Bridge Plug ~ 1, 5" Leak Determin/FC~lP~s,~, 5"/ Perf Record I 1, 5" Leak Determin Leak Detect Perf Record Contractor Sch Sch Sch Sch Sch Sch Sch Sch Sch Sch Sch Sch Prod Ini Profile IBPSetting Prod Leak Detect Leak Detect Tubin( Corn Record Cutter Puncher Patch Settin Dual Burst TDTP Central Files Phillips Chevron ANO-8 Geology BPX Exxon '", State Of Alaska'~ Mobil ',.:~,, .r .-.... · t 5" 1, 2"&5" 1 511 Sch Sch Sch Sch 1 5" 1 5" I 5" 1, 5" Sch Sch Sch Sch RECEIVED FEB 0 1 1994 Alaska Oil & Gas Cons. Commission Anchorage Please acknowledge receipt by signing and returning a copy of transmittal. By: .._/.~(~,./~.:.~, ~ Date: ARCO Alarm, Inc. I$ a Subsidiary of AtlantlcRIchfleldCompany ARCO Alaska, Inc. P.O.Box 100360 Anchorage, Alaska 99510 DATE: 1-3-94 REFERENCE: ARCO CASED HOLE FINALS ~?-~-~1-11 12-18-93 CNL (Crt) 1 ~ZZO-~i 0~;0 Run 1, 5" 1-18 12-12-93 ~Detect}~[~}Y~}(re~ ~ 1, 5" ~~-22 12-03-93 Peri Reco~ ~9~0 ~lO~oO ~ 1, 5" ~-25 12-17-93 P~d Profile [ ~{~ ~ ~ ~ 1, 5" ~-6 12-05-93 Peff ~co~ ~O~%-Ilqq~ ~ 1, 5" ~-22 10-22-93 ~ (dep~ co~ected) ~ 1, 5" -4 12-20-93 InJ Proffie {~,0 ~~tSS ~ 1, 5" -36 12-11-93 Peff Reco~ I~qO~[~ 0 ~ 1, 5" -1 12-06-93 Peff Reco~ fl~0 ~5~O ~ 1, 5" -I1A 12-13-93 peff~co~ 19~ ~0 ~l~ ~ 1, 5" 4-23A 12-14-93 Dual B~t ~T-P {~] . . ~ 1, 5" "'~-?q4-31 12-11-93 Prod Proflle~f,~m~}~lb)(~} ~1,5" Peri Reco~ _.5-28 12-10-93 Du~ Brat ~T-P · ~;~-2 m-20-~s ~roducUon '~-i 12-5-93 Mak Detect~.~l~'a~ 12-9-93 ~ MI Im ~oflle .... 9-20 12-19-93 ~-36A 12-17-93 CNL } C~ ~-36A ' 12-17-93 D~ B~t~T-P/GR _ _.,~ _ ~~9-51 12-07-93 P~d P~flle 12-14-93 ~d ~~taa~~4.1 12-5-93 ~G Cuter ~-ZZO 16-17 12-4-93 M~ Detec~on ~6-23 12-10-93 ~ Detec~on I~re~ I ~g ~ ~16-29A 12-18-93 Peal ~co~ ~o0-i~l~ ~ 1, 5" 18-29A 10-19-93 ~ (dep~ co~ected) ~ 1, 5" Please sign --d return._~e _attaf~ed c~0p.y ~}r~eeipt of data. "RECEIVED - ',Bv_'~_'~~-~t~ / John E, DeGrey APPROVED /,.,' AT0-1529 Trans# 9400~-/--r # CENTRAL FILES # CHEVRON # BPX # STATE OF ALASKA 1, 5" Sch 1, 5" jo~!c(.'.'., -.'.'0'?-~..? I Sch 1, 5" ~,yt 0 --[~-~')C. Sch 1, 5" <~ ~.9C ..- ~.q c C Sch 1, 2"&5"~"~ o '-lc 1, 5" ~C0 ~lSdo Sch 1, 5" Sch l, 5" ~o~0-~.5~ Sch 1, 1"~" O- {~ Sch 1, 5" l~50- IZ~ 5 Sch 1, 5" q~50~ I~ Sch . 1, 5" Sch 1, 5" Sch 1, T, 5"~" ~> 1,~&5"~-- II~'~O Sch · Sch ~h ~ ~0~ G~O~GY ~ ~ON ~ MOB~ The correct well name is 4-1lA and the corrected API# is 50-029-20286-01 The correct well name is 4-31 and the corrected APl# is 50-029-21334-00 The correct well name is 18-29A _~nd the corrected APl# is 50-029-22316-01 ARCO Alask~ Inc. P.OJ]ox 10O360 Anchorage, Alaska 99~10 DATR: 10-8-93 77- 5'7 1-11 -~~-12 ~4-29 -42 1 ~'7-q~ · 1-25 ~-ql 14-24 ~.~~15-18 e~15-3o qa-?s 16-31. ~7-21 8-29-93 8-29-93 8-29-93 9-7-93 9-7-93 9-3-93 9-8-93 9-3-93 9-4-93 9-4-93 9-10-93 8-31-93 8-31-93 9-2-93 9-10-93 8-29-93 9-5-93 9-12-93 8-30-93 9-10-93 9-3-93 .9-5-93 9-7-93 9-4-93 ' , . Prod Proffiel~~ele~ Run 1, 5" Prod ~offie/~n{~~f R~ 1, 5" ~od ~offie {~lw~~ R~ mj ~o~e & S~flc;S~~~~ 5" ~~Sch ~j ~o~e & S~flc/~'~ir~~ 5"~o~~ch D-~! Burst TDTP Rult_ L 5" ~p. qc~- 8ch InJ Proffie & Static I~IT~-~,>5" ~?~-a ~o 8ch Dual Burst TlYrP Run 1, 5"~o~-q~o Sch Peri Record t~-tto~e~ Run 1, 5" Sch Peri Record ~s~-,o-,'l~.ct5 Run 1, 5" Sch . Productiong~al~J~m~e Run 1, l"&5" e~-schq~=5 USIT (Cement] Color R~ 1, 5"~ t~~ch~ USIT (~sion) ~lor R~ 1, 5"t~~q Sch ~ B~t ~ R~ 1, 5" ~ ~-- Sch~ ~od ~offie~[~~ R~ 1, 5'~ Sch ~- as~ ~od ~offiel~iT~~ R~ 1, 5" ~o~ Sch ~ C~ l~ ~ ~~ R~ 1, 5" 8ch mP %~~o R~ 2, 5" 8ch ~ Detectl~l~R~ 1, 2" 10o-~ Sch Peff Record ~z~-~$~ R~ 1, 5" Sch GR/CCL [TCP ~e-~] R~ 1, 5" ~~ ~~z~o ~ ~/~al~i~/~ R~ 1, r'&5" ~- Sch ~t ~ ~ ~ ~- ~~ R~ 1, r'&5" Sch Pe~Record %~o R~ 1, 5" Sch Please sign and return the attached copy as receipt of data. RECEIVED BY___~~ Have A Nice Da~t : Sonya Wallace ATO-1529 # CENTRAL FILES # CHEVRON # CLINT CHAPMAN # EXXON # MOBIL The correct top logged interval for this log is 12,900 feet. The correct top logged interval for this log is 10,400 feet. STATE OF ALASKA ' ALASKA(' .AND GAS CONSERVATION CO( tlSSION ' REPORT UF SUNDRY WELL OPEHATIONS/O. Operations performed: Pull tubing .~. Alter casing ~ Repair well Other ~ '~~J_ I 1. Operation shutdown ~ Stimulate Plugging Perforate. X v~.~ ~ ~.. T-'~';' of W---'~'~ m ~'. ~vation(DF~6~_ I Development X 73 RKB ~,~faet I Exploratory ~ ~ ~ ~ ~'-- _~ Stratigraphic ~ 7. Unit or Property '( J 2. Name of Operator ARCO Alaska, Inc. 3. Address P.O. Box 100360, Anchorage, AK 99510-0360 4. Location of well at surface 898' FNL, 777' FWL, Sec. 8, T10N, R15E, UM At top of productive interval 1324' FSL, 1541' FEL, Sec. 8, T10N, R15E, UM At effective depth 1023' FSL, 1372' FEL, Sec. 8, T10N, R15E, UM At total depth 971' FSL, 1343' FEL, Sec. 8, T10N, R15E, UM Service Prudhoe Bay Unit RECEIVED AU 2 0 199 Alaska .0il .& Gas Cons. C0mmis~, Anchorage 8. Well number 1-11 9. Permit number/approval number 77-57 10. APl number 50 - 029-20268 i~i-t. Field/Pool Prudhoe Bay Oil Pool 12. Present well condition summary Total depth: measured true vertical 11010 feet 9394 feet Plugs(measured) PBTD Tag @ 10749' MD (6/3/93) Effective depth: measured 10749 feet true vertical 9191 feet Junk(measured) Casing Length Size Cemented Measured depth True vertical depth Conductor 120' 20" 300 sx Arcticset 120' 120' Sudace 2640' 13-3/8" 5670 sx PF II 2713' 2713' Production 10915' 9-5/8" 800 sx Cl G & 300 sx PF II 10988' 9375' Perforation depth: measured 10462-10472'; 10495-10517'; 10535-10545' true vertical 8956-8965'; 8985-9004'; 9020-9028' Tubing (size, grade, and measured depth) 5-1/2", 17#, N-80, NPCT @ 9894' MD; 4-1/2", 12.6#, N-80, NPC tail @ 10024' MD Packers and SSSV (type and measured depth) Baker SAB packer @ 9894' MD; 5-1/2" Baker PFVE SSSV @ 2208' MD 13. Stimulation or cement squeeze summary Intervals treated(measured) See attached. Treatment description including volumes used and final pressure 14. Representative Daily Averaae Production or Injection Data OiI-Bbl Gas-Md Water-Bbl Casing Pressure Prior to well operation 1506 '"; ..... 16571 3269 Subsequent to operation 1080 ......... 7824 1982 Tubing Pressure 1315 318 15. Attachments Copies of Logs and Surveys run Daily Report of Well Operations 16. Status of well classification as: Oil x Gas Suspended Service 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed Title Engineering Supervisor Form 10-404 Rev 06/15/88 1020/4 DEE cc: SW, JWP Date ¢'~---/J'/~-'~' SUBMIT IN DUPLICATE 1-11 DESCRIPTION OF WORK COMPLETED CTU CEMENT SQUEEZE FOR GAS SHUTOFF 5124193: RIH & tagged bottom at 10872' MD. 5/26193: An Acid Wash & CTU Cement Squeeze for Gas Shutoff were performed as follows: MIRU & PT equipment to 4000 psi. Loaded the wellbore w/Hot Seawater, then RIH w/CT & reciprocated a presqueeze acid wash across the open perforations located at: 10420 - 10425' MD (Z4) 10438 - 10440' MD (Z4) 10462 - 10470' MD (Z4) 10470- 10472' MD (Z4) 10495 - 10505' MD (Z3) 10505 - 10517' MD (Z3) 10535 - 10545' MD (Z2) 10555 - 10570' MD (Z2) 10575 - 10585' MD (Z2) 10591 - 10601' MD (Z2) Ref. Log: BHCS 10/26/77. Pumped 53.5 bbls 12% HCI w/10% Xylene, followed by 50.5 bbls 9% HCI - 1% HF @ 3.2 bpm, followed by 107 bbls 1% NH4CI Water, followed by 10 bbls Seawater spacer. Continued pumping 61 bbls Latex Acid Resistive cement, to squeeze the perforations (listed above). Placed 21 bbls of cement behind pipe at 3500 psi maximum squeeze pressure, held for 1 hour. Contaminated cement & jetted cement from wellbore to 10750' MD. POOH w/CT. Rigged down. 5/29193: RIH & tagged bottom fill at 10436' MD. 5131193: RIH w/CT & jetted a fill cleanout from 10480' to 10750' MD. PT the squeeze to 1500 psi OK. RD. 611193: RIH & tagged bottom fill at 10753' MD. 614193: Reperforated: 10462 - 10472' MD (Z4) 10495 - 10517' MD (Z3) 10535 - 10545' MD (Z4) Ref. Log= BHCS Tagged bottom at 10749' MD. POOH w/perforating gun. AUG 2 0 t993 Rigged down. ~a$~ 0/J & Gas Cons. Commission ~chorage Placed well on production & obtained a valid production test. Note: Oil rate decreased by 426 BOPD, but the decrease in gas production provided an incremental rate benefit of 1093 BOPD, resulting in a net oil benefit of 667 BOPD. ARCO Alaska. Inc. P.O.Box 100360 Anchorage, Alaska 99510 DATE: 7-20-93 REFERENCE: ARCO CASED HOLE FINALS 1-3 ~]0 ~ 6-4-93 Peri' Record R~m 1, 5" 1-11 ~_~'~ 6-4-93 Peri Record R-~ 1.5" 1-12 ~ 6-4-93 Peff Record R~m 1, 5" 4-76T ~ fl~l 5-30-93 CBT R._n 1, 5" 4-76T ~ / 5-30-93 TDTP (Borax) R.n 1, 5" 4-76T ~. ~,/5-31-93 Peri Record R!m 1, 5" Peri Record 1, 4-18 ~ ~ 5-31-93 R._~ 5" 5-14~/I'_~/ 6-2-93 TBG Puncher Record Run 1, 5" 5-19~.~ 6-5-93 Production Log R,- 1, 5" 13-3 ~.~'~/, 6-1-93 Leak Detect R~_m 1, l"&5" 13-8~~' _ 6-3-93 Gas Tilt/Leak Detect R._~ 1, l"&5" 14-8~ ~'~, 6-3-93 Leak Detect Run 1, 2" 16-30~/1~P6-1-93 InJ Profile R.n 1, 5" 16-30-~ - 6-1-93 TDTP (Borax) Run 1, 5" Sonya W-"~ce dO[. 3 0 PROVED ' l~s$ 93~2 ATO- 1529 ~a;~ 0il & Gas cons. C0mmi~ion · ... # CENTP-AL # CHEVRON D&M # CLINT CHAPMAN # EXXON MARATHON # MOBIL # PHILLIPS PB WELL FILES R&D # BPX # STATE OF AIASKA TEXACO Sch Sch Sch $ch $ch $ch Sch Sch Sch Sch Sch $ch $ch Sch .,~,R~ .Maska, Inc. P. 0 .Box 100360 Anchorage, Alaska 99510 DATE: 4-22-93 REFERENCE: ARCO CASED HOLE FINALS '~--~ 1-9 3-29-93 1-11~,,,.q,, ~ 7,, ~,2-9s ~-1951-19 .....~ ...... I':22-9s ~~ 1-29 4-6-63 1-33 ~-~ 4-4-93 ~-~2~8 3-27-93 2-,~ ~~ 4-2-s3 7~~ 3-8 3-28-93 3-10 ~~ 3-28-93 ~0 -~ 4-2 3-20-93 4-29 ~-~3-26-93 ~~ 4-33 3-25-93 5-11 ~9~ 3-29-93 9~~ 6-3 4-5-93 6-9 ~7~ 4-5-93 ~ ~ 6-1S 3-30-93 6-22 ~~ 3-26-~3 -4A '--9-ss~ 4- x-os 12-11 ~~ 3-31-93 ~~3-20 3-21-93 14-15 ~~ 3-30-63 4-22A 4-2-93 16-30 ~-~ 3-21-93 ~~17-20 3-22-93 ~7-20 4-3-93 ~~~8-26 3-23-93 ~8-26 8-24-93 18-27 3-23-~3 3-24-63 Leak Detect Run 1. 1".5"&2~* Production Run 1, Production Run 1. Perf Record Run 1, Production Run 1. Perf Record Run 1, In# Profile Run 1, Perf Record Run 1, Production Run 1. Tubing Puncher Run 1, CNL Run 1, Static Pressure Run 1. Press/Temp/Spin Run 1, 2~'&5" Static Pressure Run 1, Production/Gas Entry Run 1, Perf Record Run 1, Leak Detect Run 1, Production Run 1, Peri Record Run 1. Perf Record Run 1, Static Pressure Run 1, Perf Record Run 1, Production Run 1, Perf Record Run 1, Production Run 1, PITS Run 1, I~' Perf Record Run 1, Perf Record Run 1, Perf Record Run 1, Perf Record Run 1, Static Pressure Run 1. GR/CCL Run 1. Static Pressur~ Run 1, GR/CCL Run 1, Sonya Wallace 9_ '~ ~ APPROVED # Exx[~( ~ # STATE OF ALASKA Sch Sch Sch 8ch Sch Sch Sch Sch Sch Sch Sch 8ch Sch Sch Sch Sch Sch Sch Sch Sch 8ch Sch Sch Sch Sch Sch Sch Sch Sch Sch Sch Sch Sch Sch ARCO Alaska. Inc. P.O~ 100360 Anchorage. Alaska 99510 DATE: 77,-- %1-11 -30 -14 -/cl.- ~'/.- 3-9 ~-24 3-32 ~3-32 -~~--'S-S4A .4-ss ~_.~.~ 9-27 ,9-27 ~-61 1-18 1-18 ~ I-' \%'7 --- 12-4A ,~ ~.,.... ~.~%..--,,,~]. 2 - 19 ~~ ~12-32 4-37 4-37 RECEIVED 4-13-92 PSGT 6-21 7-23-92 PSGT Computed Results 6-21 7-23-92 PSGT -'~-~4-.~-'~ 16-27 8-23-02 Perf Record ~4~- ~ 16-30 2-12-93 Perf Record ~~1~ 7-21 12-20-92 Perf Record Pleue s~gn and return t~e attached copy u receipt of data. 8onya Wallace ATO-1529 APR 1 9.1993 RRFERENCE: ARCO CASED HOLE fINALS A/aska 0il & (]as Cons. Co;nmleslon 1-24-93 Peri Record ~~" 2-7-93 Peri Record Run 1, ~' HL~ 2-7-93 Peri Record Run 1. ~' HL~ 2-20-93 Peri Record Run 1, ~' HL~ 1-24-93 Peri Record Run 1, [~' HL~ 7-27-91 TMD Run 1, ~' HL8 12-19-92 Peri Record Run 1, ~' HL8 1-25-93 Peri Record Run 1, [~* HL8 4-25-92 PGST Computed Results Run 1, ~' HL8 4-25-92 PSGT Run 1, [~' HL8 2-19-03 Peri Record Run 1, ~' HL8 2-10-93 Peri Record Run 1, [~' HI~ 8-16-92 TMD Run 1, [~' HL8 10-27-02 DSN Run 1, ~' HL8 8-18-92 TMD Boron Injection Run 1, [~' HL8 2-22-93 Peri Record Run 1, 5" HLS 3-2-93 Peri Record Run 1, ~' HL8 3-1-92 PSGT Computed Results Run 1, [~' HL8 3-1-92 PSGT 5 Ft/Mln Run 1, ~' HI.8 3-1-92 PSGT 10 Ft/Min Run 1, ~* HL8 2-6-93 Peri Record Run 1, [~' HLS 2-8-03 Peri Record Run 1, ~' HLS 4-21-92 PSGT Computed Results Run 1, [~' HL,q 4-21-92 PSGT Run 1, [~' gI~q 3-8-93 Peri Record Run 1, ~' HL8 4-14-92 PSGT Computed Results Run 1. ~* HL8 4-14-92 PSGT Run 1, ~' HL8 2-11-93 Peri Record Run 1, ~' HI,8 2-11-93 Peri Record Run 1, [~' HL8 12-22-92 Perf Record ' Run 1, [~' HL8 12-26-92 Peri Record Run 1, [~' HLS 2-20-93 Peri Record Run 1, ~' HLS 4-24-92 PSGT Computed Results Run 1, 4-24-92 PSGT Run 1, [~' HLS .4-13-92 PSGT Computed Results Run 1, [~' HL8 Run 1. ~' HL~ Run 1, ~' HL~ Run 1. ~' HL~ Run 1. ~' HL~ Run 1. Run 1. I;' HIS PHILLIPS MOBIL BPX STATE OF ALASKA # CENTRAL FILE~ # CHEVRON # LUCILLE JOHNSTON # EXXON * The correct apl# for 3-32 is 50-029-21141-00. ARCO Ahsk~ lac. P.O.Box 100360 Anchorage, Alaska 99510 DATE: 3-22-93 ARCO CASED HOLE FINALS ~1~93 CNL 3-1~93 CNL 3~6-~ Dual Brat ~ ~~ D~ Brat ~ ~1~ ~~ ~7~ ~ ~ ~ ~~ Ve~g ~I-5 ~~ ~/~~ S~ ~d ~~ ~e atoned copy Nice ~y! . , Sonya Wa~ce ATO-1529 Sch Sch Sch Sch Sch Sch Sch' Sch Sch Sch Sch Aths Sch Atlas Sch Sch Atlas 8ch Atlas Atlas APPROVED_.~~___ Trans# 93042' # .CENTRAL ~ .# ~ # CHEVRON PB WELl. FILES , D&M R&D ' # LUCII2~ JOHNSTON # BPX ., # EXXON # ~'r&TE OF ALASKA MARATHON 'rEx~ # MOBIL The correct APl# for 1-31 is 50-029-21626-00. The correct well n_~,~e for this log is 16-4. STATE OF ALASKA ALASK,~¢ '_ AND GAS CONSERVATION C~" MISSION - ' REPORT'uF SUNDRY WELL OPERATIONS Operation shutdown Stimulate Plugging Perforate X Alter casing Repair well Other 1. Operations performed: Pull tubing ...-- 2. Name of Operator ARCO Alaska, Inc. 3. Address P.O. Box 100360, Anchorage, AK 99510-0360 5. Type of Well Development Exploratory Stratigraphic Service 4. Location of well at surface 898' FNL, 777' FWL, Sec. 8, T10N, R15E, UM R E C E iV £ At top of productive interval 1324' FSL, 1541' FEL, Sec. 8, T10N, R15E, UM At effective depth MAR 1 5199 1023' FSL, 1372' FEL, Sec. 8, T10N, R15E, UMAlaska 0il & Gas Cons. At total depth Anchorage 971' FSL, 1343' FEL, Sec. 8, T10N, R15E, UM 6. Datum of elevation(DF 73 RKB 7. Unit or Property Prudhoe Bay Unit 8. Well number 1-11 9. Permit number/approval number 77-57 10. APl number 5O - O29-2O268 11. Field/Pool Prudhoe Bay Oil Pool feet 12. Present well condition summary Total depth: measured 11010 feet Plugs(measured) true vertical 9394 feet Effective depth: measured 10945 feet true vertical 9342 feet Junk(measured) Casing Length Size Cemented Conductor 120' 20" 300 sx Arcticset Surface 2640' 13-3/8" 5670 sx PF II Production 10915' 9-5/8" 800 sx CI 'G' & 300 sx PF II Measured depth Trueve~icalde~h 120' 120' 2713' 2713' 10988' 9375' Perforation depth: measured 10420-10425'; 10438-10440'; 10462-10472'; 10495-10517'; 10535-10545'; 10555-10570'; 10575-10585'; 10591-10601 '; true vertical 8920-8925'; 8938-8940'; 8955-8964'; 8985-9004'; 9018-9027'; 9037-9050'; 9054-9063'; 9068-9077' Tubing (size, grade, and measured depth) 5-1/2", 17#, N-80, NPCT @ 9894' MD; 4-1/2", 12.6~, N-80, NPC tail ~ 10024' MD Packers and SSSV (type and measured depth) Baker SAD packer @ 9894' MD; 5-1/2" Baker PFVE SSSV @ 2208' MD 13. Stimulation or cement squeeze summary Intervals treated(measured) See attachment Treatment description including volumes used and final pressure 14. Representative Daily Averaqe Production or In!ection Dat.~ OiI-Bbl Gas-Mcf Water-Bbl Casing Pressure Prior to well operation 1545 16167 3582 .... Subsequent to operation 2096 19934 3958 .... Tubing Pressure 1161 .... 1221 15. Attachments Copies of Logs and Surveys run Daily Report of Well Operations X 16. Status of well classification as: Oil X Gas Suspended Service 17. I hereby certify that the fore is true and correct to the best of my knowledge. .Signed.~ ~'~ Title Senior Engineer Form 10-404 Rev 06/15/88 Peirce cc: S. Wallace/DS Engr/J."W. Date SUBMIT IN DUPLICATE REPORT OF WELL OPERATIONS DS 1-11 API# 50-029-20268 PERMIT 77-57 ARCO Alaska, Inc. perforated the subject well within the Sadlerochit interval as follows: INTERVAL 1O495-105O5 10462-10470 10470-10472 10535-10545 TVD ZONE COMMENTS DATE 8985-8994 3 REPERF 3/7/93 8955-8962 4 REPERF 2/7/93 8962-8964 4 ADPERF 2/7/93 9018-9027 2 REPERF 1/24/93 MD intervals reference 10/26/77 BHCS. RECEIVED Alaska 0il & Gas Cons. Commissior~ Anchorage ARCO Alaska, Inc. P.O.,Box 100360 Anchorage, ,A~.et,.~ 99510 DATE: 10-2-92 REFERENCE: ARCO CASED HOLE FINALS 8-21-9~ Prod Profile ~~.- d-~u 8-30-~ GR/ColLur Run 1, ~" '~'---~',~2 9-8-93 Temp 7-~ ~., 9-7-92 prrs ~ ~j ~rome ~. ~, ~ conn./ntte~. 8-31-93 Leak Detect (FlentnkJ Please sign and return_. th/~ atta~l, copy es ree~ of data. RECEIVED B~ Sonya Wa]bce OCT 0 § 199~_ _APPROVED-~-- ATO-1529 0221~-'~--- Alas~ 0it & Gas Cons, commi.~uns# Anchorage # CENTRAL ~ # CHEVRON D&M # EXTENSION EXPLORATION # EXXON # MOBIL #PHILLIPS PB~~ R&D # BPX # .STATE OF ALASKA C-qmco Cum©0 Camco ~meo * Tlds is not a fleM print for 1-11. STATE OF ALASKA Ii~ i G I N j~ ALASKA~' . AND GAS CONSERVATION C~'" ,,IlSSION 0 REPORT SUNDRY WELL OP -dATIONS ,D Stimulate ~_ Plugging Perforate X Repair well Pull tubing Alter casing 1. Operations performed: Operation shutdown 2. Name of Operator ARCO Alaska, Inc. 3. Address P.O. Box 100360, Anchorage, AK 99510-0360 5. Type of Well Development Exploratory Stra~Jgraphic Plugs(measured) Other 6. Datum of elevation(DF or KB) 73 RKB feet 7. Unit or Property Prudhoe Bay Unit 8. Well number 1-11 9. Permit number/approval number 77-57 10. APl number 50 - 029-20268 11. Field/Pool Prudhoe Bay Oil Pool 4. Location of well at surface 898' FNL, 777' FWL, Sec. 8, T10N, R15E, UM At top of productive interval 1324' FSL, 1541' FEL, Sec. 8, T10N, R15E, UM At effective depth 1023' FSL, 1372' FEL, Sec. 8, T10N, R15E, UM At total depth 971' FSL, 1343' FEL, Sec. 8, T10N, R15E, UM 12. Present well condition summary Total depth: measured 11010 feet true vertical 9394 feet Measured depth True vertical depth 120' 120' Effective depth: measured 10945 feet true vertical 9342 feet Junk(measured) Casing Length Size Cemented Conductor 120' 20" 300 sx Arcticset Surface 2640' 13-3/8" 5670 sx PF II Production 10915' 9-5/8" 800 sx Cl 'G' & 300 sx PF II S E P 1 0 199~ Alaska 0ii & Gas Cons. Commission Perforation depth: measured 10420-10425'; 10438-10440'; 10505-10517'; 10555-10570'; 1{~5~-0{~5'; 10591-10601 '; true vertical 8920-8925'; 8938-8940'; 8994-9004'; 9037-9050'; 9054-9063'; 9068-9077' Tubing (size, grade, and measured depth) 5-1/2", 17#, N-80, NPCT @ 9894' MD; 4-1/2", 12.6~, N-80, NPC tail ~ 10024' MD Packers and SSSV (type and measured depth) Baker SAB packer @ 9894' MD; 5-1/2" Baker PFVE SSSSV @ 2208' MD 13. Stimulation or cement squeeze summary 14. Intervals treated(measured) See attachment Subsequent to operation 15. Attachments 16. Status of well classification as: Copies of Logs and Surveys run Daily Report of Well Operations ~ Oil. X Gas Suspended 17. I hereby certify that the fo~g.~oing is true and correct to the best of my knowledge. Signed ~ (~' ,,~ ~"~",~-- -- Title Senior Engineer Form 10-404 Rev 06/15/8~,/ . Treatment description including volumes used and final pressure Reoresentative Daily Average Production or In!ection Dat~, OiI-Bbl Gas-Md Water-Bbl Casing Pressure Prior to well operation 1506 13961 3257 .... ,. 1702 .... 16579 3489 .... Tubing Pressure 1051 1106 cc: S. Wallace/DS Engr/J. W. Peirce Service Date ~.//~Z--~ SUBMIT IN DUPLICATE ~ REPORT OF WELL OPERATIONS DS 1-11 APl # 50-029-20268 PERMIT 77-57 ARCO Alaska, Inc. perforated the subject well within the Sadlerochit interval as follows: INTERVAL TVD ZONE COMMENTS DATE 10505-10517 8994-9005 3 REPERF 8/7/92 ,E'E' EIVED S E P 1 0 1992 Alaska Oil & Gas Cons. ~;or~mission Anchorage ARCO .~;;;k~, Inc. P.O.Box 100360 Anchorage, Alaska 99510 DATE: 8-21-92 REFERENCE: ARCO CASED HOLE FINALS 1-11 8-7-92 6-12A~~8-6-92 9-44 ?,~/>~ 8-8-92 13-13J~ 8-9-92 13-13 8-9-92 15-12 8-2-92 15-18~,;-~d 8-10-92 ~.c-~/16-7 8-8-g2 O2L Rrm 1, 5" PFC/GR Run 1, 5" CCL Run 1, 5" CCL/Tubing Patch Run 1, 5" CCL Run 1, 5" CNL Run 5, 5" GR Run 1, 2"&5" CCL Run 1, 5" Please sign and retum ~he attache~opy as receipt of data. RECEIVED SOnya W~_ll. ce APPROVED ATO- 1529 Trans# 92193 ) Atlas Atlas Atlas Arias Atlas Sch Arias Aths # CENTRAL FILES # CHEVRON D&M # EXTENSION EXPLORATION # EXXON MARATHON # MOBIL # PHILLIPS PB WELL FILES R&D # BPX # STATE OF ALAS~ TEXACO RECEIVED SF..P 0 ~ 1992. Alaska Oil & Gas Cons. Commission Anchorage ARCO ALASKA, INC. P.O. BOX iE)0360 ANCHORAGE,. ALASKA DATE: 7-i2-9t REFERENCE: ARCO CASED HOLE FINALS t-ti 6-5-9t PROD PROFILE-~"' RUN t, 5" CAMCO i-ii 6-5-?t GR-COLLAR -~' RUN t, 5' CAMCO ~-2~ 6-?-?~ PROD PROFILE~ RUN ~, 5' CAMCO 2-4 6-3~-9~ CCL-PERF~ RUN ~, 5' ATLA~ 4-i 6-ii-9i GAB LIFT/ RUN t, 5' CAMCO ~4-36 6-i9-9i CBT/ RUN ,, S" ~CH ~1~(,4-36 6-i9-9i CET~ RUN t, 5' ~CH 4-36 6-2i-9t F'FC-GR (PACKER ~ETI'ING~ RUN t, 5' ATLA~ ~4-37 6-2i-9i CBT~ RUN i, 2'&5" ~CH ~.~ ~ 4-37 6-2t -9t CET~ RUN t, 2 "&5" ~CH -m _'~4-3'~ 6-24-9i PFC-GR (PACKER SETTING~ RUN t, 5" ATLAS ~ I'~J~-3t 6-28-9i GR-CCL~ RUN t , 5" AI'LA~ ~~)5-33 7-2-9i COLLAR-F'ERF~ RUN i, 5' Al'LA&' -33 7-2-9t PRODUCTION PACKER~ RUN t, 5' ATLA~ 5-3 &-3e-gl SBLYGRYCCL- RUN i, 5" ATLA&' ~-t5 6-3~-9t CCL-PERF~ RUN t, 5" AI'LA~ . 9-6 6-i6-9i LEAK I)EI'ECTIO~ RUN t, 2"&5" CAMCO 9-8 6-5-9t PERFORATION BREAK~OWN~ RUN t, 5" CAMCO 9-9 6-23--9i COLL. AR-PERF'~ RUN i , 5" AI'LA~ ** 9-t~ 4-t7-9i INJ PROFILE.~ RUN t, 5" CAMCO 9-i8 6-i3-9i JEWE[.RY.~ RUN i , 5" CAMCO 9-33 6-t4-9i LEAK ~ETECTIO~ RUN t, 2" CAMCO )~. 9-4e 6-i2-9i INJ PROFILE~ RUN i , 5" CAMCO ~ 0 ~1~9-47 6-8-9i DATA FRAC 'FEMP~ RUN t, 5" CAMCO *. ti-3 4-t?-~t LEAK ~ETECTION~ RUN t, 5" CAMCO ~. ~t t-5 e-t~-gi PRO~ PROFILE~. RUN t, 5' CAMCO t i-22 7-i-9i P~K--t ee/GR/CCL-BORAX~ RUN t, ~" ATLA~ t2-t2 6-t6-9i LEAK ~ETECTION-- RUN t, ~"&5" CAMCO t)-i5 6-i?-9i INJ PROFILE-- RUN t, 5 · CAMCO **** i3-t6 &-i?-gi INJ PROFILE~ RUN t, 5" CAMCO t 6-i 6 6-i 3-9i INJECTION/PRO~UCTIO~ RUN t, 5" CAMCO t?-t &-t&-gi PRI~ RUN t, 5" ATLA~ iT-it 5-8-9i LEAK ~ETECI'IO~ RUN t, 2"&5" CAMCO RECEIVED BY HAVE A NICE DAY! $ONYA WALLACE ATO-t527 DISTRIBUI*ION CENTRAL FILES CHEVRON EXTENSION EXPLORATION EXXON MARATHON MOBIL BPX STATE OF ALASKA TEXACO * CORRECTED.LOG INTERVAL FOR 9-6 I$ 670~-77ee ** REFERENCE MIX UP ON TRANSMITTAL 9ti57 - POSSIBLE DUPLICATE LOGS *** CORRECTED LOGGED INTERVAL FOR ?'4~ IS t375t-~425i **** CORRECTED API~ FOR t3-t6 I$ 50-~29-2~823 STATE OF ALASKA " ALASKA( . AND GAS CONSERVATION CO~:' IISSIC~I REPORT t l:: SUNDRY WELL OPF-HATIONS 1. Operations performed: Opera~ion shutdown Stimulate .--- Plugging Perforate Pull tubing ~ Alter casing ~ Repair well Other 2. Name of Operator ARCO Alaska, Inc. 3. Address P.O. Box 100360, Anchorage, AK 99510-0360 4. Location of well at surface 898' FNL, 77' FWL, Sec. 8, T10N, R15E, UM At top of productive interval 1324' FSL, 1541' FEL, Sec. 8, T10N, R15E, UM At effective depth 1023' FSL, 1372' FEL, Sec. 8, T10N, R15E, UM At total depth 971' FSL, 1343' FEL, Sec. 8, T10N, R15E, UM 12. Present well condition summary 5. Type of Well Development X Exploratory _ Stratigraphic 6. Datum of elevation(DF or KB) 73 RKB 7. Unit or Property Prudhoe Bay Unit 8. Well number 1-11 9. Permit number/approval number 77-57 10. APl number 50 - 029-20268 11. Field/Pool Prudhoe Bay Oil Pool Total depth: measured true vertical Effective depth: measured true vertical Casing Length Conductor 120' Surface 2640' Production 10915' 1 lO10 feet Plugs(measured) 9394 feet 10945 feet 9342 feet Junk(measured) Size Cemented Measured depth 20" 300 sx Artic Set 120' 13-3/8" 5670 sx PF II 2713' 9-5/8" 800 sx CL 'G' & 300 sx PF II 10988' feet Perforation depth: measured 10420-10425'; 10438-10440'; 10555-10570'; 10575-10585'; 10591-10601' True vertical depth 120' 2713' 9375' true vertical 8920-8925'; 8938-8940'; 9036-9050'; 9054-9063'; 9068-9077' Tubing (size, grade, and measured depth) 5-1/2", 17#, N-80, NPCT @ 9894' MD; 4-1/2", 12.6#, N-80, NPC tail @ 10024' MD Packers and SSSV (type and measured depth)Baker SAB packer @ 9894' MD; 5-1/2~B~p F~/~/.~¥.~ @ 2208' MD 13. Stimulation or cement squeeze summary .'. · ~ ,,., a,= ~ w h,=,~ Intervals treated(measured) Treatment description including volumes used and final pressure Reoresentative Dai!v Averaae Production or In!ection Dat~ .......... ~' Prior to well operation OiI-Bbl Gas-Md Water-Bbl 3027 13348 533 3951 13620 401 '=:,~.OJi.& Gas Cons, ~.o..ml~ SS~:~.; .' Casing Pressure Tubing Pressure 1351 14. 1418 Service Date Subsequent to operation 15. Attachmeats 16. Status of well classification as: Copies of Logs and Surveys run Daily Report of Well Operations x Oil. x Gas Suspended 17. I hereby certify/~at the foregoing is true and correct to the best of my knowledge. SJgned~4~...~r.~l~/l '~/Z,.._ Title Senior Area Engineer SUBMIT IN DUPLICATE Form 10-~04 Rev 06/{5/88 ' ' - - ~. DESCRIPTION SUMMARY PRUDHOE BAY UNIT DS1-11 WELL APl # 50-029-20268-00 PERMIT # 77-57 ARCO Alaska, Inc. perforated the subject well in the Sadlemchit Sandstone as follows: Measured De_otb Subsea De_otb Zone Comments Date 10419-10424' 8847-8852' 4 Add Perf 9/1 2/90 10440-1 0442' 8865-8867' 4 Add Perf 9/1 2/90 ARCO ALASKA, INC. F'~O. BOX iOOS68 ANCHORAGE, ALASKA ~ . · . DATE' 9-28~78 995 ~ O REFERENCE' ARCO CA£ED HOLE FINALS RECEIVED .... , 0 1990 Alaska 0i~ & Gas Cons. Commission Anchorage t-lO 9-i2-90 PERF RECORD R'UN i , 5' i-i i 9-i 2-9t] F'ERF RECORD RUN i ,. 5' 2-iS 9-22-90 CNL-GR RUN i, 5' tt-4 9-t~-99 PERF RECORD RUN f, 5' i t -t i 9-20-90 CNL.-GR RUN i , 5' i i-J6 9-2~-9~ F'ERF RECORD RUN i , S" i i-27 m-2e-me CNL-GR RUN i , ~" 'i5-2 ~-t8-99 COLLAR/PERF RUN i, 5' PLEASE SIGN AND RETURN THE ATTACHED COF'Y AS RECE:'IF'T OF DATA. RECEIVED BY ~__~__ HAVE A NICE DAY! SALLY HOFFECKER AT0-t529 SCH $ C H A T i...A $ SCH A i' L A,S' SCH A i' I... A S A'i i_AS CENTRAL FILES CHEVRON D&M EXTENSION EXPLORATION EXXON MARATHON MOBIL .f. PHIL. LII='£ F'B WELL FILES R & D' '~ BPX -r STATE OF' ALASKA TEXACO ~.~ RU._, AL_ASK A .[NC F'., O. BOX i (-)(.)36(.~ ANCHORAGE: ALASKA 99~ i ~-} DATE ' 9-6-9(-) RFFEF,'EN[]E' ,ARCO CASED HOLE FINALS !-6 8-!,'Z)-9(~ F'RODLJCTION PROFILE RUiu, ~, ~-i ~ 8-6-96, F'F~ODtJC'I':[ON F'I;~OI=IL.F_ RUN 'i , 2--27 8-i 3-9,,9 F'RODUCTION F'ROFILE RUN i , 2-28 8-i3-90 F'I;,'ODtJC'TI[3N PROFILE RUN i, 4-6 9-2-9,3 C'.OLL. AF~/F'E:RF RUN t, 5-5 8-i i.-ge F'RODUC,*'FION F-'I;:OF!!_E RUN i , · i i - ? 8 - ?- 9',:.') F' ]: T,S' F;.: U N t , i :3,.-t 8-25-9e F'ERF RECORD f-;.:UN i , i 3-i 8--25-.9,'.0 (:;R/CCL RUN t , t5--4 8-'9-9e LEAK DETECTiON/C,A$ L'I'F'i' RUN t, · ': 5-i.t 8--6-?e F'IT.~' RUN t , ! 5-t ,3 8-6.-?r3 PITS F:UN t , i'.5.-22 8-2:3--?0 CNL RUN t , i 5-22 8-23-?e F':['FS RUN t , i'7-3 8--8'-?e PRODUCTION PROFILE RUN t , t 8-2e 8-2;3-?e CNL RUN t , t 8-2.e 8-29-9e CCL RUN 1 , F'LEASE SIGN RIECE]:'v'E:I) BY .;..~ ~ AND i;,'ETURN THE ATTACH'El) COPY AS RECE'[F'T OF DATA. HAVE A NICE DAY! RECEIVED SEP 12 1990 Alaska.Oil .& Gas Cons. Comm ¢Ot cliorage DISTRIBUTION ,'~'A L. LY HOFFECKER A'TO- i 529 AF'F'ROVED:~__~ CENTRAL FILES ¢ PHILLIPS CHEVRON F'B WELL F'IL.E.S' D & M R & D EXTENSION EXPLORATION ~ BF'X EXXON ~ STATE OF ALA~'KA MARATHON TEXACO MOBIL C A M C'. 0 (]AMC(] CAMCO C A ~.4, (] (] ATL_AS C A f'! C 0 $ C H .'"- I I J,..* J"l CAi"ICO CAMCO CA~'iCO ~'CH 5,'CH C A M C 0 SCH A'f'LA~' 1. Type of Request: .. STATE OF ALASKA '-:' ':'"' : ' ..... ALASK~A '. AND GAS CONSERVATION C~, ',,VllSSION APPLIC ,ION FOR SUNDRY APPROVALS Abandon Suspend Operation shutdown Re-enter suspended well · ~ · Alter casing Repair well Plugging Time extension Stimulate Change approved program Pull tubing Variance Perforate X ,, 2. Name of Operator ARCO Alaska~ Inc. 3. Address P.O. Box 100360, Anchorage, AK 99510-0360 4. Location of well at surface 898' FNL, 77' FWL, Sec. 8, T10N, R15E, UM At top of productive interval 1324' FSL, 1541' FEL, Sec. 8, T10N, R15E, UM At effective depth 1023' FSL, 1372' FEL, Sec. 8, T10N, R15E, UM At total depth 971' FSL, 1343' FEL, Sec. 8, T10N, R15E, UM 12. Present well condition summary 5. Type of Well Development Exploratory Stratigraphic Service Other , 6. Datum of elevation(DF or KB) 73 RKB feet 7. Unit or Property Prudhoe Bay Unit 8. Well number 1-11 9. Permit number 77-57 10. APl number 5O - 029-20268 11. Field/Pool Prudhoe Bay Oil Pool Total depth: measured 11010 feet Plugs(measured) true vertical 9394 feet Effective depth: measured 10945 feet true vertical 9342 feet Junk(measured) Casing Length Size Cemented Conductor 120' 20" 300 sx Arctic Set Surface 2640' 13-3/8" 5670 sx PF II Production 10915' 9-5/8" 800 sx CL 'G' & 300 sx PF II Measured depth 120' 2713' 10988' True vertical depth 120 2713' 9375' RECEIVED Perforation depth: measured 10555-10570'; 10575-10585'; 10591-10601' SEP - 5 199t) true vertical 9036-9050'; 9054-9063'; 9068-9077' Alaska.0il & Gas Cons. N~ctioragai Tubing (size, grade, and measured depth) 5-1/2", 17#, N-80, NPCT @ 9894' MD; 4-1/2", 12.6~, N-80, NPC tail @ 10024' MD Packers and SSSV (type and measured depth) Baker SAB packer @ 9894' MD; 5-112" Baker PFVE SSSV @ 2208' MD 13. Attachments Description summary of proposal . x Detailed operations program BOP sketch x 14. Estimated date for commencing operation J 15. Status of well classification as: . September 1990 16. If proposal was verbally approved Oil x Gas -._. Suspended .__ Lonnie Smith 8/31/90 Name of approver Date approved Service 17. I hereby ce~ the foregoing is true and correct to the best of my knowledge. Signed 4/~,.O''[~r.4 ~//~,~,,.,~- -" -'3 Title Sr. Area Engineer ~ " ' ' -~OR ~OMMIR~ION U~F ONLy Conditions of approval: Notify Commission so representative may witness Plug integrity BOP Test . Location clearance .___ Mechanical Integrity Test Subsequent form required 10- ORIGINAL ~IGNEO g¥ LONNIE C. SMITH Approved by order of the Commissioner Form 10-403 Rev 06/15/88 WHS/SunVII Commissioner Approved Copy .Returned Date SUBMIT IN TRIPLICATE DESCRIPTION SUMMARY PRUDHOE BAY UNIT DS1-11 WELL APl # 50-029-20268-00 PERMIT # 77-57 ARCO Alaska, Inc, proposes to perforate the subject well in the Sadlerochit Sandstone as follows: Measured Deoth Subsea Deoth Zone Comments 10419-10424' 10440-10442' 8847-8852' 4 Add Perf 8865-8867' 4 Add Perf All depths per BHCS log dated 10/26/77. s -CP - 5 1990 Alaska 011 & Gas Cons. Commission Anchorage 4 2 C0]LE*D TUB ~1~ BOP El)ti! PHEN? 1. 5000 PS1 ?" W£LLHr. jI~) CONN£CTOR IrLAhO£ 2. 5000 PSI 4 1/16" PIPE; RAMS 3. 5000 PSI 4 1/6" HYDRAULIC SLIPS 4. 5000 PSI 4 1/6" SH~ RAMS 5,.5000 PSI 4 1/6" BLIND RAMS 6. 5,000 PSI 4 1/16.". STUFFING BOX 2 RECEIV $ EP - 5 1990 Alaska Oil & Gas Cons. Commission Anchorage H]RELINE BC~ EOUIPIdENT i __ 1. 5000 PS1 ?" WELLH£.,~ CONNECTOR rLANG! 2. 5000 PS1 WIRELIN[ RAJAS (VARIA~BL[ SIZE) 3. 5000 PSI 4 1/6" LUBRICATOR 4. 5000 PSI 4 1/6" FLOW TUBE PACK-OfF F:' ... 0 ~ B 0 'X 'i (:;, (i:, ¥ 6 (i:, ~"" ~,. A N C: I.'10 R A E; E, A I... A J...' I'-.'.' A 9 5,t .... ,3, T D A 'i" E · 7 -. :.5- 9 (.~ F:' L.. iii: A E: E 21 C.,: N A N i) R E T LJ R N "1" I"ilii: 0 F:' i) A"I"A ,. I:;..' Iii: C !!!: ]: V F:: D BY ........................................ R 'E"C"E'~'V"E 0 I"IAVE: A NICI!:' DAY! $ A L.. I... Y I"1 Ct I::' I::' liE: C i< Iii: R A'l" 0 .... '1 '.if 2 9 J U L - 6 1990 Alaska Oil & Gas Cons. uommissW~ A F" F:' R 0 V Iii: D Rncho~ge 'T' R A N 5' :~ 9 (.)2 5 9 A "1" !.. A ,? HI...5' A l" !... A ;!;' H L....?; ;;::CH ;::;' C i..i ;:.;' C ;..i .1[) I ,~' 'T' R. I B U "1" I 0 N · "",. I ......... ~ ..... ,."! L, ~::. N I !", A !... F"' ]. I... !::.,:', C: H Iii: V R C) N D & H 'i"A M HA,?; BROWN Iii: X X 0 N M A R A '1" H 0 N M 0 B I L. ( C: I.-i ) ( 0 I"1) :ii,: I::'HII_LIF',."':,' F:'B Wlii:l...I... I::':l:L..iii:$ I:;.: & D :II: BF:'X :I,~.ST'ATE OF AI...AS'KA 'T'I!i:XACO A F;.'. C 0 A L. A S K ~'::~, I iH f':, P, O, BOX i ANCHOR. A[iE, AL.~,KA , , DATE' 6/7/90 REFERENCE' ARCO CASED HOLE FINALS F'WDWI-2 ~-_ .~c,,..q~n.., .,.., ;., ...~'QIJEEZE. F'ERF RI.IN.. t, 5" F'WDWi-2 5-29-90 BRIDGE F'LIJG SETTING REC RUN i, .-- · · ~ '' i ' .~ "II i ii 6-2-90 COMP NE.L. IRL)N G/R RUN ! 5 i.-:?;.', 6 '" ~ " .... · -.."-,0 COMP NEUTRON G/F: RUN t.. i-29 6-;5-90 (]OMF' NEUTRON G/R R'LJN t, 5" 3-27 5-24-90 COMP NELJ'I'RON RUN ~, 4-~3 5-t9-90 F'OSI' IN,.J I'EMP RLJN t, ;2" 6'-2 5-25-?0 COMP NEUTRON RUN ~,: 7'"t 6 5-;24-90 COMP NEUI'RON RUN ,:$",5' t 2"'i 8 5-~0-"?0 COLLAR RUN i , S' i8-i7 5-2~-9G COMP NEUTRON - RUN t, 5' t 8-t 9 5-23-90 COMP NI'-U'I'I;:ON RUN t , 5" PLEASE SIGN AND RETURN THE AI'TACHED COPY AS RECEIF'T OF DATA. RECEIVED ALL Y H[)FFECK ER Alaska Oil & B~ Cons. commisslot~ T O- t 5 2 ~ nchomge AF'F'ROVE ___~_ I'RANS~ 902t3 $ C I..I A'i LAS A 'FI_AS ATLAS ~' C 1'4 H R ,S' S C H SCH n'FI_~S SCH SCH DISTRIBUTION' CENTRAL FILES .. , CHEVRON D & M EXTENSION EXPLORATION EXXON MARATHON MOBIL PHILLIPS F'B WELL FILES R& D BF'X STATE OF ALASKA TEXACO STATE OF ALASKA .,~, ALASK(,'" ILAND GAS CONSERVATION q '1MISSION REPORT OF SUNDRY WELL OFr, RATION 1. Operations performed: Operation shutdown .~. Stimulate ~. Plugging Perforate X Pull tubing Alter casing Repair well Other X 2. Name of Operator ARCO Alaska, Inc. 3. Address P.O. Box 100360, Anchorage, AK 99510-0360 4. Location of well at surface 898' FNL, 777' FWL, Sec. 8, T10N, R15E, UM At top of productive interval 1324' FSL, 1541' FEL, Sec. 8, T10N, R15E, UM At effective depth 1023' FSL, 1372' FEL, Sec. 8, T10N, R15E, UM At total depth 971' FSL, 1343' FEL, Sec. 8, T10N, R15E, UM 12. Present well condition summary Total depth: measured true vertical 5. Type of Well Development Exploratory Stratigraphic Service 11010 feet Plugs(measured) 9394 feet 6. Datum of elevation(DF or KB) 73 RKB 7. Unit or Property Prudhoe Bay Unit 8. Well number 1-11 9. Permit number/approval number 77-57/9-909 10. APl number 50 - 029-20268 11. Field/Pool Prudhoe Bay Oil Pool feet Effective depth: measured 10945 feet true vertical 9342 feet Junk(measured) Casing Length Size Cemented Conductor 120' 20" 300 sx Arcticset Surface 2640' 13-3/8" 5670 sx PF II Production 10915' 9-5/8" 800 sx CI 'G' & 300 sx PF II Measured depth 120' 2713' 10988' True vertical depth 120' 2713' 9375' Perforation depth: measured 10555-10570'; 10575-10585'; 10591-10601' 'i:Jlj'-~¥ 0'8 .[o;:,,'iC~'~"';., ~.!,~,,~$ · ...,, ka..O~I .& Gas Cons. C0mmissi0r~ true vertical 9006-9018'; 9023-9031'; 9036-9045' ' ~ ~nchorag~ Tubing (size, grade, and measured depth) 5-1/2", 17#, N-80, NPCT @ 9894' MD; 4-1/2", 12.6#, N-80, NPC tail @ 10024' MD Packers and SSSV (type and measured depth) Baker SAB packer @ 9894' MD; 5-1/2" Baker PFVE SSSV @ 2208' MD 13. Stimulation or cement squeeze summary Intervals treated(measured) See attachment Treatment description including volumes used and final pressure 14. Prior to well operation Subsequent to operation Reoresentative Daily Average prQducti0n or Injection Data OiI-Bbl Gas-Md Water-Bbl Casing Pressure 1750 21871 267 -- 1800 5468 500 Tubing Pressure 2185 80O 15. Attachments Copies of Logs and Surveys run . Daily Report of Well Operations 16. Status of well classification as: Oil x Gas Suspended Service 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed Title Date Form 10-404 Rev 06/15/88 301 D. C, Reem CC; J. ~,[uB~R. ~ ~1'o- 1478, SUBMIT IN DUPLICATE DS 1-11 DESCRIPTION OF WORK COMPLETED CTU CEMENT SQUEEZE FOR GAS SHUT-OFF 11/11/89.' MIRU CTU & Stimulation Equipment. PT Equipment to 4000 psi. RIH w/CT and washed perforations at: 10450 - 10470' MD Ref. Log: BHCS 10/26/77. 10482 - 10520' MD 10530 - 10570' MD 10575 - 10585' MD 10591 - 10601' MD Pumped the following treatment: 59 bbls 12% HCI w/10% Xylene, followed by, 57 bbls 12-3% HCI-HF, followed by 55 bbls 12% HCI. Displaced w/47 bbls of Diesel. POOH. Rigged down. Flowed well. 11/13/89: The Squeeze was performed as follows: MIRU CT & Cementing Equipment. PT equipment to 4000 psi. RIH w/CT and fluid packed wellbore w/seawater. Pumped 76 bbls cement, squeezing perforations: 10450 - 10470' MD Ref. Log: BHCS 10/26/77. 10482 - 10520' MD 10530 - 10570' MD 10575 - 10585' MD 10591 - 10601' MD Placed 10 bbls of cement behind pipe at 3000 psi squeeze pressure. Contaminated cement with 150 bbls contaminant. POOH. 11/14/89: Jetted out contaminated cement from wellbore. 11/27/89: Reperforated: 10555 - 10570' MD 10575 - 10585' MD 10591 - 10601' MD Ref, Log: BHCS 10/26/77. Returned well to production and obtained valid production test. ARCO AL. ASKA, INC~ p~ !'..!~ BOX ~ ~(')36¢~ ANCHORAGE: AL. ASKA 995 ~ ~ DATE' ~ 2-8-89 R F F F R E N C E · i .... ii i 2-'5 i :'.~-- i 6 i 4.-..4 i S .... i 8 i i2 .... i4 i i S-.98 i i ~..-98 t i 3-98 i i 5-t f i 5-.. i 3 i i 5 .... t 5 t t 5.'.' 2 i i F'I...liEASE SIGN RECEIVEI) BY HAVE A NICE ,S'A I...I... Y !"10 FF'Ii!: ATO-' t 529 ARCO CASED HOI_E F]:NAI_$ i '-' 2'7--" 89 C 0 M F' I.. I:i: T I 0 N !:;.'. E C 0 R I) R t.J N i ¢'~ o 4'" i .... 89 C C)I.. !... A R / F:' E R I::' R U N i "' 2 8"' 8 9 F' E R F' I:~'. E: C (] R D R. U N,S' t 2'"' 3;'" 89 F:' F C R U N i t '" 3 ¢'" 89 I::' I::' C I:;'. U N i , j" .............. % .... i '~ '2 .... t -'89 .,OMI-.'I_I::. liON REt.,UI'~D RUN 2-2....89 DIL.. I:(tJ N 35 2 - 2 ...' 89 6 N L. '-'f' H E R M A I_ R U N 2-.2'-89 CNL-EPI THERMAL RUN 2 .... t .... 89 COLL. AR/F:'ERF RUN t -.22....89 F'AL. RUN 2....S....89 COI_L..AF~/F'ERF RUN 2-.3-'89 COL. L. AR/PERF RUN ~,ND I"::Ij'ETLJR~I~ THE AT'f'ACHED COI'"'Y AS F;tECEII:'T OF' DATA, C: I< E R DEC ! ]519B9 APF:'ROVED ...~.. Oil & Gas Cons..6omlill 89 4~5 Anchorage D I S 1' R I B U T ]: 0 N ~' CI::NIkAL FII_E~ ...'"' C Fi IE V R C) N .,-'"' EXIE. N,S:ION EXFLCIRAI"ICIN T EXXON MARAI'HON; ,.~ MOBIL F'H :!: I_ L :[ !::'$ 'ir F'B WEI_I_ I::'II...EJS I:;: & I) '"' B P X 'ir "'- ,S' T A T Iii: 0 F' A L.A 5' K A :-': l' I_:i: X A C 0 .~>" '5" .... i2., 5" .~>, , '5" 5" 5" '5" 5" I::, II ,.:. U I"l A f'I...AZ ,?.,' C H A f'i...AS A 'f' i... A S ,S' C l..i S C i"1 $ C !'.1 S C H A'I"L. AZ ,.S'CH A .A'f'L.A$ ARCO Alaska, Inc.i" Prudhoe Ba~ ,,gineering Post Office Box 100360 Anchorage, Alaska 99510-0360 Telephone 907 263 4248 Donald F. Scheve Operations Engineering Manager OR(,GINAL October 10, 1989 C. V. "Chat" Chatterton Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Re: DS 1-11, Permit No. 77-57 Dear Mr. Chatterton:. Attached is the Application for Sundry Approval detailing work to be performed on the above-referenced well. Sincerely, D. F. Scheve DFS/DCR/jp Attachment cc: J. Gruber, ATO-1478 PI(DS 1-11)W1-3 ARCO Alaska, Inc. is a Subsidiary of AtlanticRichfieldCompany AR3B--6132-C STATE OF ALASKA 0 I{ 161 N A L ALASK,~ 'LAND GAS CONSERVATION C{"' 'MISSION APPLICA ,'ION FOR SUNDRY AF,-'ROVALS 1. Type of Request: Abandon Suspend Operation shutdown ~ Re-enter suspended well Alter casing Repair well Plugging Time extension Stimulate Change approved program Pull tubing Variance Perforate X Other X 2. Name of Operator ARCO Alaska, Inc. 3. Address P.O. Box 100360, Anchorage, AK 99510-0360 5. Type of Well Development X Exploratory Stratigraphic Service 6. Datum of elevation(DF or KB) 73 RKB feet 7. Unit or Property Prudhoe Bay Unit 4. Location of well at surface 898' FNL, 77' FWL, Sec. 8, T10N, R15E, UM At top of productive interval 1324' FSL, 1541' FEL, Sec. 8, T10N, R15E, UM At effective depth 1023' FSL, 1372' FEL, Sec. 8, T10N, R15E, UM At total depth 971' FSL, 1343' FEL, Sec. 8, T10N, R15E, UM 8. Well number 1-11 9. Permit number 77-57 10. APl number 50 - 029-20268 11. Field/Pool Prudhoe Bay Oil Pool 12. Present well condition summary Total depth: measured true vertical Effective depth: 11010 feet Plugs(measured) 9394 feet Casing Conductor Sudace Production measured 10945 feet true vertical 9342 feet Junk(measured) Length Size Cemented 120' 20" 300 SX Arctic Set 2640' 13-3/8" 5670 sx PF II 10915' 9-5/8" 800 sx Cl 'G' & 300 sx PF II RECEIVED OCT 113989 Nasla 0ii & Gas Cons. Commission Measured dejJl~[10RIO~ vertical depth 120' 120' 2713' 2713' 10988' 9375' Perforation depth: measured 10450-10470'; 10482-10520'; 10530-10570'; 10575-10585'; 10591-10601' true vertical 8916-8933'; 8943-8976'; 8984-9018'; 9023-9031'; 9036-9045' Tubing (size, grade, and measured depth) 5-1/2", 17#, N-80, NPCT @ 9894' MD; 4-1/2", 12.6#, N-80, NPC tail @ 10024' MD Packers and SSSV (type and measured depth) Baker SAB packer @ 9894' MD; 5-1/2" Baker PFVE SSSV @ 2208' MD 13. Attachments Description summary of proposal x~ Detailed operations program BOP sketch x 14. Estimated date for commencing Operation I October 1989 16. If proposal was verbally approved Name of approver Date approved Service 17. I hereby/i=ertify that t~ foregoing is true and correct to the best of my knowledge. Signed ~/'~~~~~, Title Operations Engineering Manager 15. Status of well classification as: Oil ~ Gas Suspended FOR COMMISSION URI= ONLy Conditions of approval: Notify Commission so representative may witness Plug integrity BOP Test Location clearance , Mechanical Integrity Test Subsequent form required 10- ~ ORIGINAL SIGNED BY LONNIE C, $~,.{ITH Approved by order of the Commissioner Commissioner IAppr°va'N°' 9.-' Date Form 10-403 Rev 06/15/88 203 D. C. Reem, 265-1353 SUBMIT IN TRIPLICATE D.S. #1-11 CTU GSO Cement Squeeze Preliminary Procedure Objective: Acid wash perforations. Squeeze off all perforations with acid resistive cement. Wait on cement. Reperforate and return to production. 1. RU slickline. Tag fill. Surge well. Re-tag fill. RD. Production test well. 2. RU CTU and acid equipment. Acid wash all perforated intervals. Displace acid into the formation. Flowback acid load and production test well. 3. Rid CTU and cementing equipment. Cement squeeze all perforated intervals. Volume of cement will be sufficient to cover all perfs. The following perforated intervals are to be squeezed: (Ref. BHCS dated 10/26/77) Perforations, MD Zone Density Comments 10,450'-10,470' 4A FSD Gas Source 10,482'-10,520' 3 FSD Gas Source 10,530' - 10,570' 3,2C FSD O pen 10,575'-10,585' 2C FSD Open 10,591'-10,601' 2C FSD Open 4. Hold 2000 psi surface squeeze pressure for one hour. 5. Dilute cement left in wellbore with contaminate. 6. Reverse or jet out contaminated cement. Cleanout wellbore to PBTD. RD CTU. 7. WOC for two weeks. 8. Reperforate well as follows: (Ref. BHCS dated 10/26/77) Pre-squeeze Perfs 10,450'-10,470' 4A 10,482'-10,520' 3 10,530'-10,570' 3,2C 10,575'-10,585' 2C 10,591 '-10,601' 2C Zone post-squeeze Perfs Density Comments 10,555 '- 10,570' FSD R e- p e rfs 10,575'-10,585' FSD Re-perfs 10,591 '-10,601' FSD Re-perfs 9. Return well to production. Estimated Reservoir Pressure = 3700 psi Estimated Reservoir Temperature = 203OF 5 4 2 C0tLED TUBtNi~ UNIT 60P E0U ! P~£NT 1. 5000 PSi ?" W[LLH[.AD CONNECTOR FLANG£ 2. 5000 PSI4 1/16" PiP[ RAMS 3. 5000 PSi4 1/6" HYD~LIC SLIPS 4. 5000 PSI4 1/6" SHEAR RAU$ 5. 5000 PSI4 1/6" BLIND RAMS 6. 5000 PS14 1/16" STUFFING BOX H]REL]NE BOP EOU]PHENT 1. 5000 PSI ?" W[LLHr~I~) CONN£C10R FLANGE 2. 5000 PSI WIRELIN[ RAIdlS (VARIABLE SIZE) 3. 5000 PSI 4 1/6" LUBRICATOR 4. 5000 PSi 4 1/6" FLOW TUB[ PACK-OFF ARCO AI..ASKA, INC I:'~ O, BOX ANCHORAGE, AI_A3KA 99.51 0 DATE · 8-....-.9-89 Ir4EFERE"NCE' ARC(] CASED HOLE FINALS i -'i t 8-'12--89 3- t e 8--'7..-89 4-3 8-.i 9-89 5"-3 8 .... t 2-89 '?-8 8-i e-..89 7-33 7-2(.)-89 9-"4 '?-.i 9-'89 9-i2 8.-3--89 9-28 7-i 9-89 i i '-'5 '7-23'-89 i t .... i 7 8-.i i-'89 t2-23 8-7-89 t 4-..i 2 8-i 6-89 t 6-.-i 8 8.-2i -89 t 7-9 8--9-89 t 8-2e 8-t i-89 F:'F(C.IDLJC;'/'I ON F:'ROFI L.E INJECTION F'ROF' I I_IE I'UB I NC,; C;IJI'TER PITS F'RODUCTION F'ROFILE F'EF~F:' F:,'F."C.C)R D F'ERF RECC)RD INJECTION F'ROI'- I LE F'ERF RECORD F'ERF' RECORD LEAK DETECTION INJECTIC)N F'ROFII_IF COI_LAR/F'I:~.RF TEMF'/CAP/GR/$PI NNER F'RODUCTION PROFIL. E FLUID ID/PITS/LEAK DE1'FCI'ION PI_ErASE ,?IGN AND RETLJRN THE ATTACHED COF:'Y AS RECEIPT RUN t, 5" RUN t , 5" RUN i , 5" RtJN t, 5' RUN t , 5" RUN t, 5" RUN i , 5" RUN 4, 5" RUN i, 5" RUN t, 5' RUN t , 5" RUN t, 5 · RUN i, 5" RtJN~ i&2, 5" RUN t, 5" RUN t, 5" 01"- D A'f'A, CAHCO CAMCO A'I' [..A,S' CAMCO CAMC;C) HL.$ HL..? (;AMC(:} HL£' Hl..3' CAMCO CAMCO ATLAS HR$ CAMCO CAMCO Anchorage D I STR I BUI'I DN ¢ CENTRAL FILES ~ ~ PHILLIPS ~. CHEVRON I::'B WELL. F'ILE~' D&M R& D .,."~EXTE:N,S'ION EXPLORATION ~ BF:'X .,*'EXXON ;~ STATE OF AL.A~KA MARATHON ~*' TEXACO ~ MOBIL TFIE C;ORRECT AF']:~ FOR 9-4 "" i i" ~ THE CORRIr. CT AF'I~ FOR i i"-"$ IS Se" .e29-2821 ", &;. & I$ 5(~-e29.-2e6'70. STATE,OF ALASKA ALASKA OIL AND GAS CONSERVATION COM'MISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1. Status of Well REVISED Classification of Service Well OIL [~ GAS [] SUSPENDED [] ABANDONED [] SERVICE I'-I 2. Name of Operator 7. Permit Number ARCO Alaska~ Inc. 77-57 3. Address 8. APl Number P. 0. Box 100360, Anchorage~ AK 99510 50- 029-20268 4. Location of well at surface 9. Unit or Lease Name 898' FNL, 777' FWL, Sec.8, T10N, R15E, UM Prudhoe Bay Unit At Top Producing Interval 10. Well Number 132/+' FNL, 15/+1' FEL, Sec.8, T10N, R15E, UM 1-11 At Total Depth 11. Field and Pool 971' FSL, 13/+3' FEL, Sec.8, T10N, R15E~ UN Prudhoe Bay Field 5. Elevation in feet (indicate KB, DF, etc.) I 6. Lease Designation and Serial No. Prudhoe Bay 0i 1 Pool RKB 73tI ADL 28329 12. Date Spudded 13. Date T.D. Reached 14. Date Comp., Susp. or Aband. 115. Water Depth, if offshore 116. No. of Completions 10/09/77 '10/27/77 11/0/+/77'I N/A feet MSLI 1 ' 17. Total Depth (MD+TVD) 18. P.lug Back Depth {MD+TVD) 19. Directional Survey I 20. Depth where SSSV set 21. Thickness of Permafrost 11010'MD/939/+'TVD 109/+5'MD/93z~2'TVD YES ~ NO []I 2187' feet MD J1900' (approx) 22. Type Electric or Other Logs Run D IL/SP, BHCS/GR~ FDC/CNL~ GR/CNL/CC1 ~ Gyro 23. CASING, LINER AND CEMENT.I.NG RECORD SETTING DEPTH MD CASING SIZE WT. PERFT. GRADE ITOP .BOTTOM HOLE SIZE .CEMENTING RECORD AMOUNT PULLED 20" 9~# Weld H-/~0 Surf 1~13, ~{3- 13-3/8" 72# Butt N-80 Surf 271_~, 17-1/9- ~,R7t3 _~x PF II 9-5/8" /~7# Bul;t N-80 Surf 1098R' 1 9-1//~" Rnn & RS-95 24. Perforations open to .Production .(MD+TVD of Top and Bottom a.nd 25. TUBING RECORD interval, size and number) SIZE DEPTH SET .(MD.) PACKER SET (MD) Perforated wel I w//+ spf 5-1/2" 1002~ ' 9894' 10/+50 ' -10/+ 70 'MD/8916 ' -8933 'TVD 10~82 ' -10520 ' MD/89/+3 ' -8976 'TVD 26. ACI D~ F,RACTU:R E, CEMENT SQUEEZE, ETC. 10575'-10585'MD/905/+'-9063'TVD DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED 10591 ' -10601 'MD/9068 ' -9077 'TVD ' , 27. PRODU.CTION TEST Date First Production I Method of Operation (Flowing, gas lift, etc.) 02/21/78 '1 F1 owi n.q Date of Test Hours Tested PRO.DUCTI'O.N FO,R. OI L-BBL GAS-MCF WATER-BBL .CHOKE SIZE I GASh'OIL RATIo . 8/03/87 9.6 TEST PERIOD I~ 166/+ 2636 17 30 ~ ~R', I Flow Tubing Casing Pressure CALCULATED.lk OIL-BBL GAS-MCF WATER-BBL OIL GRAVITY-APl (corr) Press.1716 --- 24-HO.UR RATE "~ /+160 6591 /+2 2~).8° APl 28. C.OR E .DATA Brief description of lithology, porosity, fraCtures, apparent dips and presence of oil, gas or water. Submit core chips. . ,~. r,~., * NOTE: Perforated well 2//+/78. Added perforations 7/11/87. l~..~'~,j'.,.:,:! ~;.~ ~,.,,. Form 10-407 (Dani) WC5/021 Submit in duplicate CONT.IN~UED ON REVERSE SI.DE Rev. 7-1-80 29. 30. NAME GEOLOGIC MARKERS Top Sadlerochit GOC Base Sadlerochit MEAS. DEPTH 10233 ' 10253 ' 10896 ' 31. LIST OF A'FTACHMENTS None TRUEVERT. DEPTH 8731' 8748 9296' FORMATION TESTS Include interval tested, pressure data, all fluids recovered and gravity, GOR, and time of each phase. N/A 32. I hereby certify that the foregoing is true and correct to the best of my knowledge Title Associate En§ineer Date INSTRUCTIONS General' This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. Item 1' Classification of Service Wells: Gas injection, water injection, steam injection, air injection, salt water disposal, water supply for injection, observation, injection for in-situ combustion. Item 5: Indicate which elevation is used as reference (where not otherwise shown) for depth measurements given in other spaces on this form and in any attachments. Item 16 and 24: If this well is completed for separate production from more than one interval (multiple completion), so state in item 16, and in item 24 show the producing intervals for only the interval 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 (G L) or other elevation (DF, KB, etc.). Item 23: Attached supplemental records for this well should show the details of any multiple stage cement- ing and the location of the cementing tool. Item 27: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water In- jection, Gas Injection, Shut-in, Other-explain. Item 28' If no cores taken, indicate "none". Form 10-407 ARr..I] Ala..~ka, .Tnt., P,.O. Aox t~)e36~) Anchorage, A la.~ka DATE: t t -9-87 REFERENCE: ARCO Cased Ho [e F ina I. J-3 9-5-87 Collar (Perfnrafion log) Run i, 5' t-7 8-22-87 CoLLar (Perforati.on Log) R~Ln t, 5-' J-il 7-~t-87 Collar (Perforation Log) Run ~ 5' t-~2 7-~t-87 CoLLar (Perforation Log). Ru~ ~, 5' t-2e 7-t t-87 Col lar (Perforaf ion 1..o9) Run t, 5" 2-t2 7-22-87 CoLLar (Perforatio~ Log) Run 't~ 5' 4-22 7-24-87 Co[tar (Perforation Log) Run '~, 5' 5-4 8-2t -87 Cottar Run 4, 5" 5-t3 7-26-87 CoLlar(Perforation Log) Run t, ~' 6-7 7-t2-87 Collar (Perforation Log) Run t 5m T-tt 7-~e-87 CoLLar (Perforation Log). Run t, 5' 9-2 ~e-~5-87 Collar (Perforation Log) Run ~, 5' ~-34 8-2~-87 Col I. ar ... Ru~ ~ ~ 5' ~-24 7-3~-87 ~ollar (Perfnrafton Lng) Run ~ 5" ~-27 &-2~-87 Col. l. ar Ru~ ~ 5" ~-27 T-3t~g7 Collar (Perforation Log) .. RHn ~, 5' ~-SB ~-~-87 Col. l. ar (Perforation Log) Ru.~ ~, 5" ~2-~5 7-~e-87 'Col [ar (Perforaf ion Log). Run ~ ~ 5' 42-45 9-2-87 CoI. Lar (Perforation'Log) Run t~ 5' ~-~ B-~l-B7 Collar (Perforation Log) Run ~, 5" t3-t8 9-3-87 CoLLar (Perforation Log) Run t~ 5" ~-~4 8-~7-87 Collar (Perforation Log) Run ~ 5" ign and return the _a_t,%aar. bed c.opy as rec. eip* '.of 'da*a,".;~. "':. PLeases HAVE R N~CE OAYO~/" -"- ~"'~A1as~ ~- ~,. ~ch0rageG~C°ns' . C0mmmsi0n' . . · . ATO-t 529 TRAMS ~876e6 ~ Approved m.a..me. D I$TR.T:BI. JT.T DN Atlas Afl. as At la.~ Afl. as Atla~ AtLas' At la..~ At I.a.~ At I.a.~ At I'a.~ Af Las' Atla~ At I.a.~ Atla~ A~ I.a.~ At I.a.~ At la.~ Central. Fil. e~ Chevron D&H Extension Exploration Exxon Marathon Mobil. STATE OF ALASKA ALA(c,,,,A OIL AND GAS CONSERVATION CO ,WlISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: Operation shutdown [] Stimulate [] Plugging [] Perforate ~ Pull tubing Alter Casing [] Other [] 2. Name of Operator ARCO Alaska~ Inc. 3. Address Post Office Box 100360, Anchorage, AK 99510 4. Location of well at surface 898' FNL & 777' FWL, Sec. 8, TION, R15E, UN At top of productive interval 1324' FSL & 1541' FEL, Sec. 8, TION, R15E, UM At effective depth 1023' FSL & 1372' FEL, Sec. 8, TION, R15E, UM At total depth 971' FSL & 1343' FEL, Sec.8, TION, R15E, UM 11. Present well condition summary Total depth: measured true vertical Effective depth: measured true vertical Casing Length 11010 feet 9434 feet 10895 feet 9333 feet Size 5. Datum elevation (DF or KB) 73' RKB Feet 6. Unit or Property name Prudhoe Bay Unit 7. WellDr~r~b_e, lr1 (34-8-10-15) 8. Approval number 7-390 Plugs (measured) Junk (measured) 9. APl number 5O-- 029-20268 10. Pool Prudhoe Bay 0il Pool Conductor 120' 20" Surface 2713' 13-3/8" Product i on 10988 ' 9- 5 / 8" Cemented Measured depth None 300 sx Arctic Set 5600 sx PF II 800 sx Class G 10895' - Fill Perforation depth: measured 10575'-10585' 10591'-10601' true vertical 9054' -9063' 9068' -9077' Tubing (size, grade and measured depth) 5 mm ~ 17#, L-80, 10027'MD Packers and SSSV (type and measured depth) Baker "$AB" Packer @ 9894'MD; Baker Flapper $$$V @ 2182'MD 12. Stimulation or cement squeeze summary Intervals treated (measured) Treatment .description including volumes used and final pressure Representative Daily Average Production or Injection Data' True Vertical depth 120' 120' 2713' 2713' 10988' 9415' RECEIVED AUG Naska Oil & Gas Gons. Commission Anchorage Tubing Pressure 1550 Prior to well operation OiI-Bbl Gas-Mcf Water-Bbl Casing Pressure 4000 6800 0 -- 7/1/87 Copies of Logs and Surveys Run [] 6591 42 13. Subsequent to operation 8/3/87 4160 14. Attachments Daily Report of Well Operations 15. I hereby certify that the foregoing is true and correct to the best of my knowledge Signed Title Form 10-404 Rev. 12-1-85 1716 Operations Engineering Manager Date (MRM) 263-4537 Submit in Dupli.cate ~ DS 1-11 ADD PERFS Daily Report of Well Operations 7/11/87 PT equipment to 3500 PSI. OK. RIH w/20', 3-3/8" Perf Gun, 4 SPF @ 120° Phasing. Open well for drawdown. Attempt to perf 10575' to 10585' & 10591' - 10601'. SI. POH - no shots pired. Redress gun & RIH. Open well for drawdown. Shoot 10575' to 10585' & 10591' to 10601'. SI. POH - all shots fired. RD. WELL COMPLETION OR RECOMPLETION REPORT AND LO _ 1. Status of Well Classification of Service Well -,~ OIL'~ GAS [] SUSPENDED [] ABANDONED [] SERVICE [] Producing 2. N-'me of Operator 7. Permit Number ARCO Alaska, ]:nc. 77-57 3. Address 8. APl Number P.O. Box 100360, Anchorage, Alaska 99510 50- 029-20268 4. Location of well at surface 9. Unit or Lease Name 898'FNL, 777'FWL, Sec. 8, TION, R15E, UM Prudhoe Bay Unit At Top Producing Interval 10. Well Number 132/+'FNL, 15/+i'FEL, Sec. 8, TiON~ R15E, UM DS 1-11 (3/+-8-10-15) At Total Depth 11. Field and Pool 971'FSL, 13/+3'FEL, Sec. 8, T10N, R15E, UM Prudhoe Bay Field 5. Elevation in feet (indicate KB, DF, etc.) I 6. Lease Designation and Serial No. Prudhoe Bay Oil Pool 73' RKBJ ADL 28329 12. Date Spudded 13. Date T.D. Reached 14. Date Comp., Susp. or Aband. 115. Water Depth, if offshore 16. No. of Completions 10/09/77 10/27/77 11/0/+/77I N/A feet MSL Single 17. Total Depth (MD+TVD)ll010,MD, 939/+'TVI) 18. Plug Back Depth (MD+TVD)109t+5,HD 93/+2'TVD YES19' Directional Survey[~lO[ NO [] I20' Depth where SSSV set2187 feet MD ] 21. Thickness of Permafrost , 1900' (Approx.) 22. Type Electric or Other Logs Run DIL/SP, BHCS/GR, FDC/CNL, GE/CNL/CCL 23. CASING, LINER AND CEMENTING. RECORD SETTING DEPTH MD CASING SIZE WT. PER FT. GRADE TOP BOTTOM HOLE SIZE CEMENTING RECORD AMOUNT PULLED 20" 944k Weld H-40 0 120' 30" 300 sx Arct~cset Cmt 13-3/8" 72~ Butt N-80 0 2713' 17%" 5600 SX PF II Cm~ 9-5/8" ~74~ Butt N-80 & 10988' 12~," 800 sx Class G Cmt RS-95 .. 24. Perforations open to Production (MD+TVD of Top and Bottom and 25. TUBING RECORD interval, size and number) SIZE DEPTH SET (MD) PACKER SET (MD) 10575'-10585' 10591'-10601'MD 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. 905Z+'-9063', 9068'-9077'TVD DEPTH INTERVAL (MD) AMOUNT& KINDOF MATERIAL USED U/A 27. PRODUCTION TEST Date First Production J Method of Operation (Flowing, gas lift, etc.) 2/21/78] Flow: ng Date of Test Hours Tested PRODUCTION FOR OI L-BBL GAS-MCF WATER-BBL CHOKE SIZE I GAS-OIL RATIO 8/3/87 9,6 TEST PER IOD I1~ 166/+,,", .... 2~,36 ,'I 7 ~C~I 1 Flow Tubing Casing Pressure CALCULATED OIL-BBL GAS-MCF WATER-BBL OIL GRAVITY-APl (corr) Press. 1716 -- 24-HOUR RATE I~ /+160 6591 /+2 29.8 28. CORE DATA Brief description of lithology, porosity, fractures, apparent dips and presence of oU, gas or water. Subn~ E~ilsV ~D AUG Aluk~ 011 & Gu Cons. Commission Anchorage Form 10-407 Rev. 7-1-80 CONTINUED ON REVERSE SIDE Submit in duplicate ~/~ GEOLO('iIC MARKERS j F'o~'4MA'IIC)N l'b~ib NAb.'I[-: 1; ................................ ~ ......................... Include ~nto;~.a~ testod MEAS. DEPTH i TRUE lv'ERT DEPTH GOR ,d timeoi 'h Top Sadlerochit ii 10233' GOC 10253' Base Sadlerochit II 10896' 8731' 8748' 9296' 32, I hereby certify that the foregoing is true and correct to the [)est' of my knowledge INSTRUCTIONS General' This 'form is designed for subrnitting a complete and correct well completion report and log on all types of lands and leases in Alaska. Item 1' Classification of Service Wells' Gas injection, water injection, steam injec6on, 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 thar~ 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 addition'~il interval to be separately produced, showing the data pertingnt to such interval. Item 21' Indicate whett~er from ground level (GL) or other elevation (DF, KB, etc.). Item 23' A'ttached supplemental records for this well should show the details of any multiple stage cement- lng and the location of the cementing tool. Item 27: Method of Operation.: ..... FIowing,.,.,... Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water In- jection, Gas Injection, Shut~i:n, Other-explain. Itern 28' If no cores taken, indicate "none". Form 10-407 APPLICATION FOR SUNDRY APPROVALS 1. Type of Request: Abandon ~ Suspend ~ Operation Shutdown [] Re-enter suspended well ~ Alter casing ~ Time extension _--.' Change approved program .-1 Plugging [] Stimulate ~ Pull tubing ~ Amend order [] Perforate ~ Other :'" 2. Name of Operator ARCO Alaska. ]:nc, 3. Address Post Office Box 100360~ Anchora~e~ AY, 99510 4. Location of well at surface 898' S & 777' E of NW cr, Sec. 8, TION, R15E, UM At top of productive interval 1323' N & 1540' W of SE cr, Sec. 8, TION, R15E, UM At effective depth 1030' N & 1376' W of SE cr, Sec. 8, TION, R15E, UM At total depth 971' N & 1343' W of SE cr~ Sec.8~ TION, R15E, UM 5. Datum elevation (DF or KB) 73' RKB 6. Unit or Property name Prudhoe Bay Unit 7. Well number DS 1-11 8. Permit number 77-57 9. APl number 50- 029-20268 10. Pool Prudhoe Bay Oil Pool fee~ 11. Present well condition summary Total depth: measured true vertical Effective depth: measured true vertical Casing Length 11010 9434 1O894 9333 Size feet Plugs (measured) feet feet Junk (measured) feet Cemented Measured depth 10945' 9377' (PBTD 11/13/86) True Vertical depth Conductor 120' 20" Surface 2713' 13-3/8" P roduc t i on 10988' 9- 5 / 8" 300 sx Arctic Set 5600 sx PF II 800 sx Class G 120' 120' 2713' 2713' 10988' 9415' Perforation depth: measured 10575'-10585' 10591'-10601' true vertical 9054' -9063' 9068' -9077' Tubing (size, grade and measured depth) 5~" 17#, L-80, 10027'MD Packers and SSSV (type and measured depth) Baker "SAB" Packer @ 9894'MD~ Baker Flapper SSSV @ 2182'MD 12.Attachments Description summary of proposal ~ Detailed operations program [] BOP sketch 13. Estimated date for commencing operation June 19, 1987 14. If proposal was verbally approved Name of approver Date approved 15. I hereby~Jertify that~he foregoing is true and correct to the best of my knowledge Signed .~. ~~~~ Title Operations Engineering Manager COmmission Use Only Date ~~7 Conditions of approval Notify commission so representative may witness [] Plug integrity [] BOP Test [] Location clearance Approved by Commissioner I Approva, No. 7 ' f by order of _/ lA the commission Date ~ Form 10-403 Rev 12~-85 (MRM) 263-4537 Submit in triplicate ARCO Alaska, Inc. proposed to perforate DS 1-11 at selected intervals within the Sadlerochit Sand of Prudhoe Bay Unit. Upon perforating, the well will be flowed for clean-up. All wireline work will be done through a 5000 psi WP BOP/Lubricator, tested to 1.2 times the maximum expected surface pressure. The SSSV will be installed at the conclusion of the perforating and clean-up operation. Ref. BHCS 10/25/77 Proposed Perforation Intervals' 10575' - 10585 'MD 10591' - 10601 'MD R E F:' E R E N CIE · A R CCI M o g n e !' i c '1" a. I::, e.'..? w/I. i .~: t' i n g Recei,,:ed By ...................................................................................... 1..I A V ['E A N I C Iii: D A Y ! D I ~;' T R I B I..J '1" I 0 N ARCO Ala.~;km, Inc F'.O. Box Anchorage, Al. 99...~ t (') I)ATE: November REFERFN[;E ' ARCO Cas'ed HoLe FinaL "% t -t t t t-t S-'86 CNL ~ t-t 9 t t-t :.-8~ CNL '"- t S-' t t t - t 4-86 CNL "'"t 8-2 t t -t ,'~_oz.... ,.,,., Ct,IL. Ruin S, 5 · $ch F:tin 2, 5 · $ch Run t, .5 · $cln F'Lea.~e sig~ and returrl the attached Rece i red By HAVE A NICE DAY! Rosanne Peek ATO-.t 529 'FRANS ~86'74':~; I) ISTRIBLJTION · "' Central Fi Le.~ -"' Chevi-oi] ~" Ext'en.sion ExpI. ora~io~ · .."" EX x ol'l Mar a '1; hol'~ · "' Mob i L copy as receipt' of data, ,. ARCO AI.a.'.;ka, Inc· I::'~0~ Box 1~)0360 Anchorage, Alaska 99.5:'10 DATE: A~g~m't .5, ~986 ~ -.- 4 4--9-- 13 6 ,S' 't a t' i c C; r a d i e ¥1 .I.. C. a m c: o t -- t t 4.-'7..- 8`5 ,.~ 'l' a t' i c f.; r a d i e n 't C a m c o t -.. t `5 4 .... ~ 0.-. 86 5' 't a ~.' i c (.; r a d i e n .1: C a m c o 3-t 6 6.-2e-86 I::'re..~s'ure Fa I.I. off ."?.' :.3.... S ~7.-2-' 86 I""' I. o w i n g (.; r a cli e ¥~ ~.' C a m c o T.~ ..- 32 '7-- 2- 86 F' I. o w i n g I.'; r a ¢:1 i ce n T C a m (: o S-.. S S 7-.- 4-. 8,5 F I. o w i ¥~ g (.; r a d i e ¥~ t C a m c o 3.-34 7....4-.86 F:' I. ow ing (;r'ad i e~.1t Camc:o ~ 6-.7 7'"'2=.~-'86 ,S'~.'a~.' i c C;rad i en~ C:amco F:'Lea.~;e .~;ign anti re'turn 'i'he at'tac:hed c:op¥ a..~ receip'i' of da'l'a, HAVE; A N~ I... i ~.1cla I Alaska 0il & (~as Cons. Commission ~,, ..,,) · A T 0 ..- ~ .:~ ,. 9 Anchorage l RAN,S :,":86483 I) I ,.$' T R I B I..J 1' I C) N (.,e~'l'ra I. F'i Les ,', , Cl~evron · ,,.'"' .'0 & M I.'.!: x '1.. e',",.s i o'n I.::'. x p I. o r a .1: i ,[:', 1.1 :.":E X X 0 i'1 Pi ara 't h o r~ :U: M o b i L .11. · ,~ F:'1.1 i I. i. ip ~; P B WPI. I. I::'i I.e '"' ,5' 0 h i o · '".,. ,~ta'l'e of AI. asl<a · ,,.'"' l' e x (~ c o. O~1 and Gas Con,party Norlh Alaska District Post ~,' Box 360 Anchol....~, Alaska 99510 Telephone 907 277 5637 Jerry A. Rochon District Operations Engineer October 24, 1980 Reference: ARCO Magnetic Tapes ~.S. 12-7 ~,,'D. S. 12-4 lO/6/8o zo/6/8o lO/6/8o Tape #8130-11160 Tape #9890-19010 Tape #7880-10940 ~/ D.S. 2-lA 10/1/80 Tape #8200-9700 ,.'/',,- ¢ ,J ~e sign and return the attached copy as receipt of data. Mary Kellis North Engineering TRANSMITTAL #748 DISTRIBUTION NORTH GEOLOGY R&D DRILLING ENG. MANAGER D&M GEOLOGY STATE OF ALASKA EXXON MOBIL GETTY P~ILLIPS SOHIO MARATHON CHEVRON !. 'l ARCO Oil and Gas Company is a Division ol AllanllcR~chl~eldComl:)any ARCO Oil and Ga~ Company Alisa,0 ~ ( Post Or,~.-; dox 360 Anchorace. Alaska 99510 Te!ephono 007 277 5837 September 3, 1980 Reference: ARCO Cased Hole Logs ...ri%.,-... 7/3/80 CNL O.S. 1-17 7/3/80 " D.8. 2-10 7/2/80 " D.S. 6-13 6/7/80 " D.S. 6-14 6/25/80. CNL D.S. 6-14 6/25/80 CCL/Gyro D.S. 7-11 6/30/80 CNL D.S. 7-12 8/2/80 Caliper D.S. 7-14 6/30/80 CNL D.S... 9-14 8/6/80 Diff Temp Run 2 5" Run 2 5" Run 1 5" Run 1 5" Run'"' 1 · 5", Run 1 2 & 5" (same log) Run 3 5" Run i 5" Run 3 .... 5" Run 1 5" ~',~/Please sign and return the attached copy as receipt of data. K. J. Sahlstrom North Engineering TRANSMITTAL #580 DISTRIBLrFION North Geology Exxon R & D Mobil Drilling Getty Eng. Manager Phillips D & M Sohio Geology ~rathon State of Alaska Chevron ARCO Oil and Gas Coml~any is a Division of AtlanhcRichtieldCompany ARCO Oil and Ga.~,' ompany .... ., .~, ...... ~}.}', ?':'7 March 28, 1980 Reference: ' D.8. 1-12 D.$. 2-11 D.S. 2.12 D.S. 4-9 D.S. 4-9' . 7-12 aSe sign of data. ARCO Cased Hole Logs 7/4/78 Spinner Run 1 5" 7/11/78 Continuous Flow' Ran 2 5" 7/1/78 " " Ran 1 5" 6/21/78 " " Run 1 5" 10/4/78 Continuous. Flow Run i 5" 10/5/78 Differential Temp Ran 1 5" 1/29/80 Spinner 5" and return the attached copy as receipt ,, · K. J. Sahlstrom North Engineering -i -- j ~:OMM ..... I J RES ENO I ~ I 3 ENG '7-- ~ 4 ENG-- ~ ~EoL' ' GEOL I ~ER: TRANSMITTAL #239 DISTRIBL~ION North Geology R&D Drilling Eng. b~anager D ~ M Geology State of Alaska Exxon Mobil Getty ?hillips Sohio Marathon Chevron Enclosed are copies of the following Arco Pressure Buildup s: D.S. # 1-11_ .?-2-78 '-D.S. # 1-14 ~"7-12-1h-78 D.S. # 1-lSd-- 7-15-16-78 D.S. # 1-16,'. 7-18-19-78 D.S. # 1-17,j 7-21-22-78 Please sign and return attached copy of enclosed transmittal' as receipt of data. Very truly yours, North Operations Engineeri.ng Transmittal #418 AtlanticRjchfieldCompany North Am 'e~ ,n Producing Division North Alasl(., Oistrict "" Post Office Box 360 Anchorage, Alaska 99510 Telephone 907 277 5637 August 2, 1978 Mr. Hoyle Hamilton State of Alaska Department of Natural Resources Division of Oil and Gas 3001 Procupine Drive Anchorage, Alaska 99501 ./[~.?'". ,,,,.., Subject: DS 1-3 Permit No. 70-16 ~ermit No. 77-57 DS 1-12 Permit No. 77-58 'DS 1-14 Permit No~ 77-77 DS 1-15 Permit'No. 78-7 DS 1-16'Permit No. 78-8 DS 1-17 Permit No. 78-9 Dear Sir: EnClosed please find a Completion Report for the above- mentioned wells. Very truly yours, Frank M. Brown District Drilling Engineer /gk Attachments . D-t.s,-,,n' cf Oil an.:l AIt..~'h,',,~i~~ C°n$orv...~tion {" SUBMIT IN DUPLICATE* STATE OF ALASKA :s~ ..... n.'r~:~- r t.'v ~' I'.~ t, OIL AND GAS CONSERVATION COMMITTEE WE1-L COMPLETION OR RE£OMP1-ETION REPORT AND I.OI3' la. TYPE OF WELL: OIL -------------------~,, WEl. I.~ I%'ELL __ DRYil Other b, TY?E OF COMPLETION: .,',:~.~ ~',.~.,< r~ ~.,:P. F] ~.,.~.~ ~] ~,F~. ~ Perforated W I':l.l. - ,' OVER ~ £N , -' BACK EESVR. Other 2. NAME OF OP~RATOR Atlantic Richfield Company 3. ADDR. ES,R OF OPERATOR P.O. Box 360; ~chorage, Alaska 99510 4. 1.0CaIION OF WELL (Report location clearl~ and in accordance with a.y ~tate requirements)* At surface 898'8 ~ 77'E of At top prod. interval reported below ' 1323'~ ~ 1540'~ of SE cr Soc 8~ T10~ R15E~ U~ At total dep~ 5. AP1 N~-L?.,8/CAL CODE 50-029-20268 6. L~SE D~IGNA~ON ~ND SER~L NO. ADL 28329 7. IF INDI.-~N. .~L.LOTTEE OR TRIBE NA.%IE 8. UNIT.F.a. RAI OR I..F_~.kSE NAME Prudhoe Bay Unit g. %VELL NO. DS 1-11 (34-8-10-15) Prudhoe Oil Pool 11. SEC., T., R., M.. (BOTTOM HOLE OBJECTIVE) Sec. 8, T10N, R15E, 971'N & 1343'W of SE cr Sec. 8, T10N, R15E, UM "Z.P~ITNO. 77--57 10/9/77 10/27/77 11/4/77 73' RKB ~ 18. TOTAL D,~F'rI-I, MD & TVD[9. PLUG, .]E~A,C'K MD & TVD[~90. 1F 1VrUL'r .J~L~ COiVIPL., ] 21. INTERVALS DRILLED BY · ! I~OW IVf. A.NY* ROTARY TOOL~ 10,010'MD, 9394 ' TVD [10,945 'MD, 9342 '.~VD Sinqle CABI,E TOOLS 23. WAS DIRECTIONAL ! S'URVEY MADE ,i Yes Ail 22. PRODUCING TN'rEHVAL(S), OF 'r~:l$ COMPLE'riON--TO~, BOTTOM, NAME (MD AND Top Sadlerochit 10,235'MD, 8732 'TVD Base Sadleroohit 10,894'MD~ 9295 'TVD 24. TYPE ELE. CTillC AND OTha~ LOGS RUN DIL/SP, BHC.S/GR, FDC/CNL, GR/N/CCL CASING RECORD (R~port all strings set in well) 20" 949 Wei'dI H-401 120' 12-3/8" 72# Butt[ N-80[ 27i3' 9-5/8" [47# Butt! N-80~ 10,988' I s-esl, '26. LINE~ ~CO~ 28. PEI~ORATfONS OP~ TO PRODU~kO~ (In~rval size and number) 10,550'-10,570' "" 10,530'-10,550'.,'~-'' ',... 10,482'-10,520' 10,450'-10,470' W/4 shots per foot 30. P KOD UCTI ON HOURS;['ESTED , '[CI1OXE SiZE [PROD'N FOR ....... _.2/21/78 [ 34/64 -' > 6996 31.'D~S~OSlTiON O~ CaS (8old, ~,ed [or ~ei, .w~ed, etc.) Reiqjected 30" J 300 mw t'z.-'~ /2 "1 _~nn L2-!Y4"]I 800 sx Class G Cmt 1 SCi~E~ (~D) SIZE DEPTH SET (~D) ~ PACI~ER SET (~D) 5-1/2" 10~024' ~894' .! 29. ACID, SHOT, F~I.~CT~R~, C~,~Ei~T SQUeeZe, ~C. I DATE F1RST PI%ODUCTION [. PRODUCTION NIEI.[iO'D (Flowil~g, ga.s 1i£~, pumping--size and type of Pum~ ...... .q' owing 'L °~6~uc in q OI~BEL. G.~MCF. WATE~BBL. ~ GAS.OIL IL%TIe I sss I 1 G~-~CF. W~BBL. I 4931 I lO4 32. LIST Ole ATTACHMENT8 U] OIL GRAVITY-APl (CO/:I,R.) I TEST WITNESSED BY Production 0perationn 33. I hereby certify that the.~oregpj/lg and attached information is complete and correct as determlned from all-available records ', SIGNEI. TITLE .......... ~U , / ~.~1 -- E~~r DATE ............ *(See Instructions and Spaces [or Additional Data on Reverse Side) INSTRUCTIONS General: This form is designed for submitting a complete and correct vve!l completion report end log on all types of lan:Is and leases in Alaska. Item: !6: Indicate which elevation is used as reference (whe-.,'e not o;her-~,ise sho,,%'n~, for dep;h measure- ments given in cther spaces on this form and in any a.?tachme:~.:s. Items 20, and 22:: If this well is completed for separate- prcduction from more than one ~nterval zone (multiple completion), so state ~n item 20, and in ite~ 22 show the p;cduci~:g interval, o: ~ntervals, top(s), bottom(s) and name (s) (if any) for only the inlerva! reported in iten~ 30. Submit a separate repor..' (page) on this form, adequately identified, for each additional interval to be seperately produce:J, show- lng the acfditional data pertinent to such interval. Item26: "Sacks Cement": Attached supplemental records for this well should show the details of any mul- tiple stage cementing and the location of the cementing tool. Item 28: Submit a separate complelion report on this form for each interval to be separately produc~cl. (See instruction for items 20 and 22 above). 34. SUMMARY OF FO~-MATION TESTS INt'LUI)IN(; INTERVAL TESTED. PHEF~SUHE DATA AND ~_,COVEHIES OF OIL OAS. 35 G~GIC MAR~ WA~ AND MUD NAME 36_ CORE DATA. Aq=I'ACI[ I~HIEF D~CRI-PI~ONS O~ LITllOLOGY. POROSITY. FHACWR~. APP~T DIPS AND DETECTED SIIOWS OF OIL, G~ OR WA~{. nticRichliolciCompany North American Producing Division North Alaska District Pos!Office' x 360 Anchorage, ,u~ska 99510 . -:X~'[ ~~-x,~Toleph°ne- 907 277 5S37 -- t'~:.",[ ;' ~i..' ;-' .,-, '- ; ; , ,.. ..,~ ~ ~..~' · . .'~ ~ .i ~.."~' .,:, ~ .... , . x.;~t.' ,'..?'~_.~ ' .., .. ~rme 26, 1978 [-¢~-, Re£erence' Enclosed are copies of the follm,'ing cased hole logs' Differential Temperature Log NGI #3 NGI~iO ' D.S. #3-8 D.S. #4-9- 11 Fluid Density . D.S. #3-8 D.S'. #4-9 11 D.S. ;~1-16 D.S. Ill-.17 D.S. ~/4-13 D.S. ~4-15,. 11 Hydro Log 5" D.S. #3-8 Please sign~ and return copy of trm~smittal as receipt of data. North Operations Engineering Transmittal ~;371 AtlanticRichfieidCompany North Ameri( Producing Division North Alaskai~,strict Post Office B'ox 360 Anchorage, Alaska 99510 Telephone 907 277 5637 June 21, 1978 Hr. O. K. Gilbreth, Jr. State of Alaska Division of Oil and Gas 3001 Porcupine Drive Anchorage, Alaska 99501 In response to your request for data pertaining to reservoir pressure information, please find the enclosed data. A list of stabilized flow rates prior to shut in and CtaTmulative oil produced since last pressure equalization has been tabulated for all wells requested; with the exception of the following: ..~,.'i.~,~,?~l;~ ~,~ ~. . S,,, #~-1.~¢'1-12, and 1-14-To be run in the future. · S."*~k~i, 2-12-Are currently being run. D. S. #3-9, 3-10-No plans for these wells to be drilled at this time. Per your request, copies of Initial Static Pressure reports are again being submitted for the following: D. S. #4-7-Distributed to State 5-19-77 D. S. #9-3-Distributed to State 11-24-77 NGI #3- Distributed to State 19-78 NGI #5- Distributed to State 10-9-77 To date, no pressure buildups have been run on NGI wells. Plans are to run pressure surveys only at this time. I hope that this information will satisfy the state requirements adequately. Very truly yours, 3~;~/RAL/er HKVp North Alaska l}istr:i.ct Eng. ine___~71 ng_ T RAN SM I T TA L · Front' J. A. Rochon/R. A. Logue No. Scale Xe. rox Sepia BL Line . . Acid or Fracture Treatment Log · BHP Buildup ~ Flm~ Profile Survey Borehole Geometry Log ,. Carbon Oxygen Log ~_.~ Collar Log ~ Cement Bon~ Log · , _ Compensated Neutron Log -. Cased'Hole · Core Analysis - Interval' Core No. Core Description (SMC) - Interval · ~.-'. Core Description {Cony.) - Core No. __.Directional Survey .- Gyro '.' '-- Singl'e Shot - Multishot ,.,.,, 'En~'ineerin§ Production Log Fluid Analysis ~__--_ Fluid Density, Gamma Ray Location Plat --, . ~_ ~lonthly Well Test Data Blud Log Perforating Record __ ,State Reservoir Pressure Report '[',..Surveillance Reports Temperature Log, ~-'' Transient Pressure 'Surveys T\q) Logs - Duel Induction Laterolog - Compensated Formation Density Log - Compensated Neutron-Formation · ' Density Log - Borehole Compensated Sonic Log - Porosity. Log · eipt Acknowledged By- ~f~,~" /~).. 0'~<." _. Date' · .! ase Return Receipt To: Ms. R. A. Logue .. Atlantic Richfield Company" P. O. Box 560 Anchorage, Alaska 99510'' .. · . Dl',~isio~ ¢Oii and Gas Atlanti'cRichfieldCompany ,. North American Producing Division North Alas(' ')istrict Post Office uox 360 Anchorage, Alaska 99510 Telephone 907 277 5637 March 9, 1978 Mr. Hoyle H. Hamilton State of Alaska Department of Natural Resources Division of Oil and Gas 3001 Porcupine Drive Anchorage, Alaska 99501 Subject': '"'~4-8-10-15 ) '~ No. 77-57 DS 1-12 (21-9-10-15) Permit No. 77-58 DS 2-11 (32-1-10-14) Permit No. 77-63 Dear Sir: Enclosed please find a Well Completion Report and Perforating History for the above mentioned wells. Very truly yours, Frank M. Brown District Drilling Engineer /am Enclosures RECEIVED D~vt~ior~ ef ~it ~cl ~t~h~,~:~.:,:~.~ }' ~u'::t T) - T SUBMIT IN DUPLICATE* STATE OF ALASKA OIL AND GAS CONSERVATION COMMITTEE WELL COMPLETION OR RECOMPLETION REPORT AND LOG* la. TYPE OF WELL: tun f'Trl, WEI.I.[AJ WELL I~1 DRYL_J Other b. TYPE OF COMPLETION: w~:Lf, ovn~ ~ 2. NAME OF OPrRATOR At]antic Richfield Company 3. ADDRESSOF OPERATOR P.0. Box 360; Anchora,qe~ AK 99510 4. LOCATION OF WELL (Re])ort location ciearlv and in ~ccordilRce with a*ly ~iate requircment,)* At surface 898'S & 77'E of NW cr Sec. 8, TION, R15E, UM At top prod. interval reported below 1323'N & 1540'W of SE cr Sec. 8, TION, R15E, UM At total depth 971'N & 1343'W of SE cr Sec. 8, TION, R15E, UM 5. APl NLrM~A~ICAL CODE 50-029-20268 6. LEASE DESIGNATION A-'ND SERLA. L NO. ADL 28329 ?. IF INDIA.AT, A/~OTTEE OR TRIBE 1N'A.~%EE 8. UNIT,FA.I~.Z OR LF-'X-SE NAME Prudhoe Bay Unit 9. WELL NO. DS 1-11 (34-8-10-15) 10. FLEL,D A2qD POOL,OR %VIL,DC&T Prudhoe B~ Fie]d Prudhoe 0~{ Pool il. SEC., T., R., M., (BO'I'rOM OB) ECI'IVE Sec. 8, TION, R15E, UM 12. PER,MIT NO. 77-57 10/9/77 10/2..7/77' 11/4/77 73' RKB ~ lO,OlO'MD,9394'TVD! 10,945'MD,9342'TVD!.. ~OWM~Y.sin~le ROT~ TO0~,~ ' o.A,,.~ Too,.,~ 2,2. PRODUCING TNTERVAL(S). OF THIS COMPLETZON~TO~, BOTTOM, NAME (MD AND TVD)' 23. WAS DIRECTIONA.L ! SUR.V~IY MADE Top Sadlerochit 10,235'MD, 8732'TVD t Yes Base Sadlerochit 10,.894 'MD, 9295'TVD i 24, TYPE ELECTIIlC AND OTHER LOGS RUN DIL/SP, BHCS/GR, FDC/CNL, GR/N/CCL __ m m Lh. CASING RECOB.D (Report all strings set in well) 20" 94// Welded| H-40 ! ~20' t3~" ] 300 sx Arcticset Cmt 13-3/8" 72~ Butt ] N-80 [ 27i3' 1~-~/~,, 5600 sx PF II Cmt 9:5/8" 47t Butt I N-RR~! 1'0,988' 12-1J4" 800 sx Class G Cmt IRS: 5 i I ,- [ , 5-1/2" 10,024' 9894' i ~ i 28. PERFORATIONS OPEN TO PRODUC~ON (Interval size aiid number) 29. ACID, SiiOT, ~';~.~C%'CRE, C~,IE'NT SQUEEZe, ~'C. 10,550'- 10,570' DEP'~I I~,T~V.~ (~D) ~ AM"O~'¢:~!4~FJ~'~?~ALi, ~ ~ ~ , , ~ USD 10,530'- 10,550' , ,... N/A 10,482'- 10,520' I ,,, :..~ 10,450'-10,470' w/4 shots per ft. Jv ~""'~ D~'I'E FIRST PR. ODUCTZON [ PRODUCTION ME'I.[{O~ (Flowing, f.~u$ lif~, purn. ping~size and type of pump} ~]'~'~ATUS ('Producing or DATE OF TEST, IHOU'RS TEST~ [C}iOXE SIZE [PROD'N FOR OI~BEL. ~6'w, TUBING.~ ]CA~I. NG PRESSURE IOALC~T~ OI~BBL. GAS--~CF. ITEST WITNESSED BY 32. LIST OF ATTACHMENTS , Perforatinq Histor? 33. I hereby certify that the foregoing and attached information is complete and correct as determined from all-available records SIONED.~ ~ TITLE District Drilling Engineer DATE ~8 ............ General: This form is designed for submitting a complete and correct ;~,:ell comp!etlon reF,.o,t ..end leg on all types of lan:ts and leases in Alaska. item: 16: Indicate which elevation is used as reference (whe,'e not otherwise sho'-wn} for depth n:e:~sure- ments given in ather spaces on this form and in any att.act',:n, eiqts Items 20, ,,ncl 22:: If this well is completed for separate prc. c{u, ction from ~ore than one ~nterval zone (mulliple completion), so state ~n item 20. and in item 22 show the p~cJuc~;'g interval, or ~nterv~ls, top(s), bottom(s) and name (s) (if any) for only the interv:~i re.~arted i~ iter~.: 30. Submit a separale report (page) on this form, adequately identified, for each additional inte~ val to be seperately produce.'{, show- ing the additional data pertinent to such interval. Item26: "Sacks Cement": Attached supplemental records for this well shoulJ show the details of any mul- tiple stage cementing and the location of the cementing tool. Item 28: Submit a separate completion report on this form for each inlerval to be separately produced. (See instruction for items 20 and 22 above). 34. SUMMAH. Y O1~ PORMATION TF,.STS IN(.'LUI)iN(; INTERVAL TF_~STET). P}{F_,S,SURE DATA. ~ ~OVERI~ OF OIL GAS. 35. (;~G l{~ MARK~ WA~ AND MUD NAME M~AS i 36. CO[{E DATA, AR'I'ACIi flRIK~ D~CRiPi~O~S OF LITIIOLOGY, POROSITY, FRAC~R~, APP~ DIPS AND i)~i~C~'EI) SHOWS OF OIL, GAS OR . . DRILLING HISTORY DS 1-11 (34-8-10-15) AP I 50-029-20268, ADL 28329, PERMIT NO. 77-57 Spudded @ 1800 hrs 10/9/77. Drld 17-1/2" hole to 2750'. RU & ran 13-3/8" csg w/shoe @ 2713'. Cmtd w/5600 sx PF II cmt, slurry wt 14.8 ppg. Did top job w/70 sx PF II cmt. NU BOP. Drld FC, cmt & 10' new form. Tstd form to 12.5 ppg equiv. Drld 12-1/4" hole to 10,950'. Dropped multishot. Ran DIL/SP, BHCS/GR, FDC/CNL. Drld to 11,010'. RU & ran 9-5/8" csg w/shoe @ 10,988', FC @ 10,945', lower FO @ 2467', upper FO @ 2338'. Cmtd w/800 sx Class G cmt w/1% CFR-2, 0.15% HR-7, slurry wt 15.8 ppg. Installed & tstd pkoff OK. Did Arctic Pack job. Ran junk bskt. Circ out mud wtr, circ out wtr w/10.6 CaCI.. Ran GR/N/CCL & gauge ring junk bskt. RU to run 5-1/2" tbg, pkr stopped @ 39§2'. Sheared off SBR, LD tbg. RIH w/retrieving tool. Engaged SBR, backed off "K" anchor. LD fish. Milled over SAB pkr, LD fish. Ran gauge ring & junk bskt. Rec approx I qt. cuttings, bar & rubber. Ran scraper. RU &.ran 5-1/2" compl assy w/shear sub @ 10,024', SAB pkr @ 9894', Baker SBR @ 9883', sliding sleeve @ 9752', ball valve nipple @ 2208'. Displ tbg w/248 bbls diesel. Dropped ball & set pkr. Tstd OK. NU & tstd xmas tree to 5000 psi OK. Pulled dummy valve, ran dummy gun w/CCL. Reran dummy valve. Tstd balance & control lines to 5000 psi. RU for long term tbg tst. Released rig @ 2400 hrs 11/4/77. PERFORATING HISTORY (. DS 1-11 Began perf operations @ 0600 hrs 2/4/78. Tstd tree, csg & wireline BOP's. Pulled dummy valve. Perf'd intervals 10,550'-10,570', 10,530'-10,550', 10,482'-10,520' & 10,450'-10,470' w/4 shots per ft. All perf'd depths referenced to open hole BHCS log of 10/26/77. Ran Amerada press bombs & FDL. Flowed well. Ran & set ball valve. Tstd balance & control lines to 5000 psi OK. Bled press above ball valve to 0 psi, held OK. Installed & tstd tree cap to 5000 psi OK. Released well to Production Dept @ 0200 hrs 2/8/78. " O. K. Gilb~, February 15, 1978 Director Hoyleodef H.petrole~mm~l= Engh~r~ witness surfaoe safety valve (SSV) and Subsurface Safety Valve (SSSV) Arco Drill Site 1-11 Sec. 8, TION, R15E, %M. Pexmit #77-57 ssc~y, Fehxuazy 8, 1977 - 1:30 PM. Ken Jcx~s, opera~ for Arco c~ safety ~alve tests ~ DS 1-11. ~~ ~at 2208 ~. ~ b~ ~ ~ c~ ~ 600 ,.~i ~ 600 ~ ~~ f~ ~ a ~~ Drlg. Permit Operator /~, P~ z"~ A~ .a Oil and Gas Conservation Commi.. Field Inspection Report Wel 1/Platfm S e c ~' T~..r',_'j,~z~, Represented by/¥,~/~ ,..T~/,~.~ Name & Number_~ Satisfactory Type Inspection Yes No Item ( ) Location ,General () () () () () () () () ) () ') () () () () () () () 5. Su-rface-No. Wells / 6' Subsurface-No. Wells ? ( ) Well Test Data 7. Well Nos. , , , 8. Hrs. obser , , , 9. BS&W , , , ( ) ( ) 10. Gr. Bbls. ( ) Final Ab~nd'onr~ent '-- Satis ~actory Type Inspection Yes No Item ( ) BOPE Tests 1. Well Sign ( ) ( ) 15. "Casing set @ 2. General Housekeeping ( ) ( ) 16. Test fluid-( )wtr.---~--C)mud ( ) oil 3. Reserve Pit-( )open( )filled ( ) ( ) 17. Master Hyd. Control Sys.- psig 4. Rig ( ) ( ) 18. N? btls. , , , ps~g (:~ Safet,v Valve.. Test.s_. ( ) ( ) 19 R~mote Contr-~ol~ -- ( ) ( ) 20. Drilling spool- "outlets ( ) ( ) 21. Kill Line-( ) Check valve ( ) ( ) 22. Choke Flowline ( )HCR valve ( ) ( ) 23. Choke Manifold No. valvs flQs ( ) ( ) 24. Chokes-( )Remote( )Pos.(~dj. ( ) ( ) 25. Test Plug-( )Wellhd( )cs.o( )none ( ) ( ) 26. Annular Preventer,~psig ( ) ( )/ 27. Blind Rams, psig ( )' ( ) 11. P&A Marker ( ) ( ) 28. Pipe Rams ~psig ( ) ( ) 12..Water well-( )capped( )plugged ( ) ( ) 29. Kelly & Kelly-cock psi9" ( ) ( ) 13. Clean-up ( ) ( ) 30. Lower Kelly valve ~sig' ( ) ( ) 14. Pad' leveled ( ) ( ) 31 Safety Floor valves-( ~BV ( )Dart Total inspection observation time ~-J~f,...~/days Total number leaks and/or equip, failures /'~ Remarks ~~ '~'_~'Sc~ ..~: f ~:r'~_'~.~_,-~'_x' ?'~"/~/ ~' ?.~ / .- ~ .~-~ -- cc: ?ml] ~(~!~'~ No~i~ i~ ~s or w,e~ re~ Ins~ec~e~ ~.~'W/~ ZW~Da~e_ ,. North Alaska District Fmgineering T RANSM I TTAL To' From' J. A. Rochon/D. R. Jackson Da t e: _J_am~_, 197~ ;Veil Name' ,. Transmitted herm~ith are the following for the subject well' Run No. Scale Xerox BHC Sonic/Caliper Log BHC Sonic/Caliper - GanmmRay Log BHC Sonic/Gamma Ray Log Caliper/CCL Cement Bond Log/VDL Compensated Formation ·Density Log Compensated Neutron-Formation Density Compensated Neutron Log Core Analysis - Interval Core No. Core Description (SWC) -' Interval Core Description (Cony..) - Core NO.' Directional Survey - Gyro Single'Shot ~hltishot Drill Stem Test - Test No. Dual Induction Laterolog Formation Density Log' FormatiOn Density Log/Gamma Ray Gamma Ray/CCL Laterolog Location Plat Microlaterolog Microlog ~dlog '- Inter~al Sample Log (A.R. C0~) - Interval Synergetic Log TVD-DIL · TVD-Porosity Log Receipt Aclmowledged For' Date' Please return receipt to' · At~:/ Mr. 'Donogan Jacxson AVlaj~tic Richfield Company. N6~h Alaska Engineering P. O. Box' 360 Anchorage, Alaska 99510 D;,S. 1-1]' · Sepia BL Line .t[733 North Alaska District Engineering TRANSMITTAL To' From: J. A. Rochon/D. R. Jackson Date- Dac~mh~r 5~ ~077 Well Name' D.S. 1-11 Transmitted herewith are the following for the subject well' Run No. Scale .' '1' · BHC Sonic/Caliper Log BHC Sonic/Caliper - Gamma Ray Log BHC Sonic/Ga~una Ray Log' Caliper/CCL Cement Bond Log/VOL Compensated F:ormation Density..Log Compensated Neutron- Formation Density. Compensated. Neutron Log Core Analysis - Interval ' 'Core NO. Core i Description [SWC) - Interval Core Description [Cony.) - Core NO. Directional 'Sm~ey.-. Gy.'ro. "; ..... ". . Single' Shot ~'hl tishot Drill Stem Test - Test No. Dual Induction. Laterol.og , " Fomation Density Log .Formation Density Log/Ganm~a ,Ray" Gmma RaM/CCL Laterolog Location Plat Microlaterolog ,. Microlog ~adlog- Inierval .Sanple Log (A.R.,Co~) ' Interval' Synergetic Log TVD-DIL ,~D-Porosity Log 2" '@. 5" Xerox Sepia BL Line · 4 ea. __O__ea/:z 7-~ . ea, 0 ea ~._.. ea 0 ea'" _z , . Receipt Ach~owl'edged For" Date' Please return receipt to' /z-/z -..77 Attn' Mr. Donovan Jackson Atlantic Richfield Company. North Alaska Engineering P. O. Box 560 Anchorage, Alaska 99510 · ' DN!sio. 01' Oil ;:tho Gas ~.,t't.,.,'.'.~ :7! '''~'? q · , At~anffcRichfieidCompany ,-, North Ame{r n Producing Division North Alas~._ Jistrict Post Office Box 360 Anchorage, Alaska 99510 Telephone 907 277 5637 November 15, 1977 ~'~"- Mr. Hoyle Hamilton State of Alaska Department of Natural Resources ]-"a e~c,t of a.d 3001 Porcupine Drive Anchorage, Alaska 99501 ~ ~-"-'~c ' / --~ .,.r~,. ,{~;; ... ..~ ,. ~]~, ':.. ........ . ............. DS 1-11 (34-8-10-15) Subject: Permit No. 77-57 Dear Sir: Enclosed please find a Completion Report along with the ~ ~'-' Drilling History and Multi-Shot Directional Survey for the above mentioned wells. Very truly yours, ,,..~>T~_~ ¢.,., r Frank M. Brown District Drilling Engineer /am Enclosure STATE OF ALASKA OIL AND GAS CONSERVATION SUBMIT IN D~PLICATE* ', ~e, otbor s! :'uct Ions on COMMITTEE WELL COMPLETION OR RECOMPLETION REPORT AND LOG* la. TYPE OF WELL: Oho [] uAS ~ [] %% ~'~1. I, $¥I.:LL ~.___J DRY Other b. TYPE OF COMPLE~ON: WE[.I. OVER ~ EN ~ BACK ~E~VR. Other 2. NAME OF OPERATOR Atlantic Richfield Company ADDRESS OF OPERATOR P.O. Box 360; Anchorage, Alaska 99510 4. T.oc^'rIO.X oF W~:LL (ReI~ort location clearlll and in accordance with any State requirementz)* 898'S &.??'Eof NW cr Sec. 8, T10N, R15£, UM · t top prod. inter(R1 repot(eft below 1323'N & 1540'W of SE cr Sec. 8, T10N, R15£, UM At total depth 971'~ & 1343'W of SE ce Sec. 8, T10N, R15£, UM 10/9/77 J 10/27/77 11/4/77 (73~/RKB 1~;. TOTAL DEPTH, MD & TVD[19. PLUG, B,A,C'K MD & TVDp. IF iVI'ULT1PLE COiViPL.,~ J 21. - I I I I ROTARY ....11,01.Q...MD 9394 TVD/10,945 MD, 9342'TV.p "°~n~X~ ~. PRODUC1NO !IN'TE1RYAL(S), O.F TH. IS CO,iVlPL~gTIO~TOP, BOTTOM, ~AME (MD AHD ~'VD), Top Sadlerochit 10,235'MD, 8732'TVD Base Sadlerochit 10,894'MD, 9295'TVD 24. TYPE ELECTiJlC AND OTHER LOGS RTJI~T DIL/SP, BHCS/GR, FDC/CNL, GR/N/CCL m m ~. CAS~NO RE~ (Ruport a11 strings set tn w~ll) CASLNG SIZE 13-3/8:: ii [WEIGHT, LB/PT,~ 'GP,~DE ! DEPTH SET (M_D) 94# weldecl ! H-40 ] 120' ' [/z~ Butt [ N-80[ 2713" lq/~ Butt .; i m-8om ! 10,988" I i LINE~ ~CO~ API NU~IEIiICAL CODE 50-029-20268 $.LEASE DESIGNATION A-ND SERL~L NO. ADL 28329 ?. IF INDIA.N, A.LLOTTEE OR TRIBE NA~XLE 8. UNIT,F~%Ni OR LF~KSE NAME Prudhoe Bay Unit PERFORATIONS OPeN TO PRODUC'I~.ON (In~rval, size and number) N/A DS ,,.1-11 j( 34-8-10-15 ) 10. FLF_J.,D-A_-NT) POOL. O,,H Prudhoe ~ay r~emd P~'u_rthoe Oil Pool 11. SEC., T., R.. M.. (BOTTOM I-IOLE OBJECTIVE) Sec. 8, T10N, R15E, UM 12. PERMIT NO. 77-57 RT. GR, ~L'TC)* {17. ELEV. C.A. SINGIiEAD ! INTERYALS DRII. LED BY CABI,E TO01,S 23. WAS DIRECTIO'NA-L SURV~EY MADE Yes hereby certify tha_.t the fore~loing,.a,F__d attae~he,d information is complete and correct as determined from all-available records I *(See Instructions and Spaces for Additional Data on Reverse Side) 32. LIsT 0~' ATTACHMENTS ~ Drilling History, Multishot Directional Survey PItODUCTION .. ,." J~:~.L S:rATUS or N/ADATEFI?{ST Pf~.ODUCTION I~%ODUCTI. O.N ME'I [{O'D (Flowhlg, [~as lif~, pumping--size alld typo of pump) ~l~u'~-in)m (Producing DAT~ OF T~ST.Ii'OURS TEST~. "IJCI1OXE SIZE ]TEST PEi~OD [JPROD'N_ FOR;. OI~BEL. JG'~S--~CF' J WA'I'E~BBL. J GAS-OIL,. FLOW, TUBINGI~S. j jICASING PRESSURE, ,J24-EO'U~m ~A~ ,[JCALC~TD OI~BBL. ]GA~-I~CF' W&~BBL. IOIL GRAVITY-~I (CORR.) 31.. WS?OSITION OF oas (Sold, used/or tuel, vznted, etc.) I m m m m m J TEST WITNESSED BY | .o~ sIz~ J c~,~T~N~ ~.co~ J 30mm J 300SX Arcticset Cmt J 12½" j 5600sx PF II Cmt J 12.% t 800sx Class G Cmt i.&MOLTNT PULLED 27.. TUBING REGOI%D J SCilEEN (~ID) SIZE DEP~ SET (~D) ~P~C'IfiER SET (~D) 5% 10,024' 9894..' _ t .... .... ~ r"," ~ ,' f') ~ ,', "'~ ~,~ ? ~, ~ , .'~ % ·., ; U TM :~,:'~'~ :'; I~ .:" .... ; "."',' '.": ' .... ,].]],~q INSTRUCTIONS General: This form is designed for submitting a complete and correct we!l compJetion report and leg on all types of lanJs and leases in Alaska. Item: 16: Indicate which elevation is used as reference (where not o;herwise shown) for depth measure- ments given in other spaces on this form and in any Items 20, and 22:: If this well is completed for separate prc-duction from more th. an one ~nterval zone (multiple completion), so state ~n item 20, and in item 22 show the p.,cJuc,r:g interval, or intervals, top(s), bottom(s) and name (s) (if any) for only the interva! reporled in item 30_ Submit a separate report (page) on this form, adequately identified, for each additional inte;val to be seperately produced, show- ing the additional data pertinent to such interval. It®m26: "Sacks Cement": Attached supplemental records for this -,,veil shouIJ show the details of any mul- tiple stage cementing and the location of the cementing tool. Item 28: Submit a separate completion report on this form for each interval to be separately produced. (See instruction for items 20 and 22 above). · '14. SUMMAIt¥ O!~' I.'Oll. MA'I'I(.)N TF..ST.'4 IN('LUI)IN(; IN'I'~HVAL '~'F_~qTED. PHESSUI't~-- DATA A.N'D EF_.C_OVF. I~.IF_.S OF OIL. GAS. 35. GI!IOLOG IC WATEH AND MUD · .~ND' I~'T~--(.'TEI~ SI'lOWS Ol~ {)IL,, G~ 0I! WA"FI~. _ _ A PETROLANE COMPANY REPORT of SUB-SURFACE DIREC TIOWA L SURVEY ATLANTIC RICHFIELD COMPANY COMPANY D.S. #1-11 WELL NAME PRUDHOE BAY LOCATION JOB NUMBER A1077 SO141 TYPE OF SURVEY MULTI-SHOT DATE 11-8-77 SURVEY BY JEREMY BEATTIE OFFICE ALASKA I.,4 C,v-302: R,~ --' _8 T.~.L..__A._N__Tj_C R ! CHF I ELD COMPANY D_.R..I..L_L_S_I_T_E._i_-_i.i_ .......... ~,:'-M'A'~-N'E-? I:-;'.__I~__U..L_.Tj_~b-_T_,'_~-U~R_79~-Y DECL iNA T 1: ON 3 1 DE GRE E_s__~-A~"T ~R=A=O-i-O`5 OF CURVATURE METHOD .OF COMPUTATION K B ELEV, 73 FT, --¢-OM-P'UYE-~--P-OR EASTMAN WHIP~S-¥-O-C~--BY F, M, I. INDSEY--~-~I-I~--AS$OC!ATE$ ........ . oF sU.R-ViY ALL CALCULATIONS PERFORMED BY ! B M ELECTRONIC'COMPUTER · ?-. TRUE -~'E:~A-5, DR-i-F~ VE:RTICAL SU~B DRIFT DEPTH ANGLE DEPTH S'E-A DIREC --D M DEG, TOTAL COORDINATES C L___.O___5___U--__~-~Ei~,5. __ SE_V.E.8 !_T.Y_ 5'EC T I ON DISTANCE ANGLE .........DE.G410_OFT D[ 5TAN.CF:. D M 0 0 0 0,00 -73,00 $34,00E 27-0'0 0 0 2700,00 2627,00 $34,00E 2-?-7-/+ 2 30 2-7-7-3-,-97 2700,97 $34,00-E 2868 4 15 2867.80 2794,80 2963 $ 45 2'96-2-,-36 ' 2889,3-6 3057 8 30 3-0'55-°-53 315-i 10 30 3-i-4-8-,-2'3 3075,2-3 $59,00E-- 3-2-4-2+--1-2 0 3~2-3-9-,-'4-4 3-1-66,44 857 · 00E-- 3-3-~-8--1-4 30 3-3-3-0-,-'9-3 32-5"7~-9-3 561 0,00 $ 0,00 W. 0,00 S 0,00 W 1,33 $ 0,90 E 5,92 $ 3,99 E 13,60 5 8,88 E 2~'~2~-5 16,7f--E 32~58 $ 29,07 E 42.19 S 4.4.46 5'3";2-9--5 --62 · 92 --6-~',"~'3-~ 84.9o I8-z-;-~'i-S lo9.83 0,00 5 0 0 0 W 0,00 S 0 0 0 W !_,A ~_s__3 _3_5_%_5..9__E 7,14 S 33 59 59 E 16e25 S 33 9 35 E 28,64 $ 35 41 26 E 43,67 S 41 /+4 47 E o.ooo 0,00.0 ................. 0,00 3 · 3_7_8__ __ .1._, 5.9_ 1,8.62 ............... 7,06 2_..6'32 ................ 16,01 __1,898 2_8_.41 2,169 4,3,66 82,46 $ 49 44, 21 E __2.673 .8_1.,87_. 3432 17 0 3421,/+0 3348,40 S58,00E 3527 19 15 3511,68 3438,68 557,00E ~__..__~21 21 15 3599.86 3526,86 556,00E 3715 23 0 3686.9/+ 3613,94 S57.00E 380-8--2-5--i-5 3-7-7-~-;-81 3698-~-8-i---557,00 E-- 100.07 S 136,95 E 119,61 $ 166e47 E 3902 27 15 3856.11 -3783.11 556,00E 3996 29 45 3938.71 3865.71 555.00E 4090 32 0 ~-~-1-~-'-3-9-'--3'9%-6-.-~-9 '5~5-'~",-6-~E~' 4279 37 0 -4175,34 4102,34 43'7-3--38 0 4249,92 '~ 17~]-~-2 .... $~-8, O. OE-- 140,31 S 198e35 E 163.25 S 233,02 E 188,66 S 269,98 E 216,32 S 309,49 E 246.10 S 352,01 E 278,28 S 396,30 E 4457 36 30 4324.74 4251,74___548.00E 4561 36 45 .4400.18. 4327,18 4654 37 15 4474.45 4401,45 $48.00~ .... 4841 38 45 4621,80 4548,80 547,00E 107.68 S 52 2 27 E 2,674 137.13 $ 53 12 56 E 2.371 169,62 S 53 50 42 E 2.132 1,869 20~,99 S 54 18 12 E 2,419 _ __ 2,139 2,672 2.394 242,96 S 54 43 30 E 284,52 $ 54 59 4 E 314,66 S 440.44 E 35-2 · 73 5---4-82,73 E 390,26 S- 524.4-0 E 329,37 S 55 3 16 E 377,60 S 55 2 51 E 429,51S 55 2 31E 484,25 S 54 55 26 E 541,30 5 54 27 25 g .......... --597,87 S 5-~--50--3'7--E 2,368 3.025 2,280 1,596 653,68 S 53 20 36 E 0,266 .4_Z.7_17~ ,5 __ 5 ~__5.99 E . 466,06 S 607,85 E 709,43 S 52 55 20 E 0,538 765,97 S 52 31 16 g 0.904 .. 505,86 S 650,53 E 824,07 S 52 7 50 E 0,798 106,32 134,91. ._ 166.,.5.4_ 200,94 237,81 278,22 321,99 369,15 _ 419,91 473.&3 587,00 · _ 642,86 698.61 755.20 813.40 R'E-~ORD OF SURVEY ALL CALCULATIONS PERFORMED BY I B M ELECTRONIC COMPUTER t iS__U_E_ MEA5, DRIFT VERTICAL SUB DEPTH ANGLE DEPTH SEA D M DRIFT TOTAL COORDINATES - __ DIRE¢ DISTANCE ANGLE DEG/IOOFT DISTANCE D M $ 4936 39 45 4695,37 4622,37 546.00E '~-" 5030' 40 30 4767,24 4694,24 $46,00E 589,32 5 694,13 E 883.90 S 51 44 54 E 737,71 E . 944,20 $ 51 22 49 E 5_L27 41 45 48~_83~5 ~7_6_~,~_5___$45,00E 632,65 5 781,80 E __5217 43 0 4906,75 4833,75 545,00E 676,97 $ 826,12 E- 5311 43 0 4975,50 4.902,50 $45,00E 722,30 $ 871.45 E 53~ 44 1.5 5043.54 4970,54 S44,00E 768,56 S 916,91E ............ __5499 45--15 5k10,30 -5037,30 $44,005 816,16 $ 962,88 E .................................. ~ ......................... %5~3_45 45 _~k!6~_18 5103,1..8 $~4,00E '864,39 S 1_0.0~,45 E 1005,71 S 51' 1 10 E 1068,07 S 50 40 0 E 1131.88 5 50 20 47 E 1196,41 S 50 1 48 E 1262,24 S 49 42 52 E l_3...Z_q.._9 7 5__4.9 2 5 3 6 E__ __0.798 933_,88._ 1,411 995,64 1,344 1058,28 __ 0.000__1122,_34_ 1,427 1187.17 .1_.06~ ........... 1253.33 0..532__ 1320,37 5_6.8_7 45 /+5 5_2_4_.!~__7._8 5_1_6_8_,_7_8 _5_4_~__,__00E ,91_2_~__82_~5__1..0_5_6_~_22 E __5781 46 0 5307.22 5234,22 544.00E 961,36 S 1103.10 E ..... 9_5_5__._5_ o...o_oo 1463,23 S 48 55 38 E 0,266 -- - ___.53A~..__~3 0 5436.%%__A3~_,_23____SgD_,_00E 1~5~..~._5_$ .... 1.~.~6_,~0 E 15_~.~.~0.9_5.._4_8. 29 21 .... E' 6062 47 15 5500,19 5427.19 543.005 1109,53 S 1243,68 E 1666,67 S 48 15 46 E 6157 47 15 5564,68 5491.68 544,00E 1160.13 S !291,70 0.269 0.980 0.266 6251 45 45 5628,79 5555,79 544,00E 1209,58 S 1339,45 E 6440 46 45 5758,29 5685,29 543,00E 1309,85 S 1433,78 E .~'- 6534 46 45 5822.69 5749,69 543,00E 1359,92 S 1480,47 E __6_6_2_8 46__4_5.__.5.8_87,10 5_8...14,10 ..... S_Z+_3_.,_OOE 1409.99 S 1527,17 E __6721 46 0 5951,26 5.878,26 544.005 1458,82 S 1573,51 E ______6_8_1.5 46 15 6016e41 5941:_4.1 .....$45...?_0_.Q~ '1507,15 5 1621.00 E 69_09 45 45 608.1,71 6008,71 S44,00H 1555,38 $ 1668,39 E 7003 45 0 6147,74 6074,74 $44,00E 1603,51S 1714.87 E 7097 45 0 6214,2'1 6141,21 S44.00E 1651.32 $ 1761.04 E 7192 43 45 6282,11 6209~11 $44,00E 1699.11S .1807,19 E 6276.29 $45.00E 7378 43 15 6416,75 6343,75 S45,00E 1790,25 S 1897,53 E 7472 43 0 .6485,36 6412,36 545,005 1835,68 S 1942,97 'L.-~.566 43 0 6554.11 6481.11 S45,00E 1881,01 S 1988.30 1736.20 S 48 4 17 E 0,773 1387,69 1455,15 1522,18 1590,50 1659,38 1729,14 1804,78 S 47 55 0 5 1873.78 S 47 45 13 E 1942,02 S 47 35 10 E 2010,27 S 47 25 49 E .... 1-7 ....... 4'--"E ' 2145,72 S 47 9 57 E 0,532 1797,87 0,767 1867.06 0,000 1935,5'3 0.000 2004.00 0,000 2072.47 0'980 2139,78 2213,40 S 47 5 3 E 2280,95 S 47 0 27 E 2347,77 $ 46 55 19 E 0,616 2207.51 0,762 2275.10 0.798 23~1,99 __ 2414.15 S 46 50 29 E 0,000 2408,45 2480,51 S 46 45 55 E 1,316 2474,87 __2544 ,_7....7__5__~+_6._ ~+ 2__ 29__E Q.3~4 __ 2.539.,_16. __2608,76 S 46__39 .... 58__5 0_...538 ............ 2603,13 __2_6_7_2._~_9_9__$_46_3_7_3.4_E 0...266 .......... 2667.3.5 2737.07 5 46 35 17 E 0,000 2731.4,1 · ALL CALCULATIONS PERFORMED BY I B M ELECTRONIC COMPUTER TR _ME.._A_S. ,._DR__ I_F__T. VE R_..T_! CAL DEPTH ANGLE DEPTH SEA DIRE¢ D M DEG, TOTAL COORDINATES DO.G_LEG ....... C.._L._O _,5_..U__R E .,5 .......... ,SEVER. i TY ...... ,SECTION D 1,5 T AN. CE ........... ANGLE ...... D.E.G/. 100 E_I'. ....D ! STANCE D ~ S ';'.. --7660 42 45 6622.99 6549-;-~-9 ~-4-5~-00E 1926.24 S 2033.52 "'--' 7753 42 0 6691.70 6618.70 S-4-5-,-00E i-9-7-0,56 S 2077.85 7847 41 15 6761,96 6688.96 S44.00E 2015,09 '5 2121,61 7-9-42 40 45 6833.66 6760,66----S-4-4--~-0'0E---2'0'5-9-~-9-~--S 2164,90 8-0-3-6--3-9--4-5 6-9'(J-5-~'-~-0 '6-8-~-~=;%-0 ,5~4-,--0-0E 2-103,62 S 2207.09 81-3'0 39 0 6978.06 6-9'~)-~-e 06 S43.OOE 21'4' ~-;-8-;?--$ 2248.14 8223 38 15 7050,72 6977e72 $42,00E 2189.67 S 2287.36 8-3'16 37 15 7124.25 70'5-1~-2-5----~-f-~-0-0-5 22-2-2~-3-1 S 2325,09 ....... 8410 36 0 7199,69 7126,69 S41,00E 2274.64 S 2361,88 ?. ...... . ......... .. 8504 35 0 7276,22 7203,22 '540,00E 2316,14 $ 2397,33 8-5-9'9--3-3--4-5~9-3-5'4-,--6-3---7-2-8-1-,-6-3 ...... $-~-O-;'b-O-E ..... 2-3-5-7-:-2-3 ..... $ ..... 2-43~, 8O 8693 33 30 7432.90 7359.90 S40.OOE 2397.10 S 2465,26 'E 8787 33 30 7511.28 7438.28 S40.OOg 2436.85 S 2498.61 E 8881 33 45 7589,55 7516.55 S40,OOE 2476.72 S 2532.07 E 89-T4--3-3--4-5 76661~-'g8 -'7-593,88---,5-4-i";-b-O'E 2516.01 .5 2565.63 E-- 9068 33 45 7745,04 7672.04 S41.OOE 2555.43 S 2599.89 E 9162 33 15 7823,42 7750,42 S40.OOE 2594,88 S 2683.58 ~ 9256 33 0 7902,15 7829,15 S39.00E 2634.51S 2666.26 9349 33 0 79~0Vf~---79-0'7~4 S39~0~ 2'6'7~-;'88 S 2698,1'3 --9443 33' 0 8058Y§'~----7'9-8-~;-98 S39.00E 2'~'i':3'i~-S 2730.55 9537 33 15 8137.70 8064.70 $39.005 2753.58 S 2762.68 --9632 32 15 8217',60 814~,60 S37,005 27-9~,08 S 2794.32 9-7'2'6 32 0 8297.21 8224.21 S36,00E 2834-26 $ 2824.05 18o1.-~i s 46 33 7 E-- __2863,66 ,5 46 31 4 E _0_:.8.06 __ ~_ _9 2..6... .0 6_.s__46_'_2.~_2__9__ S .......... Q, 9_22_ _ 2988,33 S 46 25 24 E --30-49.'-01 S 46 22--3'0--E --3-1~-6-'g'-5-7 S 46 19 11 E-- 3166,50 $ 46 14 59 E 3223,24 S 46 9 58 E 3279,0g S 46 4 40 E 3333,42 S 45 59 12 E 3'386.77 S 45 53 31 E 3438,55 S 45 48 11 E 3490.17 S 45 43 1 E -- B5'4 i-.97'--~--~-5--37---5-9 3' 5' 9 3- ;-4-3--~--4- 5--3' 3 33 E 3645.fi9 $ 45 29 38 5 3697.18 S 45 25 26 E 3798.62 S 45 15 31 E 3849,52 S 45 10 32 E 285.7,96_ 2920,38 .... ~,526_ ........ 2982.69 1.064 3043.42 _. 0.._9~ 2__ ......... 3103.04 __0,906_ ......... 3161 1.145 3218.01 __1,330 ........ 3274.06 1,120 3328,60 1,316 . . 0.266 . _ 0.000 0,266 0.597 0,000 0,621 0.413 0,000 0.000 . - 0.266 _ . 1,211 3382.16 3434,15 3485,96 3537.95 3589,57 -- 3611,77 3693.60 3744,88 3795,~1' 3846.49' - 3897.74' 39~8,94 3900.59 S 45 5 40 E 3998.61 3951,59 S 45 0 8 E 4001,04 S 44 53 47 E 0,400 9-8'i'9 3i i5 8~-7'6,4o 8303,40 $34,00E 2"8-7-4-,-20 S 2852,02 E 4049,-08 5 44 46--'-4-0--E--0,9-93 4o46.9i " 9'9'13 "'3'1'- 15 .... 8-4-'5' 6' -;- 7 6 .... 8'3-8'3-;-7'6 .... $3-'2--;-0'0-E----29'1-5"; 1-0 .... $---~-8-TS-;-5-7--E 4'b'-9-6'-,'~3---5'--'44-'38 "1-9' 'E ........... 1, ~04 ............ 4094.95 --i-00-0-6 30 45 8536.47 8463.47 S30,OOE 2956.15 S 2903.24 E 4143.39 S 4/+ 28 57 E 0,778 4141.82 ---10099 31 15 8616,19 8543.19 $31,00E 2997.42 $ 2927,55 E 4189,8-8--S 44 1'9--2-~/--E------0:.611 4188.60 :; 10193 31 15 8696.55 86-2-3-~-55 S29.00E '3039.65 S 2951,93 E 4237,15 S 44 9 40 E--l.104-- 4236,13 10287 31-15 .8-~7-7-6-.-9-i 870-3-~-9-i S2"9-~-~-0E 3-0'8-2-~-3'0$ 2975,58 E . /+28/+.23 $ /+3 59 26 E 0.00'0 ............. 4283./+6 RECORD OF SURVEY ALL CALCULATIONS--PER'FoRMED BY ]: @ M ELECTRON]:C CoNpU-TER TRUE MEAS. DRIFT VERTICAL `SUB DRIFT --D'EPT H-,~-N G-L-E-- DEPTH--$E~,- ....... D-i-R-E'C D M DEG, TOTAL COORDINATES C L 0 `5 U R E `5 D M D_OG.._LE.G SEVERITY SECTION DEG/3-OOFT DZSTANCE -. -:' '"~'-_t0382_3~1__3.0_j. 8_8 5.._8_,_0 2_,..8_7. 8_ 5_. _0 2 .... $3_0,_0_0E 31Z5,35 S 2999,93 E ._._1.0_4_7. 6.__31_1_5__8_9.3_8_,..2_8 88..6._5_,_2.8___53_0,0.0E 33_67.73 5 3024.4.0 E .__..~__1_0_.57.0 31 30__9_Q_1_8__,_5_3 8.9_.4__.5_.,_5~. ...... ~53_0_. 00E___3.2]._0.._,__.1.2__5_ .... 304.8.87 E L->i_106_6.~___3_1__4.._5.__9_0_9_8:_57 9025,5'7~$28.0_pE ..... 3.25.3__,_23 5 3072.77 E ~__10758 31 15 9178.72 9105,72 ,S29eOOE 3296,39 S 3096,20 E __1_ 0.88 _l_ 3.!__1..5___._e Z. 8. 3._._8__8____ _92.. 1_o_._r~_8___S ~_?.:_.0. 0 E _109.5_0_3 :t__!.5 9_3_4.2_... _8 ~. .... _92(~_9~....8..~___52.9_o. 00E .... 11010 3352.Z0 5 3127.14. E 33_83,50 _.5____3_1__4._~+_,_4..9 E' _~_3_~.9_,.6_8_$_43.4.0 26 E__0.2.66 _4.379.28 __~427.24.__.$ 43...31 27 ~4.Z~.9.7 ..... 5 43_21 57 E 4584.35 S 43__ O..~fl___E ........ 0..000 ......... ~6.19,08_.S.~2 54 ll_.E ....... 0_,.000 ........ 4619,08 31 15 9394,16 9321,16 $29,00E 3_4:..._!0,7_3 S 3159,58 E 464.9:.3.Q...S_~.2.__4._.8__3_9 E 0.000 30_ . 3 I N3'ERP_OLA.T_ED_.]'RUE V_E.R_T_I_¢AL__DEP_TH$._i__CO_ORD_I_NA_TES__A~ND_CLO. S.U.RE&_F_OR_G [ VEN-.-DEP_T.H& ....... CODE NAME TRUE -. MEASURED VERTI'CAL --TOTAL COORDINATES C L. O ~, U Ri..E_ _,,SUB ..... DEPTH' DEPTH DI6TANCE 6~G.LE_. '" _ . D M 5 ,SEA TOP ,SAD BOTTOM 5AD __10235 8732./+6 __39_58.71 $ 2962.50 E /+258.3.8 1089~!. 929/+,99 3358~09 ,5 .3-'130~/+3. E /+5c)0~89 59 2/+ E 9 MEASUR__E_D__DEPTH AND OTHER DATA .F..O._R_..EVERY EVEN . ._1_0..0_ FEET OF S_U_Bj_E_.A D_EP_T__i~I.,__ +. TRUE MEASUR ED VER T-~:-C-A-I.--~'OB M'D-T VD DEP-~'H DEPTH 273 273, 200 0 37-3 3~.--300 ..... o 473 47"3, 600 ......... 0 573 573-~--- '500 673 600 0 7!3 873 973 1073 1173 . -- . 1273 ...... 1373 1473 1573 16-7b 1773 673. 773, 700 0 873. 800 0 973, 900 0 1073, 1000 0 1173. 1100 0 1273. 1200 0 1373 . 1300 0 1473. 1400 0 ~.-57 3.--15oo o 1673, 1600 0 1773, 1700 0 1973 2073 217-3 ,--,, 2_2.'7-3 2373 2473 2573 2673 1873, 1800 0 1973. 1900 0 2073. 2000 0 2173. 2100 0 2'2'73~ 2~0-0 0 2373, 2'3'0'0 0 2473, 2400 0 2573, 2500--0 f~-;----Z%'o o o 2773 2873 2-974 2773. 2700 0 2873-~---'--2-~ 00 0 29 73. 2V~O --o 3'075 3-S7'6 3'27 8 3C7-3. 3ooo--1. 317-3, 3100 3 3273, 320.0 5 3382 3-4~-6 3'5'9-2 3373, 3300 8 3ZF73, 3400 13 3573, 3 ~-0.0 19 VERTICAL CORRECTION · O0_W O0 W ._ O0 W O0 W O0 W ._ O0 W .-_ O0 W O0 W O0 W --o o_.,..0;0--_]i ........... o_; 0 0,00 S O. 0 0,00 $ O, 0 0,00 S O, " 0 0.00 5 O, 0 0.00 S O, 0 0 0 0,00 S - 0.00 S O. 0,00 $ O. 0 0,00 S 0.00 W 0 0.00 S 0.00 W .--, __0._. 0,00 S O,O0..W o ~,9o s o..o.o._w 0 O_~O_O_S__ O.,.O0_._W 0 0.00 S 0,00 W 0 0.00-'-$ O.O0'---'W 0 0.00 $ 0.00 W "0 0,00 S 0.00 W 0 0,00 S 0.00 W o d;-do--s o .'o'o- w 0 0,0-~-'$ 0'.00 .... W 0 0,00 $ 0.00 W 0 0.00 $ 0o00 W 0 0,00 S O,O-O'-W _. 0 0,00 S 0.00 W 0 0.00 $ 0,00 W 0 1.30 S 0.87 E 0 6.23 S 4.20 E O~ 1~.68 S 9*56 E 1 25.04 S 18.69 E 2 34.99 S 3 ~;'O~-'E 2 46,11 S 50,66 E 3 58.90 S 72,77 E 5 7~,98 S 98e7~ E .... 128,35 E .MEASURED DEPTH AND OTHER D-A~--F-O'R EVERY EVEN MEA,SURED 'DEPTH 'F~O-E: vE'i~YZ'CXU%'OB ....... ~D-;'Yvb DEPTH SEA DIFFERENCE 100 FEET OF SUB SEA VE R-Yz-C'A'c co R R-E-¢'~'-'i-ON TOTAL D EP_T_H, ................................. · ....... ,, COORDJNATE-$ ........... --37bb 3809 39'2-1 -- ~-o-3-6 ~-f54 ...... 4402 3673, 3600 26 3773, 3700 36 3-'8 73. 3~-~0 ........ 4 8 3973. 3900 6'2 7 10 12 14 4073. 4000-- 8'0 18 4173, 4 foo'- fO3 2-3 4273e 4200 129 26 ! !6_._4_0_5 i_~ 1_._55_.E 140.52+ $ 198.71 E __ i~__8_._%.7 s . _24o_: 2 8__E._ 200.12 S 286.34 E 236,19 $ 337,86.__E 2!7j_1.~__$ ...... 394,86._5 32_6_,63 `5__ 453,73_E 4652 4473. 4400 179 25 25 4779 4573. 49b-7 5'0-3-7 4773. 5'1 ?-i 48-7'3. 5307 4973. 3_7__~_,_6_~__s ........... 5o9.30 _ E ...... '. .......................... 426,90 5 565,09. E .................... . ............ _ ._ 5446 5073, 5-58'8 5-f7-3, 5732 5273, 5876 450-0 205 26 _ - '4600 233 28 47b0 294-- 3'i 4800 298 34 4900 334 36 .-. SO00 373 39 ............... 5200 458 43 6'o2-~ 61-6-9 63-f5 479,3_8__S 6.22.,..1_4._5 5_37__,_4_3_ $ ........... 680, 592.48 ,5 740.98 E 654.92 S 804,07__E 720e37 $ 869e52 E ........................ 789e22 $ 936e86 861.81 S 1006.96 E 9'35.92 S 1078,53 E 1010.57 $ 1150,62 E i-0-8-8-.-0-6--$ 12 Z 3.66 -'E 1166,46 S 1297.82 E i243.30 S-- 1371-,64-'E 1321,03 S 1444,21 ffg'8.8 i $ 'i-~-i%-,'7 4 6607 6752 6896 7039 .--. 7179 7318 5373 · 530'0 ......5-0'2 ........................ ~ 4 5473. 5400 548 46 557'3-;' 5-~'t-O - ~-9-6 4'8 5673 · 5600 642 --4-6-- 5-8-73 .--5 8'0'0 7-3"~ --46 597-3, 5-90-0 779 4-5 607'3, 6000 823 · 44, 1474,83 S 1589,05 E 1548~69 S 1~61e91 E 7592 __ 7728 7862 f~h-f,%-7--S--fT'32.4 i 1692~63 S--1800','93" -E i'7%o. 97 ,5 1827,48 S--fg'3'4-e-'7-7--E 189-3-~%-5--5 2'00o ',--? ............. 1958,61 5 2065,90 ......... 2,022,05 ,5 212,8,32 6i7-3.----6i~0 '866 43 6273~ 6200 906 40 6~-31 6'~00-- 945-- 39 6'~. 6~00 982 37 6573. 65-0'0 1019. 37 6673. 6600 1055 36 ..... 6773. 6700 1089 34 2084.07 2188e22 E · 2245.13 E 2298.89 E 7994 6873, 6800 1121 32 ._ 8123 6973e 6900 1150 29 8251 7073, 7000 '1178 28 2143.65 2202,54 MEA$ORED DEPTH AND OTHER DATA FOP_,_E_.V_E_R_Y__E_V_E_~__!QO FEET' OF .,5__UB SEA_DEP_T_H.__ · DE~TH TRUE VERTICAL SUB ND-TVD DEPTH $EA DIFFERENCE VERT ! CAL CORRECT ! ON TOTAL, CO_OB_D_I_N_A_T..E.,5 8377 8500 8621 87-~ 1 8861 _ 8981 .... 9101 9221 .. . 93/+O ..... 94.6O ..... 9579 9697 ..... 9815 ..... 9932 1.0048 ..... 10165 10282 10399 10517 1063/+ 10751 10868 10985 7173. 7100 12_07 7273. 7200 1227 7373. 7300 1248 7~73'~ .... ~4~0 .....i~-68 7573. 7500 1288 7673. 7600 1308 7773, 7~Op_.. %~28 7~ 73. 7 8.90 .... 7973. 7900 1367 8073, 8000 1386 8173, 8100 1/+06 8273. 8200 1424 8373, 8300 1442 8473. 8400 1/+59 8573. 8500 1475 8673. 8600 1492 ~773.--~7~0--1509 8873. 8800 1526 - .. 8973, 8900 1543 9'o-7-3-, ~:'9-0~o--156o -- 9-i'73 · '~)-~.-0-0. 1578 92-7'3; ....-9~-00 . 1595 2_6 23 21 -- 20 2O 17 16 17 _._ 17 17 17 17 z.~9.~, s .-~s~9-~'-85--Z~ 2314,38 S 2395,85 E 2366.59 $ 2439,65 E Z~-f~-;-4-O-S .... 2;¢82'".'2 ~-~ ............ . ............. 2468.22 S 252~.93 E .............................. 25~8.95 ~ 2568.~8 E 2569.27 S 2611.84 E 2619.72 S 265~..2Q_E 2670.07 $ 2695.05 E 2720.74 S 2736,08 E 2771.52 S 2776.98 E 2821.8/+ S 2814.97 E 2872.~8 $ 2850.86 E 2923,/+6 S 2883.76 297~.77 S 2914.09 3026e99 S 29/+4,82 .... 3133,04 $ ..... 3186,02 $ 3034.96 ........................ 3239.31 $ 3065.27 ................. 3293.21 ~ 309/+./+4 .................. 3346.30 $ 3123.87 3399.38 $ 3153.29 .............. 2974,32 E 300/+.37 E ~'E-R'PUI4-A-TED VALUES FOR EV~-I~-'I'O'(~)-O--F-E'ET OF MI~A-$'ORED DEPTH. ' TRUE · ~ MEA-SUR ED D E.-P'T-H D-E-P TH SUB $ E'A ........... -T-O'¥'A'L. C ~(~'I~-~-~"NA'T E $ 1000 2-o-00 3-0'00 /+000 ~0~oo . 6-0'0'0 7-0'00' 8'-0'00 £~-0-0. 92'7. 2-000. -~-9'27'. 3-9-~2. 3869. -- 5-4'5-8-; 5 6'174-$. 60-72 0.00 S 0.00 W / 0.00 S 0.00 W / 17.3'8 s__i'i~'5 189.80 $ 271.61 E .. 575.82 $ 723.73 E 10~6.Z7-~ ~'i-21Z.67 E 6877. 9000 ................... 76'8'~-. ...... ~0'0 0'0 -- 8531, 1-{ o-0o --9 6804. 7 6'3:5'. -- 8-~+- 5-8 '. 400. 1200 2400 .......................... VERTICA'L SECTION ......................................... i SCALE I"' = I000' ATLANTIC RICHFIELD COMPANY' ' ............. DRILL SITE !- II ...................................... . . . RADIUS OF CURVATURE ._. MAGNETIC MULTI- SHOT ........ ~ . , , . .-. . . . ; .... : 3200 -i, · · , ............ . . , .. ~.. '.' .'~--.:'..-..'.:..'.~""~" ~....~_~ i '.. 3600 ............. ' '":' ' ' ' ' " ~ ," ' : i ........................................... .... ' : ' ' J .... i .......... ' ...... '; '" : ........... '"' ' ' "'-": ....... ...... ~ ..........e .......... · ............................................ ' ................ ~"' ................................. i ................................. i ................... ." .............................. : : '': ...... ""':"" ' ' "' : ':"i ......... ............. '.'i.'.. ~'....~.....'.~i'.~'.~.':...iALL' DE THS 'S ~ ' "} ....... : .... -TIT-',"": ......... I'"-i ............ ' ......... · i'"', ....... ': [ ...... '~ .......... i-:"" :-"-: .... i' : .' :" ilm ' . [ J.ARE TVD. · ........ -i'" 52~ ....... ~ :..-'...: .... : . ,. ': ~' i ..................., :... ! . .............. : ....................; ................................................... . ....... . ........ -~.--'1 ................. , .......... ......... ~ .... " ........ ..' ". ;. : ~ ~ '. ............. . ........................ . ..... : ..... -...:_- ......... , ~ ' . i ' ' ' ":'"'. ....... :" ':" ' ' ' q ~ :' ', i ............. L ~ ....... i ; '"': ..........·": ..................................... t ................. , ' '~ .......... : ....... ~ ...... '; ........ :,"':"i--'. ......... i'-'7'; ....= .... .' -, - ' · i ..... ;"*';' 't" : , ' ~ t I ~ I . j . ~...~..~...: .... ! ........................ ......... ' ......... ,' ........................ ~ ...... :' ""j ............ , ........ j :- "~ .... , ............................ ......... ,~ .................... ................. ~ ................. ~ ....... ~ .......... ~"",. ....... ..'"."~.' ".ii'." F"7'"-~~, ~.' .................. ...... i-'''~'-'.-~.._, ..... ............ ! ..... ~ ......... : ............. "" '," 'i : ~ .... j. , -"i I. , . ' · "' ; . · '"': ' '" ......... ;" ' , i.. , · .: ......... ;' : , : ' ! .' ! : ' : J,. _ ' '--, '..; ........ ' . : ........... ' ........ : ...... : . . .,-'. .... i. _:.. ' .:..J.i..' .... i ! ,.' .' ....... :_.',..! ....... ...... '.. , -..: ....... : ..... : ........... i.,..., ..... ..: .............. '-"\' ! ....... '"'i · : _ .:.I_~_'. ._ I , : ' ' '',' " '. : ' ' 'k ' ~ ' ! ; -,' ' "'1'~-x ..... . ' .... ~ .................. t ...... ~ ...................... ...., · ' -_-. '~ ................. = .......· .......... :.- ~ ................ ..., ................................. . ................ : ....... : .... ..~'...:_.: .... . ~ .. . j ~ [ . , . . ~. . . ,-. ............. ~ ..... ~ ............ ::.:-:<: ....... : ........................................... , ....................... ~._.~ ......... ~ ................................ : ' ....... ! ........... ~-': .... . ....... i'": .......... : "' '~"'.7~:'" : ~ · ' i", ................. "I .... ' ' ' . ' ' ...... . .......... ' ......... , ........... : ............... '~"1 ......... ,\ .... : .... ; "' ....... ~ .......... J .......... ..... : ...... : ....... ,'-: ........... ~' -: ". ............. i .... : ........ } ......... '. ............ i ..... !' ................................................................ ' ................. : .... ' ...... : .............. : ..... ' " ................. ~ ...... : ..... : ....... :'"! ............ : ........ ~' ...... :"' ..... "' ~"' ! : ....... i '"','' ': '' ...... ; ....... ......... ~ .............. , ......._..= ,; ....................... ',. ....... ,: ..... : .i ' I ...... ~ .: .. .~_I .. : ' i ..,. ........ \ , : ' ' · · ! . : . ' ' : i ......... ~ ........... :'" ~''''''''~ '":'"..L'-'i' ..!.".i..:._. :~ ~ ..... : ............... i'"':-":'-'. ............................................. ~" J .... '" .: ' '~ .............. '; : ....... ~ ,' .............. '. '?' iL''-:,,':L,\'~'¥-\i ..... : '"~' ~' ".i..= "'~]i.''':'''''.= L'-!."..~.',.: ":. ;.'[.', '..' ';:. 'L i~- ~ : . · '" ' i'i ......... : ...... i' .......... :. '.'-"., '-."' : °,"'""-'~ ':'": ...... ."-':"/fi~' i'i .... ' i' '~ ...... i.. "'. i'.~.... '.'.'U..' . Jl ' ' 'i , ' , ".~ ...... ~---: --- .~.'~ .... ~'' \ : .... . ~. .. , . . ~ ..... '~-,'----'v._.. _, ... , ,. ,. ' ' , -'" ' .... 1 ........... . ............. ~' ........................................ ~ ~ ---.-- ...... i' ' I . . .... ' .., - .. !"~oo~ .' ........... ' ..... t ....... , .......... : ......... . . · I . ; ' : . ~ , , . i, ..-7-- \ .. ' t ..... !. '...... i : . ! I .' ~ ! ~ ' ' i .... ~ ~-wn: ~ ~c~,~' i ' : J-:""'""'"":'- .: .. . .: J ..... .. . . ! ..... ~ ' , ' ' : ," ''i ........ ;...v~ ,7 "~'"'""", 'I .... . ........ " ............. : ...... .~ ~ ~ ., '~ ........ i ................ T" TMD'= !I',010 .......... :'"~ .... TTF-'f ..... '~ .... ; ' ~ J r ' ' ' ~ ' : ' ~,i" '' ' , . ' ~ ' ' , ' ; '"' .... , ........... · ' . , :..: .; ....... : ........... ... . I . . , J - ~ ' ~ . , ' ' ~ . . ~ .... ' . .' '.. !'~. .~ ....... i. · . HORIZONTAL VIEW ; SCAEE i"= 500' ' , ATLANTIC RICH'FIELD COMPANY ~ i ~ ........................ DRILL_SITE I-',11 ............ ~ ................. i '. ..... - RADIUS OF CURVATURE .. ! .... ~ -" MAGNETIC MULTI- SHOT" :' .... ,. .. · . . : 3200 .............. ~ ....................... : ................................................................. : .................... *~ ............. ' ......................... I , ' ; ' ~ ! ~ . 3600 ' ' i : · . '~ ' '.; · ' ~ ' i . ' 4000 ' : i ' ~ ; ' : ' ~'~ . i' '' '.', ; ' ~ - '. ~ .. r , . ; · 800 I :- ' ............ '~ .......................... : ................................... ' ................ .... ~ ~ ~ ;i . ' ~ . ' . i ". ". ALL. DEPTHS S'HOWN. .~.'....~'...!__' .... ; ..... ' ' ...... Lo": ...... ""~'-'i ..... ~"~":~'.-"!-~:!' ~, ..~vo · . ..~.~ .... ,64o~ : '7200' " ..... :" ,600 . 8800 ...... ': ..... TVD' 9, :594' ..... ' ............. ~ ..... i ......... ~ .... TMD =1,1.,0 I0'. 4' LOCATED IN THE APPENDIX WFL IPR LOG CALIPER SURVEY 'UI ,VOLAN CURVE DATA [21 STRATIGRAPHI,C HIGH RESOLUTION DIPMETER '.UI OTHER: . AtlanticRichfieldCompany North Amer,;'an Producing Division North Alas( .)istrict Post Office Box 360 Anchorage, Alnska 99510 Telephone 907 277 5537 November 2, 1977 Mr. Hoyl e Hami 1 ton State of Alaska Department of Natural Resources. Division of Oil and Gas 3001 Porcupine Drive Anchorage, Alaska 99501 Subject' DS 9-17 (xx-1-10-15) Permit No. 77-38 DS 2-11 (xx-1-10-14) Permit No. 77-6'3 ."~'~ DS I 11 xx 8-10-15 t"'~.-~7-57 ) C(.',; FII .... Dear Sir' Enclosed please find the Monthly Report .of Drilling Operations for the above mentioned w, ells. . Very. truly yours, Frank M. Brown District Drilling Engineer /am Enclosures · '1 ~Porm ~To. ~q~'V. ~- 1-70 STATE OF ALASKA OIL AND GAS CONSERVATION COMMITi'EE SUBMIT IN I~.J'PLICAT~- MONTHLY REPORT OF DRILLING AND WORKOVER OPERATIONS 1, WKLL W~-LL 2. NAME OF OP~iRATOR Atlantic Richfield Compan,y P.O. Box 360, Anchorage, Alaska 99510 '4. LOCATION OF w~ 898'S & 777'E of NW cr Sec. 8, TION, R15E, UM ~API NU~i~,ItlCAL CODE 50-029-20268 LEASE DESIGI~ATION AND SEI~IAL N'O. ADL 28329 IF II~DIA)~, ALOi ~//;15 OR TRIBE B.L~.'IT F.a.l~i OR LEASE NAME Prudhoe Bay Unit 9 w.I~.;L,L .~0 DS 1-11 (xx-8-10-15) 10. F~ A.ND POOL. OR WILDCAT Prudhoe Bay Field-Prudhoe Oil 11. SEC., T., 1~., 1~i.. (BOTTOM HOLE oamm-zv~ Sec. 8, TION, R15E, UM Il, PER.MIT NO. 77-57 "13. REPORT TOTAL DEPTH AT F.2qD OF MONTH, CHA~IGES IN HOLE SIZE. CASING AND CEMENTING JOBS INCLUDING D~ SET A~ VOL~ USED, P~O~TIONS, ~TS ~ ~SULTS FI~ING JO~. J~K ~ HO~ ~D SIDE-~CK~ HO~ ~D ~Y O~R SIGNIFIC~T ~G~ ~ HO~ ~ITIONS. Report of Operation for the Month of October, 1977. Pool Spudded @ 1800 hrs 10/9/77. Drld 17-1/2" hole to 2750'. RU & ran 13-3/8" csg w/shoe @ 2713'. Cmtd w/5600 sx PF II cmt, slurry wt 14.8 ppg. Did top job w/70 sx PF II cmt. NU BOP. Drld FC, cmt & 10' new form. Tstd form to 12.5 ppg equiv. Drld 12-1/4" hole to 10,950'. Dropped multishot. Ran DIL/SP, BHCS/GR, FDC/CNL. Drld to 11,010'. RU & ran 9-5/8" csg w/shoe @ 1.0,988', FC @ 10,945', lower FO @ 2467', upper FO @ 2337'. Cmtd w/800 sx Class G cmt w/1% CFR-2, 0.15% HR-7, slurry Wt 15.8 ppg. Installed & tstd pkoff OK. Did Arctic Pack job. ' Ran junk bskt. Circ out mud w/wtr, circ out wtr w/10.6 CaC1.. Ran GR/N/CCL & gauge ring junk bskt. As .of October 31, 1977, RU to run 5-1/2". comp~ assy. 14. I hereby certJ~that th& forego~ts t4'ue and sza~z,//~~ ~~~ :~ District Drlg Engineer ~.~ 11/2/77 NOTE--Report on this fora is requi~d ~r ee~ calendar ~th~ regerdMss of ihe status of operations, and must ~ filed in dupli~te with the oil end gas eoneervatbn commiflee by the 15~ of the suec~ding mn~, ~le~ otherwise directed. ,, O.~K. Gilbreth, C~.~v ~ October 19 , 1977 Acting O~ef Petrolemn Enginee~ ~, Oc~ 10,..1977..- I de~ my ~ at 4:00 PM for a 4:30 PM s~ ~ 5:30 PM departure via Wien flight %19 for De~se, arriving at 8.'05 P~L I arrived at DS 9-17 at 9:30 PM. Wednesday, ~ 12, 1977 - Test~ BOPE (~ IlS' 9-I7 during the early ~sOay,. Oetuber 13, 19'77 - I arri~ at drill site .1-11 at 1:00 ~M and well c=ganized, reserve pit ~LI built, rig /n good ~air, but we// Drilling fuxewan for ~xco was Shorty Allen and '~oo1~ for Rowan Rig %35 'was D. C. Murphy. Shoe c~ 13 3/8'" was at 2713' and testing ~ util~ clear wa~er with mud pump to 3000 psi ~ F, ocm~ ~ sta~e pump to 5000 .psi.. .Tests .began 'at 5:00 PM with ~ Pit:~ rams, inside valve c~ the k{3=l ~,. ~~~~~2500 ~. ~~~~~l~e ~ it ~ ~st ~ ~s" '~ ~~ a ~~ ~_~~ pl~ rig fl~. '~ whir was 2'800 spig. N2 ~ bott]m~ tested. 1750 psdjg, 1400, 1950, 1950, .1950 'and 1950 psig ~est/ng left to right facing the aecumula~. Both ball .~,:t dart ~e valves ~ ~'plac~ before the .~. TWelve valves an~ tw~nty-~ flanges in the choke manifold %est~d to 5000 spig. ~, the Hal_]~.~ plug valve just. upstxeam of the manual fully closed. lower pipe rams, blind rams and kelly cock then tested to 5000 psig. the check val~e in the kill line ~ not test. DS 1-11 -2- October 19, 1977 a copy atta~ to tb~ z~port. As i~cated c~ the .report, cpera~ %~s given to 10-19-77 to repa~ defective plug valve and check valve, t~st, ~, because the test plug was not in place. D. C. Murphy, toolpusher, advised it would be tested at the first I departed Deadh~rse via Wien flight %24 at 10:10 ~4, arriving in Anch~ ~ Fairbanks at 12:35 PM and at my ~ at 1:05 PM. wi~ suoc~ssful ~ tests c~ Aroo's DS 1-11. The valves will he zepaired or replaced and trusted by 10-19-77 and our office advised of Drly. Permit No.~_ Operator Satisfactory Yes No Item ( ) Location,General ( ) (')' 1. Well Sign (.) () (,.) () (, .,,) () 'Ala ~ Oil and Gas Conservation Commit .e Field Inspection Report Well/Platfm Sec T ., .R, ,' .... Rep,resented by. Name & Number ' Type Ins'pection SatiSfactory Type Inspection Yes No Item ( ) BOPE Tests , M ( )' ( ) 15. "Casing set @ 2. General Housekeeping (',.) ( ) 16. TesL fluid-(~,)wtr.---~ imud ( ) oil ~. Reserve Pit-( )open( )filled ( ) ( ) 17. Master Hyd. Control Sys.- 4. Rig (',).' ( ) 18. N2 btls. __, ', ~,.,.~'psig () () () () () () () () ( ) Safety Valve Tests 5. Surface-No. Wells 6. Subsurface-No. Wells ( ) Well Test Data 7. Well Nos. , , 8. Hrs. obser ,~, . ( ) ( ) 9. BS&W ~., , , ' ( ) ( ) 10. Gr. Bbls. ( ) Final Abandonment (,,.). ( ) 19. Remote Controls .... (,.)" ( ) 20. Drilling spool- "outlets (,,..)' ( ) 21. Kill Line-(') Check valve (,.,).., ( ) 22. Choke Flowline ( ) HCR valve. (,,,). ( ) 23. Choke Manifold No. valvs,,,' flos (...,) ( ) 24. Chokes-(:.)Remote( )Pos.(~djl ('.,) ..... ( ) 25. Test Plug-(.,,)Welihd( )csg( )none (,,~ .... ( ) 26. Annular Preventer,~si.~ (',.,)'.'" ( )27 Blind Rams,.',.',..,,:,,psi.~ ( ) (). 11. P&A Marker (~.,) .... ( ) 28. Pipe Rams ,',.:,, _psiq ~,'", ,( ) ( ) 12. Water well-( )capped( )plugged (~:.,,)'," ( ) 29 Kelly & KeTi~¥-cock.v,.. psig '( ) ( ) 13. Clean-up (i,)(? ( ) .... 30. Lower Kelly v alve:,","'!~,.,',,,';~psi? ( ) ( ) 14. Pad leveled ( ) 31 Safety Floor valves--L-(- ~BV (~:~:)Dart 'Total inspection observation time .,;r, ii'" hrs/da.ys. Total number leaks and/or equip, failures Remarks '".. ..:.....,,..,...,.,,.,.... ...,...,,...,,. ,~.. ::.~. ..,, ..,,,.;..,:,.::...,.. .,.~.. .. .... ..., . ..... .: ...... ...... ..... . .~.,. ... :.. ,..,..<:.:, .. :.,,,~...:,. .. . .......... _.~.., .... , "' '" ' "' "" ' '"' '". '""'~'"'",- '"'q"' "' ' "L:'~."'," '~'?.~" , ,~.':""' .' ',~":". ," .", ',' .'"' ' "'." ,.r:' !..:' '.." ~ ;'~L':;,', .~' ,,'..' ". ',,i.:,~:,,~.'.!,,,' ,,,,., .,..,,!!' _ " .'. . ,,. ~ ' ': '"' '.",'" '.i':'.r...~,.' .... ~"',~;".'..'.~,.. '.,'-~! '. '.,:'~!" .,.. '.,~,~..., .~..' ~ '",~"!,,'~'..,...., ,'Y'"'."i '" .~,,.~",,.~],. :~',,.~;~.'., .'.'.;,'.i' .':':'i ,.:.i ',,'".' ?:'.!,.'~i i '. i:.' .... '.'.:~.~-',;' !,?:'"'"..,,,,-.'~. ....... . .... ,. ,:;...~.... ,.? ' ~ .... ."~ ' ' ~ ...... " '" "'"'"."' :" ," '...: ,.'.T" <,,:,"" ,,,L'.~__ r.',.~';'"'~;:i !?"..'~,'~'i'~ .,"""'~'.'. ".. .~:;:'.::..' ~,~'.,~' .;'.,'.." ,"~.i., ;.r ~.'~ i,:!'.~. .... ',,.'?~! '!! ~,." ............ ," :; ' ~ cc' ''~,,.., ... "',"'. ,, ,, ,,,.,,..,., Notify in days or when read,y Inspected by ~:"i'.,"i ,',, ,.,:,..,. ~,...,,,,.;,.:.,,. ,,,, · Date,.,.,,;.~,~: · __ _ . ,.. ~ _1! _, , Se~ 27· ].977 ~ Bay (a'd.t ~ 1-1]. (xx-8-10-15) Atlantic A.td, n!'ield ~¥ Pe-13~. 't Ilo, 77-57 nist:r~.t o,:i~ ~..~~ p. o. Bc= 360 ~ctlc~'ac~, ~J. aska 995:10 ~~ ~Ou 'may be ~ by the Hahi.'.~at C~orclt~a~or's office, ~t of Fish PO11utic~ of any ~ of the Sta~e is ~tted by AS 46, Chapter 03, ~t tO AS 38.40, Looal RL~e ~ Sta~e Leases, the ~ Depar~m~t of Lab~ is being notified of the t..ssL~_~e o~ this pemit to drill. To aid us in ~~!!ng field: w~rk, .~ ~ appreciate your not/lying tbis offh~e within 48 hours af~er"the well is ~. We woxId also Like to be notifie~ so that a 'rep~e~T~ativ~ of the Divis~ may be pre~ to witnes~ ~estJx~ of blowout ~~er equipment before ~urfaoe casir~ shoe is drilled. F. M. Brcm~ Bay Unit DS 1-11 27, 1977 In the e%~nt of ~ ~r abar~lo~t please gi~ this office adequate advanoe n~/ficatic~ so that ~ may ha~e a wit~ess present. O. K. C~lhreth, Jr. Department of Fish and Game, Fm~itat Section w/o encl. Di~i~ w/o. ~1. AtlanticRichfieldCompany North Ameri~;,,,-'.~ Producing Division North Alaska[ ~trict Post Office Box 360 Anchorage, Alaska 99510 Telephone 907 277 5637 September 19, 1977 Mr. Hoyl e Hamilton State of Alaska Department of Natural Resources Division of Oil and Gas 3001 Porcupine Drive Anchorage, Alaska 99501 Subject: D.S. D.S. D.S. 1-11 (xx-8-10-15) 1-12 (xx-9-10-15) 1-13 (xx-7-10-15) Dear Mr. Hamilton. Enclosed herewith is .our Application for Permits to Drill for the above mentioned wells along with a $100.00 filing fee, and the required survey plat. Very truly yours, Frank Brown District Drilling Engineer /kb Enclosures Fdrm 10-401 ' REV. 1-1-7! l i!~ ' SUBMIT IN TRI) F ~ : ~(O~er i~st,uc~ OIL AND GAS CONSERVATION COMMIT~EP 2 1 !077 PERMIT TO DRILL OR DEE~r,n of Oii ai'u+ Gas Canservati Ail;"ool" :~ DRILL [] DEEPEN 0 la. TYPE OF WORK b. TYPE OF WELL OIL GAS SINGLE MULTIPLE r--{ WELL C~ ' WELL ['~ OTIIER- ZONE [~ ZONE U 2. NAME OF OPERATOR Atlantic Richfield Company 3. ADDRESS OF OPERATOR P.O. Box 360; Anchorage, Alaska 99510 4. LOCATION OF WELL xt'u'f"'ee898'S & 777'E of NW cr Sec. 8, TION,.:.R15E, UM At pro~o~ed pred..zone (@8800'ss) 1280'N & 1630'W of SE cr Sec. 8, TION, R15E, UM 13. DISTANCE IN MILES AND DIRECTION FROM NEAREST TOWN OR POST OFFICE* Approximately 6 miles NE 6f Deadhorse API No. 50-029-20268 6. LEASE DESIGNATION AN[) SERIAL NO. ADL-.28329 7. II.: INDIAN, ALLOTTEE OR TRIBE NAME 8. UNIT FARM OR LEASE NAME Prudhoe Bay Unit 9. WELL NO. DS 1-11 (xx-8-10-I 5) .FIE~.,D AND i~OL OI~3¥1L~&T ruanoe uay ~ela P_~,j. dhne Oil Pool . ,_ 11. SEC. T., R., M., (BO3~]'OM HOLE OB.IEU.rIVE) Sec. 8, TION, R15E, UM 12. 14. BOND INFORMATION: ~E Statewi des,,et~a,d/or~o. Federal 15. DISTANCE FROM PROPOSED * LOCATION TO NEAREST PROPERTY OR LEASE LINE, Fr. · (Also to nearest d~ig. unit, if any) "1280' 18. DISTANCE FROM PROPOSED LOCATION TO NEAREST WELL DRILLING, COMPLETED, OR APPLIED FOR, FT. 2500'. 21. ELEVATIONS (Show whether DF, RT, CR, etc.). 39.7' Pad EleVation (Gravel) Insurance Co. #8011-38-40 ,~o.., $100.,000.. 16. No. OF ACRES IN LEASE · '. 2501 " 19. PROPOSED DEPTH : ' · . 9400 :.+TVD 17. NO, ACRES ASSIGNED TO THIS WELL ' ' ' .. 160 20. ROTARY OR cABLE TOOLS ·Rotary 22., APPROX. DATE WORK VdLL START 10-1-77 23 ..... , PRC POSED CASING AND CEMENTING PROGRAM SIZE'OF HOLE SIZE.OF CASING WEIGHT PER FOOT . GRADE S~ING DE~H Quantity of cement 32" '' '20" '" 94 lb. "H-40 144'+MD .. 300SX Permafrost Ii'tO'sUrface .... 17-1/2" 13-3/8" Y2 lb' MN-SU Z/OU'+--~D Circ to surface~approx 5500 sx. "12-1/C' 9,5/8" ''47 lb. 80 & 95111OUT+MU IbOU'~ Cm~ COlumn on ISt stage.(a 1000sx) plus 300'+ column on 2~d . . ..... stage (approx 300~x) · )re Atlantic Richfield Company proposes to dir. ectionaliy thi.s well to lllO0'+MD,_ 9400'+TVD.to_ produce the Sadlerochit zone. Logs will be run across selected intervals., A 13-5/8" ..'.5000 psi Hydril and 13-5/8" 5000 psi pipe and blind rams will be used on the 1'3'-3/8" casing .The .BOP equipment will be pressure tested each week and operationally tested .each trip. A string of. 5-1/2" 17# N-80 tubing, ·packer and necessary provisions 'for subsurface safety equipment will be run. The packer will be set above the Sadlerochit. A non-freezing liqui( .will he left in all. un·cemehted ahnuli' wi't'hin the permafrost int. erval. Selected intervals ' within the Sadlerochit interval will be '.perforated, and reported on subsequent report..· A 5000 psi WP wireline lubricator, tested to working pressure, .will be .utilized with all .' wi rel i ne ...work. Well wi'Il be.flowed to a surge tank. Al·l recovered liquids will be trucke( ' IN ABOVE SPACE DESCRIBE PROPOSED PROGRAM: ff prO'posal is to deepen give data on present productive, zone and proposed . ' new productive zOne. It' propo~l is to drill or deepen directionally, give pertinent data on subiur face locations and measured and tiue ( C 0 nt. Re vet s e S i d ( vertical depths. Give blowout preventer program. 24. I ~ereb.y ce~_~hat tl~e F.~oing is True and Correct SIGNED ' ~'~',~'~[ (d. ~/..~,~'-~' . (This'space .for State office use) · s^.,,,,L~ ~Dco,, cra,, ~,,~qu,,,~D ' I MUD LOG ElvEs R3 NO 1' OYES DIRECTIONAL SURVEY REQUIRED [] ~o. CONDITIONS OF APPROVAL, IF ANY: ' ' · . ~ NO OTHER REQUIRFMENTS: A.P.I. NUMERICAL CODE 50'029-202 68 PERMIT NO. APPOVED BY 77-57 APPROVAL DATE ' ' - ' /t~'ee Instruction On Reverse side s~pe~mber 27, 1977 DATE'' Septamber, 27, 1977 to the oily waste disposal facilities for disposal. The down hole safety valve will be installed and tested upon conclusion of job. INSTRUCTIONS General: A filing fee of $100.00 must accompany application for permit to drill or deepen. Checks shall be made out to State of Alaska Department of Revenue. This form is designed for submitting proposals to perform certain well operations, as indicated, on all typess of lands and leases for appropriate action by the State agency, pursuant to applicable State laws and regulations. Any necessary sPecial instructions concerning the use of this form either are shown below or may be obtained from the Division of Oil and Gas. ITEM 1: Use this form, with appropriate notations, if the proposal is to redrill to the same reservoir at a different subsurface location or redrill to a new reservoir. FI'EM 13: Attach hereto a neat, accurate plat or n~ap, drawn to scale, showing the site or proposed site for this location, distances from section, distances from section line, lease line, if any, and other information that is pertinent. Refer to Section 51,050 of Oil and Gas Regulations. ITEM 14: Enclose drilling bond on Form 10-402 with this application for permit to drill, or deepen, unless covered by other suitable bond. ITEM 15 and 18: If well is to be, or had been directionally drilled, use subsurface location of hole in any present or objective productive zone. I ¢"~' .,.:~,;' ':= :"":,~q~Y..d ,:" %,. '~*'"'"" :.~!i ' { ;~'" :" ,".,.:' .," rt. ~ ,,¢ ,.; .:.: 'r..,.:'.':~' '-. '. :~: , . :', ?: '."..""] .'"4~, , · ~'~'' · ' '~::'" ~:":'/ ..... '" .... : ': ~:,¢~ ' ' ¢, %.,,.... . t. orA~ ~.: OF A~ ...... ~K~..~ ANOT'~A~ TH~3 PLAT [~EPRESEN'FS AN .AS-~U:JLY ?,dRVE'/ MADE BY'ME OR UN~ER MY SOPER '-- V~S~ON~ ANO ALL D~,~ENS~ONS AND OTiICE OETA~I..$ ARE OORREC~. AS- BUILT WELL LAT, LONG. NO. i APPROX!MA'FE O__NL.Y ;s~e note) 7C,°;4'32.88± Y ~ 9~'rO 845.14 1487'27.,'43.83~ X 698 ¢.48 17 WELL NO. ! I LAT. 70°14'2~4 77;" Y 5 940009. II LONG. 148o 24 0'.0',i :' X $98 I I 3.59 WELL LAT. LONG ','YELL. LAT. L.ON G. WELL LAT. LONG. ~',' 0. '2 -*0o 14' :~r, o32''_~._, v, 5 940 126.51 i4[;0;84.' 0.656" X 698 088,31 .~0. )3 . 70° I4' 27.091" Y 5 940 243.77 148°24' 1.302" X 698 062.97 NO. I~ 70° 14' 28.249" Y 5 940 360.83 t4.8°24' 1.947" X 698 037. T'0 WELL NO. f5 LAT. 70° .!4' LONE I48° 24 29.407" Y 5940477.95 ' 2.590" X 698 012,50 WELL NO.16 LAT. 70° ~,, 3u. 569" LONG. 148° 24' 3.238" WELL. , NO. I? LAT. ;zO° 14'3' 1.724" LONG. 14.8o24~ 3.886" Y 5 940 595.50 .X 697 98.7.12 5 940712.30 X 697 961,74' NO'FES: I.MPFDIMFNT S ON WELL. 1 PRECLUDED ACCUR~FE LOCATION~ APPROXIMATE WELL. 1 COORDINATES LISTED ABOVE. WELLS :I-17 TOP PAD E.L_EVATION 39.7 ABOVE ML. LW EXISTING WELL OR CONDUCTOR PAD ARCO ,..Ne. AFE i'.l ~'~ No. · AT.LANT!C .R~CHFIEL.D CO. AS-BUILT WEST' PAD DR.iL.L .<::;IT E No. t WEULS '11 THRU L~.C~.~ ED IN PROTRACTED SECTION 8~'f"iON.,RISE,[.I.M ?R E F'AR E'_ ~,n BY ,';,~'rE 2 SEPT ;~:~"7'7 ~:;'~ c, [.. ,::.' .'~" '" ' ' , :, . ...................................................................................... ',; CHECK LIST FOR NEW WELL PERMITS Company Yes Nd Remarks 1. Is the permit .fee attached ........ ' .... ' .~>-'~'q' - Lease & Well No. 2. Is well to be located in a defined pool . 3. Is a registered survey plat attached .......... ' ...... ~u~< 4. Is well located proper distance from property line ......... ;~( 5. Is well located proper distance from other wells .......... 6. Is sufficient undedicated acreage available in this pool ...... 7. Is well to be deviated ....................... . ~W~o( 8. Is operator the only affected party ............. . . . . .x/Fj~' 9. C~n permit be approved 'before ten-day wait ' · ...... ~_'~)____~?' 10. Does operator have a bond in force ........ · ...... ' 11. Is a conservation o'rder needed ............. · ...... 12. Is administrative approual needed ................. 13. Is conductor' string provided ' · . . .' ........... ~ 14. Is enOugh Cement us6d to circulate on conductor and surface .... j~ 15. Will cement tie in surface and intermediate or production strings . ~_I ~ · 16. Will cement cover all known productive horizons - · ~ 17 Will surface casing protect fresh water zones ........... [t~l . 18. W~ll all cas~n~ §ire adequate safety in collapse, tension & burst . 19. Boes B0PE have sufficient pressure rat~n~ - lest to. ~D"~o ps~ .. ~ 20. Has B~[M approved Plan of 0perat~on ................ Additional Requirements' Approval Recommended' Geo~ ogy' Enqi neering: TRMX~X~ OAL HWK ~/-~.~_.. LCS~/..~ RAD Revised 11/17/76 Well Histo[y 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'thle nature is.'accumulated at the' end of the file under APPE .N..DIX. · . No special'effort has been made to chronologically organize this category of information, LIBRARY TAPE CURVE SPECIFICATIONS Company Well Arco Oil ~ Gas Co. DS 1-11 ~ Field Prudhoe Bay County, State North Slope, Alaska Date 10-6-8~. Curve Name (Abbreviated) Standard Curve Name Logs Used Scale GR Gamma Ray CNLOG ~ 'Multi- 0- 100 SPACH LSN Long Space Neutron " 0-2000 SSN Short Space Neutron " 0-2000 ... _ NEU Compensated Neutron " 60-0 ,, , · ".?~'~:"?:i~? . , , , · ,, _ ., . . , , o ., ., . , , , , ', ~.,...,; :..-',.~' , LIBRARY TAPE CURVE SPECIFICATIONS Company Well Arco Oil & Gas Co. DS 1-11 Field Prudhoe Bay County,State North Slope, Alaska Date 10-6-8~. Curve Name (Abbreviated) Standard Curve Name Logs Used Scale ., GR Gamma Ray CNLOG ~ Multi- 0-100 SPACE LSN ,L°ng Space Neutron " 0-2000 SSN Short Space Neutron " 0-2000 NBU Compensated Neutron " 60-0 , . ,, , , PAGE 1. ARCO DRI._!DHOF BAY .... DATA EtlE'RY OIL AND SLOPE, SA~LES SAg .... 3RILL SITE 1-11 ALASKA 9890,00 0,00 9890.50 O,&.O 9891,00 0,00 9891.50 9892,00 0,00 989~.50. 9893.0.0 ~.5,.~2 9893,50 ~6.55 LS~ SgN WEd ........ O,O0 O..OO ........ 30..,.8~ 0,00 0,00 30.,5~ 0.00 0.0.0 ..3.0..,27 .0,00 O_...O.O ............ 0o00 0.00 .0.,.00. 22 a.~.,..~l 9897,50 9B9A,00 9898,50 9899.0~ 9899.50 3900,00 9900,50 9901,00 9901.50 990p.00 99o2.50. 990~.00 ~90~.50 .... ~90~.00 990~.50 ~9o~.oo 9905.50 · , 990~.00 9906.50 · , 35,82 35.5~ 38.65 4~.89 ~9,86 · . 62.80 71.92 7~.86 76.85 77.0~ 7q.,~%~ 76.~ 7&.lO 73.36 72.~7 75.86 75,18 .. . 71,&~ ... 71.01 73.30 ...... 72.97 72.97 7~.98 69'28 .. 66,80 67.78 .. 69,28 70,97 9907,00 9907.50 9908.09 9908,50 9909.00 990q.50 · . 9910.00 9910.50 9911..0~ 9911,50 9~lP.O0 9912.50 .. 9913.00 991~.50 .. ggla. O0 991~.50 ~915.00 935.B9. 995.6~ lO1~.36 1119.87 1076.87 1151.72 1~83,86 133'6.38 ............ 1~80,81 1527.~3 1. g57.57 .......... 1.~98.87 1385.23 1~79,27 1278,87 1~86.59 1283.8:5 1~95.~9 1289.79 1~0~.99 1~95,6R 25,08 23,03 18,00 ~,10 · , 1~.01 12,65 ...... 12.97 11.95 11.~9 . . 11.90 12.,i~ 12,52 1~.6~ 12.88 12.98 ].3.01 12,56 !~i~,5.1 !~.o.o....~o .... 1e,.~2 .............. i~2~.~5 1~o~.~9 ~.~ 1~29.05 1~01.79 12,08 ........ 1~%~0.23 l~OO.~ 1~.14 1.~28.83 1299.35 12,35 ................... 1~27.ff2 1298.67 1~.~6 1~30.17 1286.10 11.96 ........................ lq. 2~.~ 1~.11 11.78 .. . 77.5n 1..~t0.67 12~.1~ 11.93 77.,~ 1~07.09 le.59.9~ . ~!..,..~.8 ..... 77.77 1391.19 !25%.~3 12.1.~ · . 76.58 1396.51 77.11 l~O~.Bl 12~3.5g mAGE 2 ARCO OIL AND GAB .... DRIL~L SITE PRUDHOE BAY .... N. SLOPE, AL;ASKA DA'TA E~/ERY ,1. SAVlPLES 1-11 mR LSNI S,q.N ~,l ELI 9915.50 7~.,-'35 lq-13.~ 1240.2;> 11.36 991¢,.00 78.89 1_q, 22..o, 2 1240.30 10.85 9916.50 77.61 lalP_.90 1250.25 .11.,20 ................. 9...9!. 7._0. 0 ........... 7.6. ,.. ! 9.... ,!.,,q:,,...0,,7.,,,,.~. 2 ........... ..... 9. 9 !7... 50 ........... 7 ~.,...8.6 .... ...1.,..!+......t........9,. ....... 5.0 ...... ~...~.Z.O.. ........ ~.,.~ ............................ :!.,.!.....,,..:6,.....0., ................ · ......................... 991R,00 77.1.7 lq-36.57 12~3,,65 .,1,,.1.07 9919.00 81.15 14.7_9.,58 19_85,68 10,67 ...... .......................... ................ .. 9.9.2.0,.0..0 ..... ~9.2~ 1~79.03 1525,!...~ ......................... ~,,..1,...,....,O..~ .... e 9 ...2._ 0..·,···5.0. 7 5.0 ~ l'~ 8 7.7 ~ 1 · ··9·92 ]., 0....0 ........ 7;..!..,....! 3 1 ~ 9~..,...~,$ .......... !,.~,..~.,,~..,,..,.0,,..8.. ............................ !,.~.,,.,,,~,..~, ................................ ................... ~..9.2..~....,··..5.0 ....................... S7.,.6.9.........!...5.0..5...,.,..!.,..~,..........~., 9923,0.0 ..... ~.9.2.3..50 ....... 992~.00 77.q-1 .1.41.9.40 125.~.~.?, 11.144 ........ 9925.00 80,7~ lq1~.80 12. g1..2[~ 1!,..5~ . . :)925.50 81.05 lq05.56 1~0,15 992¢,.00 77.72 1,'59.5.¢~.! 12..55,71. .~!..~% ........ 99~.50 75.0,'5. 1_~..8~.,'55 12t~.7~ 11.87 9927.00 7,"1.93 1,'5E, 7o70 11.:)l.70 .!.1.97. 9927.50 '7~.1~ 135i."05 1i~,'c3.55' 992R.00 74.67 1326.35 .11.~2,..61 1.1~..~3 ......... 992¢,.50 '77.88 .15q-~_. ?..7 12..99.59 ].2.;5'5 9929.110 .79.1~ 1,"479..4~ 1255.,'50 12,,.57 .... 9929.50 80,q. 1 1~.2:5.7~ 12R1.7% 11.,2.9 9930.00 80.06 t477.20 12B~_.71 10.41 9930.50 80...50 1~79.3& 1280,91% 10.19 9951.00 81.8..,2 1.475.57 12~5.92 10,49 99~1.50 80.59 l~70o6__~ 1290.91 10..~7 99~2,00 7g.25 1~69,__95 1295.89 10,73 · . 99,~.50 7g.53 l~&~.O]. 1500.87 10.85 993~.00 80.15 1~,%9,~_5 1506.~7 11.55 993q..00 79.79 1%;51.27 1335.25 12.52 ........................ ?.. ?.~.. 5.. :... ~..0. ......................... F..~_ ,... 5...0 ......... i.. ~.. 6.. 5....,..... 0...3,..........Z..~. ~.,~ .,..~. ~ ......................... ~....!....,....6...0 9..~.~.5.,...5. 0 6,.9 ...~ 8 ..... t ~. 8....~ 3..O.t.. ~..5 :~. 0._.,.~9.:.5 :: ....... .................... ?.?.~.6..,...g..~ 6.?..,.. 9.93 ~.,.50 6 ,9.6 ! ~52.. 8 !.2,2 .,.86 9....,..8.9 9957,50 75.~5 1.~32.1~ 123G.37 . !0,.35 9.~ ~?..,...0..0 ............ 7.~. ,. ~..! ~.~.~..~.,..6.~ ..... !.2..~.,_~.,_0.6 .............. ~.~,.~...~..~ 99~0,50 69,50 t~05,~6 ~2~7,~ ~0,76 PAGE 3 ARCO OI ::'RUDHOF BAY .... N. S .DATA EWERY .1. SA L AND SAg .... 3RILL LOPE, ALASKA ~LES SITE 1-11 GR 9941.00 70,75 99~1,50 69,6~ 9992,00 69.36 99~2,50 72.67 9943,00 71,51 9943.50 70,32 99~4,00 72.29 99~a.50 72.54 99~5,00 70,53 99~5.50 69.31 g9~,O0 67,71 99~6.50 67.1~ 9947,50 9948.00 73.85 994,~.5o g950. 9951., 9951, 9959, 9952, 9953. 995~. .... 995~, O0 50 O0 50 O0 50 O0 50 O0 71.21 70.~8 74.25 7~.2R 7~..09 73.?G 73.88 7~.'70 70.~7 ... ~9,77 7~.7~ · 75.2~ 995a.50 70 9955.00 68 g95g.50 70 g95~.50 69 9'957.00 '66 9957,50 .. 995~.00 5B.gO ~5~.5o ~95~.00' 60,02 9959.50 63.99 9960.50 77.79 9961.50 75.~6 '9'~.o0 ?'5.17 996~.50 7~.~[7 LS~ SgN ~EJ .......... 1390,~9. 1217.3.2 lO...B7 1~83.91 1.2.0B..99 11.17 ............................................................................ ~3~2,.~9 1211 1381,46 121~.72 1..1.,49 1360.~3 1~1.~.55 11,62 137.4,57 !.222..39 ..... 1.1.,7.7 1368,61 .12.~6.23 1.~.,.Q? 1355.83 1230.07 12,3.1 1351.~7 1233...7.3 136.5.12 1.231,67 ........... 12..,..~..~ 1361.73 1.2.0.~.99 11,81 1343,.0.8 !.1.~.6_...~ ................... !~.,.~..~ 1333,.1.5...!1~9,...7~ ....... 1305,43 1199.30 1303..~3 1206.76 1325,1.8 121~.23 13~6,~2 12~1,78 · . 136s.4~ 12so.os 14oo.o5 12~7.8~ .............. .27 ]..:66.&0 12~3.17 .5o 1.~13.65 12~'.6o .9~ 1.39o.~1 1252.78 · .~5 1367.1.7 1240.09 .92 1~5.05 12~.39 .';9 1323.07 1201.5A 13,39 13,15 ... 13,1~ 12..73 ...... 12.19 11.54 11,3~ 10,9~ lO.TG 11.25 11.71 12.2~ 13.11 13.58 1415.36 1224.50 "10'~'~2 !~07.~1 12:12.88 10,19 1389.57 11~.41 10.59 z3~o.~s ~!75'.6~ 'z'O'.'~"' 1371.33 1173.63 10.74 ~63.oo ?a..~7 t'._$~a'.~_l 1'1~':.~? .... lO;.~? ................................................. 9~o,~.5o 8o.,~_~ 1~5o,.95,.,,lz.~!,..,.z....,t. ......... !:.!,.~..2 ' .................................... mAGE ~ ~RCO OIL AND ~,Rtl,.qHDE RAY .... ~J. SLDmE, DATA £t/ERY I SAg~LES 2&g .... DRILL SITE 1-11 ~LaSK& 99~6,50 9967,00 9967,50 9968,00 9968,50 99~9.00 9969,50 9970.00 9970.50 9972.00 9971.,50 9972.00 997p..50 9973.00 9973.50 9974.00 GR 76.82 75.3% 75.7& 77.15 77.34 77.01 LS\I SS~ 1337.53 119'0.75 13q%.99 119&.98 1352..~4 1205.22 1559.90 1205..53 1367.55 119&.56 1,~74.20 NEJ 12....3.6 ...................... 12.~2 1~..~2 _11.,...~3 11)9.~0 11,11 76.7B 1&75.07 11~.,6~ . 10...~5 .................................................................... 76.07 1370.&& 1175.77 10.70 ..................................................................... 77.74 1366,~5 11~9 .....1.6 10.,..7..0 ......................................................................................................... 79.69 1361..~4 116.2.55 ....... 1.O...,~_~ ......................................................................................................................................................................................................................... 8.0.86 1362,05. 1160 74o~8 136So91 11~5 6,,5 i,.0,.9.~ .................................................................................................... 72.15 1~71.~5 ..... !.,2i0 ..... 7~.15 1.382 ~:.0 i2~,2,,0¢ ......................... !..!,,,..,.~ .................................................. 9975.00 72.95 1390,27 1256,07 11..88 ................... 9.,97~.on 997~.50 9977..00 9977.50 997a.00 · 9'~7R.50 9979.00 · . 9979.50 qgan.oo 9980.50 9981.00 ...... 9981.50 998~.00 998~.50 998~.00 9983,50 99Ra. OO ... 998q..50 9985.00 ...... 9985.50 998~.00 99R~,50 9987,00 9987.50 99R~.00 .. . 998q.50 99R9.00 · . 9~5~.50 75..60 .136B,.18 12~B.,23 74,95 1357.04 118~.69 75.48 1340.~9 117~.00 78,~4 1~57.57 1195.65 74~31 1377.59 1208.~9 72.R~ 1~97.~1 1215.70 1!,8~ 74,~9 1416.0.7 1221..!8 11..~9 75,52 14~0.97 1235.~8 80.08 1~5..88 1251.0~ 11.0~ 82.07 ].g60,78 1296.57 10.98 ~.51 1173.98 1279.~7 10.~0 .. 82.95 148q.7~ 1292,17 10.54 81,5'? 1%81.97 15~5.~8 10.~6 8~.~9 lq8~.98 131~.~ 10,89 ll..5.o 11.52 11.59 .... 11~7~ mm 79.79 %485,01 1329.55 11,59 ~.23 !.~42.9~ 1308.50 11.42 87.58 1415.~0 1297.]5 1!,54 . 86.3~ 13~8.75 1285.79 11.79 7q.~a 1351.37 1216.].6 ................ 73.00 13~o.18 12~i.5o 75.57 t367.~3 .!.251,~7 1~..5.1 ...... 77.61 1407.75 1251.86 82.g3 1.428.58 12~&.90 11.19 .............. a2.23 1115.73 12~1.94 21.00 * ALASKA COMPUTING CENTER * ****************************** ............................. * ....... SCHLUMBERGER ....... * ............................ ****************************** COMPANY NAME ~ ARCO ALASKA, INC. WELL NAME = D.S. 1-11 FIELD NAME ~ PRUDHOE BAY BOROUGH : NORTH SLOPE STATE ~ ALASKA API NUMBER : 500292026800 REFERENCE NO : 97357 LIS Tape Verification Listing Schlumberger Alaska Computing Center 19-AUG-1997 13:10 PAGE= **** REEL HEADER **** SERVICE NAME : EDIT DATE : 97/08/19 ORIGIN : FLIC REEL NAME : 97357 CONTINUATION # : PREVIOUS REEL : COMMENT : ARCO ALASKA INC., PRUDHOEBAY, D.S. 1-11, API# 50-029-20268-00 **** TAPE HEADER **** SERVICE NAME : EDIT DATE : 97/08/19 ORIGIN : FLIC TAPE NAME : 97357 CONTINUATION # : 1 PREVIOUS TAPE : COb~4ENT : ARCO ALASKA INC., PRUDHOE BAY, D.S. 1-11, API# 50-029-20268-00 TAPE HEADER PRUDHOEBAY CASED HOLE WIRELINE LOGS WELL NAME: D.S. 1-11 API NUMBER: 500292026800 OPERATOR: ARCO ALASKA, INC. LOGGING COMPANY: SCHLUMBERGER WELL SERVICES TAPE CREATION DATE: 19-AUG-97 JOB NUMBER: 97357 LOGGING ENGINEER: G.JOHNSON OPERATOR WITNESS: K. St.G~4E SURFACE LOCATION SECTION: 8 TOWNSHIP: iON RANGE: 1SE FNL: FSL: 898 FEL: 777 FWL: ELEVATION (FT FROM MSL O) KELLY BUSHING: 73.00 DERRICK FLOOR: 72.00 GROUND LEVEL: 34.00 WELL CASING RECORD IST STRING 2NDSTRING 3RD STRING PRODUCTION STRING OPEN HOLE CASING DRILLERS CASING BIT SIZE (IN) SIZE (IN) DEPTH (FT) WEIGHT (LB/FT) 9.625 10988.0 47.00 5.500 9894.0 17.00 4.500 10024.0 12.60 CURVE SHIFT DATA - ALL PASSES TO STANDARD(MEASURED DEPTH) LIS Tape Verification Listing Schlumberger Alaska Computing Center 19-AUG-1997 13:10 BASELINE CURVE FOR SHIFTS LDWG TOOL CODE: BCS LDWG CURVE CODE: GR RUN NUMBER: PASS NUMBER: DATE LOGGED: 26-APR-78 LOGGING COMPANY: SCHLUMBERGER WELL SERVICES BASELINE DEPTH 88888.0 10523.5 10522.5 10520.5 10519.0 10497.5 10475.0 10471.0 10469.5 10453.5 10451.5 10447.5 10445.0 10444.0 10440.0 10439.5 10435.5 10432.5 10429.5 10413.5 10410.0 10409.0 10398.5 10391.0 10387.0 10386.0 10384.5 10383.5 10374.5 10371.5 10362.0 10360.0 10356.5 10346.0 10341.0 10340.0 10329.0 10328.5 10326.0 10325.5 10324.5 10309.5 10300.5 10298.0 10294.5 .......... EQUIVALENT UNSHIFTED DEPTH .......... GRCH CNTG 88887.0 88888.0 10522.5 10522.5 10519.5 10519.5 10497.5 10497.5 10476.0 10476.0 10470.0 10468.5 10454 . 0 10454 . 0 10452.0 10452.0 10448.5 10448.5 10445.0 10445.0 10440.0 10440.0 10436.5 10436.5 10433.0 10433.0 10429.5 10429.5 10414.5 10414.5 10410.5 10410.5 10408.5 10408.5 10399.5 10399.5 10392.5 10392.5 10387.5 10387.5 10385.0 10385.0 10374.5 10374.5 10372.0 10372.0 10363.5 10363.0 10360.0 10357.5 10357.5 10347.0 10347.0 10341.0 10341.0 10329.5 10329,5 10324.5 10324.5 10322.5 10309.0 10309.0 10302,5 10302.5 10300.0 10300.0 10296.5 10296.5 PAGE: LIS Tape Verification Listing Schlumberger Alaska Computing Center 19-AUG-1997 13:10 10289.0 10290.5 10281.5 10282.5 10282.5 10279.5 10280.5 10280.5 10276.5 10277.5 10277.5 10272.5 10272.5 10272.5 10267.5 10268.0 10268.0 10256.5 10254.5 10254.5 10248.0 10247.5 10247.5 100.0 99.5 99.5 $ CONTAINED HEREIN IS THE CNTG DATA ACQUIRED ON ARCO ALASKA INC. WELL D.S. 1-11. THE DEPTH SHIFTS SHOWN ABOVE REFLECT PASS #1 GRCH TO GR.BCS; AND PASS #1 I~PHI TO GR.BCS. ALL OTHER CNTG CURVES WERE CARRIED WITH THE NPHI SHIFT. $ PAGE: **** FILE HEADER **** FILE NAME ~ EDIT .001 SERVICE ~ FLiC VERSION ~ 001C01 DATE ~ 97/08/19 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 INCPd~4ENT: 0.5000 FILE SUF~ARY LDWG TOOL CODE START DEPTH STOP DEPTH GRCH 10525.0 10246.0 CNTG 10530.0 10246.0 $ CURVE SHIFT DATA - PASS TO PASS (MEASURED DEPTH) BASELINE CURVE FOR SHIFTS LDWG CURVE CODE: PASS NUMBER: BASELINE DEPTH $ .......... EQUIVALENT UNSHIFTED DEPTH .......... GRCH CNTG RE~2~KS: THIS FILE CONTAINS CNTG PASS #1. NO PASS TO PASS SHIFTS LIS Tape Verification Listing Schlumberger Alaska Computing Center 19-AUG-1997 15 PAGE: WERE APPLIED TO THIS DATA. LIS FORMAT DATA ** DATA FORMAT SPECIFICATION RECORD ** ** SBT TYPE - 64EB ** TYPE REPR CODE VALUE 1 66 0 2 66 3 73 68 4 66 1 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 1 0 66 0 ** SET TYPE - CHAN ** NAME SERV UNIT SERVICE API API API API FILE NUMB NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUMB SAMP ELEM CODE (HEX) DEPT FT 500747 O0 000 O0 0 1 1 1 4 68 0000000000 NPHI CNTG PU-S 500747 O0 000 O0 0 1 1 1 4 68 0000000000 ENPH CNTG PU-S 500747 00 000 O0 0 1 1 1 4 68 0000000000 CPHI CNTG PU-S 500747 O0 000 O0 0 1 1 1 4 68 0000000000 NRAT CNTG 500747 00 000 O0 0 1 1 1 4 68 0000000000 CRAT CNTG 500747 O0 000 O0 0 1 1 1 4 68 0000000000 ~ CNTG 500747 00 000 O0 0 1 1 1 4 68 0000000000 NCNTCNTG CPS 500747 00 000 O0 0 1 1 I 4 68 0000000000 FCNTCNTG CPS 500747 O0 000 O0 0 1 1 1 4 68 0000000000 CNTC CNTG CPS 500747 O0 000 O0 0 1 1 1 4 68 0000000000 CFTC CNTG CPS 500747 O0 000 O0 0 1 1 1 4 68 0000000000 CNEC CNTG CPS 500747 O0 000 O0 0 1 1 1 4 68 0000000000 CFEC CNTG CPS 500747 O0 000 O0 0 1 1 1 4 68 0000000000 GRCH CNTG GAPI 500747 O0 000 O0 0 1 1 1 4 68 0000000000 TENS CNTG LB 500747 00 000 00 0 1 1 1 4 68 0000000000 CCL CNTG V 500747 00 000 O0 0 1 1 1 4 68 0000000000 GR BCS GAPI 500747 O0 000 O0 0 1 1 1 4 68 0000000000 LIS Tape Verification Listing Schlumberger Alaska Computing Center 19-AUG-1997 13:10 PAGE: ** DATA ** DEPT. 10600.000 NPHI.CNTG -999.250 ENPH. CNTG -999.250 CPHI.CNTG NRAT. CNTG -999.250 CRAT. CNTG -999.250 ENRA.CNTG -999.250 NCNT. CNTG FCNT. CNTG -999.250 CNTC. CNT~ -999.250 CFTC. CI~fG -999.250 CNEC. CNTG CFBC. CNTG -999.250 GRCH. CNTG -999.250 TENS. CNTG -999.250 CCL.CNTG GR.BCS 34.237 DEPT. 10220.000 NPHI. CNTG -999.250 ENPH. CNTG -999.250 CPHI. CNTG NRAT. C_NTG -999.250 CRAT. CNTG -999.250 ENRA.CNTG -999.250 NCNT. CNTG FCNT. CNTG -999.250 CNTC. CNTG -999.250 CFTC. CNTG -999.250 CNEC. CNTG CFEC. CNTG -999.250 GRCH. CNTG -999.250 TENS. CNTG -999.250 CCL. CNTG GR.BCS 110.947 - 999. 250 - 999.250 - 999. 250 - 999. 250 -999.250 -999.250 -999.250 -999.250 ** END OF DATA ** **** FILE TRAILER **** FILE NAME : EDIT .001 SERVICE : FLIC VERSION : 001C01 DATE : 97/08/19 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : **** FILE HEADER **** FILE NAME : EDIT .002 SERVICE : FLIC VERSION : O01CO1 DATE : 97/08/19 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : FILE HEADER FILE NUMBER: 2 EDITED CURVES Depth shifted and clipped curves for each pass in separate files. PASS NUMBER: 2 DEPTH INCR~TENT: 0,5000 FILE SUF~A~Y LDWG TOOL CODE START DEPTH STOP DEPTH GRCH 10525.0 10240.0 LIS Tape Verification Lis~ing Schlumberger Alaska Computing Center 19-AUG-1997 13:10 PAGE= CNTG 10530.0 10240.0 $ CURVE SHIFT DATA - PASS TO PASS (MEASURED DEPTH) BASELINE CURVE FOR SHIFTS LDWG CURVE CODE: GRCH PASS NUMBER: 1 BASELINE DEPTH 88888.0 10527.5 10523.0 10521.5 10520.0 10515.5 10513.0 10510.0 1.0508.0 10506.5 10504.5 10500.5 10499.0 10498.0 10496.0 10494.0 10488.0 10486.5 10485.5 10484.0 10479.0 10475.5 10474.0 10472.0 10470.5 10470.0 10469.0 10468.5 10468.0 10466.5 10465.0 10460.5 10459.0 10458.0 10457.0 10454.0 10452.5 10452.0 10445.5 10444.5 10444.0 10442.5 10441.0 10436.0 .......... EQUIVALENT UNSHIFTEDDEPTH .......... GRCH CNTG 88889.0 88887.5 10527.0 10521.5 10522.5 10519.5 10515.0 10513.0 10508.5 10507.0 10505.5 10503.5 10499.5 10499.0 10497.5 10496.0 10493.5 10488.0 10485.5 10483.5 10482.5 10479.0 10476.0 10473.5 10470.0 10470.0 10468.5 10468.0 10467.5 10465.0 10463.0 10462.0 10459.0 10458.0 10455.5 10456.5 10454.0 10451.0 10452.0 10445.0 10445.0 10443.5 10442.0 10439.5 10435.0 LIS Tape Verification Listing Schlumberger Alaska Computing Center ig-AUG-1997 13:10 PAGE: 10435.0 10435.5 10433.5 10432.5 10433.0 10432.5 10425.5 10425.0 10424.5 10424.0 10419.5 10418.5 10414.0 10414.5 10412.5 10414.5 10409.0 10411.0 10406.5 10408.5 10406.0 10408.0 10403.5 10403.5 10402.0 10404.5 10400.5 10403.5 10399.5 10399.5 10395.0 10395.0 10392.5 10393.0 10392.0 10393.0 10388.5 10387.5 10387.0 10385.0 10386.0 10385.0 10379.5 10380.0 10377.5 10377.0 10375.5 10375.5 10374.5 10374.5 10374.0 10374.5 10371.5 10372.0 10370.5 10370.0 10366.5 10368.0 10365.5 10366.0 10363.5 10363.5 10357.0 10357.5 10356.5 10356.0 10348.5 10348.5 10347.0 10347.0 10344.0 10344.0 10341.5 10340.5 10340.5 10341.0 10335.0 10334.5 10333.0 10333.5 10329.5 10329.0 10329.0 10329.5 10327.5 10325.0 10326,5 10324.5 10325.5 10322.5 10315,0 10317.0 10314.5 10309.5 10312.5 10308.0 10307.5 10307.0 10309.0 10301.0 10302.5 10302,5 10298.0 10299.5 10293.5 10296.5 10293.0 10293.0 10289.5 10289.5 10291.0 10288.0 10288.0 LIS Tape Verification Lis~ing Schlumberger Alaska Computing Cen=er 19-AUG-1997 13 PAGE: 10286.0 10287.0 10282.5 10282.5 10282.0 10283.0 10280.5 10280.5 10280.5 10278.0 10277.5 10278.5 10273.5 10273.5 10272.5 10272.5 10270.5 10270.5 10268.0 10268.0 10268.0 10263 . 5 10262.5 10263.0 10262.0 10260.5 10258.5 10256.5 10254.5 10255.5 10254.5 10248.5 10247.0 10247.0 100.0 98.5 98.5 $ R~VlARKS: THIS FILE CONTAINS CNTG PASS #2. THE DEPTH SHIFTS SHOWN ABOVE REFLECT PASS #2 GRCH TO PASS #1GRCH; AND PASS #2 NPHI TO PASS #1NPHI. ALL OTHER CNTG CURVES WERE CARRIED WITH THE NPHI SHIFT. $ LIS FORMAT DATA ** DATA FORMAT SPECIFICATION RECORD ** ** SET TYPE - 64EB ** TYPE REPR CODE VALUE 1 66 0 2 66 3 73 64 4 66 1 5 66 6 73 7 65 8 68 0.5 9 65 FT 11 66 16 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 19-AUG-1997 13:10 PAGE: ** SBT TYPE - CHAN ** NAME SERV UNIT SERVICE API API API API FILE NUMB NUM~ SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUMB SAMP EL~ CODE (HEX) FT 500747 00 000 O0 0 2 1 1 4 68 0000000000 DBPT NPHI CNTG PU-S 500747 O0 000 ENPH CNTG PU-S 500747 O0 000 CPHI CNTG PU-S 500747 00 000 NRAT~ 500747 00 000 CRATCNTG 500747 00 000 PIVRA CNTG 500747 00 000 NCNT CNTG CPS 500747 O0 000 FCNTCNTG CPS 500747 00 000 CNTC CNTG CPS 500747 00 000 CFTC CNTG CPS 500747 00 000 CNEC CNTG CPS 500747 00 000 CFEC CNTG CPS 500747 00 000 GRCH CNTG GAPI 500747 O0 000 TENS CNTG LB 500747 00 000 CCL CNTG V 500747 00 000 O0 0 2 1 1 4 68 0000000000 O0 0 2 1 1 4 68 0000000000 O0 0 2 1 1 4 68 0000000000 00 0 2 1 1 4 68 0000000000 00 0 2 1 1 4 68 0000000000 00 0 2 1 1 4 68 0000000000 O0 0 2 1 1 4 68 0000000000 O0 0 2 1 1 4 68 0000000000 O0 0 2 1 1 4 68 0000000000 00 0 2 1 1 4 68 0000000000 00 0 2 1 1 4 68 0000000000 00 0 2 1 1 4 68 0000000000 00 0 2 I I 4 68 0000000000 00 0 2 1 1 4 68 0000000000 00 0 2 1 1 4 68 0000000000 ** DATA ** DEPT. 10529.500 NPHI.CNTG 27.837 ENPH. CNTG NRAT. CIFi~ 2.894 CRAT. CNTG 2.930 ENRA.CNTG FCNT. CNTG 474.392 CNTC. CNTG 1596.954 CFTC. CNTG CFEC. CNTG 475.680 GRCH. CNTG -999.250 TENS. CNTG DEPT. 10238.500 NPHI. CNTG 25.665 ENPH. CNTG NRAT. CNTG 2.833 CRAT. CNTG 2.810 ENRA. C~ FCNT. CNTG 701.548 CNTC. CNTG 2019.665 CFTC. CNTG CFEC. CNTG 561.701 GRCH. CNTG 25.375 TENS. CNTG 34.797 CPHI. CNTG 5.138 NCNT. CNTG 552.226 CNEC. CNTG 3120.000 CCL. CNTG 29.989 CPHI. CNTG 4.660 NCNT. CNTG. 719.342 CNEC. CNTG 3140.000 CCL. CNTG 26.999 1 612.528 2443.992 -0.003 25.739 1972.041 2617.441 0.057 ** END OF DATA ** **** FiLE TRAILER **** FILE NAME : EDIT .002 SERVICE : FLIC VERSION : 001C01 DATE : 97/08/19 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : LIS Tape Verification Listing Schlumberger Alaska Computing Center 19-AUG-1997 13:10 PAGE: i0 **** FILE HEADER **** FILE NAME : EDIT .003 SERVICE : FLIC VERSION : 001C01 DATE : 97/08/19 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : FILE HEADER FILE NUMBER: 3 EDITED CURVES Depth shifted and clipped curves for each pass in separate files. PASS NUMBER: 3 DEPTH INCREMENT: 0.5000 FILE SUMMARY LDWG TOOL CODE START DEPTH STOP DEPTH GRCH 10525 . 0 10240 . 0 CHTG 10530.0 10240.0 $ CURVE SHIFT DATA - PASS TO PASS (MEASURED DEPTH) BASELINE CURVE FOR SHIFTS LDWG CURVE CODE: GRCH PASS NUMBER: 1 .......... EQUIVALENT UNSHIFTEDDEPTH .......... BASELINE DEPTH GRCH CNTG 88888.0 88886.5 88887.5 10527.5 10527.0 10521.5 10521.5 10521.0 10519.5 10518.0 10516.0 10515.5 10515.0 10513.0 10513.0 10510.0 10508.5 10507.5 10507.0 10506.5 10505.0 10506.0 10505.0 10503.0 10501.5 10501.5 10499.5 10500.0 10499.5 10499.0 10498.0 10497.0 10496.5 10496.0 10493.0 10492.0 10488.5 10488.0 10485.5 10485.0 10479.0 10479.0 10475.5 10476.0 LIS Tape Verification Listing Schlumberger Alaska Computing Center 19-AUG-1997 13:10 PAGE: 11 10473.5 10474.0 10472.0 10470.0 10471.5 10471.5 10470.0 10468.5 10468.5 10470.0 10464.5 10465.0 10460.5 10459.0 10458.5 10457.5 10457.0 10456.5 10455.0 10455.0 10454.0 10454.0 10453.0 10453.0 10452.0 10452.0 10450.5 10451.0 10448.5 10448.5 10445.5 10445.0 10444.5 10445.0 10443.5 10440.0 10440.0 10439.0 10439.5 10436.0 10435.0 10435.0 10435.5 10432.5 10432.5 10430.0 10429.5 10427.5 10427.5 10427.0 10427.5 10425.0 10426.0 10424.5 10424.5 10422.0 10422.5 10419.0 10418.5 10414.0 10414.5 10413.5 10414.5 10410.5 10408.5 10409.0 10411.0 10406.0 10407.5 10404.0 10403.5 10402.5 10402.5 10403.5 10401.0 10402.0 10399.5 10399.5 10400.0 10393.0 10393.0 10391.0 10392.0 10388.5 10387.5 10385.5 10385.0 10384.5 10385.0 10382.5 10382.5 10380.0 10380.0 10376.0 10376.0 10374.5 10374.5 10374.5 10372.0 10371.5 10371.5 10372.0 10370.0 10370.0 10366.5 10366.5 10360.5 10361.0 10360.0 10359.5 10359.5 10357.0 10357.5 10354.5 10356.0 LIS Tape Verification Listing Schlumberger Alaska Computing Center 19-AUG-1997 13:10 12 10346.5 10347.0 10347.0 10342.0 10341.0 10340.5 10341.0 10332.5 10333.5 10332.0 10331.5 10328.5 10329.5 10329.5 10326.0 10324.5 10325.5 10322.5 10324.5 10323.0 10321.5 10319.5 10318.5 10317.0 10316.5 10314.5 10316.0 10314.5 10311.0 10309.0 10309.0 10307.0 10308.0 10307.5 10305.5 10305.0 10305.0 10302.5 10302.5 10301.5 10302.5 10299.5 10300.0 10297.0 10296.5 10294.0 10294.5 10292.5 10293.5 10292.0 10294.0 10291.5 10290. S 10290.0 10291.0 10288.5 10288.0 10286.0 10287.0 10283.0 10283.0 10282.5 10282.5 10280.5 10280.5 10280.5 10278.5 10278.5 10277.5 10278.0 10274.0 10273.5 10273.0 10273 . 0 10268.0 10268.0 10268.0 10266.5 10266.0 10264.0 10262.5 10263.5 10262.5 10256.5 10254.0 10248.5 10247.0 10248.0 10247.0 100.0 98.5 99.0 $ REMARKS: THIS FILE CONTAINS CNTG PASS #3. THE DEPTH SHIFTS SHOWN ABOVE REFLECT PASS #3 GRCH TO PASS #1 GRCH; AND PASS #3 NPHI TO PASS #1 NPHI. ALL OTHER CNTG CURVES WERE CARRIED WITH THE NPHI SHIFT. $ LIS FORMAT DATA LIS Tape Verification Listing Schlumberger Alaska Computing Center 19-AUG-1997 13:10 PAGE: 13 ** DATA FORMAT SPECIFICATION RECORD ** ** SET TYPE - 64BB ** TYPE RBPR CODE VALUE 1 66 0 2 66 0 3 73 64 4 66 1 5 66 6 73 7 65 8 68 0.5 9 65 FT 11 66 16 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 RBPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUMB SAMP ELEM CODE (HEX) DEPT FT 500747 O0 000 O0 0 3 1 1 4 68 0000000000 NPHI CNTG PU-S 500747 O0 000 O0 0 3 1 1 4 68 0000000000 ENPH CNTG PU-S 500747 O0 000 O0 0 3 1 1 4 68 0000000000 CPHI CNTG PU-S 500747 O0 000 00 0 3 1 1 4 68 0000000000 NRAT CNTG 500747 O0 000 00 0 3 1 1 4 68 0000000000 CRAT CNTG 500747 O0 000 O0 0 3 1 1 4 68 0000000000 ENRA CNTG 500747 O0 000 O0 0 3 1 1 4 68 0000000000 NCNTCNTG 'CPS 500747 O0 000 O0 0 3 1 1 4 68 0000000000 FCNT CNTG CPS 500747 O0 000 O0 0 3 1 1 4 68 0000000000 CNTC CNTG CPS 500747 00 000 O0 0 3 1 1 4 68 0000000000 CFTC CNTG CPS 500747 00 000 O0 0 3 1 1 4 68 0000000000 CNEC CNTG CPS 500747 00 000 O0 0 3 1 1 4 68 0000000000 CFEC CNTG CPS 500747 00 000 O0 0 3 1 1 4 68 0000000000 GRCHCNTG GAPI 500747 00 000 00 0 3 1 1 4 68 0000000000 TENS CNTG LB 500747 00 000 00 0 3 1 1 4 68 0000000000 CCL CNTG V 500747 O0 000 O0 0 3 1 1 4 68 0000000000 ** DATA ** LIS Tape Verification Listing Schlumberger Alaska Computing Center 19-AUG-1997 13:10 PAGE: 14 DEPT. 10529.500 NPHI. CNTG 28.966 ENPH. CNTG NRAT. CNTG 2.906 CRAT. CNTG 2.992 ENRA. CNTG FCNT. ClFfG 498.667 CNTC. CNTG 1581.425 CFTC. CNTG CFEC. CNTG 479.855 GRCH. CNTG -999.250 TENS. CNTG 35.122 CPHI.CNTG 5.169 NCN .CNTG 546.539 CNEC. CNTG 3170.000 CCL. CNTG 27.024 lS65.948 2480.352 -0.009 ** END OF DATA ** **** FILE TRAILER **** FILE NAME : EDIT .003 SERVICE : FLIC VERSION : 001C01 DATE : 97/08/19 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : **** FILE HEADER **** FILE NAME : EDIT .004 SERVICE : FLIC VERSION : O01CO1 DATE : 97/08/19 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : FILE HEADER FILE NUMBER: 4 AVERAGED CURVES Compensated Neutron: Arithmetic average of edited passes for all curves. DEPTH INCR~ENT 0.5000 PASSES INCLUDED IN AVERAGE LDWG TOOL CODE PASS NUMBERS 1, 2, 3, CNTG R~ARKS: THE ARITHMETIC AVERAGE WAS CALCULATED AFTER CLIPPING AND DEPTH CORRECTIONS WERE APPLIED. $ LIS FORMAT DATA LIS Tape Verification Listing Schlumberger Alaska Computing Center 19-AUG-1997 13:10 PAGE: 15 ** DATA FORMAT SPECIFICATION RECORD ** ** SET TYPE - 64EB ** TYPE REPR CODB VALUE 1 66 0 2 66 0 3 73 56 4 66 1 5 66 6 73 7 65 8 68 0.5 9 65 FT 11 66 18 12 68 13 66 0 14 65 PT 15 66 68 16 66 1 0 66 1 ** SET TYPE - CHAN ** NAIV~ SERV UNIT SERVICE API API API API FILE I~MB ArOMB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUMB SAMP ELEM CODE (HEX) DEPT FT 500747 O0 000 O0 0 4 1 1 4 68 0000000000 NPHI CNAV PU-S 500747 O0 000 00 0 4 1 1 4 68 0000000000 NRAT CNAV 500747 O0 000 O0 0 4 1 1 4 68 0000000000 CPHI CNAV PU-S 500747 O0 000 00 0 4 1 1 4 68 0000000000 CRATCNAV 500747 O0 000 O0 0 4 I 1 4 68 0000000000 ENPH CNAV PU-S 500747 O0 000 O0 0 4 1 1 4 68 0000000000 ENRA CNAV 500747 O0 000 O0 0 4 1 1 4 68 0000000000 NCNTCNAV CPS 500747 O0 000 O0 0 4 1 1 4 68 0000000000 FCNTCNAV CPS 500747 O0 000 O0 0 4 I 1 4 68 0000000000 CNTC CNAV CPS 500747 O0 000 O0 0 4 1 1 4 68 0000000000 CFTC CNAV CPS 500747 O0 000 O0 0 4 1 1 4 68 0000000000 CNEC CNAV CPS 500747 O0 000 00 0 4 1 1 4 68 0000000000 CFEC CNAV CPS 500747 O0 000 O0 0 4 1 1 4 68 0000000000 GRCH CNTG GAPI 500747 00 000 00 0 4 1 1 4 68 0000000000 ** DATA ** DEPT. 10529.500 NPHI. CNAV 28.826 NRAT. CNAV 2.986 CPHI. CNAV CRAT. CNAV 2.984 ENPH. CNAV 34.632 ENRA. CNAV 5.122 NCNT. CNAV FCNT. CNAV 496.744 CNTC. CNAV 1587.299 CFTC. CNAV 546.665 CNEC. CNAV CFEC. CNAV 479.144 GRCH. CNTG -999.250 27.175 1599.608 2454.213 LIS Tape Verification Listing Schlumberger Alaska Computing Center 19-AUG-1997 13:10 PAGE: 16 DEPT. 10245.500 NPHI. CNAV 22.547 NRAT. CNAV CRAT. CNAV 2.637 ENPH. CNAV 29.996 ENRA.CNAV FCA~F. CNAV 733.788 CA~fC.C-NAV 2061.608 CPTC. CNAV CFEC. CNAV 557.718 GRCH. ClgTG 20.609 2.659 CPHI.CNAV 4.660 NCNT. CNAV 790.498 CNEC. CNAV 22.811 1990.910 2S98.689 ** END OF DATA ** **** FILE TRAILER **** FILE NAME : EDIT .004 SERVICE : FLIC VERSION : O01CO1 DATE : 97/08/19 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : **** FILE HEADER **** FILE NAME : EDIT .005 SERVICE : FLIC VERSION : 001C01 DATE : 97/08/19 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: O . 5000 FILE SU~mL%RY VENDOR TOOL CODE START DEPTH CNTG 10543.5 $ LOG HEADER DATA DATE LOGGED: SOFTWARE VERSION: TIME LOGGER ON BOTTOM: TD DRILLER (FT) : TD LOGGER (FT) : TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT) : LOGGING SPEED (FPHR) : DEPTH CONTROL USED (YES/NO): STOP DEPTH 10243.0 15-MAY-97 CP 42.2 1440 15-MAY-97 10546.0 10535.0 10250.0 10529.0 1800.0 NO LIS Tape Verification Lis=ing Schlumberger Alaska Computing Cen~er 19-AUG-199? 13:10 PAGE: 17 TOOL STRING (TOP TO BOTTOM] VENDOR TOOL CODE TOOL TYPE CNTG COMP. NEUTRON $ TOOL NUM~ER CNC-GB-125 BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN) DRILLERS CASING DEPTH (FT) LOGGERS CASING DEPTH (FT) 10988.0 BOREHOLE CONDITIONS FLUID TYPE: FLUID DENSITY (LB/G): SURFACE T~PERATURE (DEGF) : BOTTOM HOLE T~PERATURE (DEGF): FLUID SALINITY (PPM) : FLUID LEVEL (BT): FLUID RATE AT WELLHEAD (BPM): WATER CUTS (PCT) : GAS~OIL RATIO: CHOKE (DEG) : PUMPED IN CRUDE NEUTRON TOOL TOOL TYPE (EPITHBRMAL OR THERMAL): MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): EP I THERMAL SANDSTONE 2.65 12.500 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): 7000 NEAR COUNT RATE LOW SCALE (CPS): 0 NEAR COUNT RATE HIGH SCALE (CPS): 24000 TOOL STANDOFF (IN): 0.5 P.I~r~%RKS: CORRELATED TO BHCS DATED 10/26/77. MADE 3 PASSES AT 1800 FPH. GOC AT. WELL WAS LOADED WITH DEAD CRUDE. THIS FILE CONTAINS THE RAW CNTG DATA FOR PASS #1. LIS FORMAT DATA LIS Tape Verification Listing Schlumberger Alaska Computing Center 19-AUG-1997 13:10 PAGE: 18 ** DATA FORMAT SPECIFICATION RECORD ** ** SET TYPE - 64EB ** TYPE REPR CODE VALUE 1 66 0 2 66 0 3 73 76 4 66 1 5 66 6 73 7 65 8 68 0.5 9 65 FT 11 66 13 12 68 13 66 14 65 FT 15 66 68 16 66 1 0 66 1 ** SET TYPE ~ CHAN ** NAME SERV UNIT SERVICE API API API API FILE NUMB NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUMB SAMP ELE~ CODE (HEX) FT 500747 O0 000 00 0 5 1 1 4 68 0000000000 DEPT NPHI PS1 PU 500747 O0 000 O0 0 5 1 1 4 68 0000000000 ENPH PS1 PU 500747 O0 ' 000 O0 0 5 1 1 4 68 0000000000 TNPH PS1 PU 500747 00 000 00 0 5 1 1 4 68 0000000000 TNRA PS1 500747 00 000 00 0 5 1 1 4 68 0000000000 RTNR PS1 500747 00 000 00 0 5 1 1 4 68 0000000000 ENRA PS1 500747 00 000 O0 0 5 I 1 4 68 0000000000 CFEC PS1 CPS 500747 00 000 00 0 5 1 1 4 68 0000000000 CNEC PS1 CPS 500747 O0 000 O0 0 5 1 1 4 68 0000000000 RCEF PS1 CPS 500747 00 000 O0 0 5 1 1 4 68 0000000000 RCENPS1 CPS 500747 00 000 O0 0 5 1 1 4 68 0000000000 RCNTPS1 CPS 500747 O0 000 00 0 5 1 1 4 68 0000000000 RCFTPS1 CPS 500747 O0 000 00 0 5 1 1 4 68 0000000000 CNTC PS1 CPS 500747 O0 000 O0 0 5 1 1 4 68 0000000000 CFTC PS1 CPS 500747 O0 000 O0 0 5 1 1 4 68 0000000000 NPOR PS1 PU 500747 00 000 00 0 5 1 1 4 68 0000000000 GR PS1 GAPI 500747 O0 000 00 0 5 1 1 4 68 0000000000 TENS PS1 LB 500747 O0 000 O0 0 5 1 1 4 68 0000000000 CCL PS1 V 500747 00 000 O0 0 5 1 1 4 68 0000000000 ** DATA ** ~. 19-AUG-1997 13:10 PAGE: 19 LIS Tape Verification Listing Schlumberger Alaska Computing Center DEPT. 10543.500 NPHI.PS1 TNRA.PS1 2.817 RTNR.PS1 CNEC. PS1 2486.745 RCEF. PS1 RCFT. PS1 512.706 CNTC. PS1 GR.PS1 26.484 TENS.PSI DEPT. 10243.000 NPHI.PS1 TNRA.PS1 2.827 RTNR.PS1 CNEC. PS1 2564.768 RCEF. PS1 RCFT. PS1 653.420 CNTC. PS1 GR.PS1 25.625 TENS.PSi 25.790 ENPH. PS1 2.863 ENRA.PS1 421.740 RCEN. PS1 1529.003 CFTC. PSi 2235.000 CCL.PS1 25.958 ENPH. PS1 2.861 ENRA.PS1 474.392 RCEN. PS1 2019.072 CFTC. PSi 3010.000 CCL.PS1 39.089 5.537 2224.172 555.539 -0.010 29. 674 4. 627 2281. 595 750. 630 0.103 TNPH. PS1 CFEC. PS1 RCNT. PS1 NPOR.PS1 TNPH. PS1 CFEC. PS1 RCNT. PS1 NPOR.PS1 24.918 449.137 1483.707 24.918 23.999 554.271 1927.078 24.547 ** END OF DATA ** **** FILE TRAILER **** FILE NAME : EDIT .005 SERVICE : FLIC VERSION : 001C01 DATE : 97/08/19 MAX REC SIZE : 1024 FiLE TYPE : LO LAST FILE : **** FILE HEADER **** FILE NAME : EDIT .006 SERVICE : FLIC VERSION : O01CO1 DATE : 97/08/19 MAX REC SIZE : 1024 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 SU~r~RY VENDOR TOOL CODE START DEPTH CNTG 10544.0 $ LOG HEADER DATA DATE LOGGED: SOFTWARE VERSION: STOP DEPTH 10236.5 15-MAY-97 CP 42.2 ~, 19-AUG-1997 13:10 PAGE: 20 LIS Tape Verification Listing Schlumberger Alaska Computing Center TIHE 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): 1440 15-MAY-97 10546.0 10535.0 10250.0 10529.0 1800.0 NO TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE CNTG COMP. NEUTRON $ TOOL NUMBER CNC-GB-125 BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLERS CASING DEPTH (FT): LOGGERS CASING DEPTH (FT) : 10988.0 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) : PUMPED IN CRUDE NEUTRON TOOL TOOL TYPE (EPITHERMAL OR THERMAL): MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): EPITHERMAL SANDSTONE 2.65 12.500 BLUELINE COUNT RATE NORMALIZATION IN OIL ZONE TOP NORMALIZING WINDOW (FT) : BASE NORMALIZING WINDOW (FT): BLUELINE COUNT RATE SCALES SBT BY FIELD ENGINEER FAR COUNT RATE LOW SCALE (CPS): 0 FAR COUNT RATE HIGH SCALE (CPS): 7000 NEAR COUNT RATE LOW SCALE (CPS): 0 NEAR COUNT RATE HIGH SCALE (CPS): 24000 TOOL STANDOFF (IN): 0.5 REMARKS: CORRELATED TO BHCS DATED 10/26/77. MADE 3 PASSES AT 1800 FPH. GOC AT. WELL WAS LOADED WITH DEAD CRUDE. THIS FILE CONTAINS THE RAW CNTG DATA FOR PASS #2. $ LIS Tape Verification Lis~ing Schlumberger Alaska Computing Cen~er 19-AUG-1997 13:10 PAGE: 21 LIS FORMAT DATA ** DATA FORMAT SPECIFICATION RECORD ** ** SET TYPE - 64ES ** TYPE REPR CODE VALUE 1 66 0 2 66 0 3 73 76 4 66 1 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 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 500747 00 000 00 0 6 1 1 4 68 0000000000 NPHI PS2 PU 500747 00 000 O0 0 6 1 1 4 68 0000000000 ENPH PS2 PU 500747 00 000 O0 0 6 1 1 4 68 0000000000 TNPH PS2 PU 500747 O0 000 O0 0 6 1 1 4 68 0000000000 TNRA PS2 500747 O0 000 O0 0 6 1 1 4 68 0000000000 RTNR PS2 500747 00 000 00 0 6 1 1 4 68 0000000000 ENRA PS2 500747 O0 000 O0 0 6 1 1 4 68 0000000000 CFEC PS2 CPS 500747 O0 000 O0 0 6 1 1 4 68 0000000000 CNEC PS2 CPS 500747 00 000 O0 0 6 1 1 4 68 0000000000 RCEF PS2 CPS 500747 00 000 O0 0 6 1 1 4 68 0000000000 RCENPS2 CPS 500747 O0 000 00 0 6 1 1 4 68 0000000000 RCNTPS2 CPS 500747 O0 000 O0 0 6 1 1 4 68 0000000000 RCFTPS2 CPS 500747 00 000 O0 0 6 1 1 4 68 0000000000 CNTC PS2 CPS 500747 O0 000 00 0 6 1 1 4 68 0000000000 CFTC PS2 CPS 500747 O0 000 O0 0 6 1 1 4 68 0000000000 NPOR PS2 PU 500747 00 000 O0 0 6 1 1 4 68 0000000000 GR PS2 GAPI 500747 O0 000 00 0 6 1 1 4 68 0000000000 TENS PS2 LB 500747 00 000 00 0 6 1 1 4 68 0000000000 CCL PS2 V 500747 00 000 00 0 6 1 I 4 68 0000000000 LIS Tape Verification Listing Schlumberger Alaska Computing Center 19-AUG-1997 13:10 PAGB: 22 ** DATA ** DEPT. 10544.000 NPHI.PS2 TNRA.PS2 3.212 RTNR.PS2 CNEC. PS2 2422.898 RCBF. PS2 RCFT. PS2 492.123 CNTC. PS2 GR.PS2 24.891 TENS.PS2 DEPT. 10236.500 NPHI.PS2 TA~RA.PS2 2.940 RTNR.PS2 CNEC. PS2 2614.271 RCEF. PS2 RCFT. PS2 690.542 CNTC. PS2 GR.PS2 54.156 TENS.PS2 32.991 ENPH. PS2 3.264 ENRA . P S2 426. 771 RCEN. PS2 1676.624 CFTC. PS2 2370 . 000 CCL. PS2 28.027 ENPH. PS2 3.108 ENRA.PS2 522.432 RCEN. PS2 1941.460 CFTC. PS2 3025.000 CCL.PS2 36.841 TNPH. PS2 5.331 CFEC. PS2 2167.066 RCNT. PS2 533.237 NPOR.PS2 -0.003 31.428 TNPH. PS2 4.807 CFEC. PS2 2343.897 RCNT. PS2 677.180 NPOR.PS2 0.306 30.857 454.494 1626.955 30.857 26.626 543.899 1945.770 25.510 ** END OF DATA ** **** FILE TRAILER **** FILE NAME : EDIT .006 SERVICE : FLIC VERSION : 001C01 DATE : 97/08/19 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : **** FILE HEADER **** FILE NAME : EDIT .007 SERVICE : FLIC VERSION : O01CO1 DATE : 97/08/19 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : FILE HEADER FILE NUMBER 7 RAW CURVES Curves and log header data for each pass in separate files; raw background pass in last file PASS NUMBER: 3 DEPTH INCR~ENT: 0.5000 FILE SUI4MARY VENDOR TOOL CODE START DEPTH STOP DEPTH CNTG 10543.5 10237.5 $ LOG HEADER DATA LIS Tape Verification Listing Schlumberger Alaska Computing Center 19-AUG-1997 13:10 PAGE: 23 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): 15-MAY-97 CP 42.2 1440 15-MAY-97 10546.0 10535.0 10250.0 10529.0 1800.0 NO TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE CNTG COMP. NEUTRON $ TOOL NUMBER CNC-GB-125 BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLERS CASING DEPTH (FT): LOGGERS CASING DEPTH (FT): 10988.0 BOREHOLE CONDITIONS FLUID TYPE: FLUID DENSITY (LB/G): SURFACE T~PERATURE (DEGF) : BOTTOM HOLE TEMPERATURE (DEGF) : FLUID SALINITY (PPM) : FLUID LEVEL (FT) : FLUID RATE AT WELLHEAD (BPM): WATER CUTS (PCT) : GAS~OIL RATIO: CHOKE (DEG) : PUMPED IN CRUDE NEUTRON TOOL TOOL TYPE (BPITHERMAL OR THERMAL): MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): EPITHERMAL SANDSTONE 2.65 12.500 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): 7000 NEAR COUNT RATE LOW SCALE (CPS): 0 NEAR COUNT RATE HIGH SCALE (CPS): 24000 TOOL STANDOFF (IN): 0.5 R~ARKS: CORRELATED TO BHCS DATED 10/26/77. MADE 3 PASSES AT 1800 FPH. GOC AT. WELL WAS LOADED WITH DEAD CRUDE. THIS FILE CONTAINS THE RAW CNTG DATA FOR PASS #3. LIS Tape Verification Lis~ing Schlumberger Alaska Computing Cen=er 19-AUG-1997 13:10 PAGE: 24 LIS FORMAT DATA ** DATA FORMAT SPECIFICATION RECORD ** ** SET TYPE- 64BE ** TYPE REPR CODE VALUE 1 66 0 2 66 0 3 73 76 4 66 1 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 1 0 66 1 ** SET TYPE - CHAN ** NAME SERV UNIT SERVICE API API API API FILE NUMB NUMB SIZE REPR PROCESS ID ORDER # LO~ TYPE CI.~.SS MODNUMB SAMP EL:I~ CODE (HEX) DEPT FT 500747 00 000 00 0 7 1 1 4 68 0000000000 NPHI PS3 PU 500747 00 000 00 0 7 1 1 4 68 0000000000 ENPH PS3 PU 500747 O0 000 O0 0 7 1 1 4 68 0000000000 TNPH PS3 PU 500747 00 000 O0 0 7 1 1 4 68 0000000000 TNRA PS3 500747 00 000 O0 0 7 1 1 4 68 0000000000 RTNR PS3 500747 00 000 00 0 7 1 1 4 68 0000000000 ENRA PS3 500747 O0 000 O0 0 7 1 1 4 68 0000000000 CFEC PS3 CPS 500747 O0 000 00 0 7 1 1 4 68 0000000000 CNEC PS3 CPS 500747 O0 000 00 0 7 1 1 4 68 0000000000 RCEF PS3 CPS 500747 O0 000 00 0 7 1 1 4 68 0000000000 RCENPS3 CPS 500747 O0 000 00 0 7 1 1 4 68 0000000000 RCNTPS3 CPS 500747 O0 000 O0 0 7 1 1 4 68 0000000000 RCFT PS3 CPS 500747 O0 000 00 0 7 1 I 4 68 0000000000 CNTC PS3 CPS 500747 O0 000 O0 0 7 I 1 4 68 0000000000 CFTC PS3 CPS 500747 O0 000 00 0 7 1 1 4 68 0000000000 NPOR PS3 PU 500747 O0 000 O0 0 7 1 1 4 68 0000000000 GR PS3 GAPI 500747 00 000 00 0 7 1 1 4 68 0000000000 TENS PS3 LB 500747 O0 000 00 0 7 1 I 4 68 0000000000 CCL PS3 V 500747 00 000 00 0 7 1 1 4 68 0000000000 LIS Tape Verification Listing Schlumberger Alaska Computing Center 19-AUG-1997 13:10 PAGE: 25 ** DATA ** DEPT. 10543.500 NPHI.PS3 26.493 ENPH. PS3 39.674 TNPH. PS3 TNRA.PS3 2.856 RTITR.PS3 2.902 ENRA.PS3 5.589 CFBC. PS3 CNEC. PS3 2513.493 RCBF. PS3 422.270 RCEN. PS3 2248.095 RCNT. PS3 RCFT. PS3 513.351 CNTC. PS3 1552.292 CFTC. PS3 556.238 NPOR.PS3 GR.PS3 22.859 TENS.PS3 2565.000 CCL.PS3 -0.009 DEPT. 10237.500 NPHI.PS3 28.434 ENPH. PS3 31.603 TNPH. PS3 TNRA. PS3 2.962 RTNR.PS3 2.870 ENRA.PS3 4.824 CFEC. PS3 CNEC. PS3 2606.916 RCEF. PS3 530.524 RCEN. PS3 2323.232 RCNT. PS3 RCFT. PS3 628.391 CNTC. PS3 2011.838 CFTC. PS3 694.175 NPOR.PS3 GR.PS3 29.906 TENS.PS3 3040.000 CCL.PS3 0.091 25.487 449.701 1506.306 25.487 27.094 540.384 2012.728 26.028 ** END OF DATA ** **** FILE TRAILER **** FILE NAME : EDIT .007 SERVICE : FLIC VERSION : O01CO1 DATE : 97/08/19 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : **** TAPE TRAILER **** SERVICE NAME : EDIT DATE : 97/08/19 ORIGIN : FLIC TAPE NAME : 97357 CONTINUATION # : 1 PREVIOUS TAPE : COI4~ENT : ARCO ALASKA INC., PRUDHOE BAY, D.S. 1-11, API# 50-029-20268-00 **** REEL TRAILER **** SERVICE NAME : EDIT DATE : 97/08/19 ORIGIN : FLIC REEL NAME : 97357 CONTINUATION # : PREVIOUS REEL : CObt~ENT : ARCO ALASKA INC., PRUDHOE BAY, D.S. 1-11, API# 50-029-20268-00 * ALASKA COMPUTING CENTER * * * ****************************** * ............................ * * ....... SCHLUMBERGER ....... * * ............................ * ****************************** COMPANY NAME : ARCO ALASKA INC. WELL NAME : D.S. 1 - 11 FIELD NAME : PRUDHOE BAY BOROUGH : NORTH SLOPE STATE : ALASKA API NUMBER : 500292026800 REFERENCE NO : 96103 RECEIVED dUN 1;3 ~996 Nml(a 011 & ~ Cons. Ca~Jniofl LIS Tape Verification Listing Schlumberger Alaska Computing Center Il-JUN-1996 10:14 PAGE: 1 **** REEL HEADER **** SERVICE NAME : EDIT DATE : 96/06/11 ORIGIN : FLIC REEL NAME : 96103 CONTINUATION # : PREVIOUS REEL : COMMENT : ARCO ALASKA INC, D.S. 1-11, PRUDHOE BAY, 50-029-20268-00 **** TAPE HEADER **** SERVICE NAME : EDIT DATE : 96/06/11 ORIGIN : FLIC TAPE NAME : 96103 CONTINUATION # : 1 PREVIOUS TAPE : COF~4ENT : ARCO ALASKA INC, D.S. 1-11, PRUDHOE BAY, 50-029-20268-00 TAPE HEADER PRUDHOE BAY CASED HOLE WIRELINE LOGS WELL NAME: D.S. 1 - 11 API NUMBER: 500292026800 OPERATOR: ARCO ALASKA INC. LOGGING COMPANY: SCHLUMBERGER WELL SERVICES TAPE CREATION DATE: il-JUN~96 JOB NUMBER: 96103 LOGGING ENGINEER: G. JOHNSON OPERATOR WITNESS: S. WYSOCKI SURFACE LOCATION SECTION: 8 TOWNSHIP: 1 ON RANGE: 1SE FNL: FSL: 898 FEL: 777 FWL: ELEVATION (FT FROM MSL O) KELLY BUSHING: 73. O0 DERRICK FLOOR: 72. O0 GROUND LEVEL: 34. O0 WELL CASING RECORD OPEN HOLE CASING DRILLERS CASING BIT SIZE (IN) SIZE (IN) DEPTH (FT) WEIGHT (LB/FT) 1ST STRING 9. 625 10988.0 47. O0 2ND STRING 5. 500 9894.0 17. O0 3RD STRING 4. 500 10024.0 12.60 PRODUCTION STRING CURVE SHIFT DATA - ALL PASSES TO STANDARD(MEASURED DEPTH) LIS Tape Verification Listing Schlumberger Alaska Computing Center il-JUN-1996 10:14 BASELINE CURVE FOR SHIFTS LDWG TOOL CODE: BCS LDWG CURVE CODE: GR RUN NUMBER: 1 PASS NUMBER: 1 DATE LOGGED: 10/26/77 LOGGING COMPANY: SCHLUMBERGER WELL SERVICES BASELINE DEPTH 88888.0 10476 5 10455 0 10445 5 10431 0 10415 0 10407 5 10398 0 10372.5 10368.5 10358.0 10347.5 10342.0 10330.0 10303.5 10284.0 10279.0 10269.0 100.0 $ .......... EQUIVALENT UNSHIFTED DEPTH .......... 88887.5 10476.0 10454.5 10444.5 10429.5 10414.5 10407.0 10396.5 10371.5 10366.5 10357.5 10347.0 10341.0 10329.5 10302.5 10282.5 10278.0 10268.0 99.0 REMARKS: The depth adjustments shown above reflect cased hole GR to open hole ECS GR and cased hole SIGM to open hole GR. Ail other TDTP curves were carried with the SIGM shifts. $ $ PAGE: **** FILE HEADER **** FILE NAME : EDIT .001 SERVICE : FLIC VERSION : O01CO1 DATE : 96/06/11 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 INCR~ENT: 0.5000 LIS Tape Verification Listing Schlumberger Alaska Computing Center Il-JUN-1996 10:14 PAGE: FILE SUMMARY LDWG TOOL CODE START DEPTH STOP DEPTH TDTP 10535.0 10248.0 CURVE SHIFT DATA - PASS TO PASS (MEASURED DEPTH) BASELINE CURVE FOR SHIFTS LDWG CURVE CODE: NONE PASS NUMBER: BASELINE DEPTH $ .......... EQUIVALENT UNSHIFTED DEPTH .......... TDTP R~MARKS: This file contains TDTP Pass #1 (Base Pass #1). pass to pass shifts were applied to this data. $ LIS FORMAT DATA No ** DATA FORMAT SPECIFICATION RECORD ** ** SET TYPE - 64EB ** TYPE REPR CODE VALUE 1 66 0 2 66 0 3 73 96 4 66 1 5 66 6 73 7 65 8 68 0.5 9 65 FT 11 66 10 12 68 13 66 0 14 65 FT 15 66 68 16 66 1 0 66 0 LIS Tape Verification Lis~ing Schlumberger Alaska Computing Center il-JUN-1996 10:14 PAGE: ** SET TYPE - CHAN ** NAME SERV UNIT SERVICE API API API API FILE NUMB NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUMB SAMP EL~4 CODE (HEX) ....................................................................................... DEPT O0 000 O0 0 1 1 1 4 68 0000000000 FT 500347 SIGM TDTP CU 500347 O0 000 O0 0 1 1 1 4 68 TPHI TDTP PU-S 500347 O0 000 O0 0 1 1 1 4 68 SBHF TDTP CU 500347 O0 000 O0 0 1 1 1 4 68 SBHN TDTP CU 500347 O0 000 O0 0 1 1 1 4 68 SIGC TDTP CU 500347 O0 000 O0 0 1 1 1 4 68 SIBH TDTP CU 500347 00 000 O0 0 1 1 1 4 68 TRAT TDTP 500347 O0 000 O0 0 1 1 1 4 68 LCO1 TDTP 500347 O0 000 O0 0 1 1 1 4 68 SDSI TDTP CU 500347 O0 000 O0 0 1 1 1 4 68 BACK TDTP CPS 500347 O0 000 O0 0 1 1 1 4 68 FBAC TDTP CPS 500347 O0 000 O0 0 1 1 1 4 68 TCAN TDTP CPS 500347 O0 000 O0 0 1 1 1 4 68 TCAF TDTP CPS 500347 O0 000 O0 0 1 1 1 4 68 TCND TDTP CPS 500347 00 000 O0 0 1 1 1 4 68 TCFD TDTP CPS 500347 O0 000 O0 0 1 1 1 4 68 TSCN TDTP CPS 500347 O0 000 O0 0 1 1 1 4 68 TSCF TDTP CPS 500347 O0 000 O0 0 1 1 1 4 68 INND TDTP CPS 500347 O0 000 O0 0 1 1 1 4 68 INFD TDTP CPS 500347 00 000 O0 0 1 1 1 4 68 GRCH TDTP GAPI 500347 O0 000 O0 0 1 1 1 4 68 TENS TDTP LB 500347 O0 000 O0 0 1 1 1 4 68 CCL TDTP V 500347 O0 000 O0 0 1 1 1 4 68 GR ECS GAPI 500347 O0 000 O0 0 1 1 1 4 68 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 ** DATA ** DEPT. SBHN. TDTP LCO1. TDTP TCAN. TDTP TSCN. TDTP GRCH. TDTP DEPT. SBHN. TDTP LCO1. TDTP TCAN. TDTP TSCN. TDTP GRCH. TDTP DEPT. SBHN. TDTP LCO1. TDTP TCAN. TDTP TSCN. TDTP GRCH. TDTP 10540 000 -999 250 -999 250 -999 250 -999 250 -999 250 10450.000 36.832 2.359 33385.000 6750.000 17.953 10235.000 -999.250 -999.250 -999.250 -999.250 -999.250 SIGM. TDTP -999.250 TPHI. TDTP -999.250 SBHF. TDTP SIGC. TDTP -999. 250 SIBH. TDTP -999. 250 TRAT. TDTP SDSI. TDTP -999.250 BACK. TDTP -999.250 FBAC. TDTP TCAF. TDTP -999.250 TCND. TDTP -999.250 TCFD. TDTP TSCF. TDTP -999.250 INND. TDTP -999.250 INFD. TDTP TENS. TDTP -999.250 CCL. TDTP -999.250 GR.BCS SIGM. TDTP 16.132 TPHI. TDTP 25. 649 SBHF. TDTP SIGC. TDTP 2. 262 SIBH. TDTP 36. 832 TRAT. TDTP SDSI. TDTP O. 456 BACK. TDTP 36. 072 FBAC. TDTP TCAF. TDTP 14150. 500 TCND. TDTP 22197. 625 TCFD. TDTP TSCF. TDTP 2861.250 INND. TDTP 1497 . 875 INFD. TDTP TENS. TDTP 1510. 000 CCL. TDTP O. 000 GR.BCS SIGM. TDTP -999.250 TPHI. TDTP -999.250 SBHF. TDTP SIGC. TDTP -999. 250 SIBH. TDTP -999. 250 TRAT. TDTP SDSI. TDTP -999.250 BACK. TDTP -999.250 FBAC. TDTP TCAF. TDTP -999.250 TCND. TDTP -999.250 TCFD. TDTP TSCF. TDTP -999.250 INND. TDTP -999.250 INFD. TDTP TENS. TDTP -999.250 CCL. TDTP -999.250 GR.BCS -999.250 -999.250 -999.250 -999.250 -999.250 31.780 30.379 1. 735 9. 511 7858.500 350.219 51.608 -999.250 -999.250 -999.250 -999.250 -999.250 231.718 LIS Tape Verification Listing Schlumberger Alaska Computing Center il-JUN-1996 10:14 PAGE: ** END OF DATA ** **** FILE TRAILER **** FILE NAME : EDIT .001 SERVICE : FLIC VERSION : O01CO1 DATE : 96/06/11 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : **** FILE HEADER **** FILE NAME : EDIT .002 SERVICE : FLIC VERSION : O01CO1 DATE : 96/06/11 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : FILE HEADER FILE NU~fBER: 2 EDITED CURVES Depth shifted and clipped curves for each pass in separate files. PASS NUMBER: 2 DEPTH INCR~ENT: 0.5000 FILE SUMMARY LDWG TOOL CODE START DEPTH STOP DEPTH TDTP 10536.0 10248.0 $ CURVE SHIFT DATA - PASS TO PASS (MEASURED DEPTH) BASELINE CURVE FOR SHIFTS LDWG CURVE CODE: GR PASS NUMBER: 1 .......... EQUIVALENT UNSHIFTED DEPTH .......... BASELINE DEPTH GR TDTP 88888.0 88889.0 88888.5 10525.5 10526.0 10521,5 10522.0 10517.5 10517.5 10513.5 10514,5 10509.5 10509.5 LIS Tape Verification Listing Schlumberger Alaska Computing Center il-JUN-1996 10:14 PAGB: 10505.5 10506.0 10501.5 10502.0 10497.5 10498.5 10495.5 10496.5 10493.5 10494.5 10489.5 10490.0 10487.5 10488.5 10483.5 10484.0 10479.5 10480.5 10473.5 10474.0 10469.5 10469.5 10463.5 10464.5 10461.5 10461.5 10459.5 10460.0 10457.5 10458.0 10455.5 10456.5 10453.5 10454.0 10449.5 10449.5 10441.5 10441.5 10439.5 10440.5 10437.5 10437.0 10435.5 10436.0 10429.5 10429.0 10427.5 10428.0 10425.5 10426.5 10423.5 10424.5 10421.5 10422.0 10419.5 10420.0 10415.5 10415.5 10411.5 10411.5 10409.5 10410.0 10407.5 10407.0 10405.5 10405.5 10403.5 10404.0 10401.5 10401.5 10399.5 10400.0 10397.5 10397.0 10395.5 10396.5 10393.5 10392.5 10391.5 10392.0 10385.5 10384.5 10381.5 10381.5 10377.5 10377.0 10371.5 10372.0 10369.5 10369.0 10367.5 10368.5 10365.5 10364 · 5 10363.5 10364.0 10361.5 10361.0 10359.5 10360.5 10357.5 10357.5 10355.5 10356.0 10353.5 10353.0 10351.5 10352.0 10349.5 10349.5 LIS Tape Verification Listing Schlumberger Alaska Computing Center Il-JUN-1996 10:14 PAGE: 10347.5 10348.5 10343.5 10344.0 10325.5 10325.5 10321.5 10323.0 10317.5 10318.0 10313.5 10314.0 10311.5 10312.0 10309.5 10309.5 10307.5 10308.5 10305.5 10305.5 10301.5 10301.0 10299.5 10300.5 10295.5 10296.0 10293.5 10293.0 10291.5 10292.5 10289.5 10288.5 10287.5 10288.0 10281.5 10280.5 10277.5 10277.0 10273.5 10272.5 10269.5 10269.0 100.0 100,5 99.5 $ REMARKS: This file contains TDTP Pass #2 (Base 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 ** 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 1 LIS Tape Verification Listing Schlumberger Alaska Computing Center il-JUN-1996 10:14 PAGE: TYPE REPR CODE VALUE .............................. 0 66 1 .............................. ** SET TYPE - CHAN ** ....................................................................................... NAME SERV UNIT SERVICE API API API API FILE NUMB NUMB SIZE REPR PROCESS ID ORDER # LOG TYPB CLASS MOD NUMB SAMP ELD CODE (HEX) DEPT FT 500347 O0 000 O0 0 2 1 1 4 68 0000000000 SIGM TDTP CU 500347 O0 000 O0 0 2 1 1 4 68 0000000000 TPHI TDTP PU-S 500347 O0 000 O0 0 2 1 1 4 68 0000000000 SBHF TDTP CU 500347 O0 000 O0 0 2 1 1 4 68 0000000000 SBHNTDTP CU 500347 O0 000 O0 0 2 1 1 4 68 0000000000 SIGC TDTP CU 500347 O0 000 O0 0 2 1 1 4 68 0000000000 SIBH TDTP CU 500347 O0 000 O0 0 2 1 1 4 68 0000000000 TRAT TDTP 500347 O0 000 O0 0 2 1 1 4 68 0000000000 LCO1 TDTP 500347 O0 000 O0 0 2 1 1 4 68 0000000000 SDSI TDTP CU 500347 O0 000 O0 0 2 1 1 4 68 0000000000 BACK TDTP CPS 500347 O0 000 O0 0 2 1 1 4 68 0000000000 FBAC TDTP CPS 500347 O0 000 O0 0 2 1 1 4 68 0000000000 TCANTDTP CPS 500347 O0 000 O0 0 2 1 1 4 68 0000000000 TCAF TDTP CPS 500347 O0 000 O0 0 2 1 1 4 68 0000000000 TCND TDTP CPS 500347 O0 000 O0 0 2 1 1 4 68 0000000000 TCFD TDTP CPS 500347 O0 000 O0 0 2 1 1 4 68 0000000000 TSCN TDTP CPS 500347 O0 000 O0 0 2 1 1 4 68 0000000000 TSCF TDTP CPS 500347 O0 000 O0 0 2 1 1 4 68 0000000000 INND TDTP CPS 500347 O0 000 O0 0 2 1 1 4 68 0000000000 INFD TDTP CPS 500347 O0 000 O0 0 2 1 1 4 68 0000000000 GRCH TDTP GAPI 500347 O0 000 O0 0 2 1 1 4 68 0000000000 TENS TDTP LB 500347 O0 000 O0 0 2 1 1 4 68 0000000000 CCL TDTP V 500347 O0 000 O0 0 2 1 1 4 68 0000000000 ** DATA ** DEPT. 10536.500 SIGM. TDTP 13.898 TPHI. TDTP 20.520 SBHF. TDTP SBHN. TDTP 36. 900 SIGC. TDTP 2. 562 SIBH. TDTP 36. 900 TRAT. TDTP LCOi. TDTP 2.167 SDSI. TDTP 0.474 BACK. TDTP -999.250 FBAC. TDTP TCAN. TDTP 35539. 883 TCAF. TDTP 16402. 551 TCND. TDTP -999.250 TCFD. TDTP TSCN. TDTP 7335.497 TSCF. TDTP 3385.517 INND. TDTP -999.250 INFD. TDTP GRCH. TDTP -999.250 TENS. TDTP 1350. 000 CCL. TDTP O. 000 DEPT. 10450. 000 SIGM. TDTP 15. 637 TPHI. TDTP 25. 369 SBHF. TDTP SBHN. TDTP 40.502 SIGC. TDTP 2. 474 SIBH. TDTP 40.502 TRAT. TDTP LCO1 . TDTP 2. 365 SDSI. TDTP 0. 442 BACK. TDTP 67. 986 FBAC. TDTP TCAN. TDTP 34033.000 TCAF. TDTP 14392.000 TCND. TDTP 21710.000 TCFD. TDTP TSCN. TDTP 6630.000 TSCF. TDTP 2803.875 INND. TDTP 1461.152 INFD. TDTP GRCH. TDTP 30. 484 TENS. TDTP 1484 . 445 CCL. TDTP O. 000 26.034 1.635 -999.250 -999.250 -999.250 31.488 1.742 15.614 7728.625 342.523 LIS Tape Verification Listing Schlumberger Alaska Computing Center Il-JUN-1996 10:14 PAGE: DEPT. 10247. 500 SIGM. TDTP 15. 033 TPHI. TDTP 21 . 799 SBHF. TDTP SBHN. TDTP 38.163 SIGC. TDTP 2.211 SIBH. TDTP 38.163 TRAT. TDTP LCO1. TDTP 2.202 SDSI. TDTP 0. 451 BACK. TDTP 77. 997 FBAC. TDTP TCAN. TDTP 35069. 680 TCAF. TDTP 15922. 902 TCND. TDTP 22314 . 902 TCFD. TDTP TSCN. TDTP 6962 . 434 TSCF. TDTP 3161.197 INND. TDTP 1395 . 449 INFD. TDTP GRCH. TDTP -999. 250 TENS. TDTP 1480. 000 CCL. TDTP O. 000 26.581 1. 645 16. 935 8296. 367 366.383 ** END OF DATA ** **** FILE TRAILER **** FILE NAME : EDIT .002 SERVICE : FLIC VERSION : O01CO1 DATE : 96/06/11 MAX REC SIZE : 1024 FILB TYPE : LO LAST FILE : **** FILE HEADER **** FILE NAME : EDIT .003 SERVICE : FLIC VERSION : O01CO1 DATE : 96/06/11 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : FILE HEADER FILE NUMBER: 3 EDITED CURVES Depth shifted and clipped curves for each pass in separate files. PASS NUMBER: 3 DEPTH INCR~ENT: 0,5000 FILE SUMMARY LDWG TOOL CODE START DEPTH STOP DEPTH TDTP 10536.0 10248.0 $ CURVE SHIFT DATA - PASS TO PASS (MEASURED DEPTH) BASELINE CURVE FOR SHIFTS LDWG CURVE CODE: GR PASS NUMBER: 1 .......... EQUIVALENT UNSHIFTED DEPTH .......... BASELINE DEPTH GR TDTP LIS Tape Verification Listing Schlumberger Alaska Computing Center il-JUN-1996 10:14 PAGE: 10 88888.0 10525.5 10521.5 10517.5 10513.5 10501.5 10499.5 10497.5 10493.5 10491.5 10489.5 10485.5 10481.5 10477.5 10469.5 10465.5 10449.5 10447.5 10445.5 10443.5 10439.5 10435.5 10425.5 10421 5 10419 5 10417 5 10415 5 10407 5 10405 5 10403 5 10401 5 10399 5 10395 5 10385 5 10381 5 10377 5 10373 5 10369 5 10367 5 10365 5 10363 5 10361 5 10357 5 10353 5 10351 5 10349 5 10347 5 10345 5 10341 5 10337.5 10333.5 10329.5 10327.5 10325.5 10323,5 88888.5 10500.0 10492.5 10448.5 10445.0 10441.0 10436.5 10420.5 10417.0 10409.0 10404.5 10401.0 10396.5 10368.5 10365.0 10353.0 10348.5 10328.5 10325.0 88888.5 10526.0 10522.0 10517.5 10514.5 10502.5 10499.0 10494.5 10490.5 10486.0 10483.0 10478.5 10470.5 10466.0 10450.0 10445.5 10425.5 10422.0 10418.5 10406.5 10401.0 10385.0 10382.0 10377.5 10373.0 10369.5 10364.5 10361.5 10357.5 10354.0 10350.5 10346.0 10341.5 10338.0 10334.0 10330.5 10326.5 LIS Tape Verification Listing Schlumberger Alaska Computing Center il-JUN-1996 10:14 PAGE: 11 10321.5 10323.0 10319.5 10320.5 10317.5 10318.5 10315.5 10317.0 10305.5 10306.5 10301.5 10302.0 10299.5 10302.0 10297.5 10298 . 5 10295.5 10297.5 10293 . 5 10294 . 5 10291.5 10293.0 10289.5 10289.5 10287.5 10289.5 10283.5 10285.0 10275.5 10277.0 10271 . 5 10272.5 10269.5 10269.5 10265.5 10266.0 100.0 101.0 100,5 $ REMARKS: This file contains TDTP Pass #3 (Base Pass #3). The depth shifts shown above relect GRCH Pass #3 to GRCH Pass #1 and SIGM Pass #3 to SIGM Pass #1. $ LIS FORMAT DATA ** 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 Il-JUN-1996 10:14 PAGE: 12 ** SET TYPE - CHAN ** ....................................................................................... NAME SERV UNIT SERVICE API API API API FILE NUMB NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUMB SAMP ELE~ CODE (HEX) DEPT FT 500347 SIGM TDTP CU 500347 TPHI TDTP PU-S 500347 SBHF TDTP CU 500347 SEHN TDTP CU 500347 SIGC TDTP CU 500347 SIBH TDTP CU 500347 TRAT TDTP 500347 LCO1 TDTP 500347 SDSI TDTP CU 500347 BACK TDTP CPS 500347 FBAC TDTP CPS 500347 TCAN TDTP CPS 500347 TCAF TDTP CPS 500347 TCND TDTP CPS 500347 TCFD TDTP CPS 500347 TSCN TDTP CPS 500347 TSCF TDTP CPS 500347 INND TDTP CPS 500347 INFD TDTP CPS 500347 GRCH TDTP GAPI 500347 TENS TDTP LB 500347 CCL TDTP V 500347 O0 000 O0 0 3 1 1 4 68 0000000000 O0 000 O0 0 3 1 1 4 68 0000000000 O0 000 O0 0 3 1 1 4 68 0000000000 O0 000 O0 0 3 1 1 4 68 0000000000 O0 000 O0 0 3 1 1 4 68 0000000000 O0 000 O0 0 3 1 1 4 68 0000000000 O0 000 O0 0 3 1 1 4 68 0000000000 O0 000 O0 0 3 1 1 4 68 0000000000 O0 000 O0 0 3 1 1 4 68 0000000000 O0 000 O0 0 3 1 1 4 68 0000000000 O0 000 O0 0 3 1 1 4 68 0000000000 O0 000 O0 0 3 1 1 4 68 0000000000 O0 000 O0 0 3 1 1 4 68 0000000000 O0 000 O0 0 3 1 1 4 68 0000000000 O0 000 O0 0 3 1 1 4 68 0000000000 O0 000 O0 0 3 1 1 4 68 0000000000 O0 000 O0 0 3 1 1 4 68 0000000000 O0 000 O0 0 3 1 1 4 68 0000000000 O0 000 O0 0 3 1 1 4 68 0000000000 O0 000 O0 0 3 1 1 4 68 0000000000 O0 000 O0 0 3 1 1 4 68 0000000000 O0 000 O0 0 3 1 1 4 68 0000000000 O0 000 O0 0 3 1 1 4 68 0000000000 ** DATA ** DEPT. 10536. 500 SIGM. TDTP 13 SBHN. TDTP 40. 053 SIGC. TDTP 2 LCO1. TDTP 2.182 SDSI. TDTP 0 TCAN. TDTP 36670.102 TCAF. TDTP 16809 TSCN. TDTP 7284. 213 TSCF. TDTP 3339 GRCH. TDTP -999. 250 TENS. TDTP 1400 DEPT. 10450. 000 SIGM. TDTP 15 SBHN. TDTP 38. 719 SIGC. TDTP 2 LCO1 . TDTP 2.384 SDSI. TDTP 0 TCAN. TDTP 34161. 820 TCAF. TDTP 14330 TSCN. TDTP 6767. 601 TSCF. TDTP 2838 GRCH. TDTP 39.125 TENS. TDTP 1520 DEPT. 10246. 500 SIGM. TDTP 13 SBHN. TDTP 37. 590 SIGC. TDTP 2 LCO1. TDTP 2.186 SDS I . TDTP 0 TCAN. TDTP 35844. 938 TCAF. TDTP 16400 TSCN. TDTP 7300. 978 TSCF. TDTP 3340 GRCH. TDTP -999. 250 TENS. TDTP 1630 531 TPHI. TDTP 430 SIBH. TDTP 394 BACK. TDTP 570 TCND . TDTP 083 INND. TDTP 000 CCL. TDTP 20 377 40 053 -999 250 -999 250 -999 250 0 000 877 TPHI. TDTP 26. 225 257 SIBH. TDTP 38. 719 481 BACK. TDTP 82. 433 479 TCND. TDTP 21875. 938 929 INND, TDTP 1390. 255 000 CCL. TDTP O . 000 881 TPHI. TDTP 550 SIBH. TDTP 421 BACK. TDTP 699 TCND. TDTP 531 INND. TDTP 000 CCL. TDTP 20 930 37 590 93 896 22598 344 1464 031 0 000 SBHF. TDTP TRAT. TDTP FBAC. TDTP TCFD. TDTP INFD. TDTP SBHF. TDTP TRAT. TDTP FBAC. TDTP TCFD. TDTP INFD. TDTP SBHF. TDTP TRAT. TDTP FBAC. TDTP TCFD. TDTP INFD. TDTP 29.356 1. 640 -999.250 -999.250 - 999. 250 33.144 1.761 18.891 7779.569 343.182 28.293 1.649 21.165 8493.779 338.215 LIS Tape Verification Listing Schlumberger Alaska Computing Center Il-JUN-1996 10:14 PAGE: 13 ** END OF DATA ** **** FILE TRAILER **** FILE NAME : EDIT .003 SERVICE : FLIC VERSION : O01CO1 DATE : 96/06/11 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : **** FILE HEADER **** FILE NAME : EDIT .004 SERVICE : FLIC VERSION : O01CO1 DATE : 96/06/11 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : FILE HEADER FILE NUMBER: 4 EDITED CURVES Depth shifted and clipped curves for each pass in separate files. PASS NUMBER: 4 DEPTH INCR~ENT : O . 5000 FILE SUMMARY LDWG TOOL CODE START DEPTH STOP DEPTH TDTP 10538.0 10247.0 $ CURVE SHIFT DATA - PASS TO PASS (MEASURED DEPTH) BASELINE CURVE FOR SHIFTS LDWG CURVE CODE: GR PASS NUMBER: 1 .......... EQUIVALENT UNSHIFTEDDEPTH .......... BASELINE DEPTH TDTP 88888.0 88889.5 10491.5 10493.0 10459.5 10461.0 10455.5 10456.5 10451.5 10453.0 10439.5 10441.0 LIS Tape Verification Listing Schlumberger Alaska Computing Center il-JUN-1996 10:14 PAGE: 14 10435.5 10437.5 10419.5 10421.5 10415.5 10417.0 10379.5 10381.0 10375.5 10376.5 10367.5 10368.5 10363.5 10365.0 10335.5 10337.0 10331.5 10332.5 10315.5 10316.5 10299.5 10301.0 100.0 101.5 $ R~W_ARKS: This file contains Borax Pass #1 of the TDTP. The depth adjustments shown above reflect Borax Pass #1GRCH to Base Pass #1 GRCH and Borax Pass #1 SIGMA to Base Pass #1 SIGMA. Ail other TDTP curves were carried with the SIGMA shifts. $ LIS FORMAT DATA ** 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 Il-JUN-1996 10:14 PAGE: 15 ** 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 EL~ CODE (HEX) DEPT FT 500347 O0 000 O0 0 4 1 1 4 68 0000000000 SIGM TDTP CU 500347 O0 000 O0 0 4 1 1 4 68 0000000000 TPHI TDTP PU-S 500347 O0 000 O0 0 4 1 1 4 68 0000000000 SBHF TDTP CU 500347 O0 000 O0 0 4 1 1 4 68 0000000000 SBHN TDTP CU 500347 O0 000 O0 0 4 1 1 4 68 0000000000 SIGC TDTP CU 500347 O0 000 O0 0 4 1 1 4 68 0000000000 SIBH TDTP CU 500347 O0 000 O0 0 4 1 1 4 68 0000000000 TRAT TDTP 500347 O0 000 O0 0 4 1 1 4 68 0000000000 LCO1 TDTP 500347 O0 000 O0 0 4 1 1 4 68 0000000000 SDSI TDTP CU 500347 O0 000 O0 0 4 1 1 4 68 0000000000 BACK TDTP CPS 500347 O0 000 O0 0 4 1 1 4 68 0000000000 FBAC TDTP CPS 500347 O0 000 O0 0 4 1 1 4 68 0000000000 TCANTDTP CPS 500347 O0 000 O0 0 4 1 1 4 68 0000000000 TCAF TDTP CPS 500347 O0 000 O0 0 4 1 1 4 68 0000000000 TCND TDTP CPS 500347 O0 000 O0 0 4 1 1 4 68 0000000000 TCFD TDTP CPS 500347 O0 000 O0 0 4 1 1 4 68 0000000000 TSCN TDTP CPS 500347 O0 000 O0 0 4 1 1 4 68 0000000000 TSCF TDTP CPS 500347 O0 000 O0 0 4 1 1 4 68 0000000000 INND TDTP CPS 500347 O0 000 O0 0 4 1 1 4 68 0000000000 INFD TDTP CPS 500347 O0 000 O0 0 4 1 1 4 68 0000000000 GRCH TDTP GAPI 500347 O0 000 O0 0 4 1 1 4 68 0000000000 TENS TDTP LB 500347 O0 000 O0 0 4 1 1 4 68 0000000000 CCL TDTP V 500347 O0 000 O0 0 4 1 1 4 68 0000000000 ** DATA ** DEPT. 10538.000 SIGM. TDTP 14.278 TPHI. TDTP 14..139 SBHF. TDTP SBHN. TDTP 80. 726 SIGC. TDTP 0. 892 SIBH. TDTP 113.105 TRAT. TDTP LCO1. TDTP 1. 650 SDSI. TDTP O. 490 BACK. TDTP -999. 250 FBAC. TDTP TCAN. TDTP 14163.197 TCAF. TDTP 8582. 334 TCND. TDTP -999. 250 TCFD. TDTP TSCN. TDTP 2832.695 TSCF. TDTP 1716.500 INND. TDTP -999.250 INFD. TDTP GRCH. TDTP -999.250 TENS. TDTP 1325. 000 CCL. TDTP O. 000 DEPT. 10450. 000 SIGM. TDTP 15. 423 TPHI. TDTP 20. 208 SBHF. TDTP SBHN. TDTP 83. 633 SIGC. TDTP O. 231 SIBH. TDTP 124. 497 TRAT. TDTP LCO1 . TDTP 1. 867 SDSI. TDTP O . 424 BACK. TDTP 63. 809 FBAC. TDTP TCAN. TDTP 14243.324 TCAF. TDTP 7630.961 TCND. TDTP 10070.787 TCFD. TDTP TSCN. TDTP 2846. 426 TSCF. TDTP 1524 . 993 INND. TDTP 1411 . 861 INFD. TDTP GRCH. TDTP 35. 438 TENS. TDTP 1580. 000 CCL. TDTP O. 000 DEPT. 10247. 000 SIGM. TDTP 14.122 TPHI. TDTP 18.278 SBHF. TDTP SBHN. TDTP 86. 673 SIGC. TDTP O. 065 SIBH. TDTP 128. 786 TRAT. TDTP LCOI . TDTP 1. 801 SDSI. TDTP O. 358 BACK. TDTP 75. 744 FBAC. TDTP TCAN. TDTP 17624.277 TCAF. TDTP 9784. 313 TCND. TDTP 10706. 420 TCFD. TDTP TSCN. TDTP 3555.716 TSCF. TDTP 1973.995 INND. TDTP 1447.216 INFD. TDTP GRCH. TDTP -999.250 TENS. TDTP 1535. 000 CCL. TDTP O. 000 70.271 1.256 -999.250 -999.250 -999.250 65.354 1.436 16.115 4027.347 353.189 64.511 1.412 17.761 4623.415 331.274 LIS Tape Verification Listing Schlumberger Alaska Computing Center Il-JUN-1996 10:14 PAGE: 16 ** END OF DATA ** **** FILE TRAILER **** FILE NAME : EDIT .004 SERVICE : FLIC VERSION : O01CO1 DATE : 96/06/11 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : **** FILE HEADER **** FILE NAME : EDIT .005 SERVICE : FLIC VERSION : 001C01 DATE : 96/06/11 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : FILE HEADER FILENUMBER: 5 EDITED CURVES Depth shifted and clipped curves for each pass in separate files. PASS NUMBER: 5 DEPTH INCR~ENT: 0.5000 FILE SUMMARY LDWG TOOL CODE START DEPTH STOP DEPTH TDTP 10533.0 10236.0 CURVE SHIFT DATA - PASS TO PASS (MEASURED DEPTH) BASELINE CURVE FOR SHIFTS LDWG CURVE CODE: GR PASS NUMBER: 1 .......... EQUIVALENT UNSHIFTED DEPTH .......... BASELINE DEPTH GR TDTP 88888.0 88888.0 88888.0 10524.5 10524.5 10520.5 10520.0 10516.5 10516.0 10512.5 10511.5 10500.5 10499.5 LIS Tape Verification Listing Schlumberger Alaska Computing Center il-JUN-1996 10:14 PAGE: 17 10496.5 10496.0 10492.5 10492.0 10490.5 10490.5 10488.5 10487.5 10486.5 10487.0 10484.5 10483.0 10482.5 10482.5 10480.5 10480.0 10478.5 10479.0 10476.5 10475.5 10472.5 10471.5 10470.5 10471.0 10468.5 10468.5 10466.5 10467.5 10464.5 10463.5 10462.5 10463.0 10458.5 10459.5 10442.5 10443.5 10438.5 10439.0 10434.5 10434.5 10428.5 10427.5 10426.5 10426.5 10424.5 10423.0 10422.5 10422.0 10420.5 10419.0 10418.5 10418.5 10416.5 10415.5 10414.5 10413.5 10412.5 10411.5 10410.5 10411,0 10408.5 10407.0 10400.5 10399.0 10396.5 10396.0 10392.5 10391.5 10378.5 10379.0 10374.5 10374.5 10370.5 10370.5 10366.5 10367.0 10362.5 10362.5 10358.5 10359.0 10356.5 10355.5 10352.5 10352.0 10348.5 10347.5 10346.5 10347.0 10342.5 10342.5 10338,5 10339,0 10334.5 10334.5 10324.5 10323.5 10320.5 10319,0 10316.5 10315.0 10314.5 10314.5 10312.5 10311.5 10310.5 10310.0 10306.5 10306.5 10302.5 10302,5 LIS Tape Verification Listing Schlumberger Alaska Computing Center Il-JUN-1996 10:14 PAGE: 18 10298.5 10299.0 10292.5 10291.5 10290.5 10291.0 10288.5 10288.0 10286.5 10287.5 10284.5 10283.5 10278.5 10279.5 10274.5 10275.0 100.0 100.5 99.0 $ REblARKS: This file contains Borax Pass #2 of the TDTP. The depth adjustments shown above reflect Borax Pass #2 GRCH to Base Pass #1GRCH and Borax Pass #2 SIGMA to Base Pass #1 SIGMA. Ail other TDTP curves were carried with the SIGMA shifts. $ LIS FORMAT DATA ** 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 12 68 13 66 0 14 65 FT 15 66 68 16 66 1 0 66 1 ** SET TYPE - CHAN ** NAME SBRV UNIT SERVICE API API API API FILE NUMB NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUMB SAMP EL~ CODE (HEX) DEPT FT 500347 O0 000 O0 0 5 1 1 4 68 0000000000 SIGM TDTP CU 500347 00 000 O0 0 5 1 1 4 68 0000000000 TPHI TDTP PU-S 500347 O0 000 O0 0 5 1 1 4 68 0000000000 LIS Tape Verification Listing Schlumberger Alaska Computing Center Il-JUN-1996 10:14 PAGE: 19 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) SBHF TDTP CU 500347 O0 000 SBHN TDTP CU 500347 O0 000 SIGC TDTP CU 500347 O0 000 SIBH TDTP CU 500347 O0 000 TRAT TDTP 500347 O0 000 LCO1 TDTP 500347 O0 000 SDSI TDTP CU 500347 O0 000 BACK TDTP CPS 500347 O0 000 FBAC TDTP CPS 500347 O0 000 TCAN TDTP CPS 500347 O0 000 TCAF TDTP CPS 500347 O0 000 TCND TDTP CPS 500347 O0 000 TCFD TDTP CPS 500347 O0 000 TSCN TDTP CPS 500347 O0 000 TSCF TDTP CPS 500347 O0 000 INND TDTP CPS 500347 O0 000 INFD TDTP CPS 500347 O0 000 GRCH TDTP GAPI 500347 O0 000 TENS TDTP LB 500347 O0 000 CCL TDTP V 500347 O0 000 O0 0 5 1 1 4 68 0000000000 O0 0 5 1 1 4 68 0000000000 O0 0 5 1 1 4 68 0000000000 O0 0 5 1 1 4 68 0000000000 O0 0 5 1 1 4 68 0000000000 O0 0 5 1 1 4 68 0000000000 O0 0 5 1 1 4 68 0000000000 O0 0 5 1 1 4 68 0000000000 O0 0 5 1 1 4 68 0000000000 O0 0 5 1 1 4 68 0000000000 O0 0 5 1 1 4 68 0000000000 O0 0 5 1 1 4 68 0000000000 O0 0 5 1 1 4 68 0000000000 O0 0 5 1 1 4 68 0000000000 O0 0 5 1 1 4 68 0000000000 O0 0 5 1 1 4 68 0000000000 O0 0 5 1 1 4 68 0000000000 O0 0 5 1 1 4 68 0000000000 O0 0 5 1 1 4 68 0000000000 O0 0 5 1 1 4 68 0000000000 ** DATA ** DEPT. 10533.000 SIGM. TDTP 12.744 TPHI.TDTP 10.193 SBHF. TDTP SBHN. TDTP 85.533 SIGC. TDTP 0.299 SIBH. TDTP 116.389 TRAT. TDTP LCO1.TDTP 1.513 SDSI. TDTP 0.345 BACK. TDTP 97.198 FBAC. TDTP TCAN. TDTP 8758.760 TCAF, TDTP 5789.844 TCND. TDTP 7548.886 TCFD. TDTP TSCN, TDTP 1783.284 TSCF. TDTP 1178.813 INND. TDTP 1553.671 INFD. TDTP GRCH, TDTP -999.250 TENS. TDTP 1610.000 CCL,TDTP 0.000 DEPT. 10450. 000 SIGM. TDTP 15. 216 TPHI. TDTP SBHN. TDTP 88 . 982 SIGC. TDTP 0 . 225 SIBH. TDTP LCO1. TDTP 1 . 885 SDSI. TDTP O. 462 BACK. TDTP TCAN. TDTP 14146. 752 TCAF. TDTP 7505. 047 TCND. TDTP TSCN. TDTP 2770. 598 TSCF. TDTP 1469. 840 INND. TDTP GRCH. TDTP 47. 313 TENS. TDTP 1560. 000 CCL. TDTP 20 443 134 432 78 595 9399 297 1481 709 0 000 SBHF. TDTP TRAT. TDTP FBAC. TDTP TCFD. TDTP INFD. TDTP DEPT. 10235. 000 SIGM. TDTP 16. 218 TPHI. TDTP 22.146 SBHF. TDTP SBHN. TDTP 81 . 766 SIGC. TDTP O. 315 SIBH. TDTP 122. 990 TRAT. TDTP LCO1. TDTP 1. 972 SDSI. TDTP O . 710 BACK. TDTP 91. 648 FBAC. TDTP TCAN. TDTP 12887.180 TCAF. TDTP 6533. 546 TCND. TDTP 9704. 982 TCFD. TDTP TSCN. TDTP 2564.174 TSCF. TDTP 1299. 986 INND. TDTP 1483 . 761 INFD. TDTP GRCI{. TDTP -999. 250 TENS. TDTP 1500. 000 CCL, TDTP O. 000 69.759 1.138 23.161 3228.223 312.776 68. 694 1. 451 18.470 3795. 409 327.360 71. 831 1. 473 21.514 3731. 439 322. 368 ** END OF DATA ** LIS Tape Verification Listing Schlumberger Alaska Computing Center Il-JUN-1996 10:14 PAGE: 20 **** FILE TRAILER **** FILE NAME : EDIT .005 SERVICE : FLIC VERSION : O01CO1 DATE : 96/06/11 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : **** FILE HEADER **** FILE NAME : EDIT .006 SERVICE : FLIC VERSION : O01CO1 DATE : 96/06/11 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : FILE HEADER FILE NUMBER: 6 EDITED CURVES Depth shifted and clipped curves for each pass in separate files. PASS NUMBER: 6 DEPTH INCREMENT: O. 5000 FILE SUMMARY LDWG TOOL CODE START DEPTH STOP DEPTH TDTP 10537.0 10248,0 $ CURVE SHIFT DATA - PASS TO PASS (MEASURED DEPTH) BASELINE CURVE FOR SHIFTS LDWG CURVE CODE: GR PASS NUMBER: 1 .......... EQUIVALENT UNSHIFTED DEPTH .......... BASELINE DEPTH GR TDTP 88888.0 88888.5 88887.0 10528.5 10527.5 10524 . 5 10523.5 10520.5 10520.0 10516.5 10516.5 10512.5 10511.5 10508.5 10507.5 10504.5 10503.0 10500.5 10499.0 10496.5 10495.5 10492.5 10493.0 10492.0 10488.5 10487.5 LIS Tape Verification Listing Schlumberger Alaska Computing Center Il-JUN-1996 10:14 PAGE: 21 10484.5 10483.0 10480.5 10481.0 10479.5 10476.5 10476.5 10460.5 10460.5 10459.5 10456.5 10457.0 10455.0 10452.5 10451.5 10432.5 10431.5 10428.5 10429.0 10427.0 10424.5 10425.5 10422.5 10420.5 10420.5 10419.0 10416.5 10416.5 10412.5 10412.0 10408.5 10408.5 10396.5 10395.0 10392.5 10391.5 10388.5 10387.5 10384.5 10383,0 10376.5 10375.0 10372.5 10372.5 10371.5 10368.5 10369.0 10352.5 10353,0 10348.5 10348.5 10344.5 10343.5 10340.5 10339.0 10316.5 10316.5 10312,5 10313.0 10304.5 10305.0 10303.0 10300,5 10302.0 10299.5 10296.5 10297.0 10288.5 10287.5 10284,5 10283.0 10280.5 10281.0 10279.0 10276,5 10276.5 10275.5 10272,5 10273 . 0 10271.0 100.0 100.5 98.5 $ R~MARKS: This file contains Borax Pass #3 of the TDTP. The depth adjustments shown above reflect Borax Pass #3 GRCH to Base Pass #1GRCH and Borax Pass #3 SIGMA to Base Pass #1 SIGMA. Ail other TDTP curves were carried with the SIGMA shifts. $ LIS FORMAT DATA LIS Tape Verification Listing Schlumberger Alaska Computing Center il-JUN-1996 10:14 PAGE: 22 ** 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 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 500347 O0 000 O0 0 6 1 1 4 68 0000000000 SIGM TDTP CU 500347 O0 000 O0 0 6 1 1 4 68 0000000000 TPHI TDTP PU-S 500347 O0 000 O0 0 6 1 1 4 68 0000000000 SBHF TDTP CU 500347 O0 000 O0 0 6 I 1 4 68 0000000000 SBHN TDTP CU 500347 O0 000 O0 0 6 1 1 4 68 0000000000 SIGC TDTP CU 500347 O0 000 O0 0 6 1 1 4 68 0000000000 SIBH TDTP CU 500347 O0 000 O0 0 6 1 1 4 68 0000000000 TRAT TDTP 500347 O0 000 O0 0 6 1 1 4 68 0000000000 LCO1 TDTP 500347 O0 000 O0 0 6 1 1 4 68 0000000000 SDSI TDTP CU 500347 O0 000 O0 0 6 1 1 4 68 0000000000 BACK TDTP CPS 500347 O0 000 O0 0 6 1 1 4 68 0000000000 FBAC TDTP CPS 500347 O0 000 O0 0 6 1 1 4 68 0000000000 TCANTDTP CPS 500347 O0 000 O0 0 6 1 1 4 68 0000000000 TCAF TDTP CPS 500347 O0 000 O0 0 6 1 1 4 68 0000000000 TCND TDTP CPS 500347 O0 00~ O0 0 6 1 1 4 68 0000000000 TCFD TDTP CPS 500347 O0 000 O0 0 6 1 1 4 68 0000000000 TSCN TDTP CPS 500347 O0 000 O0 0 6 1 1 4 68 0000000000 TSCF TDTP CPS 500347 O0 000 O0 0 6 1 1 4 68 0000000000 INND TDTP CPS 500347 O0 000 O0 0 6 I 1 4 68 0000000000 INFD TDTP CPS 500347 O0 000 O0 0 6 1 1 4 68 0000000000 GRCH TDTP GAPI 500347 O0 000 O0 0 6 1 1 4 68 0000000000 TENS TDTP LB 500347 O0 000 O0 0 6 1 1 4 68 0000000000 CCL TDTP V 500347 O0 000 O0 0 6 1 1 4 68 0000000000 LIS Tape Verification Listing Schlumberger Alaska Computing Center Il-JUN-1996 10:14 PAGE: 23 ** DATA ** DEPT. 10536. 000 SIGM. TDTP SBHN. TDTP 87. 893 SIGC. TDTP LCO1. TDTP 1 . 866 SDSI. TDTP TCAN. TDTP 4860. 085 TCAF. TDTP TSCN. TDTP 966. 690 TSCF. TDTP GRCH. TDTP -999.250 TENS. TDTP DEPT. 10450. 000 SIGM. TDTP SBHN. TDTP 93.464 SIGC. TDTP LCO1. TDTP 1. 860 SDSI. TDTP TCAN. TDTP 14181. 293 TCAF. TDTP TSCN. TDTP 2830. 801 TSCF. TDTP GRCH. TDTP 49.531 TENS. TDTP DEPT. 10246. 500 SIGM. TDTP SBHN. TDTP 76. 584 SIGC. TDTP LCO1. TDTP 1. 733 SDSI. TDTP TCAN. TDTP 17600. 758 TCAF. TDTP TSCN. TDTP 3594. 863 TSCF. TDTP GRCH. TDTP - 999.250 TENS. TDTP 23. 984 TPHI. TDTP 1. 087 SIBH. TDTP 1. 794 BACK. TDTP 2605. 241 TCND. TDTP 518.192 INND. TDTP 1470. 000 CCL. TDTP 15.858 TPHI . TDTP 0. 062 SIBH. TDTP O. 440 BACK. TDTP 7626.143 TCND. TDTP 1522. 294 INND. TDTP 1550. 000 CCL. TDTP 14. 432 TPHI. TDTP 0.181 SIBH. TDTP O. 455 BACK. TDTP 10154. 922 TCND. TDTP 2074. 090 INND. TDTP 1485. 000 CCL. TDTP 21. 646 SBHF. TDTP 141. 809 TRAT. TDTP - 999.250 FBAC. TDTP -999. 250 TCFD. TDTP -999. 250 INFD. TDTP O. 000 20. 633 SBHF. TDTP 144. 525 TRAT. TDTP 90. 620 FBAC. TDTP 9215. 797 TCFD. TDTP 1422. 408 INFD. TDTP O. 000 17.071 SBHF. TDTP 109.331 TRAT. TDTP 100.325 FBAC. TDTP 11446.270 TCFD. TDTP 1467.259 INFD. TDTP 0.000 74.872 1.221 -999.250 -999.250 -999.250 80.078 1.436 21.512 3805.718 321.405 63.827 1.362 21.515 4998.757 323.885 ** END OF DATA ** **** FILE TRAILER **** FILE NAME : EDIT .006 SERVICE : FLIC VERSION : O01CO1 DATE : 96/06/11 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : **** FILE HEADER **** FILE NAME : EDIT .007 SERVICE : FLIC VERSION : O01CO1 DATE : 96/06/11 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : FILE HEADER FILE NUMBER: 7 AVERAGED CURVES Pulsed Neutron: Unaveraged edited Pass 1 Gamma Ray and backround counts; arithmetic average of edited static baseline passes for all other curves. LIS Tape Verification Listing Schlumberger Alaska Computing Center Il-JUN-1996 10:14 PAGE: 24 DEPTH INCREMENT 0.5000 PASSES INCLUDED IN AVERAGE LDWG TOOL CODE PASS NUMBERS SIGM 1, 2, 3, $ ~KS: The arithmetic average of passes 1, 2 & 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 1 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 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 500347 O0 000 O0 0 7 1 1 4 68 0000000000 SIGM PNAV CU 500347 O0 000 O0 0 7 1 1 4 68 0000000000 TPHI PNAV PU-S 500347 O0 000 O0 0 7 1 1 4 68 0000000000 SBHF PNAV CU 500347 O0 000 O0 0 7 1 1 4 68 0000000000 SBHN PNAV CU 500347 O0 000 00 0 7 1 1 4 68 0000000000 SIGC PNAV CU 500347 00 000 00 0 7 1 1 4 68 0000000000 SIBH PNAV CU 500347 O0 000 O0 0 7 1 1 4 68 0000000000 TRAT PNAV 500347 O0 000 00 0 7 1 1 4 68 0000000000 SDSI PNAV CU 500347 O0 000 O0 0 7 1 1 4 68 0000000000 BACK TDTP CPS 500347 O0 000 O0 0 7 1 1 4 68 0000000000 LIS Tape Verification Listing Schlumberger Alaska Computing Center Il-JUN-1996 10:14 PAGE: 25 NAME SERV UNIT SERVICE API API API API FILE NUMB NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUMB SAMP ELE~ CODE (HEX) FBAC TDTP CPS 500347 O0 000 O0 0 7 1 1 4 68 0000000000 TCANPNAV CPS 500347 00 000 O0 0 7 1 1 4 68 0000000000 TCAF PNAV CPS 500347 O0 000 O0 0 7 1 1 4 68 0000000000 TCND PNAV CPS 500347 O0 000 O0 0 7 1 1 4 68 0000000000 TCFD PNAV CPS 500347 O0 000 O0 0 7 1 1 4 68 0000000000 TSCN PNAV CPS 500347 O0 000 O0 0 7 1 1 4 68 0000000000 TSCF PNAV CPS 500347 O0 000 O0 0 7 1 1 4 68 0000000000 INNDPNAV CPS 500347 O0 000 O0 0 7 1 1 4 68 0000000000 INFD PNAV CPS 500347 00 000 O0 0 7 1 1 4 68 0000000000 LCO1 PNAV 500347 O0 000 O0 0 7 1 1 4 68 0000000000 GRCH TDTP GAPI 500347 O0 000 O0 0 7 1 1 4 68 0000000000 ** DATA ** DEPT. 10534.500 SIGM. PNAV 13.317 TPHI.PNAV 23.142 SBHF. PNAV 27.984 SBHN. PNAV 38.285 SIGC. PNAV 2.233 SIBH. PNAV 38,285 TRAT. PNAV 1. 741 SDSI.PNAV 0.372 BACK. TDTP 48.171 FBAC. TDTP 9.854 TCAN. PNAV 39037.922 TCAF. PNAV 16932.660 TCND. PNAV 23419.125 TCFD,PNAV 8372.230 TSCN, PNAV 7578.522 TSCF. PNAV 3285.984 INND. PNAV 1551.026 INFD.PNAV 357.755 LCO1.PNAV 2.307 GRCH. TDTP -999. 250 DEPT. 10450.000 SIGM. PNAV 15.880 TPHI,PNAV 25.745 SBHF. PNAV 31.667 SBHN. PNAV 38. 681 SIGC. PNAV 2.331 SIBH. PNAV 38. 681 TRAT. PNAV 1. 746 SDSI. PNAV O. 460 BACK. TDTP 36. 072 FBAC. TDTP 9. 511 TCAN. PNAV 33856. 555 TCAF. PNAV 14289.564 TCND. PNAV 21925.660 TCFD. PNAV 7788.120 TSCN. PNAV 6715.195 TSCF. PNAV 2834.401 INND.PNAV 1449.616 INFD. PNAV 345.274 LCO1.PNAV 2.369 GRCH. TDTP 17. 953 DEPT. 10247.000 SIGM. PNAV -999.250 TPHI.PNAV -999.250 SBHF. PNAV -999.250 SBHN. PNAV -999.250 SIGC. PNAV -999.250 SIBH. PNAV -999.250 TRAT. PNAV -999.250 SDSI.PNAV -999.250 BACK. TDTP 56. 724 FBAC. TDTP 13. 070 TCAN. PNAV -999.250 TCAF. PNAV -999.250 TCND. PNAV -999.250 TCFD.PNAV -999.250 TSCN. PNAV -999.250 TSCF. PNAV -999.250 INND. PNAV -999.250 INFD.PNAV -999.250 LCO1.PNAV -999.250 GRCH. TDTP -999. 250 ** END OF DATA ** **** FILB TRAILER **** FILE NAME : EDIT .007 SERVICE : FLIC VERSION : 001C01 DATE : 96/06/11 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : LIS Tape Verification Listing Schlumberger Alaska Computing Center il-JUN-1996 10:14 PAGB: 26 **** FILE HEADER **** FILE NAME : EDIT .008 SERVICE : FLIC VERSION : O01CO1 DATE : 96/06/11 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : FILE HEADER FILE ArdMBER 8 RAW CURVES Curves and log header data for each pass in separate files; raw background pass in last file PASS NUMBER: 1 DEPTH INCRI~ENT : 0. 5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH TDTP 10535.0 $ LOG HEADER DATA DATE LOGGED: SOFTWARE VERSION: TIME LOGGER ON BOTTOM: TD DRILLER (FT) : TD LOGGER (FT) : TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT) : LOGGING SPEED (FPHR): DEPTH CONTROL USED (YES/NO): TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE CCL CCL GR GAMMA RAY TDTP THERMAL DECAY $ BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLERS CASING DEPTH (FT): LOGGERS CASING DEPTH (FT): BOREHOLE CONDITIONS FLUID TYPE: FLUID DENSITY (LB/G): SURFACE T~PERATURE (DEGF) : BOTTOM HOLE T~PERATURE (DEGF): FLUID SALINITY (PPM) : STOP DEPTH 10248.0 O1-APR-96 42.2 1122 O1-APR-96 10535.0 11478.0 10250.0 10526.0 1800.0 NO TOOL NUMBER CAL-UB-299 ATC-CB-1108 TDTP SET 23 10988.0 BORAX WATER 5.0 LIS Tape Verification Listing Schlumberger Alaska Computing Center Il-JUN-1996 10:14 PAGE: 27 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): REM_ARKS: TIED INTO BHCS DATED 10/26/77 *** JOB SEQUENCE *** PUMP 330 BBLS CRUDE + 12 BBLS BORAX WATER: MAKE BASE PASS PUMP 38 BBLS BORAX WATER: MAKE BASE PASS #2 PUMP 25 BBLS BORAX WATER + 15 BBLS CRUDE: MAKE BASE PASS # APROX. 20 BBLS BORAX BEHIND PIPE: MAKE BORAX PASS #1 APROX. 35 BBLS BORAX BEHIND PIPE: MAKE BORAX PASS #2 $ LIS FORMAT DATA ** 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 LIS Tape Verification Listing Schlumberger Alaska Computing Center Il-JUN-1996 10:14 PAGE: 28 TYPE REPR CODE VALUE 13 66 0 14 65 FT 15 66 68 16 66 1 0 66 1 ** SET TYPE - CHAN ** NAME SERV UNIT SERVICE API API API API FILE NUMB NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUMB SAMP EL~ CODE (HEX) DBPT FT 500347 O0 000 O0 0 8 1 1 4 68 0000000000 SIGM PS1 CU 500347 O0 000 O0 0 8 1 1 4 68 0000000000 TPHI PS1 PU 500347 O0 000 O0 0 8 1 1 4 68 0000000000 SBHF PS1 CU 500347 O0 000 O0 0 8 1 1 4 68 0000000000 SBHNPS1 CU 500347 O0 000 O0 0 8 1 1 4 68 0000000000 SIGC PS1 CU 500347 O0 000 O0 0 8 1 1 4 68 0000000000 SIBH PS1 CU 500347 O0 000 O0 0 8 1 1 4 68 0000000000 TRAT PS1 500347 O0 000 O0 0 8 1 1 4 68 0000000000 LCO1 PS1 500347 O0 000 O0 0 8 1 1 4 68 0000000000 SDSI PS1 CU 500347 00 000 O0 0 8 1 1 4 68 0000000000 BACK PS1 CPS 500347 O0 000 O0 0 8 1 1 4 68 0000000000 FBAC PS1 CPS 500347 00 000 00 0 8 1 1 4 68 0000000000 TCANPS1 CPS 500347 O0 000 O0 0 8 1 1 4 68 0000000000 TCAF PS1 CPS 500347 O0 000 O0 0 8 1 1 4 68 0000000000 TCNDPS1 CPS 500347 O0 000 O0 0 8 1 1 4 68 0000000000 TCFD PS1 CPS 500347 O0 000 O0 0 8 1 1 4 68 0000000000 TSCN PS1 CPS 500347 O0 000 O0 0 8 1 1 4 68 0000000000 TSCF PS1 CPS 500347 O0 000 O0 0 8 1 1 4 68 0000000000 INNDPS1 CPS 500347 00 000 O0 0 8 1 1 4 68 0000000000 INFD PS1 CPS 500347 O0 000 O0 0 8 I 1 4 68 0000000000 TENS PS1 LB 500347 O0 000 O0 0 8 1 1 4 68 0000000000 GR PS1 GAPI 500347 O0 000 O0 0 8 1 1 4 68 0000000000 CCL PS1 V 500347 O0 000 O0 0 8 1 1 4 68 0000000000 ** DATA ** DEPT. 10539.500 SIGM. PS1 13.190 TPHI.PS1 22.037 SBHF. PS1 SBHN. PS1 35.342 SIGC. PS1 1.485 SIBH. PS1 35.342 TRAT. PS1 LCO1.PS1 2.225 SDSI.PS1 0.386 BACK. PSI 41.527 FBAC. PS1 TCAN. PS1 43143.578 TCAF. PS1 19389.441 TCND.PSi 24741.512 TCFD.PS1 TSCN. PS1 8629.098 TSCF. PS1 3878.060 INND.PS1 1547.067 INFD.PS1 TENS.PSI 1150.000 GR.PS1 16.188 CCL.PS1 0.000 DEPT. 10450.000 SIGM. PS1 15.748 TPHI.PS1 26.469 SBHF. PS1 SBHN. PS1 37.424 SIGC. PS1 2.247 SIBH. PS1 37.424 TRAT. PS1 LCO1.PS1 2.406 SDSI.PS1 0.449 BACK. PSi 37.152 FBAC. PS1 TCAN. PSI 34164.656 TCAF. PS1 14201.186 TCND.PS1 22312.457 TCFD.PS1 TSCN. PS1 6910.730 TSCF. PS1 2872.576 INND.PS1 1483.841 INFD.PS1 28.434 1.708 13.416 9440.854 386.078 29.306 1.772 10.609 7874.755 342.049 LIS Tape Verification Listing Schlumberger Alaska Computing Center Il-JUN-1996 10:14 PAGE: 29 TENS. PSI 1500.000 GR. PS1 17.953 CCL. PS1 0.000 DEPT. 10247.000 SIGM. PS1 14.174 TPHI.PS1 21.111 SBHN. PS1 39.970 SIGC. PS1 2.185 SIBH. PS1 39.970 LCO1.PS1 2.181 SDSI.PS1 0.391 BACK. PSI 57.169 TCAN. PS1 35913.906 TCAF. PS1 16464.238 TCND.PS1 23079.574 TSCN. PS1 7405.376 TSCF. PS1 3394.894 INND. PS1 1448.761 TENS.PSi 1495.000 GR.PS1 16.719 CCL.PS1 0.000 SBHF. PS1 TRAT. PS1 FBAC. PS1 TCFD.PS1 INFD.PS1 24. 912 1. 647 13.304 8680. 082 343.100 ** END OF DATA ** **** FILE TRAILER **** FILE NAME : EDIT .008 SERVICE : FLIC VERSION : 001C01 DATE : 96/06/11 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : **** FILE HEADER **** FILE NAME : EDIT .009 SERVICE : FLIC VERSION : 001C01 DATE : 96/06/11 MAX REC 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 INCRI~IENT: O. 5000 FILE SUIV~W. ARY VENDOR TOOL CODE START DEPTH TDTP 10536.0 $ LOG HEADER DATA DATE LOGGED: SOFTWARE VERSION: TIME LOGGER ON BOTTOM: TD DRILLER (FT) : TD LOGGER (FT) : STOP DEPTH 10248.0 01-APR-96 42.2 1122 O1-APR-96 10535.0 11478.0 LIS Tape Verification Listing Schlumberger Alaska Computing Center Il-JUN-1996 10:14 PAGE: 3O TOP LOG INTERVAL (FT) : BOTTOM LOG INTERVAL (FT) : LOGGING SPEED (FPHR): DEPTH CONTROL USED (YES/NO): 10250.0 10526.0 1800.0 NO TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE ......................... CCL CCL GR GAMMA RAY TDTP THERMAL DECAY $ TOOL NUMBER ........... CAL-UB-299 ATC-CB-1108 TDTP SET 23 BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLERS CASING DEPTH (FT) : LOGGERS CASING DEPTH (FT) : 10988.0 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) : BORAX WATER 5.0 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): REMARKS: TIED INTO BHCS DATED 10/26/77 *** JOB SEQUENCE *** PUMP 330 BBLS CRUDE + 12 BBLS BORAX WATER: MAKE BASE PASS PUMP 38 BBLS BORAX WATER: MAKE BASE PASS #2 PUMP 25 BBLS BORAX WATER + 15 BBLS CRUDE: MAKE BASE PASS # APROX. 20 BBLS BORAX BEHIND PIPE: MAKE BORAX PASS #1 APROX. 35 BBLS BORAX BEHIND PIPE: MAKE BORAX PASS #2 LIS Tape Verification Listing Schlumberger Alaska Computing Center Il-JUN-1996 10:14 PAGE: 31 $ LIS FORMAT DATA ** DATA FORMAT SPECIFICATION RECORD ** ** SBT 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 ** 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 ELI~I CODE (HEX) DEPT FT 500347 O0 000 O0 0 9 1 1 4 68 0000000000 SIGM PS2 CU 500347 O0 000 O0 0 9 1 1 4 68 0000000000 TPHI PS2 PU 500347 O0 000 O0 0 9 1 1 4 68 0000000000 SBHF PS2 CU 500347 O0 000 O0 0 9 1 1 4 68 0000000000 SBHNPS2 CU 500347 00 000 O0 0 9 1 1 4 68 0000000000 SIGC PS2 CU 500347 O0 000 O0 0 9 1 1 4 68 0000000000 SIBH PS2 CU 500347 O0 000 O0 0 9 1 1 4 68 0000000000 TRAT PS2 500347 00 000 O0 0 9 1 1 4 68 0000000000 LCO1 PS2 500347 00 000 O0 0 9 1 1 4 68 0000000000 SDSI PS2 CU 500347 O0 000 O0 0 9 1 1 4 68 0000000000 BACK PS2 CPS 500347 O0 000 O0 0 9 1 1 4 68 0000000000 FBAC PS2 CPS 500347 O0 000 O0 0 9 1 I 4 68 0000000000 TCANPS2 CPS 500347 O0 000 O0 0 9 1 1 4 68 0000000000 TCAF PS2 CPS 500347 O0 000 O0 0 9 1 1 4 68 0000000000 TCNDPS2 CPS 500347 O0 000 O0 0 9 1 1 4 68 0000000000 TCFD PS2 CPS 500347 O0 000 O0 0 9 1 1 4 68 0000000000 TSCN PS2 CPS 500347 O0 000 O0 0 9 1 1 4 68 0000000000 TSCF PS2 CPS 500347 O0 000 O0 0 9 1 1 4 68 0000000000 INNDPS2 CPS 500347 O0 000 O0 0 9 1 1 4 68 0000000000 LIS Tape Verification Listing Schlumberger Alaska Computing Center il-JUN-1996 10:14 PAGE: 32 NAME SERV UNIT SERVICE API API API API FILE NUMB NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUMB SAMP ELI~4 CODE (HEX) INFD PS2 CPS 500347 00 000 00 0 9 1 1 4 68 0000000000 TENS PS2 LB 500347 00 000 00 0 9 1 1 4 68 0000000000 GR PS2 GAPI 500347 O0 000 O0 0 9 1 1 4 68 0000000000 CCL PS2 V 500347 O0 000 O0 0 9 1 1 4 68 0000000000 ** DATA ** DEPT. 10539.500 SIGM. PS2 14.174 TPHI.PS2 21.111 SBHF. PS2 SBHN. PS2 39.970 SIGC. PS2 2.185 SIBH. PS2 39.970 TRAT. PS2 LCO1.PS2 2.181 SDSI.PS2 0.391 BACK. PS2 57.169 FBAC. PS2 TCAN. PS2 35913.906 TCAF. PS2 16464.238 TCND.PS2 23079.574 TCFD.PS2 TSCN. PS2 7405.376 TSCF. PS2 3394.894 INND.PS2 1448.761 INFD.PS2 TENS.PS2 1110.000 GR.PS2 28.328 CCL.PS2 0.000 DEPT. 10450.000 SIGM. PS2 15.674 TPHI.PS2 25.390 SBHF. PS2 SBHN. PS2 40.568 SIGC. PS2 2.482 SIBH. PS2 40.568 TRAT.PS2 LCO1.PS2 2.367 SDSI.PS2 0.444 BACK. PS2 68.099 FBAC.PS2 TCAN. PS2 33954.461 TCAF. PS2 14346.004 TCND.PS2 21691.758 TCFD.PS2 TSCN. PS2 6614.453 TSCF. PS2 2794.654 INND. PS2 1460.932 INFD.PS2 TENS.PS2 1485.000 GR.PS2 32.625 CCL.PS2 0.000 DEPT. 10246.500 SIGM. PS2 13.748 TPHI.PS2 20.640 SBHF. PS2 SBHN. PS2 40.130 SIGC. PS2 2.461 SIBH. PS2 40.130 TRAT. PS2 LCO1.PS2 2.174 SDSI.PS2 0.416 BACK. PS2 78.795 FBAC.PS2 TCAN. PS2 37493.367 TCAF. PS2 17249.883 TCND.PS2 22843.918 TCFD. PS2 TSCN. PS2 7445.012 TSCF. PS2 3425.288 INND. PS2 1461.364 INFD.PS2 TENS.PS2 1475.000 GR.PS2 24.969 CCL.PS2 0.000 24.912 1.647 13.304 8680.082 343.100 31.628 1.741 15.654 7719.432 342.965 30.716 1.643 16.234 8632.482 344.091 ** END OF DATA ** **** FILE TRAILER **** FILE NAME : EDIT .009 SERVICE : FLIC VERSION : 001C01 DATE : 96/06/11 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : LIS Tape Verification Listing Schlumberger Alaska Computing Center Il-JUN-1996 10:14 PAGE: 33 **** FILE HEADER **** FILE NAME : EDIT .010 SERVICE : FLIC VERSION : O01CO1 DATE : 96/06/11 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : FILE HEADER FILE NUMBER 10 RAW CURVES Curves and log header data for each pass in separate files; raw background pass in last file PASS NUMBER: 3 DEPTH INCR~ENT: 0.5000 FILE SUFI~ARY VENDOR TOOL CODE START DEPTH TDTP 10536.0 $ LOG HEADER DATA DATE LOGGED: SOFTWARE VERSION: TIME LOGGER ON BOTTOM: TD DRILLER (FT) : TD LOGGER (FT) : TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT) : LOGGING SPEED (FPHR) : DEPTH CONTROL USED (YES/NO): TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE CCL CCL GR GAI~MA RAY TDTP THERMAL DECAY $ BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLERS CASING DEPTH (FT): LOGGERS CASING DEPTH (FT) : BOREHOLE CONDITIONS FLUID TYPE: FLUID DENSITY (LB/G): SURFACE T~PERATURE (DEGF) : BOTTOM HOLE T~4PERATURE (DEGF) : FLUID SALINITY (PPM) : STOP DEPTH 10246.0 O1 ~APR-96 42.2 1122 O1 -APR-96 10535.0 11478.0 10250.0 10526.0 1800.0 NO TOOL NUMBER CAL-UB-299 ATC-CB-1108 TDTP SET 23 10988.0 BORAX WATER 5.0 LIS Tape Verification Listing Schlumberger Alaska Computing Center Il-JUN-1996 10:14 PAGE: 34 FLUID LEVEL (FT) : FLUID RATE AT WELLHEAD (BPM) : WATER CUTS (PCT) : GAS~OIL RATIO: CHOKE (DEG) : NEUTRON TOOL TOOL TYPE [EPITHBRMAL 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): Rb~ARKS: TIED INTO BHCS DATED 10/26/77 *** JOB SEQUENCE *** PUMP 330 BBLS CRUDE + 12 BBLS BORAX WATER: MAKE BASE PASS PUMP 38 BBLS BORAX WATER: MAKE BASE PASS #2 PUMP 25 BBLS BORAX WATER + 15 BBLS CRUDE: MAKE BASE PASS # APROX. 20 BBLS BORAX BEHIND PIPE: MAKE BORAX PASS #1 APROX. 35 BBLS BORAX BEHIND PIPE: MAKE BORAX PASS #2 $ LIS FORMAT DATA ** 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 O.5 9 65 FT 11 66 11 12 68 LIS Tape Verification Listing Schlumberger Alaska Computing Center Il-JUN-1996 10:14 PAGE: 35 TYPE REPR CODE VALUE .............................. 13 66 0 14 65 FT 15 66 68 16 66 1 0 66 1 ** SET TYPE - CHAN ** NAME SERV UNIT SERVICE API API API API FILE NUMB NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUMB SAMP EL~4 CODE (HEX) DEPT FT 500347 O0 000 O0 0 10 1 1 4 68 0000000000 SIGM PS3 CU 500347 O0 000 O0 0 10 1 1 4 68 0000000000 TPHI PS3 PU 500347 O0 000 O0 0 10 1 1 4 68 0000000000 SBHF PS3 CU 500347 O0 000 O0 0 10 1 1 4 68 0000000000 SBHN PS3 CU 500347 O0 000 O0 0 10 1 1 4 68 0000000000 SIGC PS3 CU 500347 O0 000 O0 0 10 1 1 4 68 0000000000 SIBH PS3 CU 500347 O0 000 O0 0 10 1 1 4 68 0000000000 TRAT PS3 500347 O0 000 O0 0 10 1 1 4 68 0000000000 LCO1 PS3 500347 O0 000 O0 0 10 1 1 4 68 0000000000 SDSI PS3 CU 500347 O0 000 O0 0 10 1 1 4 68 0000000000 BACK PS3 CPS 500347 O0 000 O0 0 10 1 1 4 68 0000000000 FBAC PS3 CPS 500347 O0 000 O0 0 10 1 1 4 68 0000000000 TCANPS3 CPS 500347 O0 000 O0 0 10 1 1 4 68 0000000000 TCAF PS3 CPS 500347 O0 000 O0 0 10 1 1 4 68 0000000000 TCND PS3 CPS 500347 O0 000 O0 0 10 1 1 4 68 0000000000 TCFD PS3 CPS 500347 O0 000 O0 0 10 1 1 4 68 0000000000 TSCN PS3 CPS 500347 O0 000 O0 0 10 1 1 4 68 0000000000 TSCF PS3 CPS 500347 O0 000 O0 0 10 1 1 4 68 0000000000 INND PS3 CPS 500347 O0 000 O0 0 10 1 1 4 68 0000000000 INFD PS3 CPS 500347 O0 000 O0 0 10 1 1 4 68 0000000000 TENS PS3 LB 500347 O0 000 O0 0 10 1 1 4 68 0000000000 GR PS3 GAPI 500347 O0 000 O0 0 10 1 1 4 68 0000000000 CCL PS3 V 500347 O0 000 O0 0 10 1 1 4 68 0000000000 ** DATA ** DEPT. 10539.500 SIGM. PS3 13.748 TPHI.PS3 20.640 SBHF. PS3 SBHN. PS3 40.130 SIGC. PS3 2.461 SIBH. PS3 40.130 TRAT. PS3 LCO1.PS3 2.174 SDSI.PS3 0.416 BACK. PS3 78.795 FBAC.PS3 TCAN. PS3 37493.367 TCAF. PS3 17249.883 TCND.PS3 22843.918 TCFD. PS3 TSCN. PS3 7445.012 TSCF. PS3 3425.288 INND. PS3 1461.364 INFD. PS3 TENS.PS3 1035.000 GR.PS3 27.688 CCL.PS3 0.000 DEPT. 10450.000 SIGM. PS3 16.572 TPHI.PS3 27.037 SBHF. PS3 SBHN. PS3 38.154 SIGC. PS3 2.310 SIBH. PS3 38.154 TRAT. PS3 LCOI.PS3 2.412 SDSI.PS3 0.513 BACK. PS3 80.085 FBAC. PS3 TCAN. PS3 32940.453 TCAF. PS3 13658.590 TCND.PS3 21574.703 TCFD.PS3 TSCN. PS3 6529.717 TSCF. PS3 2707.513 INND.PS3 1394,188 INFD.PS3 30.716 1.643 16.234 8632.482 344.092 32.052 1.764 19.523 7630.683 345.992 LIS Tape Verification Listing Schlumberger Alaska Computing Center Il-JUN-1996 10:14 PAGE: 36 TENS. PS3 1515.000 GR.PS3 DEPT. 10244.500 SIGM. PS3 SBHN. PS3 35.801 SIGC. PS3 LCO1.PS3 2.200 SDSI.PS3 TCAN. PS3 37375.125 TCAF. PS3 TSCN. PS3 7623.416 TSCF. PS3 TENS.PS3 1580.000 GR.PS3 40.750 CCL.PS3 13.053 TPHI.PS3 2.526 SIBH.PS3 0.385 BACK.PS3 16986.156 TCND.PS3 3464.671 INND.PS3 33.906 CCL.PS3 0.000 20.834 35.801 95.250 22890.875 1478.629 0.000 SBHF. PS3 TRAT. PS3 FBAC.PS3 TCFD.PS3 INFD.PS3 30. 072 1. 670 22. 571 8610.238 344. 899 ** END OF DATA ** **** FILE TRAILER **** FILE NAME : EDIT .010 SERVICE : FLIC VERSION : 001C01 DATE : 96/06/11 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : **** FILE HEADER **** FILE NAME : EDIT .011 SERVICE : FLIC VERSION : 001C01 DATE : 96/06/11 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : FILE HEADER FILE NUMBER 11 RAW CURVES Curves and log header data for each pass in separate files; raw background pass in last file PASS NUMBBR: 4 DEPTH INCREMENT: 0.5000 FILE SUBtLetY VENDOR TOOL CODE START DEPTH TDTP 10538.0 $ LOG HEADER DATA DATE LOGGED: SOFTWARE VERSION: TIME LOGGER ON BOTTOM: TD DRILLER (FT): TD LOGGER(FT): STOP DEPTH 10247.0 O1-APR-96 42.2 1122 O1-APR-96 10535.0 11478.0 LIS Tape Verification Listing Schlumberger Alaska Computing Center il-JUN-1996 10:14 PAGE: 37 TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT) : LOGGING SPEED (FPHR): DEPTH CONTROL USED (YES/NO): 10250.0 10526.0 1800.0 NO TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE CCL CCL GR GAMMA RAY TDTP THERMAL DECAY $ TOOL NUMBER ........... CAL- UB-299 ATC-CB-1108 TDTP SET 23 BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLERS CASING DEPTH (FT) : LOGGERS CASING DEPTH (FT) : 10988.0 BOREHOLE CONDITIONS FLUID TYPE: FLUID DENSITY (LB/G): SURFACE TEMPERATURE (DBGF) : BOTTOM HOLE TEMPERATURE (DEGF): FLUID SALINITY (PPM) : FLUID LEVEL (FT) : FLUID RATE AT WELLHEAD (BPM): WATER CUTS (PCT) : GAS~OIL RATIO: CHOKE (DEG) : BORAX WATER 5.0 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): REMARKS: TIED INTO BHCS DATED 10/26/77 *** JOB SEQUENCE *** PUMP 330 BBLS CRUDE + 12 BBLS BORAX WATER: MAKE BASE PASS PUMP 38 BBLS BORAX WATER: MAKE BASE PASS #2 PUMP 25 BBLS BORAX WATER + 15 BBLS CRUDE: MAKE BASE PASS # APROX. 20 BBLS BORAX BEHIND PIPE: MAKE BORAX PASS #1 APROX. 35 BBLS BORAX BEHIND PIPE: MAKE BORAX PASS #2 LIS Tape Verification Listing Schlumberger Alaska Computing Center il-JUN-1996 10:14 PAGE: 38 $ LIS FORMAT DATA ** 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 ** 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) DBPT FT 500347 O0 000 O0 0 11 1 1 4 68 0000000000 SIGM PS4 CU 500347 00 000 O0 0 11 1 1 4 68 0000000000 TPHI PS4 PU 500347 00 000 O0 0 11 1 1 4 68 0000000000 SBHF PS4 CU 500347 O0 000 O0 0 11 1 1 4 68 0000000000 SBHN PS4 CU 500347 O0 000 O0 0 11 1 1 4 68 0000000000 SIGC PS4 CU 500347 O0 000 O0 0 11 1 1 4 68 0000000000 SIBH PS4 CU 500347 O0 000 O0 0 11 1 1 4 68 0000000000 TRAT PS4 500347 O0 000 O0 0 11 1 1 4 68 0000000000 LCO1 PS4 500347 O0 000 O0 0 11 1 1 4 68 0000000000 SDSI PS4 CU 500347 O0 000 O0 0 11 1 1 4 68 0000000000 BACK PS4 CPS 500347 00 000 00 0 11 1 1 4 68 0000000000 FBAC PS4 CPS 500347 O0 000 O0 0 11 1 1 4 68 0000000000 TCAN PS4 CPS 500347 O0 000 O0 0 11 1 1 4 68 0000000000 TCAF PS4 CPS 500347 O0 000 00 0 11 1 1 4 68 0000000000 TCND PS4 CPS 500347 O0 000 O0 0 11 1 1 4 68 0000000000 TCFD PS4 CPS 500347 00 000 00 0 11 1 1 4 68 0000000000 TSCN PS4 CPS 500347 O0 000 O0 0 11 1 1 4 68 0000000000 TSCF PS4 CPS 500347 00 000 O0 0 11 I 1 4 68 0000000000 INND PS4 CPS 500347 00 000 O0 0 11 1 1 4 68 0000000000 LIS Tape Verification Listing Schlumberger Alaska Computing Center il-JUN-1996 10:14 PAGE: 39 NAME SERV UNIT SERVICE API API API API FILE NUMB NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUMB SAMP ELE~ CODE (HEX) INFD PS4 CPS 500347 O0 000 O0 0 11 1 1 4 68 0000000000 TENS PS4 LB 500347 O0 000 O0 0 11 1 1 4 68 0000000000 GR PS4 GAPI 500347 O0 000 O0 0 11 1 1 4 68 0000000000 CCL PS4 V 500347 O0 000 O0 0 11 1 1 4 68 0000000000 ** DATA ** DEPT. 10540.000 SIGM. PS4 13.879 TPHI.PS4 SBHN. PS4 85.773 SIGC. PS4 0.856 SIBH. PS4 LCO1.PS4 1.685 SDSI.PS4 0.429 BACK. PS4 TCAN. PS4 14421.914 TCAF. PS4 8558.004 TCND. PS4 TSCN. PS4 2884.419 TSCF. PS4 1711.623 INND.PS4 TENS.PS4 1290.000 GR.PS4 30.359 CCL.PS4 DEPT. 10450.000 SIGM. PS4 15.423 TPHI.PS4 SBHN. PS4 83.633 SIGC. PS4 0.231 SIBH. PS4 LCO1.PS4 1.867 SDSI.PS4 0.424 BACK. PS4 TCAN. PS4 14243.324 TCAF. PS4 7630.961 TCND. PS4 TSCN. PS4 2846.426 TSCF. PS4 1524.993 INND.PS4 TENS.PS4 1580.000 GR. PS4 37.938 CCL.PS4 DEPT. 10246.000 SIGM. PS4 13.290 TPHI.PS4 SBHN. PS4 87.222 SIGC. PS4 0.150 SIBH. PS4 LCO1.PS4 1.794 SDSI.PS4 0.328 BACK. PS4 TCAN. PS4 18922.344 TCAF. PS4 10546.275 TCND.PS4 TSCN. PS4 3816.818 TSCF. PS4 2127.285 INND. PS4 TENS.PS4 1540.000 GR.PS4 32.813 CCL.PS4 14 719 122 134 -999 250 -999 250 -999 250 0 000 SBHF. PS4 TRAT. PS4 FBAC. PS4 TCFD.PS4 INFD.PS4 20.208 SBHF. PS4 124.497 TRAT. PS4 63.809 FBAC. PS4 10070.787 TCFD.PS4 1411.861 INFD.PS4 0.000 17.725 SBHF. PS4 129.545 TRAT. PS4 76.758 FBAC. PS4 11090.494 TCFD.PS4 1436.175 INFD.PS4 0.000 66.390 1.288 -999.250 -999.250 -999.250 65.354 1.436 16.115 4027.347 353.189 65.957 1.420 17.876 4838.679 324.438 ** END OF DATA ** **** FILE TRAILER **** FILE NAME : EDIT .011 SERVICE : FLIC VERSION : O01CO1 DATE : 96/06/11 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : LIS Tape Verification Listing Schlumberger Alaska Computing Center Il-JUN-1996 10:14 PAGE: 4O **** FILE HEADER **** FILE NAME : EDIT .012 SERVICE : FLIC VERSION : O01CO1 DATE : 96/06/11 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : FILE HEADER FILE NUMBER 12 RAW CURVES Curves and log header data for each pass in separate files; raw background pass in last file PASS NUMBER: 5 DEPTH INCREMENT: 0. 5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH TDTP 10533.0 $ LOG HEADER DATA DATE LOGGED: SOFTWARE VERSION: TIME LOGGER ON BOTTOM: TD DRILLER (FT) : TD LOGGER (FT) : TOP LOG INTERVAL (FT) : BOTTOM LOG INTERVAL (FT) : LOGGING SPEED (FPHR): DEPTH CONTROL USED (YES/NO): TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE CCL CCL GR GAMMA RAY TDTP THERMAL DECAY $ BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLERS CASING DEPTH (FT): LOGGERS CASING DEPTH (FT): BOREHOLE CONDITIONS FLUID TYPE: FLUID DENSITY (LB/G): SURFACE TEMPERATURE (DEGF) : BOTTOM HOLE TEMPERATURE (DEGF) : FLUID SALINITY (PPM) : STOP DEPTH 10236.0 O1-APR-96 42.2 1122 O1-APR-96 10535.0 11478.0 10250.0 10526.0 1800.0 NO TOOL NUMBER CAL-UB-299 ATC-CB-1108 TDTP SET 23 10988.0 BORAX WATER 5.0 LIS Tape Verification Listing Schlumberger Alaska Computing Center Il-JUN-1996 10:14 PAGE: 41 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): REMARKS: TIED INTO BHCS DATED 10/26/77 *** JOB SEQUENCE *** PUMP 330 BBLS CRUDE + 12 BBLS BORAX WATER: MAKE BASE PASS PUMP 38 BBLS BORAX WATER: MAKE BASE PASS #2 PUMP 25 BBLS BORAX WATER + 15 BBLS CRUDE: MAKE BASE PASS # APROX. 20 BBLS BORAX BEHINDPIPE: MAKE BORAX PASS #1 APROX. 35 BBLS BORAX BEHIND PIPE: MAKE BORAX PASS #2 $ LIS FORMAT DATA ** 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 ? 65 8 68 0.5 9 65 FT 11 66 11 12 68 LIS Tape Verification Listing Schlumberger Alaska Computing Center Il-JUN-1996 10:14 PAGE: 42 TYPE REPR CODE VALUE .............................. 13 66 0 14 65 FT 15 66 68 16 66 1 0 66 1 .............................. ** SET TYPE - CHAN ** NAME SERV UNIT SERVICE API API API API FILE NUMB NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUMB SAMP EL~ CODE (HEX) DEPT FT 500347 O0 000 O0 0 12 1 1 4 68 0000000000 SIGM PS5 CU 500347 O0 000 O0 0 12 1 1 4 68 0000000000 TPHI PS5 PU 500347 O0 000 O0 0 12 1 1 4 68 0000000000 SBHF PS5 CU 500347 O0 000 O0 0 12 1 1 4 68 0000000000 SBHN PS5 CU 500347 O0 000 O0 0 12 1 1 4 68 0000000000 SIGC PS5 CU 500347 O0 000 O0 0 12 1 1 4 68 0000000000 SIBH PS5 CU 500347 O0 000 O0 0 12 1 1 4 68 0000000000 TRAT PS5 500347 O0 000 O0 0 12 1 1 4 68 0000000000 LCO1 PS5 500347 O0 000 O0 0 12 1 1 4 68 0000000000 SDSI PS5 CU 500347 O0 000 O0 0 12 1 1 4 68 0000000000 BACK PS5 CPS 500347 O0 000 O0 0 12 1 1 4 68 0000~00000 FBAC PS5 CPS 500347 O0 000 O0 0 12 1 1 4 68 0000000000 TCANPS5 CPS 500347 O0 000 O0 0 12 1 1 4 68 0000000000 TCAF PS5 CPS 500347 O0 000 O0 0 12 1 1 4 68 0000000000 TCNDPS5 CPS 500347 O0 000 O0 0 12 1 1 4 68 0000000000 TCFD PS5 CPS 500347 00 000 O0 0 12 1 1 4 68 0000000000 TSCN PS5 CPS 500347 O0 000 O0 0 12 1 1 4 68 0000000000 TSCF PS5 CPS 500347 00 000 00 0 12 1 1 4 68 0000000000 INNDPS5 CPS 500347 00 000 O0 0 12 1 1 4 68 0000000000 INFD PS5 CPS 500347 O0 000 O0 0 12 1 1 4 68 0000000000 TENS PS5 LB 500347 O0 000 O0 0 12 1 1 4 68 0000000000 GR PS5 GAPI 500347 O0 000 O0 0 12 1 1 4 68 0000000000 CCL PS5 V 500347 O0 000 O0 0 12 1 1 4 68 0000000000 ** DATA ** DEPT. 10539.500 SIGM. PS5 13.290 TPHI.PS5 17.725 SBHF. PS5 65.957 SBHN. PS5 87.222 SIGC. PS5 0.150 SIBH. PS5 129.545 TRAT. PS5 1.420 LCO1.PS5 1.794 SDSI.PS5 0.328 BACK. PS5 76.758 FBAC.PS5 17.876 TCAN. PS5 18922.344 TCAF. PS5 10546.275 TCND.PS5 11090.494 TCFD.PS5 4838.679 TSCN. PS5 3816.818 TSCF. PS5 2127.285 INND.PS5 1436.175 INFD.PS5 324.438 TENS.PS5 1240.000 GR.PS5 38.438 CCL.PS5 0.000 DEPT. 10450.000 SIGM. PS5 14.017 TPHI.PS5 21.407 SBHF. PS5 66.617 SBHN. PS5 91.694 SIGC. PS5 0.223 SIBH. PS5 143.445 TRAT. PS5 1.525 LCO1.PS5 1.959 SDSI.PS5 0.363 BACK. PS5 79.704 FBAC. PS5 19.517 TCAN. PS5 16578.082 TCAF. PS5 8463.666 TCND. PS5 9988.449 TCFD. PS5 4059.995 TSCN. PS5 3250.215 TSCF. PS5 1659.344 INND. PS5 1459.849 INFD.PS5 334.816 LIS Tape Verification Listing Schlumberger Alaska Computing Center il-JUN-1996 10:14 PAGE: 43 TENS. PS5 1560.000 GR.PS5 DEPT. 10235.000 SIGM. PS5 SBHN. PS5 82.629 SIGC. PS5 LCO1.PS5 2.046 SDSI.PS5 TCAN. PS5 7765.808 TCAF. PS5 TSCN. PS5 1545.715 TSCF. PS5 TENS. PS5 1515.000 GR.PS5 47.094 CCL.PS5 20.101 TPHI.PS5 0.474 SIBH. PS5 1.063 BACK. PS5 3796.403 TCND. PS5 755.640 INND. PS5 119.375 CCL.PS5 0.000 24.384 SBHF. PS5 126.784 TRAT. PS5 92.646 FBAC. PS5 8230.184 TCFD.PS5 1479.883 INFD.PS5 0.000 71.617 1.412 21.516 2862.540 321.973 ** END OF DATA ** **** FILE TRAILER **** FILE NAME : EDIT .012 SERVICE : FLIC VERSION : O01CO1 DATE : 96/06/11 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : **** FILE HEADER **** FILE NAME : EDIT .013 SERVICE : FLIC VERSION : O01CO1 DATE : 96/06/11 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : 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: 0.5000 FILE SUF~ARY VENDOR TOOL CODE START DEPTH TDTP 10537.0 $ LOG HEADER DATA DATE LOGGED: SOFTWARE VERSION: TIME LOGGER ON BOTTOM: TD DRILLER (FT) : TD LOGGER (FT) : STOP DEPTH 10248.0 O1-APR-96 42.2 1122 O1-APR-96 10535.0 11478.0 LIS Tape Verification Listing Schlumberger Alaska Computing Center Il-JUN-1996 10:14 PAGE: 44 TOP LOG INTERVAL (FT) : BOTTOM LOG INTERVAL (FT) : LOGGING SPEED (FPHR) : DEPTH CONTROL USED (YES/NO): 10250.0 10526.0 1800.0 NO TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE CCL CCL GR GAMMA RAY TDTP THERMAL DECAY $ TOOL NUMBER CAL-UB-299 ATC-CB-1108 TDTP SET 23 BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLERS CASING DEPTH (FT): LOGGERS CASING DEPTH (FT): 10988.0 BOREHOLE CONDITIONS FLUID TYPE: FLUID DENSITY (LB/G): SURFACE TI~PERATURE (DEGF) : BOTTOM HOLE T~PERATURE (DEGF) : FLUID SALINITY (PPM) : FLUID LEVEL (FT) : FLUID RATE AT WELLHEAD (BPM): WATER CUTS (PCT) : GAS~OIL RATIO: CHOKE (DEG) : BORAX WATER 5.0 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): R~KS: TIED INTO BHCS DATED 10/26/77 *** JOB SEQUENCE *** PUMP 330 BBLS CRUDE + 12 BBLS BORAX WATER: MAKE BASE PASS PUMP 38 BBLS BORAX WATER: MAKE BASE PASS #2 PUMP 25 BBLS BORAX WATER + 15 BBLS CRUDE: MAKE BASE PASS # APROX, 20 BBLS BORAX BEHINDPIPE: MAKE BORAX PASS #1 APROX, 35 BBLS BORAX BEHINDPIPE: MAKE BORAXPASS #2 LIS Tape Verification Listing Schlumberger Alaska Computing Center Il-JUN-1996 10:14 PAGE: 45 $ LIS FORMAT DATA ** 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 ** 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 500347 O0 000 O0 0 13 1 1 4 68 0000000000 SIGM PS6 CU 500347 O0 000 O0 0 13 1 1 4 68 0000000000 TPHI PS6 PU 500347 O0 000 O0 0 13 I 1 4 68 0000000000 SBHF PS6 CU 500347 O0 000 O0 0 13 1 1 4 68 0000000000 SBHN PS6 CU 500347 O0 000 O0 0 13 1 1 4 68 0000000000 SIGC PS6 CU 500347 O0 000 O0 0 13 1 1 4 68 0000000000 SIBH PS6 CU 500347 O0 000 O0 0 13 1 1 4 68 0000000000 TRAT PS6 500347 O0 000 O0 0 13 1 1 4 68 0000000000 LCO1 PS6 500347 O0 000 O0 0 13 1 1 4 68 0000000000 SDSI PS6 CU 500347 O0 000 O0 0 13 1 1 4 68 0000000000 BACK PS6 CPS 500347 O0 000 O0 0 13 1 1 4 68 0000000000 FBAC PS6 CPS 500347 O0 000 O0 0 13 1 1 4 68 0000000000 TCANPS6 CPS 500347 O0 000 O0 0 13 1 1 4 68 0000000000 TCAF PS6 CPS 500347 O0 000 O0 0 13 1 1 4 68 0000000000 TCNDPS6 CPS 500347 O0 000 O0 0 13 1 1 4 68 0000000000 TCFD PS6 CPS 500347 O0 000 O0 0 13 1 1 4 68 0000000000 TSCN PS6 CPS 500347 O0 000 O0 0 13 1 1 4 68 0000000000 TSCF PS6 CPS 500347 O0 000 O0 0 13 1 1 4 68 0000000000 INND PS6 CPS 500347 O0 000 O0 0 13 1 1 4 68 0000000000 LIS Tape Verification Listing Schlumberger Alaska Computing Center Il-JUN-1996 10:14 PAGE: 46 NAME SERV UNIT SERVICE API API API API FILE NUMB NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUMB SAMP EL~4 CODE (HEX) ....................................................................................... INFD PS6 CPS 500347 O0 000 O0 0 13 1 1 4 68 0000000000 TENS PS6 LB 500347 O0 000 O0 0 13 1 1 4 68 0000000000 GR PS6 GAPI 500347 O0 000 O0 0 13 1 1 4 68 0000000000 CCL PS6 V 500347 O0 000 O0 0 13 1 1 4 68 0000000000 ** DATA ** DEPT. 10539.500 SIGM. PS6 22.751 TPHI.PS6 28.478 SBHF. PS6 SBHN. PS6 85.700 SIGC. PS6 0.587 SIBH. PS6 135.070 TRAT. PS6 LCO1.PS6 2.230 SDSI,PS6 1.357 BACK. PS6 90.299 FBAC. PS6 TCAN. PS6 5934.886 TCAF. PS6 2661.375 TCND.PS6 7588,168 TCFD.PS6 TSCN. PS6 1180.239 TSCF, PS6 529.253 INND.PS6 1484.080 INFD. PS6 TENS.PS6 1255.000 GR,PS6 48.563 CCL.PS6 0.000 DEPT. 10450.000 SIGM. PS6 14.604 TPHI.PS6 20.417 SBHF. PS6 SBHN. PS6 91.677 SIGC. PS6 0.108 SIBH.PS6 142.562 TRAT. PS6 LCO1.PS6 1.889 SDSI.PS6 0.459 BACK. PS6 90.071 FBAC.PS6 TCAN. PS6 15856.732 TCAF. PS6 8396.256 TCND.PS6 9556.912 TCFD.PS6 TSCN. PS6 3167.583 TSCF. PS6 1677.258 INND,PS6 1428.142 INFD.PS6 TENS,PS6 1545.000 GR.PS6 49,344 CCL.PS6 0.000 DEPT. 10246.500 SIGM. PS6 12.968 TPHI.PS6 16.558 SBHF. PS6 SBHN. PS6 79.557 SIGC. PS6 0,145 SIBH. PS6 114.220 TRAT. PS6 LCO1.PS6 1,748 SDSI. PS6 0,344 BACK. PS6 100.079 FBAC. PS6 TCAN, PS6 19970.906 TCAF. PS6 11423.012 TCND. PS6 11992.756 TCFD,PS6 TSCN. PS6 4081.945 TSCF. PS6 2334.801 INND.PS6 1536.240 INFD.PS6 TENS.PS6 1480.000 GR,PS6 45.750 CCL.PS6 0.000 73.562 1.438 21.164 2516.403 321.985 78.574 1.471 21.869 4001.884 311.141 64.573 1.389 21.988 5297.030 335.499 ** END OF DATA ** **** FILE TRAILER **** FILE NAME : EDIT .013 SERVICE : FLIC VERSION : O01CO1 DATE : 96/06/11 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : LIS Tape Verification Listing Schlumberger Alaska Computing Center Il-JUN-1996 10:14 PAGE: 47 **** TAPE TRAILER **** SERVICB NA~E : EDIT DATE : 96/06/11 ORIGIN : FLIC TAPE NAME : 96103 CONTINUATION # : 1 PREVIOUS TAPE : CO~4ENT : ARCO ALASKA INC, D.S. 1-11, PRUDHOEBAY, 50-029-20268-00 **** REEL TRAILER **** SERVICE NAME : EDIT DATE : 96/06/11 ORIGIN : FLIC REEL NAME : 96103 CONTINUATION # : PREVIOUS REEL : CO~.I~T : ARCO ALASKA INC, D.S. 1-11, PRUDHOE BAY, 50-029-20268-00 ****************************** , * ~b~8KA CO~PUTIMG CENTER * ****************************** *mmmmmmmmmmmmmmmmmmmmmm~mmmm~ *mmmmmmmmmmmmmmmmmmmmmmmm~mm~ ******************************* COMPANY NAME : ARCO AI,ASK~, INC, BOPOUG~ : NO~T~ S~OPE aP! ~O~BER : 50-029-20265-00 REFerENCE NO ~ 94399 1. ~-JAN-1995 0~:18 TAPF NE~ .D~R PPUr~HOE ~Y C~$rD HnLE WlREI, J.',~,!E L..n.G$ WFLT. LOGG i ~..'G COMPA~.~Y: TAP~ CR~:A~ION D.A. TW: SI.lA'ACE LOC~IION 8g~ ',r I o n: ET,EVATIO~.~(FT FROM ~.'iSL O) KET;LY ~L!S},{!~.iC: DE~RTCF FLO0~: CROUND L~V~L~ WELT, ~ASI~.~G RECmR~ 1ST STD][MG ?ND STD I ~!G PR .~.D!.~CTION S~R T[~G D,S. i'11 5o0292n26800 hRCO ALASKA, .INC.. SCHLUMBErGeR WELL SERvICE~ 18-dAN-g5 94399 TO~ ALl, EM ? O0 OPE~.~ ~OT.,E: Ca.~TNG D~II.,L~RS CASING blt $IZZ (IN) $~ B (IN) DEPTH (FT) wEIGHT (LB/FT) llIIl~IIl~III llllllll~ llIllIlII~ IIIlIIIIIlllIl' 1~..375 271.3.0 72,00 ~,,625 10988,0 47',00 5,500 9894,0 17,00 4,500 10024,0 12,60 PAGEI IS 't'a~e Ver.~cat.lon l.;ist!n~ :blUe;~'er,']er Alaska Cor~.~:,}..)t~nr.~ Center IR-OA~..~-lgq5 08;18 [:. C ~ 6:: R I "'E · () , ¢'! ,.'5 o0 o0 10725.0 !0701,5 1. 0~95.5 1067V,5 1 0~51,5 tu6a?,5 10624.5 10624.5 10519.':; t0476.0 1.0476.0 ) 0454..5 10449.0 104.4~. ~ .10445,¢, 1,0357.5 10)57.$ ~0340.'~ .1. 01.5 U .."': $ H I FT~.D DFP. TH---- .... -- THE J:NFORmATIO~r',J PERTAINING TO ~HE OPEN HO[,F~ GR "SUCH AS TgE DEPTf.) CORRECTIONS $~{OWN ABOVE REFLECT CASED HO~E 'GR 'l'C nP[:i~ HOL~ GR A~D CASED [~Ob~ SIGN TO OPEN HO'bE 'GR Al..h UTHER l'"' T...).,EP CURVES ~'ERE CARRIED WITH THE SIGN $ 995 O8: .~ 8 curves for each uass ~n separate ~iles, YDuG TOOL CODE 13;i27; .... 1.074~,n STOP DEPTH 10300.0 t0300.O R A,~EL I ~.,'E DFP~ $ .......... EOIIIVA[,EVT UwSHIF'IED DEPTH ...... ---- wE"?A~KS: TNIS F.[l.,h; CO~iTAIf~S PASS ~{ OF THE TOTP. MO PASS TO PASS SH~FTS wErE APPLIED TO THIS DATA. b~S F~R~AT OATA TYPE : CO~,!S . FI, 898' FNL & 777'FWL · S~CT 8 TO~ 10~ R~N~ COU~ NORTH SLOPE 'STAT ALASKA N~.T! USA ~TT~,! ]:'OM ALLE~ SON 480775 PnAT EPD ~'T 0, L~F A~9 ~T · g~ WT 73, EDF ~T Well Name API Serial Number Field. Location Section Township Range County · State or Prov~n~e Wltngss Name ServiCe order NUmber Permanent.datum Elevation o~.Pe~ma~en~.Da.~um boq ~ea.sured From Above Permanen~ Datum .~. · Elevation of .Kelly Bushing Eleva io~ ' ~leva~ o~ Der. rlcK.'Floo~' ion of Ground'bevel IS l'ane verl. fJ. cat.~,on t isttnc Cbl-n':berqer A]..a~K..a. ComPutiao (:enter IR-JA~!-I 9q5 0~:18 PAGEt 4 l'))~".!' VA[.,Li DEFT ........T~r, ;~ .................................. 10747: .......................... Total.' ....'''''''''''''''''''''''''De~th - Driller 'I'PL ~% 10741, Total DePth - Logger B~,I ~']' 10735, 8ottom bog Interval T[.I ~2 lOlOO, Toy Log )nterval DPT CPbgE/$RAWATER/RO~AX Dr lling Fluid Type TlRn 11:15 25-~A~-~4 Time bogoer at Bottom ST~? n£~F o Surface Temperature ~T ngnF 1~5. ~tom Hole Temperature mmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmm mmmmmmmmmmmmmmmmmmmmmmmmmmmm TRB!:i?: TYPF: : CdPV Pm.~'T D WPq' Death STGu Sigma C~eutron Capture Cross section) TPMl TDT POrOSity S~HF ~o'rehol. e Sigma - far detector $~}.~ Poreho]e S~gma - ~:ear detector STGC sioma Correction ST8u Corrected ~orehole Si.~ma TPAT ~atlon Total [~ear to Far counts 5DST Standard ~evIation of $1~ma B~CK BacKgrounO Count Rates - Near Detector' FBAC BacK,tau'nd Count Rat~ - Far ~etector ~CA~! Total counts analyzed - near detector (TDTP) TCAr Wota] counts analyzed - far detector (TDTP) TCNO Total capture counts - ~ear detector TCFD Total capture Counts - far decteetor TSC~ Total Selected Counts - Near Detector TSCF Total Selected Counts - Far Detector I~'Nn Tr~elastic count rate - near detector I~FD Inelastic count rate - far detector GPCF Gamma ~av'~n Cas~n~ T~Ne T' .... · ,~ Surface enslon CCi, CCL ~mplltude G~ ~PI-Corrected Gamma ~av ** DATA FOR~A· SPFCIFICATIOM RECOnD ** ** SET TYPE - 64ER ** .Y CODE I 66 0 2 ~6 0 3 73 92 15 v'ar>e Veriflcat.~on List~no Chlt~ir,.berqer AlasKa Co~'Putt. r~o C. enter 18-J A ~',~ -.1.. 9 9 5 PAGEt 7 65 8 68 0,5 11 66 11 17 68 13 66 0 14 fi5 WT 1~ 66 I (,, 66 0 SRR U~:IT $~PVICF AP1 FILE NUmB N SIZE REP PROCESS TD n~DER ~ bOG TYPF CLASS ~OD NUMB SA~P ELaM CODE (HEX) FT ~80775 OO o00 oo 0 1 1 1. 4 68 0000000000 CU d, 8~775 On OOO O0 0 1 1 1 4 68 0000000000 Pl~-S 4.~n775 (.)0 000 O0 0 1 I 1 4 68 0000000000 C!! 480775 uO 000 O0 O 1 1 1 4 68 0000000000 CU 480775 O0 ~00 O0 0 1 1 1 4 68 0000000000 C~ 480775 On 0o0 O0 0 I ! I 4 68 0000000000 CU 4~0775 O0 000 O0 0 1 I I 4 68 0000000000 ¢~0775 O0 000 O0 0 I I I 4 68 0000000000 C[{ 460775 O0 000 O0 0 1 l 1 4 68 0000000000 CPS 480'175 O0 000 O0 0 1 1 1 4 68 .0000000000 CPS 480775 OO 000 O0 0 I I 1. 4 68 .0000000000 CPS 4~o775 O0 000 .00 0 i ! ! 4 68 '0000000000 CPS 480775 O0 000 O0 0 I I I 4 68 0000000000 CPS 4~0775 uO 000 OO 0 I I 1 4 68 0000000000 CPS 480775 OO ~00 O0 0 I ! 1 4 68' 00'00000'000 CPS 4~0775 O0 000 O0 0 1 i 1 4 68 0000000000 CP~ 480775 O0 000 O0 0 I I 1 4 68 0000000000 CPS 480775 O0 000 O0 0 1 1 1 4 68 0000000000 CPS 480775 O0 000 O0 0 1 I 1 4 68 0000000000 G~PT 480775 UO O00 gO 0 I 1. 1 4 68 0000000000 LB 4~n775 O0 000 O0 0 1 1 1 4 68 0000000000 V ~8o'775 O0 000 O0 0 1 I 1 4 68 0000'000000 G~P~ 4~r~775 DTPT T~HY TDTP SBHt! TDTP STCC ~DTP SIS~ TD~P T~AT TOTP SD$~ TbTP BAC~ TDTP FBAC ?DTP TCA~ TDTP TCA~ TDTP TC~ ..... TCFm TD~P T~C~ WDTP S' .tDTP · INFD TDTP G~CH TDTP CC[, TD~P GP RCS DFPqr'. i 0750 . ',)0,0 $1GM.TDTP -990 250 TPHI.. TDTP =999':.250 $,UH~:. TDTP -999.250 S I C C. "],]..inTP -999.'250 SIFH... TDTP -999.,.250 SDS?.mf)TP -999.2~0 gA("l<~. DTP -999 9,50 FBAC.'TDTP -999.o.250 TC.t~'. TDT f' -~9.9.2':;o T C I~! {.). T D,Ti, p ,,'q9 g :..250 'TCFD,.TDTP 999.'250 TSCF.TDTP -909.250 ! ~,~N. O..TD P -999.250 ..T. NFD. TDT~ -'999.. ~50 'SBHE'TDTP' TRAT.,TDTP TCAN.TDTP TSCN,.TDTP GRCH,TDTP ;'.~999-250 999 ,~250 IS Wa~e V~r~ficat~on List!no :hlu~::,'~erq~r ~lasK~ Computino Cemter 1~-~AN-]995 Sm~.',TOTP ~$T.TRTp TC~F.TD~? T~Cm. TDT9 -999.25~ -999.2Ft 35,000 $ !G:.~. T r~'l" P ~ I <:-C. 'r p 1'p P, ACK. Tn'to T :'~ P t'), '1' n'{.' t~ CCb.'I D'rP -999.250 -999.750 -999,250 -99g.25n -999.250 TPH:.TDTP SIBH.TDTP FBAC.TDTP TCFD,TDTP INFD,TDTP ~R.BCS -999.250 SBHFoTDTP -99g.250 TPAToTDTP -999.250 TCAN.TDTP -999.~50 T$CN.TDTP -99g.250 GRCH.TDTP 31.00o PAGEI '999,250 '999,250 '999,250 '999.250 '99g,250 FTL~ NAUE : rl)T'F .onl SwRViCF : FLTC VF'~lo::i : o01C01 D~T~ ~ a5/G1/18 ~X R~C $~Z~ : 1024 F?bW TX'D~ bAST FILE **** FTLM ~4EAt)ER **** FTLF ~A~E : ~DTT ,002 8FRVICE : Fb~C VERSION : O01C(')I ~X ~EC SYZ~ : !.024 FTRK I'Y~E : LO L~ST FiLE E~I~ED CURVES DePth Shifted end clipped curves for each pass in .separate ~tles, P~SS ~U~$~R: 2 D~PTH I~C~E~E~T: 0.5000 . . STOP DEPTH 10300,0 10300,0 IS Ware Ver{.f, icat~on f,istlno. ¢hlt;~r,.~er;er Alaska Co,-.'[:',.ut~n~ Center 18-JAM-1995 08:~8 ~747 5 0726.5 07~.5 0714,5 069~,5 ~}~94,5 0g81.~ 0~7~.5 0670.5 0~54 5 0~53i5 065~ O~4e,~ 064~ 0637 0613,5 062~.5 601'5 059~ 5 0593 5 0589 5 05'1~ 5 057~,5 0570,5 0557,5 0554,~ 055~,5 0549°5 0 K 46,5 .......... ~OUIVALE~!I U~$HIFTFD GRC~ ~t~743.0 ~0739,0 ]0734.~ 10730.5 1.0727.q !.0723,0 10715°0 10690.0 10695,5 ~69~,0 1069~.0 1068~,0 ~0674,5 10669,5 10665.5 1066~..5 1065].5 10650.5 10646.0 !0649,0 10637.5 m0633,5 10630.5 10610.5 ~.060~.5 10594,5 10591.,0 1O586.5 !.0650 5 1.0655[0 1.0651.5 10623.5 10598.5 10595.0 10579.0 ~0575.5 1057~.o 10556.0 mo551..5 10547.0 DEPTH- ....... IS Yrape ver.J, flcati, on chl.n'her.:...}er AlasKa Pomp,.~tin~ Ce.ret PAnEl .~ 0526.5 1,.)51B,5 ! 0514.5 1050~.5 1 04g~ ~ ) o494~ 5 10486.5 1 )0482.5 1 ()4.6~ 5 1 0462 ~ ~ 1 0454. ~ i 0430 ~ ~ ~042q.~ ~ 04.2~ 5 1 )04U6,5 10401,S io)gg,~ ~0t90,5 10382.5 1 0181 ~ ~ 0'377, ~ ~ 0373.5 10)62,5 0B54 5 .. . s 0350 5 ) 0~49., ~ ~0337,~ 0452.0 007 q · 5 10434,5 10430.0 ]0402,0 !.0394.0 10386.0 1..0382.5 1037~.5 ~037~,0 10370,5 10354.5 I0350.0 1033R.0 1u527,0 I0523.5 ~0510.5 ~0515,0 10511.5 !0507.0 10503.5 1.0499.~ 104~6.5 104.93,0 !048~.0 10483.0 10479,5 10471.5 ~0467.0 1O463.0 10459.5 ~0456.0 10451.5 lu431,5 10428.0 !.0424.0 104 .'5 10408.~ 10404.0 !0398.5 10395,5 10391.5 .10387,0 10383-O 1.0370.5 1.0363.5 10360,0 10.356.5 10351.5 10347.'~ ~'0343.0 IS Ta~e verification Listino lf~,'JAN-~[995 08:18 PAGE~ 10t34.~; 10335,o ~.~26'~ 10327 1.0322,5 ! 0]ln,5 1032n.0 ~ 10315,5 (')~t4'a 101 !On. . . . °E~.~,APK$: '1~[$ FILE CO~'~TATNS PASS W2 OF THE TDTP. THE DEPTH Cnh'~£Ct;:YL.)~'$ ;i~OW?~ ABOVE REFLECT P~SS ~2 G~CH TO PASS GPCF ~,:~ PA~8 ~2 SIC~ TO PASS ~1 8IG~, A. 5[, OTHER TDTP C~}RV~S ','~5~ CARPIED ~ITH THE SIG~ SHIFTS. I, TS F~RUAT ~ATA TABLE TY'P~ 2, COtiS C~ F~' P~UDHOE BAY W~ D.G. 1 ' 1.1 API~ 50'02g'20~68-00 FI, 898' FNL & 777'FWL $~CT TO~ ION R~ 1SE COUN hORTH ~LOPE STAT ALASKa. NaTT USA WIT~' TO~ AL~EN $O~. 4R0775 P~A~ MSL EPD rT 0 APD FT 7~, EK8 ~T 73, E~F ~'r 7~, E~L FT 34 TOD '~T 10~47, T~L FT 107~1. BLI FT 1~735, DFT CRI,JDE/$EAWATE~/BOgAX TLA~ 1.1:~5 25-MA~-94 BET · Well Name APl Serial Number Field Location Section Township Ranae County Sta~e or Province Nation Witness Name. Service Order Number Permanent datum 'EZeva.tton of Permanent Datum 'boq ~easured.'rrom Above Permanent Datum ,,.. El. evat$on of Kelly.BuShing Elevatlon o~ De r!c _rlogr Elevation ot.Ground, bevel 'Total Depth '- Pr'iii. er. Total DePth'- Logger: erV&l Bottom Log Iht · TopL[,OO 'Interval. Drilling Fluid T Time bogcer.'at BIpe ttom Surface Temperature · 9E~,,',~' 1~5, Bottom... Hole ,~empe'rature ............ center 18-0A,~,-!995 OB;18 T~6I.:E '.i:Ypm : CL~V STGu Slon~a (:'.,eutron Cavture Cross Section) :fPHT ~DT Porosity S~r ~orehole 81q~a - far detector $~ ~orehol. e St.~ma - ~-ie~r detector STGC Sigma ~orrectinn STUn Corrected ~orehole TPA~ ~attnn Tnt~l ~,ear to ~'er counts $~87 Stan~ar~ d~vtatlon of $icma B~C~ ~ackorOUnd Count Rates - ~.~ear Detector F~A~ nac~oround Co,Iht ~ate - Far ~etector TCA~ Total counts analyzed T~A~ Total counts analyzed - far detector (TDTP) TC~iD Total capt,]re counts - ~ear detector TCFn Tota] camture Counts - far dectector T~C*~ Total Se]lect~d Counts - ~ear Detector TSCK ~ntal .Selected Counts - Far Detector I~hm Tnelastic count rate - near detector INF~ Tnelastic count rate - far detector G~C~ ~amma Pay ~n Casino TFhF Surface Tension CCL CCh ~mmlttu~e m~m~~~m~~m~m~m~m~m~m~m~m~~m~m~m~~ PAGE~ 10 ** OATA FORMAT SPECIFICAT!L)M ~ECURO ** ** SEm T¥~E - 64. ER ** TYmC ~gPm CODE V~GUE I 66 0 2 66 0 3 73 5 66 7 65 8 68 0,~ 11 66 11 17 68 i4. 65 WY 15 6~ 68 16 66 O 66 1' IS ,'ane V-ri. flcati, on lJist,,lno :hlt.~her~er AlasKa Comput!n~ Center 18-jAN-.1995 08:18 PAG~ · . ._,rdV ~E.~V,TC API ~P~ AP P! PILE w.B NUmB IZE ~EPR PROCESS DFPT FT 48~775 O0 000 00 O 2 ~ 1 4 68 0000000000 S ? (~" T [.)Tp C!' 4. <30775 0(; 0n0 00 'II'm).{? TOTP PU-S 49n775 SRh~ TDTP CU 48n775 o0 000 O0 6TGC TDTP CU 4~0775 r)o 000 O0 ST~u ~DTP C~ a~0';75 nO 000 O0 T~A~' TDTP 4.~n775 SPS7 TI)TP CI~ 480775 00 900 00 FRAC TDTP CPS .480175 O0 000 OO ']>c A %' TDTP CPS 480775 O0 000 O0 TCAF TDTP CPO 4B0775 t~ ~..; 000 O0 TC ~.~D TDq'P CPS 480775 O0 000 00 TCF~ ,r0mp CPS a~o775 00 000 O0 T~C~~ TI.)TP CPS 4~0775 O0 O00 00 TSCW ~'Dmp CPS 4~n775 on 000 00 IN'ND TDTP CPS d80775 I ~FD '~DTP CPS 4807~5 00 000 00 G~C" ~OTP GfiPI ~0775 O0 000 O0 0 2 ! 1 4 68 0000000000 0 ~ I 1 4 68 0000000000 0 2 1 1 4 6~ 0000000000 0 2 1 I 4 68 0000000000 0 2 1 I 4 68 0000000000 0 ~ 1 1 4 6~ 0000000000 0 ~ 1 1 4 6~ 0000000000 0 2 I 1 4 68 0000000000 O 2 I 1 4 68 0000000000 0 ~ I 1 4 68 0000000000 0 ~ I 1 4 69 0000000000 O ~ I 1 4 6~ 0000000000 n ? 1 1 4 68 0000000000 0 ~ ! 1 4 68 0000000000 0 2 1 1 4 68 0000000000 0 2 1 I 4 68 0000000000 O' 2 1 1 4 68 0000000000 0 2 1 1 4 68 0000000000 0 ~ I 1 4 68 0000000000 DEPT. 10746.000 SlCa.,~:?DTP 12,371 .TPHI,.TDTP 40':964 S~H~..TDTP 37.673 SlGC,T~TP 3.153 SI~H,,TDTP 37.673 SDST.TDTP 0.444 BACK.TO~P 133.840 'FBAC'iTDTP 25.860 TCAF TDTP 3718.341 TCND.TDTP ~6749,6~4 TCFD,TDTP 378~.,.763 TSCW:TDTP 729.618 IN~O',~TDTP '1251,'0 $ "'INFD:eTDTP 229'7.0'6' T~NSoT~TP !365,000 CCL.,TDT~ 0.000 DEPT. 103o0.000 SI~',TDTP $~H~.TDTP 38.471 8IGC'.'TDTP SDST.TDTP 0.4~0 BACK;TDTP TCAF.~D~P 17745.]01 TCND','T~TP T~CF.TDT'P' ]510.3~9 IN~D, TDTP T~NS,TDTP t285,o00 CCL.TDTP 11 60 141']. 0.000 TPHI.',TOTP S. IBH..TDTP 'FBAC,'TDTP. T'CFD:*'TDTP 21,058 'SBHF'TDTP '27,4ii 38..,,47.14 'TRAT,?D?P . ~ I;,725 · 1~,,~'7 'rCA~o?DTP 402.71~',53! 8960.768 TSCN..TDTP. .17966~.4i0 345,651 GRCH..?DTP 1.7';'297 11 IS TaPe ver~ff, cat!on Listfna :blUr',berber Al. asK...a Comp,~tino ,....'.enter 08;18 SFI{~ICE ~ rbfC VFRglO~ : 09!.CO1 D~TF ~ obt!~l/I8 ~X R~C 6~ZE : !024 FTL~ ~YDf: : LO FTLF ~A~E : Fi)IT .Oa3 SFRVIC~ : F(,TC VFR$in/~ : 091C01 DATF ~ ~i~X ~{~C $1Z~ : 1.074 FILv TYPF ~ FTLF ~tJ~S~g 3 EDI~EO Cb~V~S ~e~th Shifted and c11p~ed cuTves for each Pass ~ separate 'fXle~. P~S~ ~U~B~R~ 3 ' DFpTH I~!C~E~E~T: 0.5000 FTLF SU~,~ARY LtJ~,~G TOO[., CLYDE START DEPTf,! STOP .DEPT~ ..... .... ..... .... ........ Gl{CH 10714'n.. 1030O,O TDTP 1074~, 0 10300,0 ~ · "' CURVE SN'IF.T D.~T~ - PASS TO PA~$(MFASURED DEPTg) BASELINE CURVE f'OR $~IFT$ "' ~O~ CURVE CODE'! GRCH P~SS ~U~SER~ 1 ~ASELINE DEPTH ~8P88..0 10736'5 .0728: ~0716,5 ~071~,5 m0695.5 ~691.5 ~ 687,5 '' ..... ---~OUIVALENT UNSNIrT~D D~PTH----.--..- GRCH TDTP '" '" 1.07 .0 10729°5 10726,0 10718,0 ~0715,0 10710.5 10697.5 10693,5 18-JAN-~.995 08:!8 10683,5 ~065n.5 ]067g.5 ~0675,5 ~067~,K 1066g,5 10664,5 1U660,5 10~55,5 1065~,~ 10~5],5 10647,5 10640,5 !063~,~ 10&36,K 1063K K 1 063~ ~ ~062~ 5 10627 ~ 1.0624,5 1.0620,5 ~060g,~ 10~04 5 lO o :s !.0600 5 1059g:5 ~0596,S 10~9~ 5 ~0592 5 ~05.80 5 ~0576 K ~0567 5 1056~ 5 10543!~ 10536,~ 10527,5 10524o5 !0523.5 ~05~6o5 ~0~03,5 1068.6.n 10681.5 1.0677,0 10657,0 1065~.5 106~,5 !064~,0 10641.0 10637,5 ~0634.5 10610,0 10605,5 10602,m ~.0597,5 10593,0 10569,0 1.0565,5 10561.,0 10557 5 i0541,0 1052~.0 10525,5 t 05 o~;, 5 10676,0 10672,0 1.0667,5 ~.0662.5 10654,~ 10650.0 10647,0 !OR3P.O 10634,5 10631,0 10626,5 1.0622,5 10619,0 JO~l. 4,0 1.0611.,0 J0606,0 10601,5 10~97,5 ~0594,0 1.0537 5 {.0534:5 10530,5 {0526,0 .1051B,0 10514,5 ~0502,5 verification .r..is tin~ :hlumherq~r A]..aska ¢:on:F.'.utfn~. Center 14 10495,5 I O~g'2.c~ 10~8'7, ~ ~0484.g 1 10460, c; ~ 0456,,5 10~5~,5 1 ()~52.. o r~ ~0451,5 !0447,~ t 0~27,5 I o416.5 ~ o415.K !04 . ,~ 1040a,5 10404,B 10400,5 ~0387,5 I 0383,5 1 0379 5 ~ 0375 5 ! 036R 5 ~ 0~67 ~ 10364 5 !. 03e3 5 ~ 0359 5 ! 0356 ~ 10355 5 10~ I 5 I O348 5 ! O344 5 ~ 0340 5 1 0332 5 ~ 03~4 5 10309 10316,5 ' !031~,5 10494.n 10457.5 t045~,0 I0444,5 10437,5 !.0434,n t042e,5 1.04t'?,5 10413.0 10389.0 1.( .... 10351.0 1037'7.9 1036.o_.5 10365,0 {.0361.5 10357.0 10353.5 1.02.0 !.05on,0 1~486o0 10~82.5 10462.5 t0450.O ~0454.5 1O426.5 ~.04 o 1.0414.5 10410.0 10406.0 1.0402.5 1037.0.5 10367,0 1036.2,5 10158.0 10354,.0 10351 0 10346 5 1034~ 0 10338 0 1.0334 5 t03 5 !.031~.0 1.0314,~ 1.02,0 THIK FILE CONTA!NS PASS .~'3 OF .THE TDTP. THE DEPTH CORRECTIOr~S SHO%~.~ ABOVE REFLECt' PASS #3 GRCH TO.PASS G~CH AND PASS ~3 SIGH TO PASS #1 SI~M, ALL OTHER TDTP #I IS ~'a~e Yer~.ftcatlon ~,lstlm~ :hlumber~er AlasKa Computtr',~ Center iA-JAN-1995 08;18 PAGEI 15 WTT.~~ EPD mT b~F EDF FT E~b TPD TDL FT .BLI FT TI.,I FT DFT .. TLAB T!!~'~ vALLi OEF! C~! A.~CO ALASKA, INC, CompanF Name P~UDHOE BRY Field Name D.~. 1 - I1 Well Name ~0 02g-~0~6~-00 AP! Serial Number 80~' wNb & 777'F~L Field Location 8 Section 10N Township 15E Range NORTH ~LOPE County AtASK~ State or Province OMA .ation TO~ ALLEN Witness Name 480775 Service Order Number. ESL Permanent datum 0 Elevation of Permanent Datum R~B bo~ ~easu. red.'rro~ 73, " AUove Permanent Datum' 73, Elevation or.Kelly. BUShing · 72, Elevation'or Oe'trle~..rloor. 34, Elevation or.Ground beve! i0741:0747 Total Deoth - Drt~Zer :?ora! DePth.'~ boggg, r ~o735, 8ottom bog Interva~ 10100, .Top ~Oq IntervaZ ~UDE/$EAWATER/BOeAX Orii·~fio rl. uld.Tyge :15 25-~AR-94 Time ~o~er..'at O, " '$ur[ace ?e'mpe'rat~re ~w~ D'£CF · · . lqS, ..Bottom Hole.Temperature ........... T~BLE TYPE : CUPV TPHT SBHF T~AT SDS! BAC~ SlOma CNeutron Capture Cross Section) TDT Porosity ~oreho,le Siqma - far detector Roreho.le Sigma - Near detector Sloma Correction Correcte~ Borehole Sigma ~atlon Total Near to Far couDts Standard ~e¥1atlon of Sigma Back,round Count Rates -'Near Detector £$ Tac. e Yeritication blstina :hlumberger ~:las~.a ~omputiriq Center 1 a-d.g,',l-I 9g5 08:~8 DEFT F- BacK~roun,'-; Co~nt Ra ar Detect TCAK: TOtal cou~ts analyzed - ~ear detector TCAF '*oral counts ana3yze~ - iar detector (~D~P) TC~r. "rural caoture counts - Near detector TCF~. Total cant,~re Counts - far 6ectector TSC~ Total Selected CoUnt~ - ~.;ear Detector TSCr Wotal gelected Counts - Far Detector I~}~'~ Voela$rlc count rate - near detector I~.~K~ Inelastic count rate - far detector G~C~ Gamma Pay t.n Casin~ TFN~ $~rface Tension CCL eCL amplitude PAGEI 16 ** PATA. FnR~.A~.' SP¢CIFICaT.TOt~; ~/C01~[3 ** 2 66 0 4 66 J 5 66 6 73 7 65 8 68 0.5 1~ 68 13 ~6 0 15 66 68 16 66 ~ O' 66 1 ** SET TYPE - CHA~.**. N~w SFRV UMIT S5~VIC~ APl API AP1 API FIbE NUmB NUmB SIZE REPR PROCESS ~D ORDE~ # bOG TYPE C5~'$$ MOD ~U~B. SA~P .~L~M CODE. (HEX) .... DKPT FT 480775 O0 000 O0 0 3 -i I 4 68 0000000000 SlG~ ~DTP CU 480775 O0 000 O0 0 3 I 1' '4 68 0000000000 TPHT TDTP PU-S 480775 O0 000 O0 0 3 .! I 4 68 0000000000 .$8MW mDTP Cl.! ~80775 O0 000 O0 0 3 ! ! 4 68 :0000000000 SF~'! ~DTP CU ~80775 oO 000 O0 O 3 I 'l 4 68 0000000000 '$TGC 'TDTP Ct! 480775 O0 000 O0 0 3 I 1 4 68 0000000000 ST~ ~I)TP CU 480775 O0 000 O0 0 3 :1 1 4 68 '0000000000 IS ?an.e ~erlflcation [,istino Chlumberoer Alaska tTom~,utino Cer, ter i 8',JAN-.1995 17 mmmmmmmmm m mm mm mmmm#mmmmm#mmmmmmmmmmmmmmmmmmmmmm mmmmmmmmm#mmm N~',r SEH~., tJh)l?.. S~'V .. ~P! FILE NUmB NUPB ~IZE REP PROCESS TD ~R~E~ # bOG TYPE CLASS ~OD NUmB SA~? EbEM CODE (~EX) mmmmmmmmm~mmmmmImmmmmmmmmmmmmmmmmmmmmmmmmmImmmmmmImmmmmmImmmmmmmmmmmmmmmImmmmmmmmI~mmmI TqA? ~b'~ ~8(>775 O0 o0o oO O ] 1 1 4 68 0000000000 SDST ~DTP CU 4~0775 O0 000 00 BaC~ TPTP CPS A80775 oO 000 00 F~AP TtjT~ CPS d8o775 hO C00 O0 ICA~' TI.)TP CPS ~80775 O0 oO0 TCA~ ~[.~P CPS n~n775 O0 000 O0 TC~:n TDTp CPS 480775 (~(, 000 O0 TCFD TbTP CPS 4~O775 nO 000 00 T~C~ TC?P C~$ 4~0775 O0 000 00 TSC? TDTP CPS ~80775 I~)~P 7b~p CPS 480775 00 OOO 00 I~FD TDTP CPS ~8n775 oO OOO 00 GPCU TDTP GAPI 48n775 0o 000 00 0 3 I 1 0 .t ! 1 0 3 1 1 ¢) ] I 1 O 3 1 1 0 3 1 0 3 ! 0 3 I ! 4 68 0000000000 4 68 O000000000 4 68 0000000000 4 68 0000000000 4 68 0000000000 4 68 0000000000 4 6R 0000000000 4 68 0000000000 4 68 0000000000 4 68 0000000000 4 68 0000000000 4 6~ 0000000000 DFpT. lO746.u0u SIGM..TDTP 8PH~!.TDTP 60.~00 SiGC-TDTP SDS~,T[)T~ 0,OO0 BACK.~DTP TCAF.TDTP 3759.205 TCND, DTP TSCF'.TDTP 7]Oo.Og9 !NND.TDTP TFN~.TDTP. 1485.000 CCL.TDTP 21.480 TPHI.TDTP 0.553 $IBH.'TDTP 178.8u5 FBAC.TDTP )~82~.4ol, TCFD.TDTP 1607.34I INFD.TDTP ~.000 67.~6! SBHF,'TDTP. 83.662 T"AT.TDTP 3~:608 TCAN,TDTP 391 836 TSCN.TDTP 244.002 GRCH,TDTP 60,600 2940.089 -999.250 END OF DATA **** FTL~ TRAILER **** FIbF NA~£ : ~DiT ,003 VERSION : 001C01 DaT~ FILF TYPE : LO LaS· FILE *.*** FTLM ~EADMN **** FIb~ ~)A~E ~ EDIT ,004 SFRVICE : FDIC VMR$ION : 00lC01 D~TF : 95/01/18 FTLP' TYPE : 1,0 LaS? wIb£ ~ IS q'ane ~ertf.ication Listtn~ :blU~ber<:{er alaska C,.3~r:.utjr,~ ~enter iS-JA~-lgg5 08:!8 PAGE{ 18 and clJ. pr~ed curves for each Pass O, ..'500(> START nEp]'~{ STOP DEPTH !0746.0 103C0,0 PASS TO PASSC~EASUDED DEPT~) 1074 1073 1072 !.072 !.072 1 07! ~ 071 107! 1. O700 1 0704 I 0696 1¢69] 1.068~ ...068~ 1.0684 10683 10679 10671 !0~68 1.0667 10664 10660 10~59 10655 10647 10644 1.0643 10640 10639 !.~636 T,I~E ..... .. 6,~ .5 ,5 ,5 ,5 ,5 5 ,5 ,5 '5 .5 ,5 ,5 10740.5 10732.0 ~0729,0 ~0724 0 10720:5 10717.0 1.0713.5 !0711,5 10708,5 10705,0 10697.0 10692o~ 10689.0 10687.5 10684.5 1.068~,0 10679,5 10675,0 10671.0 10668,5 10668,0 10665,0 10664'0 10660,5 10656,0 t064~,0 10644,5 !.0643,0 106~0,0 1.063q.0 10636,5 separate files. I]~SMIFTFD DEPTH---------- [$ Tare Ver!.t. lcation Li$tino .'l~lt~,~k, er(~er A.!asKa Computf. nO Center· 1B-JAN-1995 08:18 PAGE{ 19 10635 1O637 1063! 10628 10627 10624 10620 i0616 J 0~,19 ~ 0607 ~ 0604 ~0596 10591 ~058~ ~0587 105~ ~0583 10580 !u579 ~0576 10575 ~057~ ~056n 10566 10555 10552 !. 052~ 30527 1O524 10520 1,051g ~0503 ~0492 ~048~ ~0487 ~O~B] 1047~ ~0~6~ ~ 0.~55 10448 ~ O444 .5 .5 .5 .5 .5 .5 .5 .5 .5 .5 .5 .5 .5 .5 5 5 5 5 5 5 5 5 5 5 .5 5 5 5 5 5 5 ~0635.5 10631.5 I062~.o I060~.0 1o603.5 10595.5 ~{;591.0 ~0586.5 $0579.5 10576.0 ~0556.0 ~055~.5 10527.5 · . 10519.0 !.050~.0 10492°5 t048~'.0 10484.0 ~0479.5 ~0471.5 10468°0 1.0463,5 1.0459,5 10456.0 1,0~33.0 10~29.5 10625.0 10621.0 10617.5 106~2,5 106 10604.5 !0601.0 10596.5 ~0593.0 ~0589.5 10585.0 10580.5 10577.0 10573.0 10568,5 1.0556.5 10554,0 10533.5 10529,0 10525 5 lo52o15 10494.0 10489.5 10484.5 10481,0 10449.0 ~.0444.5 ...0440.5 IS Sa~e Verification I.,lsttno :blU~,~erqer A].asKa Cu~-Out.!na Center PAGEI 2O 10456 ! 0416 10415 1 0412 ! 0409 !04(;7 1 0404 1 0.400 1039~ 1 1 (,~3~ ~ ~038~ ]0~56 ~0355 1 1.0351 1 O335 10331 10327 10123 0319 ~0312 100 · '% 10~37.0 ,5 I~421on ,5 !.0~1~.5 .K lO4!6.n ,§ ~ 0405.0 · S 1,)40't. ~ o5 1 u402.0 ,5 10~90.5 ,5 10387,~ ,5 10379, ,5 10375.0 ,5 1035~,5 .5 .5 5 1035].0 5 I0351.0 5 ~033q,0 5 10335.5 5 10331,5 5 10328,0 5 10324,0 .5 10314.0 o~ 100,0 ~E~ARKS: THIS FILE CONTAINS BORAX PASS ~1. OF THE TDTP..THE. DEPTH CORRECTIONS $~OWN AROVE. REFLECT BORAX PASS #1 GRCH TO ~1. SIGN, ALL OTHER.TDTP CURVES WERE CARRIED WITH'THE $ LTS FORNAT DATA · ',[;~.B[.,E TYPr., :' CONS TI.I~:! VALU ,DEFI · . . . ,., . . CN ARCO AGASKA, INC, Company Name 'Field Name F~ 'PRUDHOE BaY · API~ 5 2 -;0~68-00 A~I Serial. Number FL 898' FNb g '777'FWb Field bocation · T'OW~ 10N Township RANC 15E. ~ange COUP NORTH SI, OPE County X$ Tape 'ver{flcstio,.. Listim~ eblUmber¢,,.~r AlasKa Co~.put_~.~.~ Center 21. T~!,:~ VALU DEF! STA? ALASKA State or Province wlT~ Nation TO~ ALb~N W~tness Name sm~.~ 4~0775 Service Order Number p~a~ ~SL Permanent datum gPP FT O. Elevation o~ Permanent Datum LvF RKB LDO Measured From ADD rT 73. RD6ve Permanent Datum EKB rT 73. ~levation ot Kelly Bushing E~F' FT 72. Elevation at Derrick rloo~ EOb rT 34, Elevation at Ground bevel IDD ~T 10747. Total Depth -Drtller TDb FT 10741. Total Depth - Logger BI, I FT 10735. Bottom b~qtIDterval ~LI FT 10100. TOy t. oq .n erval DF~' CRUDE/MEAWATER/BOmAX Dr lllng Fluid Type TLAP 11115 25-~AR-94 Time bagger at Bottom Be!.!~ DECF 195. ~o~tom Hole.Temperature · . TABL~ TYPM = CURV $IG~ &IGC "'&'DST FRAC TCAM :TCAF TCND DEFI D~PT D entb Sigma CMeutron Capture. Cross Section) TDT Porosity Borehole filqma - far detector 8oreho]e Sigma- Near detector Sigma Correction Corrected Borenole Si ma ~atlon ~otal Near to.~ar counts Standard deviation o~ Slgma ~acK~round Count Rates - Near Detector BacKground.Count Rate - Far Detector Total. counts analyzed'- near detector {TDTP) Total counts analyzed - far detector (TDTP) Total capture counts - i~ear detector · TCFD · Total capture Counts - tar dectector TSC~ Total Selected Counts - ~ear..Detector TSCF Total Selected Count~ - Far Detector 'INN~ Inelastic count rate - near'detector INF~ Inelastic count rate - far detector G~CP Gamma ~a~ ~n CaSID~ · TENS ~urface ~enslon ' · CCL CCL .~mpl~tude Ware Vert. il. catlon .'.hlumberger Al. asKa C.o~put]aq Center 995 08: 18 PAGEI Ty ~P~ 0 ~ALUE 1 66 ~ 3 73 88 4 ~(, 1 5 66 6 73 7 65 ~ 68 0,5 9 65 FT 1! 66 ll 12 68 1~ 66 0 ~4 65 FT 15 ~& 68 16 66 ~ 0 66 1 ** SET TYPE - CHAN ** NAMr ~E~V UNIT SER'VIC~ API API API ~Pi FILE. NUMB NUMB $~ZE REPR PROC~S~ ID ORDER # bOG TYPE CLASS ~OD NUmB 8A~P ELEM. CODE .(HEX) ................. . ....... ......................................................... FT 4U0775 00 · 000 00 0 4 1 ! 4 68 0000000000 SIG~ TDTP CU 480'175 00 000 00 0 4 1 i 4 68 0000000000 TPH~ TDTP PU-S 480775 O0 000 O0 0 4 ! .1 4 68 0000000000 $BHw TDTP CU ~80775 O0 000 O0 0 4 1 ! 4 68 0000000000 SBHM TDTP CU 48(~775 00 000 00 0 4 1 i 4 68 0000000000 $IGC TDTP CU 480775 00 000 00 0 4 I I 4 68 0000000000 '$IBH TDTP CU 480'775 00 000 00 0 4 ! 1 4 68 0000000000 "T~A'T TDTP ' 48077'S 0'0 000 00 0' 4 1 ~ 4' .68 0000000000 SDST TDTP CU 480'175 00 000 00 0 4 1 .1 6 ~8 0000000000 BAC~ TDTP CPS 480775 O0 000 O0 0 4 ! 1 4 68 0000000000 FBA~ TDTP CPS 48n775 .00 000 00 0 4 .l ! 4 68 0000000000 TCA TDTP CPS' 480775 00 000 00 0 4 .1 i .4 .68 0000000000 TCAF TDTP CP~ 480775 00 000 O0 0 4 1 1 4 68 0000000000 TC~D TDTP CPS 4.80775 00 000 00 0 4 I 1 4 68 0000000000 TCFP TD~P CPS 480775 00 000 00 O 4 1 1 4 68 0000000000 TSCN T~TP CPS 480775 O0 000 00 0 4 ! I 4 68 0000000000 T~CF T'DTP CPS 480775 00 000 00 0 4 ! ! 4 6.8 0000000000 'I~MD TDTP CPS 480775 O0 000 00 0 4 I 1 4 68 0000000000 I~F~ TDTP CPS 480775 00 000 00 0 4 .X I 4 68 0000000000 G~C~ TDTP GAPI 480775 O0 000 O0 0 4 I 1 4' 68 0000000000 TENS TDTP LB 480775 00 000 O0 .0 4 I ! 4 .68 0000000000 COL, TDTF ' ' V 480775 O0 000 00 0 4 i 1' 4 68 .0000000000 .22 IS ~ane verificat~.on l.istln~ :hlumberc;er Alaska Co~ut.~.no Center 18-OAM-1995 ()8-' t8 PAGE{ DVPT, TSCF,Ti)TM TV;2~.TLTP 1074b.00~ -Dgg,2$0 -999.250 -~99.250 132o.ono DATA ** S£G~,TDTP SIGC,IDTP BAC~,TDTP TC~ID,TDTP I~<ND,TDTP CCL.TDTP -999.250 -999.750 -999.250 -999.250 -99g.250 0.000 TPRI,TDTP SIBH,TDTP FBAC,TDTP TCFD,TDTP INFD,TDTP =999,250 8BHF,TDTP -999.250 TRAT.TDTP :999.~50 TCAN.TDTP 999.~0 TSCN.TDT~ '999.250 GRCH,TOTP -999, 50 -999, 50 =999,250 **** FIbM ~AILER **** FTLF NA~E : EUIT ,004 SF~ViC~ : FLOC VFR$I~,~ : nO,COl DATr : 05/01/1.8 N~X RRC SYZF : 1024 LaS· ~IL£ FlbF NA"E : MOlT ,005 SFRVlCE : FblC DATE : ~5/0!/18 M~X REC STZ~ : I024 FILE TYPE : LO bAST FILE : FIbF'NEADFR FIL~ NU~BER~ 5 EDITED CURVES Depth shifted and cltpmed curves for each pass ~n .separate files. p}$s ~U~BER: 5 DFPTH INCRE~ENT: 0.5000 FYL~ '8U~MARY I. DWG IDOL' CODE START DEPTN CRCH 1,0414.0 TDTP 10~4~,0 CURVE S~IFT DATA - mASS Tfi PASS(MEASURED DEPT~) ~ASELINE C[IRVE FOR SHIFTS LDWC CURVE CODE: GRCH STOP DEPTH ~0180,0 10180,0 Tape V~rJtlcatJon Listlna :hlUr:ber,?er A1MSKa Co~:.~:t~tJ, na Cem. ter 1R-JA~.~=I. 995 08:18 PA~E~ 24 I IIII I . 2~:~ 1041t,5 10~' 7. 1 040~,~ 10402,5 10404,5 !0399.~ . .. ,~ 1 !037~,5 1.0381 ,~ 1 O374,5 1037V. 0 ~ 0370,~ 1. 0373,5 1 0950,~ 10353,0 1 0322,5 1.0325,5 10311,5 ~O0,O !03,0 ~0426,0 !0422,5 10414o~ ~0410o0 ~403°5 ~0~00,0 t038~,5 10331.0 10314,0 10300,0 !00.0 ~E~A~KS: THIS FILE CONTAINS BORAX PASS #2 OF THE .TDTP THE DEPTH CORPECT!O~'$ SNOWN"ABOVE REFLECT BORAX PASS #~ GRCH'TO 8~SE PASS #1. GRCH AN[) BORAX PASS #2 SZGN TO BASE PASS ~1 Slg~. ALL OTH£.~ TDTP CURVES WERE; CARRIED. 'WITH THE $IG~ SHIFTS. $ L'TS FORe, AT DA~A CONS TUN~ VALO DEF! . . ...... .. . .. CN ARCO AbASKA', iNC, 'Company. Name F~~ PRUDHOE BAY Field ,ame ~ D ~ ~1 Well. Name APIN 56~62,-~0268-00 APl Serial Number FL 898' FNb & 777'FWU ·Field bocation · SFC? 8 Section TOw~ lom Townshlp R~C 1SE Range · COBH NORTH ~b. OPE County STAT AbASKA ·$ta~e or·Prov~nce N.~TT USA Nation '~IT~ TO~ Abb~N Witness 'Name IS Ta~.e ~erificatf. on Listina :blUm~era~r Alaska Com[~ut]n~ Center B-JAN-] .995 0~:18 PAGE~ 25 480775 APU mT E~B WT 7~, EDF FT 7~, ECL ~T 34. TDD FY ~0747. TDL WT 1074~, B[:I mT 10715. TLI mi: I0100, OFT CRUDE/$~AWATER/8ORAX STE~'' DECF 0 B~T DEaF 1~5, Service Order Number Permanent datum Elevation of eermaneet Datum bo~ ~easured From Aoove Permanent Datum Elevation o~ Kelly BUShing Elevation of Derrick Floor Elevation of Ground Level Total Dept~ - Driller Total De~tb o Logger Bottom ~og %nterval Lo~ Interval 5rT°~llt~ Fluid ~¥pe Time bogger at Bottom Surface Temperature Bottom Hole Temperature TABLE TYPE ~ CO~V DEFT DFPT Deoth $~G~ $ig~a (Neutron Capture Cross Section) TPHT ?DT Porosity S~ ~orehole Sigma - far detector SBH~ Borebole Sigma - Near detector $IGC Siama Correction SlB, Corrected gorehole'$igma T,Aw ~atlon Total Near to Far counts SDS! Standard deviation of Sigma B~CK Background Count Rates - Near Detector FgAC Back,round Count Rate - Far Detector TCA~ T~tal cOUnt's analyzed - Dear detector TCAW ~ota! counts analyzed - far detector (TDTP) TCND Total capture counts - Near detector TCFD Total capture Counts - ~ar dectector T~C, Total Selected Counts - Near Detector T$CF Total Selecte~ Counts - Far Detector INND Inelastic count rate - near detector I~F'D Inelastic count rate - far detector G~Cf~ Gamma ~av ~n Casing TFNS Suriace Tension .CCL CCL ~mmlitude Wane verification T,istinn :blUn~hercl,-r A..lasKa Comput'.J.r')~.~ Center 1 ~-JA~!-1995 08:]8 PA~E~ mmmlmmmlmmmmmmmm~mmmmm~immmmmN 1 6b o 2 66 4 66 1 5 7 ~5 8 6~ 0,5 9 ~5 mT 17 68 1~ 66 14 65 FT 15 6b 68 16 66 0 66 mmm#mmmmmmmmmmmmmm#mmmmmmmmmmm ..... MIB NUMB I~ REPR 0CE$$ TO O~DE~ ~ bOG TYPE CLRSS MOD NUmB SA~P. ELAM... CODE (HEX) DKPT FT 480775 00 000 00 0 5 I 1 4 68 $)G~ TDT~ Cl.) 480775 00 000 O0 0 5 1 1 4 68 TPHI ?DTP P!3-$ 4~0775 O0 O0U 00 0 5 $ i 4 68 BBHr TD~P CU 480775 00 000 00 0 5 1 1 4 68 SRHW TDTP Cl.) 480775 00 000 00 0 5 1 ll 4 68 SIGC ~:DTI~ CU 4~0775 00 000 00 0 5 ! 1 4 68 $I~U TD?P CU 4.80775 00 000 00 0 $ ~ ~ 4 ~8 T~AT T[)TPll 480775 00 000 00 0: 5 1 $ 4 68 !DST ~DTP CU 480775 00 000 00 0 5 ! ~ 4 .68 B~CK TDT@ CPS 4~0775 00 000 00 0 5 1 1 4 68 F~AC TDTP CPS 480775 00 000 00 0 5 1 1 4 '68 TCAN TDTP CPS 480775 O0 000 00 0 5 1 1 4 168 TCA? TDT~ CPS 480775 O0 000 00 0 5 1 1 4 68 TCND TDTP CPS 480775 00 000 00 0 5 ! ~ 4 68 TCF~ ~DTP CPS 480775 00 000 00 0 5 1 ! 4 68 T$C~~ TDTP CPS 480775 00 000 00 0 5 1 ! 4 68 TSCw TOTP CPS 480775 00 000 O0 0 5 ! $ 4 68 INND ~DTP CPS 480775 00 0O0 00 0 5 I 1 4 68 INFn TDTP CPS 4.80775 00 000 O0 0 5 S I 4 68 G~CP TDTP G.API 4~O775 00 000 00 0 5 ! ! 4 68 T~NS TO~P L~ 480775 O0 000 00 0 5 1 1 4 68 ICCLTDTP 'V. 480775 00 000 00 0 5 1 ! 4 68 0000000000 0000000000 .0000000000 0000000000 .0000000000 0000000000 ,000000000Om 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 26 [$ WaDe ver~,ffcation T, tsttno .'hl~.,m~ero~r ~lm~K8 Computfn~ Center DFPT. 101~0.000 $IGr,{. TDTP SgHN.?!)Tp 42.371 SIGC.TD'rP SDST.TO'rP 0.452 PACK.TDTP TCAm. TD~ 1690~.676 TCND.T~TP TSCW.TD~P 3380,168 I6~3D. TE. TP TFb~. TDTP J 3~0,QQ0 CCh. TDTP 18-JAN-I!.395 05:1.8 14.92~ TP}II.TDTP 31.008 0.000 SIFH.TDTP 149.223 138,202 FBAC.TDTP 38,482 !~905.~4~ TCFD.TDTP 49~5.28~ 1415.~13 INFD.TDTP 303,438 0.000 11,746 TPHI'.TDTP 19.139 3.792 SiFH.TDTP 4~. 71 11.4.789 FBAC.TDTP 20.]44 ~4030.957 TCFOeTDTP 8912,994 1501.170 INFD.TDTP 304.506 3.104 SBHF.TDTP TRAT.TDTP TCAN.TDTP TSCN.TDTP GRCH.TDTP SBHF.TDTP TRAT.TDTP TCAN.TDTP TSCN.TDTP GRCH.TDTP PA(;E~ 27 63,316 1...774 19587.500 3914.688 -999,250 68:2 37506,555 7458,118 **** FIbE TEAI!,E~ **** FTL~ ~gu~ : ~DIT .0o5 SFRV'IC~ : FLTC DATF : g~X RFC $:ZP: : 1074 .FIbK TY~E : LO **** FILE }'~ghD~U **** FIL~ MA~E : EDIT SERVICE : WhIC VERSlO~u ~ O0!COI D~T~ : 95/0!/~8 MaX RMC $~ZM : !o~4 FTL~ TYPE : DFpTM INC~E~ENT~ FIbF SU~ARY [,DWG TOOL CODE ~<DTP 6 and cl~pped 6 0.~000 curves START DEPTH 10714,. 1.0746,0 for each pass S~OP DEPTH 10100,0 101O0,0 separate files., I8 Ta~e Ver.~.ftcat. lon !istlno 1 ~-,JAN-19c~5 ,0~ 18 ,. PAGE~ 28 PAq~[,ft!E D~PT;t ~RCH ~DTP ~072~.5 10730,0 I071g,~ 10721.n 1070~.$ 10700.5 ~0705.~ ~u700,K ln702,5 10706.5 ~u694,~ ~0698,5 !0686.$ 10690,0 1068~ ~ ~0686.0 lO~7,~5 1. o682.~ 10670i$ 10674,0 !.0666 5 10670,5 1066~ ~ 10667.0 10650,5 106~2.0 1,0645.$ 1064o.5 1[~642,5 10646,0 10641,5 10649,0 m0638,5 10641,5 10637,5 t.(,)640,5 10634 5 10638,0 1063315 {.0637,5 1.063'0 '5 10634,0 10626 5 10630 5 ~'o~.5 io626:.5 to~i~ 5 io62~.o 1.0617i5 10621,5 10610.5 10614.0 10606,5 10609 5 1060~o5 10606;0 ~0570o5 10574°0 10546,5 ~05.48o'5 ~054~,5 1054g,0 1.0541.5 1054~,5 10537,5 1054~,0 1.0533 5 10537,5 1.9529:$ 10533°5 I. U525,S 1052~.0 t. 052~,5 ~0526.'0 UNS~IFTED DEPTH-- ..... --- :blUmberoer AlasK.~ ~omput~.no Center 18-JAN-.I. gq5 08:18 PAGEI 29 1048),5 )048g.5 10478,5 1047),5 10477,5 10~57,5 I0d61,~ 1045~ ~ 10447,5 1043B.5 10434.5 10430.5 1042q.5 10433.0 !042~,5 1O425,5 ~042~.5 I0421!~1 (,414041~ i04~5.5 10410.5 1040q,5 1041~.$ IO~06,K 10)98,5 ' 10342,5 10337,~ 1034~..0 10333'5 10337,5 10130,5' 10~26,5 10314,5 10300.0 ~00,0 ~.04.0 THIS FILE COhTAINS COR~ECTIOMS SHOWN BAS~ PASS #1 GRCH ~.' S£~M. AbL OTHER $IG~ $~XFT~, # bTS F(]R,~'~AT DATA 0495.0 1.0458.5 10450.5 ~0446,0 !.043~.5 ~0434.5 10431.0 ~04.26.5 )0422,0 t041~,O 104~4.5 1.~.0 10407,0 ~0~82,5 10.345,5 10333,5 10~29,0 ~0~1.5,5 1O301,0' ~0~,0 BORAx PASS ~3 OF THE TDTP 'T~E DEPTH ABOVE REFLECT BORAX PASS #~ GRCH TO A~D BORAX PASS #3 ,SIGt~ TO BASE PA8~ TDTP CURVES WERE CARRIED WITH 'THE' Verification Listin,.q ia-JAN-1995 08:18 PA~E~ 30 F~' P~UDHOE BAY FieldName WY D.$. 1 - 11 Well Name APl? 50'02g-~0268-00 AaI Serial Number F~, 89~' FNL & 777'F~L Field Location Tnwt~ 10~ TownshXp R~C 15~ Ranqe CO~~.~ ~O~?H $~OPE County $~A~ AbASKA State or Province ~TT~' TO~ ALb~N Wit~ess Name $~ 480775 Service Order Number PDA· SSI, Permanent datum EPb FT Oo Elevation o[ ~ermanent Datum ~F RK~ bo~ ~easured From APO FT 73, Above Permanent Datum E~8 PT 73. Elevation o~ Kelly Bush~nq ~F ~T 72. Elevation o~ Oerrlc~'Floor ECL FT 34 ~levatXon o~.Ground.~evel. TDD FT iO.~47. Total Depth - Driller T~b FT 1074~. Total Depth..- ~o~ger B[.I ~T 10735, Bottom boq Interval TLI PT 1~I00, .Top ~oc'[n~erva[ OFT CRUDE/$EAWATEE/BORAX Drl. lll~g Fluid Type ?~..A~ 1~5 25-~AR-g& Time ~ogqe'r at..Bo[tom $~E~' ~E~F' 0 Surface Temperature B~T DEaF 1~5, Bottom. Hole ..~emperatu.re ............... T~BI.~E TYPE ~ CURV .. DFPT TPHT .SBH~ TPAm SPST B~C~ 'F~AC TCAN TCA~ ~CFD T~C~~ DePth Sioma (Neutron Capture Cross Section) TOT morosit¥ Borehole S~gma - far detector Borebole $1qma - Meat detector Sigma Correction Corrected Borehole Sigma Ration Total ~ear to Far counts Standard devtatioD of Sioma 8acK~rou~d Count Rates - Near Detector ~ac~roun~ Count Rate - Far Detector Total counts analyzed - Dear detector (TDTP) Total Counts analyzed - far detector (TDTP) Total capture counts - Near detector Total capture Counts - far dectector Total SelecCed Counts - Near Detector IS Tar~e '~er~fication t.i. stino :hlumberoer AlmsKa. Comout,f.n~ Center !8-JAN-1995 0B:t8 ''T,~C~ ...... ;;;;T'~;T;;;;;'~,;unt~ - ~;; ........................ Detector 1,~.:l,~ Inelastlc count rate - near detector I~:Fm Tnel~stic eonnt rate - far detector GPC~ Canna Pay 1Ii Casino Tm~O~ Surface Tense. on CC~ ~Cb AmolttuOe PAGE~ 31 ** mAmA FPR~Am gPECTFIC~TION 9ECORD ** 2 66 0 3 73 5 ~6 b 73 7 65 8 68 0 5 9 65 17 68 13 66 0 14 65 15 66 68 16 66 0 66 ** SET TXPE = CMAN ** ~m~m~~m~m~mmm~m~m-~~m~m~mm~m~~mm~m~mm~~m~m~m~m~~~'~ ~i~ SE.RV UNIT SE~VTCF API AP1 API AB! FILE NUMB NUMB 'SIZE REPR PROCESS TO ORDER ~ LOG TYPE CLASS ~OD NUMB SAMP ELEM C~DE (HEX) DFPT FT 480775 O0 000 00 0 6 1 1 4 68 SIG~ TOTP CU 480775 O0 000 00 0 6 1 I 4' 68 TPHT TDTP PU-S 4.80775 O0 000 00 0 6 I 1 4 68 SBHF TDTP CU 48n775 O0 000 00 O 6 I i 4 68 SB}{~~ TDTP CU 480775 0O 00O O0 0 B ! 1 4 68 6TGC ?DT? CU 480775 o0 00o 00 0 6 I .1 4 68 ST~ TDTP CU 4807'75 00 000 .00 0 6 1 .l. 4 68 T~A? TOTP 4~0775 nO 000 O0 0 6 1 I 4 68 SmST TDTP C'J 4~0775 O0 000 O0 0 6 I 1. 4 68 BACK TDTP CPS 4.~0775 00 000 00 0 6 1 1 4 68 FRA~ TDTP CPS 48~775 O0 000 O0 0 6 I 1 4 68 TCA~ TOTP CmS 480775 00 000 00 0 6 I ~ 4 68 TCAF T'D~P CPS 48o775 nO 000 00 0 6 1 1 4 68 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 IS 'fane ve'r.!~icat~on l, istlnn =blU,'],berger ;%!...aSK~ ?omout.~.n~ (Tenter 18-g~-19q5 32 TCF~ TDTP C~S ~867 TSC~' TOT~ C~S T$CF' T~TP CPa 4807 I ~.4n T!)Tp CPS ~,~7 ~:~'~ T~Ti) CD~ '~807 G~Ct~ TDTD G~PT .~807 T~]S TDTP LF 4.807 ......... ;;~,.#mmA; ....... ;m~_~ ........... ; ....... m ........... mmmmmmmm APl I ~[:I I E ~U~B NU .B SIZE REPR PROCESS L~G I'YPF CBA~S ~.~OD MUMS SA~P ED~M CODE (HEX) 75 at) uno OU 0 6 1 I 4 68 0000000000 75 O0 0o0 O0 0 6 1 1 4 68 0000000000 75 ,10 000 00 0 6 1 1 4 68 0000000000 75 Oj 0¢)c O0 0 6 1 I 4 68 0000000000 75 no OhO O0 O 6 1 1 4 68 0000000000 75 O0 000 O0 0 6 I 1. 4 68 O000000000 75 nO 000 O0 0 6 1 i 4 68 0000000000 75 no 000 no 0 6 1 1 4 68 0000000000 DFPT 10746.0nu .A I G.H. 'rD'rD 2n 8~ TPI-II · TDTP 55,603 SBHF.TDTP 6Pd~ ~ TI)TP 60,600 $IGC.TDTP 6,~834 SIBH.TDTP 83.662 TRAT.TDTP SI?SI TDTP O,O0O BACK,TDTP 137' 930 FBAC.TDTD 41.359 TCAN.TDTP TCAF' Tt)T[~ 303~8.5~2 TCN{),TDTP 16357~375 TCFD.TDTP 3846.~4 TSCN..TDTP T~CF~TD~P 7!2.539 I~K!O.TDTP 163~.836 INFD.TDTP 253.~.7 GRCH.TDTP ,. ,P ~ 3~.5.000 CCh. TD'i'D 0.000 D~pT 10100.000 $ IG~,'~.. TD;r¢ ;tl.328 TPHI',,TDTP 63':179 SBHF.TD?P SDH~,' ~ TDTP 40.125 SIGC.TDTp 0 000 SIBH,TDTP 40,:125 TRAT-TDTP SDS! ,"CDTP 'i.140 BACK.TDT~ 133~225 FBAC.TDT~ .25.626 TCA.N. TDTP. TCAF.TDTP 6905.OK9 TCNO.TDTP !.7~48.176 TCFD..TDTP 4424-364 TSCN.TDTP TSCF,TDTP 876.072 I N ~.O.-. TDTP 1263.318 ' INFU.TDTP 990...'223 G.RCH. TDTP T~N~.TOTP 12~5.000 CC,b. TDTP 0.000 END OF ~AmA 60'600 .2,166 111080.,391 .2610.,552 '-999'.250 '323,7'83 ,251 .26461... i6e 3286.,484 '33:,.750 **** FILE FTLF ~A~E : EDIT .006 SERVICE VFR$ION : nOlCO1 D~TF ~ o5/04/18 MAX [{'EC STZE : !.024 FTh~i ~Y~K : bO [$ Ta~e Yer~flc~tion [,ist.in~ :blumb. er~]er AlasKa Comoutlna Center i S-.JAN.-~ 995 0B118 33 F?L~,'. FTLW. NU~BF_R: 7 AVEDACED CURVFS Compensated ~Jeutron: Ar]tDmet~c average o~ edited Passes for all curves. ~olsed Neueron: )~naveraged e~lted Pass I Gamma Ray and Dackround counts; arithmetic average ot e~itea static baseline masses for a].l other curves, D~P~H IHC~E~'~S'~T 0.5000 P~SSES TNCLUDED IN t,OwG ~OO[, CODS PASS N[lt, i~ERS AFTFR ALL DEPTH CORRECTIONS .ERE APPLIED. 5TS FORe'AT TA6~K ',[YP~ ! CONS ~L'NI VALU DEFI C~ ARCO ALASKA, INC. Company Name. Field Name PRUDHOE. BAY F!r 896' FNL & 777'FWt TO';,'~ ~ iON R.~NG C'-0.' U '~'I NORTB STAT ALASKA ~.5, T T USA ¥~ T ,'£ ~,~ TON ALLEN SON 480775 PDA? EPF ~' 72. well Name API Serial Number Field ~ocation Sectto. Township Range County State or ~atlon 'Witness. Name Service Order Number Permanent datum Elevation of Permanent,Datum· tog ~e. asu~ed F~om Above Permanent.Datum. Elevation oZ'KeliY..Bush~ng Elevation of De~rlcK FZoo~ .~8-JAN-~995 08:18 PAGEt 34 EOb w? 34. TnS FT 10747. TPb Fi; 10741, Bt~I ;T 10735, TLI Fy ~0100, D~T C~bDE/$EAWATE~/BORAX T!,A~ 1~:15 25-~AR-g4 STEv PElF O. ;levation of Ground Level Total DePth - Driller TotaX Devt~ -Logqer 8otto~ Lo~ I~terval Loo Interval T°VlllngDr Fluid TyPe Time hog,er at Bottom Surface Temperature Bottom Hole ~emperature Ta8;,~.. .rYP~ ,. CO.qV D~FT DFP? l')eDth STG~ Sigma CNeutron Capture Cross Section) TPHT TD? POrosity SPHF ~orenole Sigma - ~ar detector SPH~ ~orehole Sigma - Near detector STGC Sigma Correctior~ SI~ Corrected ~orenole $~Gma T~A? ~atlon fotaI Near to Far coumts SDST Standard deviation of Sigma 8AC? 9acR~round Count Rates - Near Detector ?BAC Background Co~nt Rate - War Detector TCA~'.~ Total cot~nts analyzed - near detector (TDTP) ~CAF Total counts analyzed - far detector (TDTP) TC~D Tot. al capture counts - Near detector TCF~ Total capture Counts - far dectector TSC~! Total Selected Count~ - ~ear Detector TSC? Total Selected Counts - Far Detector l~Nh Inelastic count rate - near detector I"FD 'Inel'asti~ count rate - far detector G~CH ~amina Ray In Casino TE~$ Surface Tension CCL CC[, ~mplitude SET TYPE - 64E~ ** TYPE REP~ CODE VALUE I 66 0 2 66 3 .73 AB 4 66 1 fane Yerifi. cation [,1. stino :hlO.~.beroer AlasKa Computlno Center iB-JAN-1995 O~:l~ PAGEI '35 6 73 ~ 68 0.5 11 66 1.1 13 66 0 14 65 FT 1~ 66 68 1.6 66 !. DFP? F~ n~o7 SIG~ P~V CU 4.807 TPH? P~AV PU-S 4~0775 S~HW P~AV C!} 480775 SBHN P~i~V Cfi 480775 · 61GC PN~V C!! 68n775 STSH PN~V C[! 4.80775 T~Am DN&V 480775 SDS~' PNAV CU 480775 BAC~ PNAV CPS 480775 FB.AC PNAV CPS 480775 TeA~ PNAV CPS 480775 TCAF PN~V CPS a, 80775 TCND PNAV CPS 480775 TCFD PNA¥' CPS 480775 TSCS PNlV CPS 480775 TSCF P~V CPS a80775 IN'N~ PNAV CPS ~.80775 INFD PNIV CPS ~U0775 G~Cg PNAV GAPI 4,80775 TwNS PN~V LB ~50775 CCL PNAV ¥ 480775 P ~ bOG TYP~ CLASS MOD M 75 OU 000 Oo 0 7 75 O0 000 O0 0 7 O0 000 O0 0 7 O0 000 O0 0 7 O0 000 O0 O. 7 O0 000 O0 0 7 O0 000 O0 0 7 O0 000 O0 0 O0 000 O0 0 7 O0 000 O0 0 7 O0 000 O0 0 7 O0 000 O0 0 7 ~0 ~00 O0 0 7 OU 000 O0 0 7 O0 000 O0 0 O0 000 O0 0 7 O0 000 O0 0 7 O0 000 O0 '0 7 O0 000 O0 0 7 O0 000 O0 0 7 O0 000 O0 0 7 O0 000 O0 0 7 mmmmmmmm~mmmmmmmmmmmmmmmmmmmmmm~m~m~m~m! NUMB SIZE REPR PROCESS FbE~ CODE (HEX) OMB SA~P I 1 4 68 0000000000 1 1 4 68 0000000000 1 1 4 68 0000000000 I 1 4 68 0000000000 1 1 4 68 0000000000 1 i 4 68 0000000000 1 1 4 68 0000000000 1 I 4 68 0000000000 1 1 4 68 0000000000 1 1 4 68 0000000000 1 1 4 68 0000000000 1 1 4 68 0000000000 1 1 4 68 0000000000 1 1 4 68 0000000000 1 I 4 " 6'8 000000000'0 1 1 4 68 .0000000000 1 1 4 68 0000000000 1 1' 4 68 0000000000 1 i 4 68 0000000000 · 1 I 4 68 0000000000 I 1 4 68 0000000000 ! 1 4 68 0000000000 mmmmmmmmmmmmmmmmmmmmmemmmmm~memmmememmeem~w! DEPT. SRH~.PNAV $OS!.PN&V TCAF'.PNAV T$Cr. PaAV 1074~.O00 45.482 0.552 4320.819. 715.562 1499.857 SlGC.PNAV BACK.PNAV TCNO.PNAV IN~O..PNAV CCbo~NAV 21.474 1.510 86..452 .17244.902 1451..149 0.000 TPI~I.'PNAV' 67.;491 .SIBtI.','PNAV 53,16.8 FBAC... PNAV · 22-.640 TCFD.'PNAV '3768.036 'INFD:'.PNAV 222.800 SBHF,PNAV TRAT.,PNAV TCAN,PNAV TSCN,PNR. V GRCH..'PNAV -999, 0 3hlumber.~i~r ~l. asK_a Conputf. nn Center iS-JAN-~.995 08:1.8 36 Dr'p"'. 1C 30,.!. ,.,,n U ,~ I ~. P,:': AY 1.m .96~ TPWI.PNAV SP HT". ~,n ~, V 39.838 S!~C.PNAV 3.098 6~'61'. m2~ A V 0.429 RACK. P"~AV ~6.~47 FB~C.PNAV ?Cav.Pb, A¥ 17~Q~egO~ TC~.:O. p ~ AV ~4~4.5~9 TCFD.PNAV TSCm. ~;.".V ~445.1.52 7[:~.~0. PNAV 1~0.g26 INFD.PNAV TF?,S.n~A'V 1. 31 9. ~65 CCb. P~.~AV O. 29,598 9558 53 3~768 ~6 X0.039 **** F'TL~ TR~ILEP SIrRV'[CE '. F!.,TC V'~IO.,; ., O0~Cnl 61~$T rILE : FTLF ~A~E : FO~T .OOS VF.R$IO~ : 001C01 DA2'F t 95/0!/1.8 ~aX RFC STZ~ : ~.024 F~LF TYPE : LO b~ST ri[.,g : FIL~ I, IEAD~R "" "FTLF 5~U~B'MR 8 R~,~,,~' CURVES Curves and log header data for each Pass in separate· 'i[l. es; 'raw bac~oround Pass D ~:FT t"! I~<C~EMENT: 0.5000 # FTLr SUMMARY VENDOR TOO[., CODE START' DEPTH LOG HEADER DATA ~ATE bOGGED: SOFI"WARE VERSIn~,~: TIME bOGGER ON BOTTO~: TL) D~ILL. ER (~T)~ TD bflGCE~CFT)I TOP [,OG INTERVAL (FT): STOP DEPTH 10296.0 25'~AR'94 38 2 .1.1{5. 25-~AR-94 10747.0 ~0741.0 ,..0100.0 [$ q'a~e YerificatJon L, istlp.~ ,'hlumberqer ~l. aTKa CQmpl)t~n~ Center 1B-JAN-1995 08:18 PA~E~ 37 'V~N~O~ TO~L COb~ TOOL TYPE '.r r) T P TnTP T n TDT~ ROI~EHOLE A~D Cl~it~ ~ATA .? "I" . . D,'~Tu.~Ert~ CISTN(: DEPTH ~OPE~O?.,E CO~DIT,IONS FLOTD TYPE~ FLUID D~SIT~ (LB/G): S~)RVACf2 TF~P~PATbPE (.DEGF) ~,OTTO~ HOI, E TEMPERATURE CDE~F)I FI, dID $1~I~'~IIY (PPM): ~L, UiD LEVEL (FT): FLUID RATE AT WWLLHEAD ~ATER CUTS (.PCT): CuOKE C.D~): '.r;p. T P T ~ .LF :',IFTP'~ MODI.!LK J0735.0 1800.0 TOOL NUMBER CGR$-A-820 CPSC-A-824 CPI, E-A-823 CPTE-A-827 CPL$-A-Si. 2 TDIC-A-797 TNC-PB-390 TND-PC-395 TNG-PB-400 CTSM-BA-324 2713,0 CRUDE/SEaWATER/BORAX 195.0 ~i Ei..ITRON TOOL TOOl, T~PF, (EP][¢I'HERMAL O~ TflERMAL)~ .~ .l T R I X: aATRIX DENSITY: HOb~ CO~R~CTI~t'.~ (IN): BbUMblNK COt{NC' ~ATE MOR~AbIZATION IN ~Ib ZONE ~ASE ~OR~AblZING t/JT?~DOW Bb~:LI~E COU~.tT R~TM 8CAbF5. SET BY WIELD ENGINEER '~A~ COUNT RATE LOW SCALE (CPS)~ .~AP COUNT ~AT~7 HIGh{ SCAbM ~,)gaR COUNT ~T~ bow SCAb~ (CBS)I THERMAL SANDSTONE 2.65 TOOb ,~'CA~IDOF~ (IN); 1 ,.q-JAN-I 995 o8;:18 't'~...D .Ti~ TO CA..'.,:CO ~i{/CCL OAIF:D 6/5/9! & SW..q, RHC DATED 10120177. dA6F ~i--490 ~ff~].,~ PI~:~PBD, ~h~'~=6 ~PN, ~HIP=450 BSX. ~OR.~A ~-- 4~ ~8L~ iN PE~S, RATE=1.5 BP~, WHIP=200 PSI. oORAX ~-2--65 F~L~ IL PKRf'S, RA~'M=I.5 BPM, WHIP=200 ~CA~E EPRATIC ABOVE 10~90 ON ~ORAX PASS BmR~X PASSES ~ g 3 WErE ~.~AD~ ~OST OF THE BORAX HAD LEFT T~E 80RFHOLF AND WAS BEHIND CASING. CHANaPL A~uVE 'r~g 10376 94' PFRFS AS SUSPECTED. THE LOG VERTFIED TH~ EXISTA~.~CF ~F AN UP CHANNE5 A~OVE THE PEERS F~Ou lU376' 'ff~ 1030~'. bTS FORe, AT DATA PAGEt 38 TUN! VAI,,iJ DEF! C~ ARCO A~ASKA, INC. Com~ ~ w~ D 1 - A~I~? 56~ 11 Well.~ame 62~-20268-00 API. Sertal .Number F~, 898' r~5 & ?T7'r~b Field Location SECT 8 8ect~oD Tow~ iON Townshl~ COUY NORTH sLOpE County · Sq':AT ALASKA " State'or Province 'NaTT USA' " ~at~on. ' W~T~.' TO~ Al, beN Witness Name: $o~. 4807.75 8ervtce Order P~AT ~ISL Permanent'datUm ~p~ r~ ~ Elevation ot eet~ane.nt patum L~F ' ~.s boq ~easu'red'.~rom ~D r~ 73, A~0ve Permanent.Datum ... g~r ~T 72. ~leVatlon of Derrick.Floor E~L FT 34 Elevation o/.:Ground.bevel TnD rT 10~47 Total DePth"-. Drill. er TDL FT 10741,. .Total DePth:"- Logger Btl rT 10735, 8ott~m bog Interval · TT,I PT lOlO0; TOp [..og"~fiterVal.' DFT C~UDE/$EAW~TE~/BO~AX Drtlllfi~ Fluld~TyDe T[,,A~ .11.;15 25-~AR-94 rime'Lo,gar'at Bo'tto~ S?g~ DEG.F ~ Surface. ?e~pera~ure. BUT D~F 5. Bottom 8ol. e ~YemDerature ............. [~ Tdre ~'er!f~.catt. or': Llstln~ :hlun:~erger AlasKa Comp~.~tin~ ret, ret SlG~' Sloma ({~eutron Capture Cross section) ~PH? TDT Porosity SFHr ~orehole $iqma - ~ar detector $~ar qoreno].e Sigma - :~ear detector STSC Stor~,a Correction Sl~ Corrected ~orehole Si. oma T~AT ~atlon To~al i~ear to Far cou.ts S~SI Standard deviation of Sigma B~Cw Bac~roune Count Rates - ~ear Detector f'~AC ~ac~orou~o Coumt Rate - Far Detector ~cA~' Iota] counts analyzed - near detector (TDTP) TCA~ Total counts analyzed - far ~etector (TDTP) TC~ Tofal capture counts - Near detector ~CFK~ Total capture Counts - far dectector T~C~,~ Total, Se)ected Counts - Near Detector TSCw Total Se]eeteo Counts - Far Detector I~i~D Inelastic count rate - near detector I~F~ Inelastic count rate - far detector T~)~ surface Tension G~ API-Corrected Gamma Pay ~PRE well pressnre PAGE) 39 I 66 0 2 66 0 ~ 73 88 4 66 1 5 66 6 73 7 65 ~ 68 0 5 9 65 F~' 1~ ~8 1,3 66 0 i4 65 FT 15 66 6~ 16 66 0 6~ IB Ta~e V'erif~catlon I,[stlno .~blumker~er ~!.aSK~ ~"o~pt.~t~.p...c Center PAGE** 4O ~* SET 'vYP~ - C~J O~nt~ ~ .uOg TY ~~ m~~mm~m~mm~mm S!'Gu PS1. C~ 4~n775 09 000 TPH~ PSI pu ~00775 S~i~ PSi C~: 480775 6B~i~' PS1 CU ~n775 nO 000 STGC PSI CU qB0'?75 nO 000 S~p PS1 CU .'!~o775 60 000 T~A.' PS~ 4B0775 SD~T PS1 CU ~q775 OU 000 Bricw P8~ CPS 48n775 Ou DO0 F~C mS~ CPf a~07~5 TCA~ PSi CPS ~775 o0 000 TCAF PSI CPS .~ 80775 O0 000 TC :.~ ~ PS1 CPS 4b~775 00 OOO TCF~ DS1. CPS a80775 00 TSC~ P5! CPS ,~ 80775 00 T.cCw P$~ CPS 480775 ~0 000 I~N~ PSI CPS 4~0775 O0 000 I~FD PS1 CPS 4.80775 t)('~ gOO TMuS P81. b~ 48(~775 00 000 Gm mS~ GAPI 480775 O0 . APl fiPI . bE NO'lB NUMB SIZE R PROCESS ,~ m- pm CLASS ~,UP ~',{U~,~B SA~'P ELEM CODE (HEX) mmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmm O0 0 8 1 1 4 68 O0000000OO OO 0 8 1 I 4 68 0000000000 O0 0 8 ! i 4 68 0000000000 O0 0 ~ 1 I 4 68 0000000000 nO 0 R I 1 4 68 0000000000 OO 0 R 1 1 4 68 0000000000 o(; 0 8 1 1 4 68 0000000000 O0 0 8 1 I 4 68 0000000000 O0 0 8 1 1 ~ 68 0000000000 O0 0 8 1 1 4 68 0000000000 ob 0 O 1 1 4 68 0000000000 O0 0 8 ! 1 4 68 0000000000 O0 0 B I 1 4 68 0000000000 Oo 0 8 ! 1 4 68 0000000000 no 0 8 1 I 4 68 000o000000 O0 0 8 1 I 4 ~8 0000000000 O0 o ~ 1 1 4 6~ 0000000000 00 0 8 1 1 4 68 0000000000 oo 0 8 1 I 4 6R 0000000000 O0 0 8 1 1 4 68 0000000000 O0 0 . , , 4 oooooooooo ,,,,, ooo oo o , , s. oooooooooo mm,mmmmemmmmm emmmemmmmmmmmmmmmmmmmmmmmmmm mmmmmmmmsmmNmmmmmm.emmeme~ ** U~TA ** DEPT. 1A755.500 81GN*PS1 $MH~}.PS1 lO0.1Ol SIGC.PS1 SDS'{.PS1 1.252 BACK.PSi T$Cr."PS'I 0.000 Y'NNIJ',PS1 GP.P$1. t2.9)0 DFPT. 10296,000 81GM.PSi S~HN.PS1 36.576 SI~C..P$1 SDST.PSI 0.44.8 BACK.PS1 TCA~.PS1 16880.Ol. 3 TCND,PSI T~CF.PS~ 33~9,249 'INND,PS1 G~.DSt 1.0.57o WPPE'.P$1 15.949 TPHI,PS1 0.000 SBHF.,P$1. 1.855 SIBH.PSI .122.]08 'TRAT,PS1 85.881 FB.AC.,P$! '.25,185 TCAN,P$1 -9~.7~7 TCFO, P$1. -298.,381 TSCN,PS1 2.919' "INFD.PS1 "-0..856 TENS.P~I 36~0..229 i2.277 TPHI*PSl 22.1'23 B. BHF'PS! 2.613 8IBHaP$1 36,576 TRAT:PS! B5.951 FBAC.,PS1 .14-782 TC~N~ 23630'.'449 TCFD'*PS1 8363,?58 TSCN.PS1 1334.098 INFDopS1 306.785 TENS.PS1 3533.834 11.9;::1.93 0'.'.000 .0'000 0:,.000 935'000 '3.8654,406 ..76~3'~547 ** END Or DAWA ** IS "a~e verification Listing .'hlumberoer AlasKa Computino, Center SvRvI'Cg VFRSl~ D~'.!'= Y,~X RFC FILF TYPE L~ST FILE 19-JAN-1995 08:18 PAGE{ 41 8~RwlC~ ! FLTC V~RSIO,'~ : PO!CO1 ~X RfC STZ? : !u2~ F!L~ q'¥PE : b~$? rll,g w ~;U~B~R 9 CURVES Curves and log h~ader data ~or each pass in separate # VEMD~R TOOL CODE START DEPTH TDTP 10751,5 bOG HEADER DATA DATg L'~GCED: SOF~I:WARE VMRSION~ TI~E LOG~ER ON TD TOP LOG ~NTERV'AL BO']'%'O~ LOG INTERVAL ~fP/q CO~T~OL nSwD (YES/MO): Tf~OL STPING (TDP q'O ~OTTO~) VM~DO~ TOOL CODF TOOL ~YPE TDT~ G~ RaY TOTP TDT~ TOTP TDTP STOP DEPTH 1.0295,0 25-~AR-94 i~lles~ .raw bacKqround pass in fast 38,2 ~.1157 25-MAR-94 1074 .0 · .10741 0 101.00~0 10735.0 1800,0 NO TOOb NUMBER IIImlIIIlII 2 1/8" HO WT CGR$-A-820 CPSC-A-824 CPLE-A-823 CPSE-A-827 CPLS'-A-812 PAOEI 42 # C~I~DE/$EAWATMR/BORAX 19~.0 THERMAL SANDSTONE 2.65 BLUEL!~4K CC}[i;~T RATE ~,~OR~,~ALIZATIOh IN OIL ZONE ..RASE i~ORI~ALiZING ~IN[?,O~ CF'T): RATE LOW GCAL£ (CPS): TIED IN TO Ch~CU ~RI/CCL DATED 6/5/9~ & S~S MHC DATED PI!~PI~G ~ .. DAT~: '' ,,. :, .1 .BP~ WHIP:200 PSI., 6A8~ ~3 445 BBb$ PU'~ '"' ' .. -- ~,PED, RATE=I. B~M" ' ' ' wH,IP=~O0 PSI, PSI.. SOR~× #2--65 RSl.,.$ I~ PERF$, kRT~:l.5' "BPh., WHIP=200 .PSI. SO~A~ #3--75 8~$ ~N PELFS, RATE-1..5 BPU, WHIP=~00 PSI, I'DT-P TO(.)[, BECAME ERRATIC ABOVE ~0.390' ON BORAX PASS BORAX PASS 2 & 3 ¥I~bDED GOOD YDT-P DATA. 8g T~E ~O~HOL~ ^~D WAS ~£~I~P 995 08: t8 F~O~.'~ ~C, 37S' TO 1 .. TU~.:Y VALU D£FI F~ A~CO AhASKA, ~NC. Company Name PRUDHOE BAY Field Name ~.~ b,S, 1 - 11 wel2 Name APl~ 50-029-20~68-00 iPI Serial Number F!. 898' FNL & 777'FW[, Field Location SFC7 8 ~ection T[!~'~ iON Township R~i~c 15~ Range STA? ALASKA State or Province N~TI USA Nation ~lT~ TO~ A5bEN witness Name SO~ 480775 Service Order Number PPA~ NSb Permanent datum EDO FI ~ Elevation of Permanent Datum b~F ~ bog ~easured. From APO ~'~' 73, A~ove Permanent Datum ..,.. E~B ~T 73, Elevation of.Kelly Bushing EDF FT 72, E~evation of Oer'rlC~.Floer: gGb FT 34' Elevation of,Ground ThO F'[ 10~47., Tota.1 .DePth', Orille. r ' · T~L FT 10741,., To:a! Depth] .~I,I .FT 10735, ... Bottom T[.I FT 10100' Tom Loc 'Xnte'rVai'~ OFT CRUD£/SEAWATER/BOPAX DrtllI6o FlUid Type TLAP 1~:15 25-MAR-94 Time bo~ger.at. Bottom 8TgM D~GF 0~ Surface TemperatUre B~T l)gGf' 1..5, Bottom Hole':T. empe'~.atu~e .... TAO[.~i TYP~ : CURV DFPT.., t~ STG~,~ ~i~ma (I,!e'utror~ C~pture C~oss Section) TDH? TDT Porosity SBHF Borehole $1;jma - far detector : SgMu Borehole Sigma - ~eaF detector SIGC Sigma Correction SYBN Corrmcted Bore~ole Sigma rS ""a~e ~ert..~i. catton [.lstin¢~ :h 1,~.,~'~be r ~j ~., r ..... .~ 1 as ka r,..~.~.~,,. '~.u t i n~' . renter. I~-JAN-1995 08:18 44 T . R~ ! , to r SPS~ ~n~rc deviation fiAC~' nacKeroun:~ Count Rates - Near Detector F~AC 5ack.round Count Rate . Far Detector TCA~.~ ""oral counts analyze~ TCA~ Total co,~nts analyzed - far detector (TDTP) TC~{r~ Total capture counts - 3<ear detector TCFD Tota~ camg,3re Counts - ~ar Q~ctector TSC~.~ Tota~ ,~el. ected Co~nts - Near Detector TcCr Total Selected Counts - Far metector I~'f~D Inelastic count rate - near detector I~.}FD Inelastic count rate - far detector TFN~ gurface Tension G~ ~PI-Corrected ~amma ~av ~PRW ~,e 1 1 pressure 2 66 0 3 73 88 4 6b 5 66 '7 65 S 68 0.5 9 65 11 66 1~ 68 13 66 0 14 65 FT I~ 66 1.6 66 0 66 1. ** SET ~YPE - CHAM ** N~MF SE~V UNIT SERVTCE APl 'API API RPI FILE NUMB NUMB 'SIZE 'REPR PROCES~ Ii) ORDER ~ LOG TYP~ CbASS MOD NUMB SAMP.. EL£M. .. CODE (HEX) DEPT FT 4.80775 ~)0 OOU O0 0 9 1 I 4 68 0000000000' SIG~ PS~ CU 4.80775 O0 000 O0 0 9 1 i 4 68 0000000000 T~NI PS~ PU ~80'775 00 OOO O0 0 g 1 1 4 68 0000000000 $~W. ~S2 CU ~.80775 ¢'0 OOO O0 0 9 i I 4 68 0000000000 Tare Vertflcat~on [,tstino ,~hlum~er~)~r Alaska ComI.:,utine eenter 1 R-JACk-1995 08:~8 PAGEI 4S ;,~.i'~' ~'RV O~<IT ,. .VIC? ~ ~P? APl AP! FILE NUM ~UMB SIZE EPR PROCESS TO C?{PmP ~ L~Gm~..,ypE CheSS... ~OD NUMB 8A~'~P, ELEM CODE (HEX) CU 4 ~0775 oO oOU O0 0 9 1 I 4 68 0000000000 STGC uS? C~ ~$0775 OO OOO O0 0 9 X i 4 68 0000000000 $T6}~ PS? CU ~.8o775 O0 OOu Oo 0 g 1 I 4 68 0000000000 'I'PA~ ~S~ a~775 O0 000 O0 0 9 1 I 4 68 0000000000 SDST PS~ C[~ 480775 O0 UO0 O0 0 9 I i 4 68 0000000000 B~CW' oS~ C~S 480775 od 000 O0 0 q 1 1 4 68 0000000000 F~AC PS~ CPS ~8~775 O0 000 O0 0 g I 1 4 68 0000000000 ICA~ PS? CP'8 ~o775 ~0 ()o0 oo n 9 1 I 4 68 0000000000 TCA~ PS9 CPS 480775 nO OOO O0 o 9 1 I 4 68 0000000000 TC:~O P59 CPS 4u0775 O0 O00 O0 0 9 1 i 4 68 0000000000 TCF~ P5~ CO5 4~0775 ~0 000 O0 0 g 1 1 4 68 O00OO00000 TSC~ PS~ CPS ~8o775 ~{) 000 O0 0 g 1 I 4 68 0000000000 ~'~C; P$~ COS 489775 Dr.) O00 oo 0 9 1 ~ 4 68 0000000000 I ~,' ?<~ ~ PS2 CPG 4o0775 09 OOt) ~0 n g 1 i 4 68 0000000000 I~FD P69 CPS 4~n775 O0 O00 O0 0 9 I I 4 68 0000000000 TF~,S PS~ L,B .¢8~775 O0 000 O0 0 9 1 I 4 68 0000000000 GAPr a8o775 nc.) 000 O0 0 9 1. I 4 68 0000000000 D~PT. 1¢)751.500 SlGM..PS2 .12.277 TPHI..PS2 22.423 &BHF,P&2 SRH~I.P$2 36.576 $.I~C.P$2 2 613 5IBH,.PS2 .36. 76 TRAT.,PS2 TeAr.PS2 i6~0.613 'TCND..PS2 236~0.4~g TC.FO,PS2 8363. TSCN,P$2 TSCF,PS2 33~9,249 tN~.~D,PS2 1334,098 INFD.,PS2 306,785 TENS.,P$2 G~.PG2 52,250 i.~P~E.P$2 3678'619 '~29::,854 654,406 387 · 623,547 1:000,.000 OFPT 102~5,000 SlGg.'PS2 SD T P$2 0'41.8 RACK.'PS2 TCA~.DS2 1840~.461 TCND,PS2 T$CF.PS~ .~833.928 INND,PS2 G~.DS2 16.344 !4P~E.PS2 12,192 2.933 114'7'64 25750.066 ~CFD,:P82 1451.153 .INFD.~P82 3535.271 P$2 21.'i03 SBH .:p 2 s t ...tTO CA.,PS 920').96) ~SCN,P$2' 345..46) TENS.PS2 29,390 4tsS. ggeos, 821o,.o49 1285.000 ** END OF nATA ** FTDF r~A~g : EDIT ,{:)09 SPRVICE : rbTC V~RSIO~ t OO1COl DaTF : ~5t01,1~8 ~X REC STZ~ : ~.0~4 FTL? TYPE : 18-JA~.~-'.!995 o~:~8 PA~E= 46 Yr~Kic;~ t aO~CO1 ~aX R~C ST'Z~ : FTL~ TYPE : Curves an.j log hea~er data for each oa~s in separate P~S~ ~zl.i,~dFR~ 3 ?F,,P ................. 1 ;;;;7;.... . .... $ DATE · IME LOG~ER ON 6OI'TO~: TI) ORILL~R (FTC: ~'O LOGGE~(FT): TOP LOG 'TNTE~VAb (FT): nOT'£Oi~ bOG Z~T~RVAL T.,,OGGI~G 8PEEP D~PTH CO~'r~oI, STOP DEPTH 'fOUL ,$T~I~IG ('TOP ?0 BOTTO~) VMi'~iPOR TOOL CODE TOOL TYPE TnTP TOTP G A t~' A RAY TDTP TDTP TDT~ T~T~ TDTP Tr, TP TtTT~ TDTP P,O~j;RO[.,~ A~,.~D C~]]~',~G DATA' TDTP TDTP TDTP DETECTOR TDP GENERATOR TELFi4ETPy files; raw background pass in ~5-~AR=94 ]8,2 1115 25-~AR-94 .10747,0 10741.0 10100,0 10735.0 1800,0 ~0 ~ 1/8" HD WT CGRS-A-820 CPSC-A-824 CPLE-A-$~3 CPSE-.A-8~7 'CPLS-A-8i2 TDIC~A'T97 TND-PC-~95 T~G-PB-400 CTGM-BA-324 2713.0 £$ Tane verff.!catt, on :blU,'Hberqer ,::%l. asK8 Co~.;..-'.utiDa Cent,r lf~-JA.N-1995 08:18 PAG~: 47 # dO]TO:" WOT,E iF:~'~PE~ATUR~ F!,L;TO S~,L~.:T!'V (PPi"'.): ,'~l'!'~a C'~'I'S (PC'I): GAS/OT~ R.~TTC~ finL~ CORR~3C'riO,>~ (I~,~): i'~.U~bT;";~ ~!.]1,r.~ ~ATE i',iOR~.~ALI~ATIO~ IM OIL ZONE TOP ~ODr,IAbTZTh~G ul'NOO~ (FT): FAD COUNT RATE 1.,~ SCALE tAR COU,~T '~ATE HIGH SC.ALE ~,~E~R COUNT RA%'~ LO~ SCAGE CRUD~/SEANATER/BORaX ~95.0 THeRmAL SANDSTO{~ 2.65 TTgD IN T~ CAf~Cn GRtCCL DATED 6/5t9! & S~S BHC DATED ~A~ ~1--40o B!~L6 PUMPED, RAT~:6 OPM, WHIP=450 PSI.. SASE ~2--420 BBLS PUMPED, 'RATE-1FPM, WHI~2OO.PSI. BASF ~3--~45 B~L~ PUMPEDA AATE=I BP~, ~.HIP=200 PSI.,' BORAX ~!-:40 ~.8r,$ AN D~R~S, ~ATE=I~5 BP~, WHIP~200 ~(]RA.X ~i2- 65 BOLS IN' PERFS, RATE:I..5 OPM, WHIP=200 .PSI. Bt]RIX ~- 75 ESL& IN PERFS, RATE=I.5 BPM, WHIP=200 PSI. TDT-P ?O(JL BECANE ERRATIC ABOV~ ~0390' O~ BORAX PASS 8aR~.X PaSS ? & 3 YIELDED GOOD ~DT-P DATA. BY THE TIME 80RAX PASSES 2 & 3 WERE ~AD~ ~OST OF THE BORAX HAD LEFT TuE ~OREHOL~ A~:iD WAS BEHIND CA6ING. TEE PURDOSE OF ?HE LOG wAS TS DETERMINE 'IF THERE WAS A ~' . CHA~.~;:~...,L .A~,OVE THE 10376-94' PERFS AS SUSPECTED. THE LOG Vg~IFI£D ?HE ~XT$TaNCE OF AN UP C~A~N~L ABOVE 'THE P~RF$ FRO~ 1.0376' TO 10302", LTS F'~RHA'{' PAGEI 48 P~UD~E BAY A.=~.? §0 029- 0268-00 FI: 89~' F~L &. 777'F~L SFC~ 6 I'0~' COUP' N ORTf.~ 6LOPE STAT ALASKA N ~TT 0SA S~ 480775 EDL~ WT O, A~D w'I' 73. E~ ~ ?3, EDF rT 72, E~L mT TDD FT I0747, T~D WT 10741, BLI FT TLI DWT TLA~ STE~ Well Name AP! Serial Number Field Location Section Township ~anqe County State or Province ~atlon Witness Name Service Order Num~er Permanent datum ~levation o~ Permanent Datum LDO ~easured From A~ove Permanent Datum Elevation Elevation oZ Derrlc~ Floor Elevation of Ground ~eve. Total Deoth - Driller Total DePth - Loooe lo735 9ottom b0~ Interg&~r 10100: TOp LOg Inte'rVa[ CRUDE/SEAWATER/BORAX Drillifio Fluid .Type 11:15 25-~:tA~-94 Time bo4oer at.Bottom 0 Surtace Temp~ratu, re 1~5, Bottom · . DFPT.~, Depth TPHT TPAT B~CW F~AC TCA~ TCA~ TCNP TCF~ T$CN Sioma (i~eutron Capture Cross Section.) TDT Porosity ~orehole Sigma - far detector Borehole Sigma - Near detector ~loma Correction Corrected Forebo].e Sigma Pation Total i:4ear to Far counts Standard devlBtloD of $1oma ~ac~oro~nd Count Rates - Near Detector 8ackoround Count Rate - Far Detector 'Total counts analyzed - near detector CTDTP) Total co!~nts analyzed - far detector (TDTP) Total,. caDtux'e counts - Near detector Total capture Counts - ~ar dectector Total Se!.ecteo Counts - Uear Detector IS 1'ane V-rtfi. cation List. ir',o .'b-l,mberqer AlasKa Computlno Center 18-JAN-~995 08:18 l~:~n Inelastic count rate - near detector I~F.n... ~n-..laStic c. ount rate - far ~etector TFlx,-e Surface Tens.{ on G~ API-Correcte~ Cam.~a Pay 49 ~ DA~"A FOR:',.~AT SPECI~TCA'flO~.' D, ECODD ~* ~ 66 0 2 66 0 3 73 88 4 66 6 73 7 65 ~ 68 0.5 9 65 FT 1~ 68 i~ 66 0 !4 65 15 66 16 66 1 0 66 ** SET TYPE - CHAN . · NAHW SERV UNIT SERVIC~ AP1 IP! APl A.P! FILE NUMB NUMB SIZE REPR ID O~DER ~ bog TYPE CLASS MUD NUMB SAMP EGEM CODE ':(HEX) DEPT FT .~80775 O0 000 O0 0 10 1 I 68 0000000000 $~H~ PSt TRA? SDS~ PS3 B~.CK P$3 F~AC ICA~ TCAW P83 CH 4.80775 O0 000 O0 0 t0 pU ~80775 O0 000 O0 0 CU 4~0775 O0 000 O0 0 10 C!) 4,80775 O0 000 O0 0 10 C~ 4607?5 Or) 000 O0 0 1.0 C~) 480775 OO 000 O0 0 10 450775 OO 000 O0 0 1.0 CU 480775 00 OOU O0 0 10 CPS 4-80775 O0 000 O0 0 10 CPS 460775 O0 000 O0 0 10 CP& 480775 O0 000 O0 0 10 CU$ d80775 O0 000 O0 0 10 68 0000000000' 68 0000000000 68 0000000000 0000000000 68 0000000000 .68 0000000000 68 0000000000 68 0000000000 68 0000000000 68 0000000000 68 0000000000 6'8 0000000000 :blUn'.ber~er A]as~.a Cor:':putinq Center l~-,,]A~J=19q5 08:18 PAGEI 5O TC~t'~ ~ CPS ~. TCF~ PS~ CPS TSC? PS~ CPS TSCF PS3 CPS '~ 807 I ~' :"~n ~$3 CPS I~F~ PS3 CPS TF ~'~ ~ PS~ bg DmPT. ln74g.500 TCA~.PS] SBH~.!,PS3 8QST.PS~ 0.419 TCAF.P$3 193'78.254 T$Cm. PS3 35~5.797 GP.P$3 91,7~I ICl:" A PI APl APT I[,E ~U~ NUMB SIZE ~ P~OCES$ R ~t LOG TYPE CLASS ~Oh NUmB SAMP ELEM CODE (HEX) ..... ............. ......... ............ ; .... . ..... ~5 ~.., o() 0 l ! 4 6 000o0000 0 ~5 O0 0o0 O0 0 10 I i 4 68 0000000000 75 O0 000 O0 0 10 1 1 4 68 0000000000 75 oO 0o~ Oo 0 10 ! 1 4 68 0000000000 ~5 au o00 O0 0 10 i I 4 68 0000000000 75 O0 0o0 Oo 0 10 1 I ~ 68 0000000000 75 nO 000 O0 0 10 1 1 4 68 0000000000 75 O0 OOO nO 0 I0 1 I 4 6~ 0000000000 ~5 oO 000 20 o 10 1 I 4 68 000000000~ SlG:4.'P83 i2.192 TPHI.P$3 21.103 SBHF.P$3 SIgC.P$3 2.933 $IBH.P$3 37.482 TRAT.P$3 BA~K.PS3 I14.764 FBAC.P$3 19.170 TCANePS3 · C~.!D.PS3 ~5750.066 TCFD..P$3 9203.963 TSCN.PS3 lI~:iO.P$3 1451.153 INFO,PS3 348.463 TENS..PS3 HP~g. PS3 3773.079 SlG=~.P$3 il.980 ?PHI.PS3 20.942 'SBBF P$3 S~..,~.P~3 3 076 SIBH,PS3 39,548 TRAT'PS3 ~ACK.P$3 133.099 FBAC'~P$3 22.339 TCAN.:PS3 ~ ~ ~l '~ ~ · . · .. -~.~t, PS3 ~5303 266 TCFD.PS3 9077,506 T$CN.*PS3 I~'~NO.PS3 1436.590 INFD.e'PS3 347.O4! TEN$.'PS3 wPPE.PS3 3654.69~ .29 8210 049 1165 000 34"21~2 : 1,.*.723 56.0.852 4~.108..97.3 350.000 **** FILE TRAILE~ **** FILF ~A~E : EDIT .010 SFRVlC~ : FLIC V~R~IO~ : O01COi D~T~ : 05101f~8 ~X RfC STZ~ : 1074' FILW TYPE 2 l.,O L~ST FILE' : IS ~ane V~ri~icat~o- :hlUwberqer f~,.aska ro;~uutin~ ~en'ter 18-JA~-I, 995 08:18 FTLr' p..-a . ..... J~.. DW.R R r., t~ CUi<V.~f..'$ murve$ an(; lo,:~ ~mader ~ata for each Dass iD separate DFFTH .t ?.;C~, L'~;~,' ',...': 0. ~0¢? 0 'tri',:'?~i:'>n?~ Tnt.)!.. CD, I":,E $'['AR'T DEPTH b.r3...G ~FTADE~ r~ATA STOP DW..PTH I)A.W~; ~OG ..,ED: ~OFTwAPE V..W. RSInN: T:'I~E bnGC, E~ O~ ~D LOG~E~CFT): TOP LOG Ti)~TERVA. b (PT): ~iJ~'TC?~ bog IMT~VAb [,CCGTNG SPEED (~'PHR): DEP'~H CO~'I'RG[., !.~L%ED (YE,q/MO): " ~ "' TOOL 8'lt~i~.~G (flOP ,b BOTTO ) TDTP TDYD GAM~qA RAY T D T P TDTO TDTP TDTD TOTP T n 'r P !'nTP 'fDTP T 0 T ~ OPE~ wOLE .~T'~' ~7'Z~ fiN}: DRT~L,E~8 C.~SI?~C DEPTH TDTP TDTP DETECTOR TOP GENERATOR TELEMETRY MOD!!L~ files; raw bacKarou~d pass in last fi 25-~AR.=94 38.2 1115 10747.0 10741.0 101'00,0 10735.0 1800.0 NO TOOb NUMBER CPSC-A-824 CPLE-A-823 CPSE-A-827 CPSS-A-812 TDIC-A-797 TNC-PB-$90 TND-PC-395 CTS.-SA-324 2713.0 # ~..'r'El.~O.'t,E Ci':,~:?. ["r-t.r,.:'. % F 1'..., u T a '£' ¥ 9 F' ~ FT,LITT) S~.uT,4T'iY {PDi..-~I: ~'f..UfO R.'ai.F af :i~'l.!.,i,~F'i.:r:. CF;Pt':}: G ~, ,5/['.'.. T [,.. CT4:3~E (DEC;): C' RI!DF../$EA ¢ ATER/BOR~X 19~.0 THFRMAL SANbSTONE 2.65 bf..bF, L.T. ne C~'..'.i,~m ~,.'ATE HOR~-~A[,I.%ATIn~ IN OiL ZONE ~A,.qE ~'~OR,",~A.T.,I?if'.iG ',<I~:i,.')OW PI.,I'~Ef.,I~.~M COU~T ~TE SCAbF:S $~T BY FIEbD EI<GINEE~ F~R COI.;~,:T RAmE bO~ SCALE FA~ CUU:~,~T PAT~; HTGH SCALE ~,'E~R COuP, iT RAT~ LOW SCAb~ ~.~EAR COONT ~A'I.'~ H'/GH SCALE (CP8)I TTe:D ti~ ]'n CA~CO OR/CCh DATED 6/5/91 & SW$ BHC DATED ~0/26/77. PLI~PI~4G DATa: t~A. 6~ #i--400 BBL~ PUMPED, RA. TE=6 BPM, 'W'~'IPm450 PSI. S~$~ ~2--420 BBI..S PUMPED, RAT~'I 'BPM, ~ASE ~3--445 B8LS PUHPED 'RATE:I BP~, 'NNIPm200 PSI. bOA.AX ~1.--40 B.BLS IN PER~$, RATE=I'*5 BPM W.HIP=200 BORa. X ~2--6~ BOLS IN' PERFS, RA~E=I,5 BPM~ WHIPm200 PSi, 60RAX ~3''75 BBL8 %~ PERF'$~ RATE=I. IOuL 8fCA~E E~RATIC Bore 1'0~90' O~ BORAX PASS,#{ 60~hX P~SS 2 & 3 YIELDED ~OOD TDT-P DATA, BY THE TIME 8OR~X'P~SSES ~ & 3 WERE MADE MOST OF THE BORAX HAD hEFT THE PURPOSE OF THE LOG WAS TO DETFRMINE IF THERE WAS'A ,. ~.~. 1.0376 4°,PERES AS 'SUSPECTED..TNB bOG VER.'TFT~P THE ~X. ISTANC~OF AN UP CHANNEE ABOVE THE P~RF$ $ his FORe, AT DATA PAGE: 52 IS ~'are v~ri. ficat~o,~ !.,istinn :blu:'~,~er,'.'.~er ~,.lasKa C.o~[.:,utinq Center 1 ~-JAN-_~ 905 F~ P~UDHnE BAY Field Name ~. ~S~:l 11 Well Name API).' ~u-u29-z0268-O0 API Serial Number Fl, 69b' Fr~L & 777'FW!, Field Location $¢C" 8 Section To ~ ~: 101~ Towns h ! p RA~C 15E Range COU f.' NORTH SLOPE County $~AT ALASKA State or Province hnIT USA Nation She 480775 Service Order Number p~A~' ~iSb Permanent datum EP~ ~'l' O. Elevation of Permanent Datum L~F RKB Log ~easured From APo FT 73. Aoove Permanent Datum E~B ~'~ '!~. Elevation of Kelly Bushing EDF PT 72, Elevation of DerricK'Floor £C~ ~T 34, Elevation of Ground.Level TDO r't' 10747. Total Depth - Driller TOb PT 10741. Total Depth '- Logger B[..I FT 10735. Bottom bog Interval T[.I ri 10100, TOO LOg lhterval DrT CRUDE/SEAWATER/BOrAX Dr'llling FlUid Type TLAP 11=15 25-gR~-94 Time bugger, at .Bottom aWE~ ~E~F 0 Surface Temperature BHT DEaf' 1~5, Bottom Hol.e.T. emperatu~e ....... DFPT $IG~ TPH? STGC T~AT 'F~^r TCR~~ TCAF TCFD TSC~ BeDth $1. gn),a (i{eutron Capture Cross section) TDT Porosity gorehole Sigma - far detector ~orehole Sigma - ~ear detector Sioma Correction Corrected Boreho]e Sigma oatlon Total ~{ear to Far counts Standard oevlatlon of $ioma gacKqround Count Rates - Near Detector gacKoround Count Rate - Far Detector Total counts analyzed - near detector (TDT~) Total counts analyzed - 'far detector (TDTP) TOtal capt,]re counts - ~ear detector · otal capture Counts - far dectector Total Selecte~ Counts - ~ear Detector Center PAGE~ 54 T,~C.w .. oral .~el _ cnvntm - ... t.'.etect r I~':.r: Ir",e.tasr. ic cot,hr rate - n~er detector i~'F'r ~:el~$tic count rate - ~..ar ~etector G~ ~,PT-Correcte.d. ~am,',.a ~,sV w?'R? '~'e]i oressure ] 66 0 2 66 0 4 6b 1 5 66 b 73 7 65 ~ 6~ 0,5 9 65 mT 1~. 66 t! 1~ 68 ~3 66 0 14 65 F~ 1'5 66 68 16 66 l ~ 66 J N~F SERV UNIT SE~VIC~ APl AP! APl API FILE NUMB NUM~ SIZE REPR PROCESS ID OR~E~ # LOG TYPE CLASS MOD NUMB SA~P E~EM CODE .(HEX) DEPT FT 4'80775 O0 000 O0 0 ~1 1 1 4 68 STG)~ ~84 CU 480775 oO OhO O0 0 ].1 .1 ! 4 68 TOHT P$4 PU 4~0775 O0 0()0 O0 0 1.1 1 1 4 68 SBH~ P$4 Cl.) 480775 O0 OOO O0 0 11 1 1 4 68 $~i~ P$4 CU 480775 nO 000 O0 0 ~1 1 I 4 68 STGC PS4 C)? 480775 O0 000 O0 0 11- 1 1 4 68 ST~ P$4 Ct.! 480775 O0 000 oo 0 ~l 1 I '4 68 T~A? PS4 480775 ()Q 000 00 0 I! 1 1 4 68 SDST PSd CU 4.~0775 O0 000 oo 0 1~ 1 I 4 68 BIC~ PS! CPS 480775 O0 000 O0 0 11 i I 4 68 FBAC P$4 CPS a80'775 O0 0o0 O0 0 ~.I 1 ! 4 68 TCA~ P&4 CmS 480775 OO 000 O0 0 II 1 ~ 4 68 TCAw v$4 C~$ 480775 O0 000 O0 0 1X I .1 4 68 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 00000.00000 0000000000 0000000000 .-hltlmher~,r i~].asKa '"omi)',l~il~,~' Center 55 !,~t~ .-' ~.~.V U~"~I? ...b' TCk~~ P54 C~5 -~ ~r'~'~ 75 O0 GOO O0 T~F~ PS4 C~S .I.S~775 ~0 t)OO TS C," PS4 CP~ ~J0775 O0 GDO T~<C~' P5~ C~5 ~Ur)775 oo O00 O0 INFO nS'-~ CPS "~0'/75 OU OhO no T F r.~ K oS4 LR 4t~0775 O0 OOO O0 G~ ~84 G~PT 48e775 O0 OOG '00 ~ ~ [%~' PS.~ Pg.[ 0 11 1 I 4 68 0000000000 n 11 I I 4 68 0000000000 O 11 I I 4 68 0000000000 0 11 1 I 4 68 0000000000 O ]1 1 1 4 68 0000000000 0 11 1 1 4 68 0000000000 0 11 1 1 4 68 0000000000 DS'PT 16749.d00 TC~.¢S~ ~23S.~9 *CND.PS~ TSCF.mS4 6~7.759 T~i~D.PS4 G~.PS4 75.3~3 wPR~.PS4 DFP?. 1.02q5.500 SRHs~.uSq g4.u12 ~IGC.PS4 SDST.PS4 <;.~55 ~ACK,PS4 TCAF.P$~ i0~02.~03 ~'C~D.PS4 T$CF.DS~ 216~.424 INNU.PS4 G~o~ 22.64I 19.609 TPHI.PS4 42.391 SBHF.PS4 n. O00 $IBH.P$4 ,56.648 TRAT.P$4 143.389 FBAC.P$4 30.204 TCAN.P$4 9144.986 TCFD.P,4 2724.?~ TSCN.P$4 1435.R17 I. NFOoPS4 281,~ TENS.PS4 i1..0~8 TPHI'PS4 18.597 SBHF,PS4 0.165 SIBH,-PS4 .136.~38 TRAT,.PS4 11'9.126 FBRC...P$4 20.~80 TCAN..P$4 11596.172 TCFD.PS4 4782.286 TSCN,PS4 ld37.076 TNFOeP$4 333.803 TENS,.P$4 365~.047 75.400 490 17.94.302 1095.000 791.541, · .l, 5'25 '20651-..684 4099.. 743' 1.2'25..000 Fib? .~,{A~-'..E : ~OTT .0 8?F(V IC~; : ~i~TC VFRSI.~i.~ : OOICO1 DhT~? : 95101118 t~X R~C SIZE : 1024 .' ~ , )...FTL.. TY~E : I.,0 BlS~ FILE IS !'ar, e v-r~.,ffcatJon f,istino ChlUm~eroer ala~<a co,;;.>utfn,~ Center 1 ~-J A..,.",~- 1 9 q 5 ~ t'; 0 ~'~ P,~ ~{ :!..2 Curves add lo~ nearer ~ata for e~ch OaSs in separate DFP°."'H i?'C~E~'.~F'."i': 0 5I')00 FTi.,r'' VEr"!D('I.N 'tOOL COD~g S'].'~RT D~jPTH ~i)~ r-,, .. ,. ?;X;X:~. .... LOG H~iADE',R DATA vi) OR.ILLFR (r'l'): T9 LOGGER (F'J,' ~: P. UT't'O~ 50G iMT~]~'{~AL [:OGGTNG SP~ED (FPH~)~ STOP DEPTH !.01,50 TOOL STD'IRG (TOP ~O .P.:,.OTTO~) VF.,NDOR TOD. O COl.J~i: fOOl., TyPf] T I) T P TOTP GA~{A R.~Y TDT~ TDTD TDTD TF~TD 'TDTD TDTP T'~TP '%DTD TnTP ODE:r4 HOLg BIT ~IZ~ (I~,~)': DR!bi, ERS C~SI~)~ DEPTH TDTP IDTP CARTRIDGE TDTP DETECTOR TDP GENERAYOR files; raw backaround pass ~n last 25-MAR-g4 38.2 .1115 10747..0 10741.0 10100.0 10735.0 1800.0 NO 25-~AR-94 TOOL NIJNBER 2 ~/8" HD WT .CGRS-A-820 CPSC-A~824 CPl.,E-A-823 CPSE-A-827 CPLM-A-81.2 TDIC-A-797 TNC-PO-390 TND-PC-39§ TNG-PB-400 CTSM-6A-~24 2713.0 IS Ta~e 'ver~ffcation Listl.~o :blt:~r,[~'erc;'er AlasKa Cc)mp:..',t~no Center' 1~-,]AN-!995 0[t;18 FLUID kATE ~.' l~l.t'~ 0 ~ ?bOb ~LL,I~bT;~,J~' COii;',T ~AT[] HOR~,~A[,I~AmIOI':, I~.I OIL ZONE TOP N(~R~A.blZTNG ~-I'[NOn~ (F'f): ~]A R C ~ U ~'.l. ~,~E~,R COUN'I' R~T~ HlGd SC~[,E (CPS)~ TOOL 6TA~'~t3~TFF (I~.?): # CR[~DE/SEA~ATER/BORAX THERMAL 8ANDSTON~ 2.65 TIED IN TO CA~CO GR/CCb DATED 6/5/9~. & SW8 8HC DATED 10/~6/77. ~A~E ~1--400 BDh$ PUMPED, RAT~=.6 BPM, WHIP~450 PSI,; BAS~ #2--420 BBL$ PU~PED,RATE-1BP~, 'WHIP:200 PSI.'. dA$? #3--445 86[,S PU~PED RATE=! BP~, wHiP=200 PSI. 80RAX ~1--40 BBhS IN PE~S, RATEm!.5 BPN', WHIP=200 PSI. BORAX SORAX ~3--7~ B~LS IN PERFS. RATE=! 5 BP~. ~HZP=200 PSI ..... ~ m .... ' TOT-P ~OOI, ~CAME E~RATIC ABOVE 10~9.0' O~ BORAX PASS #~, 50RaX PASS 2 & 3 YIELDED ~OOD TDT-P.DATA. BY THE TI~E 80~.~X P~$$ES 2 & ] WERE MADE NOST OF ?HE'BUPAX 'HAD LEFT T~{E BOREH~LE AgD WAS BEHIND CASING.. 1H~.; Pt!~PC}S~ OFT~ ~94' '" ' FROU ~0376' TO $ LIS FORMAT DATA 57 :hlurr~t'erc]er A].@ska Co~.'.puti. n~ ~ente~ PAGEt 58 Tt!?iT VALd DEF! ..........................................C"~F'; A~C.~'~';~:;;'~:.i, ................. Compan~''''''Name ....... ''''''''''''''' PROnHn~. ,.. BAY Field Name ~ b,S i - ~I Well Name API~: 5m-~29-~026~-00 AP! Serial Number FL Sg~' Fi'~[, & 7??'FwL Field bocation S~C~' 8 ' Section T~' 10N Township STA~ ALASKA State or Province mTT~' T~ ALLffN Witness Name S~;~ ~R(.>T?5 Service Order Number pPA~. ~Sb Permanent datum g~i:.~ r~ ~ ~levatlon ot Permanent Datum ~" ~b Log ~easured From A~O r!r 73, A~ove Permanent Datum g~ ~,:' 73. ~levatton ot ~el. ly Bushing ~F r~ 7~' Elevation oi Derric~ rloo~ ECb ~T 34' Elevat on ot Ground bevel T~ rT 10~47, Total DePth - Driller T~£, FT 10741, Total De~th' B[..I ~T 10735. 'Bottom 6bq I terval TLI rT 10100. Top bOg 'Iht DF'i; CRUOE'/SEAWATE~/BO~AX Drilling Flul~ Type TLAP 11:15 25-~AR-94 Ttme..bo~ger at Bottom $~E~ DECF 0, · ' Suriace'.Temperatu~e .. otto ,,,,.................... · · ~em~eratu~e ......... .... · TABLE TYPE : CURV DEFT D~PT. neDth. . SIB~ T~AT 'FBAC TCA~ rCAr TCND TCF~ TSC~ $ioma (~{eotron Capture Cross section) TPT 'ooroslt¥ ~orehole $tqma - far detector Borehol. e Sigma~ Near detector Sigma Correctio Corrected Borehole $tama Ratloa Total i~ear to Far counts Standard deviation of Stoma ~acKoro~Dd Count Rates - Near Detector aac~Orou~d Count Rate - Far Detector ~'otal counts analyzed - Dear detector (TDTP) TOtal counts aDalyzed - far detector (TDTP) Total'capture counts - Near detector Total capture Counts - far dectector Total Select, ed Cou~ts - Near Detector IS )are Verf~.!catlon ~hlu~berger A]asK~ ~omput~.n,~ Center TSC~ Tota ... ted Court - ~ar De r I~,~f,~ Tr~elastlc count rate - near detector I~;F'~ Tneiastic cou~t rate - far ~etector TF~'o ~ surface Tens~om G~ ~P~=Corrected Ca~ma RaV ~' well pressure PAGE~ 59 1 66 0 ~ ~6 0 3 73 4 66 1 5 66 'b 73 '7 65 ~ 68 1! 66 11 lP 68 I~ 6~ 0 14 65 FT 15 6b 68 ** SET Type - CMAN ** NaN~.C SMRV O~!,[.? SE~'VICE APl API' APl API FILE NUMB NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS ~OD NUMB SAMP. ELEM CODE. (HEX] DFPT FT dB0775 O0 000 O0 0 12 i 1 4 68 0000000000 STG~ PS5 TPHT PS5 SBHF PS5 S~H~~ PS5 STGC USS T~A? B~C~ PS5 FBAC PS5 TeA~ TCAr CU PU C[,i CU CU 4~0775 O0 ~g0775 o0 4G0775 O0 4~n775 O0 480775 O0 4~0775 ~0775 O0 480775 CPS ~.80775 O0 CPS 480775 O0 CDS a80775 O0 CPS 480775 O0 000 O0 0 12 OoO O0 O' O00 O0 0 12 000 O0 0 12 000 OD n 12 000 O0 0 12 000 O0 0 12 000 O0 0 1,2 000 O0 0 12 000 O0 0 1.2 000 O0 0 12 O00 O0 0 12 1 1 4 68 0000000000 I 1 4 68 0000000000 1 1 4 68 0000000000 1 1 4 68 OHO0000000 1 1 4 68 0000000000 1 I 4 68 0000000000 1 1 4 68 0000000000 I i :4 68 0000000000 1 1 4 68 0000000000 1 1 4 68 0000000000 1 ~ 4 '68 0000000000 I I 4 68 0000000000 wane V~rif?cstto, [isti.n,~ -~hlum~erg~r ;~].a. sKa Com[..'.ut~D.~ Center 1 ~-JAN-J 995 08 ~ -~. 8 PAGE~ 60 .;,~v $~RV ~,.; T AbpVTC. ~%t~I Ap! I FILE ~B ~UMB ~ E REPR P~OC 8S .......... .......... ........................ . ......... ...... ; ......... ~?..~ P~5 , 4~775 . 00,~ O0 C' 12 I t 6 00000 0000 'reFt DS5 C~6 48C775 f)O ~00 O0 0 12 I I 4 68 0000000000 TSC'? P$5 C~S ,~.B¢.775 oO O~t) 0() 0 ~2 L 1 ~ 68 0000000000 YSC~ PS5 CD~ ~5n775 o0 000 O0 0 t2 ~ ~ 4 68 0000000000 I~'"~F' PS5 CPS .~.6r775 O0 090 O0 o 12 1 ~ 4 68 0000000000 ~vF'r~ P5~ CPS 4 e(:,??5 ~"~ (~ 000 Oo 0 12 1 Z 4 68 0000000000 'l' F ~',. ~ PS~ [,,n. 4U0775 O0 000 O0 ~ ~.2 1 ~ 4 68 0000000000 , GP PS5 GAP]. 40c:775 nO OOO O0 ~ ~2 ~ I 4 68 0000000000 DDPT. 10148.5n0 SIG;'4.P$5 TCAF.D$5 1~3~5.74U TCNi).P$5 T$CF.P$5 2062,~3 INNO.PS5 GP.P$5 1~.500 ~PRg. PS5 0.000 TPHI.PS5 0.000 $IBH.PS5 0.000 TCFD,D$5 O.OOO !NFD'PS5 3~60.795 20.378 TPHI.PS5 2.516 SIBH~PS5 1.27.027 FBAC'P$5 23297.969 TCFD.PS5 ~53~.227 INFD.PS5 34b~,207 '" 0o000 TRA 0o000 0,000 TSCN,P,55 0.000 TENSeP$5 41.82! SBHF.PS5 :34.264 TRA?.PS5 · 28.442 TCAN.P$5 6853..85~ TSCNoP$5 278.891 TENS.PS5 0.,000 0,000 0.,,000 0,000 1140,000 .~., 051 30892., 242 614'7.,.708 1340'.000 END OF DATA **** F'IL~: TRAILEg **** FTLF NA~E : EDIT ,012 S~RVl;CE ~ ~blC VFRKIO~ : OOJCOi M~X R~C StZ~ ! 1074 FIL~ 'TYPE : LO L~S~' rILE : [$ ~'ae'e verl~.tcatlon T,istino :hlUr,,her~:er ~,lasaa ~o,~:(.,otin~ Center 1 O-dA.N-1995 08:18 PAGE~ 61 Curves and lo,:~ header -~at.a for each pass lf~ separate imi~iIiiI~ 10087.5 TD D~II..,!,~BR (F'fl: · D LOG~Er~ (BT): TOP [,0~ I',¥TE~'~L, (~*T): ~i.,'].".}0~% bOG INTerVAl, (FT): PgPT'H CO~'~TQOI., nS~O TOOL ST~I~.~G (~OP TO i~OTTOt~)' ......... ~ ~IIIiIIIiIIIIiii I~IIiIiI~ TDTP G A~4a RAY TgTP TDT~ T~TP To'rp T~TP '? }) T P ~[iP~ilOLb; A~i') C~,Sli,.~t.q PA. TA DR'TLLE~5 CASING DEPTN (FT)~ 'TD'£B CARTRIDGE' T~TP DETgCTOR 'ti'DP GENFR~TOR 37EL~T~Y ~ODULF files: raw back~round pass t.n last'fi 25-~AR-94 38. 2 tl'{5 25-MA~-94 10747.0 1074~.0 lOlO0 0 10735:0 1800.0 '2 1/8" .HD WT CPSC-A-824 CPLE-A-823 CPSE-A.-827 C.PLS-A-812 TD]C-A-797 TNC-PB-390 TND-PC-395 TNG-PO-400 CTSM-SA-324 271].0 :hlu~.ber.ger A!sS.Ka CO~-;,ut~.r~a Center l~-JAN-~995 V8218 FLUID S~.bl;~TiY {PP~,~): TOOT, ~E (~DTTHh~,~.RL .H~G~ C[)RRF'CTImL, (TN): 5T.,HmLli',~ COT~%~ ~'A~'5 NOR~,~A[,I~ATIgN IN nit. ZOnE TOO ~.~C]~i~:&aTZTI~.~C ~,~I~.'gn~,, ~A~ COUn'~ I~ATE boa 6CA~E 7AR CO~HT RATE HIGM SCAbE ~.~EAR COUNT RRTF bOW SCAbE (CPS)I ~,~Saa COoN'r ~A'I'~ HIGH SCALE (CPS)= CRUD£/SEAWATER/BORAX 195.0 THERMAL SANDSIONE 2.65 T.I~D !~ TO CAMCO Ga/CCD DATED 6/5/91 & SW$ BBC DATED 10/~6/77. PUMP.lNG DA'~: SaGE ~l--4. gO BBI..,~ PUMPED, RATE=6 BP~, WHIP=450 PSI.,. DAS~ ~'2::120 P. BL~, PU~pED, RATE'I 'BP'~', '~gI'P:200 PSI.. SAS~ ~'31.~45 BOLS Pu~ED~ ~ATE=I BP~, ~OR~X ~ 40 BOI,$ IN PELFS, ~ATE:i.5 BP~ wHIPz2OO'P$I. ~ORax ~- 65 B'BLS IN.PElFS, RATE=l.5 .BP~' ~HIP:200 PSI' ~!~aAX'i'3- 75 B~[,S IN PERFS, EI~E=I 5 BP~, W~IP:200 PSI TDT-8 TOO~ ~ECA~E ERRATIC ABOVE lOig0''ON. BORAX'PASS SOR.~X PASS ? & 3 YIESDED GOOD TDT-P DITA..SY THE TIME BORAX PASSES ? & '3 !,ERE ~AD.E ,OST OF TH~ BORAX HAD LEFT THE SORE[~OLE ~ND WAS BEHIND CASING. T~E PURPOSE OF THE LOG WAS TO DETERMINE IF THERE WAS A CHA~aEL A~OVE THE 10376-94' PFR. F$ AS SUSPECTED..'THE 50G V~RIFIEo THE EXISTANCE ~F A~ UP CMANNFb ABOVE THE P~RFS FRO~ 10376' TO t0309'. $ LIS FORMAT DATA PAGEI 62 [8 Ta.n..e vertft, cation I..ist~.t:o 995 08: 1 8 A~CO A K Compan~ Na~e Ft~ PRUDH~ BaY Field .ame ~' D,S,.~. - ~1 Well Name APi~; 50-029-2026R-00 ADI Serial Number ~'[' 89~' F~L & 777'W~5 Field Location SwC? 8 Section TC~,i ION Township Ra~,;C 15~ Range ' COUP: NONTH &[,OPE County STAT ALASaA State or Province N~TT USA Nation '~T~~ ~O~i Abb£N Witness Name Sn~d 480775 Servtce Order Number Permangnt datum EPD ~T 0, Elevation of Permanent Datum L~F RED Log Measured From APO PT 73, Above Perm. anent Datum Ew~ PT 73. Elevation of Kelly Bushing g~g FT 72, Elevation o~ Derrick FXoo'f' ECb rT 34 Elevation o~ Ground Level T~[) ~T 1d~47. Total Depth - Driller TDL FT 10741, Total Depth'- Logger BLI FT ~0735, Bottom bog Xnterval TLI FT 10100' TOp Log ~hterval DFT CRUDE~SEAWATER/BORA× Drilling Fluid Type T[,A~ 11:1.5 25-~AR-94 ' Time Logger at Bottom STE~' Ot~F ~§ 'Surface'Te~perature BH!I.' DEGF 5. Bottom Hole ?em. peratur· ........ T~BLE TYPE nenth Siama (Neutron Capt~l'e Cross Section) · DT Porosity ~oreho].e $1qma - far detector Bore~ole.Si~ma - {~ear detector Sio~a Correction Corrected gorehole S~,~ma ~atlon Total Near to Far counts Standard deviation of S1oma RacKoround Count Rates - Near Detector gacKoro'und Count'Rate'- Far Detector Total counts a~alyzed - near detector (TDTP) Total. counts analyzed - far detector (TDTP) Total. capture counts - Meat detector wota], capture Cou~ts - far dectector · ota! Selecteo Cou~ts - ~}ear Detector 18-JAN-1995 08:18 PAGE~ 64 mmmmmmmm~mmmmmmmmmmmmm~mmmmmmmmm~mmmmmmmmmmm~mmmmmmmmmmmmmm T$Cr ~otaX ~e!.ecte<i Counts - Far Detector INt~ Inelastic cogent rate - ~ear detector I~'F~ Inelastic count rate - far detecto~ TF~ Surface Tension GP .~PT-Corrected Gam,,a PAV ~RF ,~,el. 1 pre~sure 2 65 0 3 73 88 5 66 ~ 73 7 65 8 68 0.5 9 65 ~T 13 66 0 14 65 F~ 15 66 6~ 1.6 66 ~ ** $~T TYPg - CHAN ** .. NA~iF $~RV U~1T SERVICE APl AP! API AP! FILE NUMB NUMB SIZE 'REPR PROCE~ ID O~PgR # LOG TYP~' CbA$$ ~OD NUMB SAMP, ELEM CODE (HEX) DFPT FT 480775 O0 000 oO o 13 .1 I 4 '68 SIG~ P$6 CU 4,80'775 O0 000 O0 0 1,3 1 1 4 68 TPHT PS6 PU 480775 .00 000 O0 0 13 1 .1 4 68 SBH~ P66 CU 480775 O0 000 O0 0 13 1 I 4 68 8~H~ P$6 CU 4~r)775 Oo 000 00 0 13 1 1 4 68 SIGC P$6 CU 480775 o0 00u 00 0 13 1 I 4 68 $IB~ P86 CU 480775 O0 0o0 O0 0 13 I ! 4 68 IRAr PS6 490775 .nO 000 O0 0 13 i 'l 4 68 SDS? ~S6 C;; 48O775 O0 000 O0 0 13. 1. '1 4 68 BaC~ PS6 CPS 480775 00 000 00 0 1~ 1 I 4 68 F~AC P$6 CPS 4~o775 00 000 O0 0 1] 1 ! 4 68 TCA~ PS6 CPS 480775 o0 000 00 0 13 1 I 4 68 TCAW P$6 CPS ~8o775 oO 000 00 0 13 1 I 4 68 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 00000.00000 0000000000 :blu~her,.'..,,er ~)asKa co~puttno Center 65 TO TSC~: p$~ CPS T$C~ ~$6 CPS I ~;~r P~6 T~~ PS6 mmmmmmmmm m mmmmmm mmmmmmmmmmm mmm r:FDETM # ~OG TYPF CbASS ~OD NUmB 8&~P EbEM CODE (HEX) : ....... ..................................... 'i~80775 O0 O0 0 13 1 1 4 0000000000 4g~775 O0 000 O0 0 13 1 1 4 68 0000000000 48~775 ou (:o(? O0 0 13 1 1 ~ 68 0000000000 480775 o() (300 O0 O !] 1 1 4 68 0000000000 480775 Ou COO O0 0 13 I ! 4 68 0000000000 480775 (')~ uO0 O0 0 13 1 1 4 68 0000000000 4~n7v5 cO ()Ou O0 0 13 1 1 4 68 0000000000 480775 nO 000 O0 o 13 1 1 4 68 0000000000 D~P~ 10747.5 TSCF,PS6 G~.PM6 ~5.2 ~>0 SIOh. P86 O.OO0 TPHI,P$6 0.000 SBHF,P$6 Oo $iGC.PS~ 0.0O0 SIBH,P$6 0.000 TRAT,PS6 O0 BACK.PSb 0.000 FBAC,PS6 0.000 TCAN,PS6 OU ~C~:~t).ps.b O,OOO TCFD,PS6 0,000 T$CN.,P$6 0,.) I~.lNO.PSb 0.000 INFD..P86 0,000 97 v:P~g. PS6 3645.170 0~.000 0,000 0,000 0,000 1065,000 TCA~.P86 6602.6 TSCF.PS6 857.4 GP,PS6 38.0 OO SiC?4.PS6 30.790 TPHI,PS6 65,604 SBHF,P$6 06 SI~C,PS6 0 000 SIBH,PS6 39.606 TRAT.P$6 04 BAC~,PS6 128~640 FBAC,PS6 26,.q17 TCAN,P$6 3o TC~O'.PS6 17~01.555 TCFD,P$6 447B.923 TSCN.,PS6 04 ~i,'~{NO.PS6 1315,616 INFD,PS6 299o127 TENS,PS6 63 'WP~E,PSU 3422,504 '34.. 6t! 3- '254'.'7'...01~6 3338'430 1-225',.000 ** g~'.~...i') OF DAq'A ** **** FTLF TR~II,EP **** FTLr NA~E t EDIT .013 S~RVICE : FLTC VER$IOi~ : O01. CO1 D~Tw : o5/01/t8 'Fib? TYuE : LO L~Sm FiI,~ 18-,.J^~J-!995 08:~8 PAGEt 66 REVISION= 4.1 PART NUMBS: W5550-MICRO Start of execution: Thu 28 JUN 90 9:41am WELL DATA FILE: C:\WDSDATA\W04396.WDF ECC: 4396.00 COMPANY NAME: ARCO ALASKA, INC. WELL NAME: D.S. i - 11 FIELD: LOCATION: Top of Well: Bottom of Well: Level Spacing: 10180.000 10920.000 0.500 NUMBER OF CURVES: 13 DEPTH CCL CLSN CN LSN SPD SSN TEN CNC TTEN CNRA CSSN GR COMPANY:ARCO ALASKA, INC. WELL:D.S. I - 11 'FIELD:PRUDHOE BAY COUNTY:N.SLOPE STATE:ALASKA TAPE INFORMATION FILE:PASS 1.001 FILE INTERVAL: START= 10920.000 END= 10180.000 DEPT GR SPD TEN TTEN CLSN CSSN CN CNC CNRA LSN SSN CCL 10920.000 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 10895.000 10870.000 10845.000 10820.000 10795.000 10770.000 10745.000 10720.000 10695.000 10670.000 10645.000 10620.000 10595.000' 10570.00'0 10545.000 10520.000 10495.000 10470.000 10445.000 10420.000 10395.000 10370.0.00 -9 99.250 45.786 49.807 31.275 50.160 43.803 47.042 42.190 45.463 30.868 44.140 29.717 45.929 65.692 48.089 27.518 37,042 35.817 40.581 44,471 46.778 37.245 35.7'64 24.18.3 48'..916 25.385 45,'500 52,363 38',579 27,605 12,229 42,264 11.300 20.522 11.897 28,948 11.964 57.685 12.918 26.283 13.424 25.124 11.743 33,701 -999.250 30.997 0.057 30.997 0.056 30.997 0.059 30.761 0.060 30.652 0.061 30.997 0.060 30,342 0.058 30.997 0.069 30.997 0.065 30;997 0.059 30.,997 0.071 30.997 .0..057 30.997 0,060 30,997 0,067 30,997 0.154 30.99'7 0,162 30,997 0.157 30.997 0,156 30.997 0.148 30.997 0.145 30.997 0.158 30.997 -999. 474. 32, 195. 29. 118. 30. 38. 30. 4. 35. -10. 32. --0. 33. 26. 51. --0. 3'6. 25. 30. 16, 45. 11. 29. 5. 9. 51. 126. 338. 55. 357. 30. 340. 30. 334. 21. 305, --2. 283', 14, 336, -34. 250 613 988 726 287 821 019 906 784 201 391 570 169 405 965 157 412 062 092 058 462 631 454 987 819 902 407 5'57 209 231 887 483 692 519 858 343 382 0.00 303 462 041 589 23O 114 -999. 1455. 145. 1356. 129. 1357. 127. 1281. 128. 1284. 144. 1237. 135. 1280. 146. 1343. 186. 1330. 139. 1333. 129. 1322. 160. 1392. 130. 1379. 160. 1318, 190. 1521. 550, 1464. 552. 1491. 544. 1512. 5.35, 1469. 514. 1396. 488. 1518. 532. 1319. 25O 5O9 565 624 772 072 959 879 421 861 839 243 O74 972 756 746 159 692 530 651 394 315 359 906. 176 199 305 693 989 639 711 ' 792 51 625 224 ' 986 813 007 O3O 799 671 362 411 984 -999.250 8.247 0.000 7.322 0.000 7.505 0.000 7.696 0.000 8.848 0.000 8.042 0,000 8.491 0.000 12.853 0.000 9.023 0.000 7,616 53.000 11.363 1.000 7.455 0.0.00 9,602 9,000 12.8.02 '0.00.0 84.722 2.000 89.423 0.000 85.215 1.000 83.595 2.000' 76.326 0.000 70.760 0.00.0 84.057 0.000 77.477 145.565 129.772 127.959 128.421 144.839 135.074 146.756 186.159 139.530 129.394 160.359 130.176 160.305 19.0.989 550.711 552.751 544.224 535.813 514.030 488.671 532.411 501.748 45,807 46.160 43.042 41.463 40.140 41.929 44.089 33.042 36.581 42.778 31.764 44,916 41.500 34.579 8.229 7,300 7.897 7.964 8. 918 9.424 7.743 8.158 10345.000 10320.000 12.158 0.154 309.909 33.647 30.997 -43.749 12.251 0.154 317.418 24.135 30.997 25.373 12.814 0.149 298.320 D.S. 1-11 501.748 2.000 1307.816 79.354 516.411 0.000 1572.695 74.580 499.637 1.000 DEPT GR SPD TEN TTEN CLSN CNC CNRA LSN SSN CCL 10295.000 25.820 30.997 -33.589 11.656 0.159 326.769 10270.000 38.229 31.761 -22.586 11.387 0.161 334.091 10245.000 35.470 31.888 -8.805 11.212 0.163 334.019 10220.000 66.747 31.761 -7.952 11.082 0.164 351.168 10195.000 67.25'8 0.000 -100.000 0.000 0.000 0.000 10180.000 -999.250 -999.250 -999.250 -999.250 -999.2'50 -999.250 . , WELL DATA FILE: C:\WDSDATA\W04397.WDF ECC: 4397..0'0 'ARCO ALASKA, D.S. 1-11 INC. COMPANY NAME WELL NAME FIELD LOCATION 10180.00.0 10920.00.0 0.500' Top of Well.: Bottom of Well: Level Spacing.' NUMBER OF CURVES: 13 DEPTH CCL CLSN CN CNC LSN SPD SSN TEN TTEN 1381.563 81.692 514.970 2.000 1434.778 83.523 518.773 0.000 1461.230 83.505 513.606 2.000 1411.628 87.792 536.025 41.000 0.000 0.000 50.000 150.000 -999.250 -999.250' -999.250 -999.250 ... CNRA CSSN 516.411 499.637 CSSN 514.970 518.773 513.606 536. 025 50.000 -999.250 GR 8.251 8.814 CN 7.656 7.387 7.212 7.082 0.000 -999.250 FILE:PASS 2.002 FILE INTERVAL: START= 10920.000 END= 10180.000 DEPT GR SPD TEN TTEN CLSN CNC CNRA CCL' LSN SSN 10920.000 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -99'9.250 -999.250 CSSN -999.2'50 cN' -999.250 10895.000 10870.000 10845.000 10820.000 10795.000 10770.000 10745.000 10720.000 10695.000 10670.000 10645.000 1062O.000 10.595.000· 10570.000 10545"000 10520.000 10495.000 10470.000 10445.000 10420.000 10395.000 10370.000 43.369 41.803 25.215 51.490 41.850 55.521 40.426 44.526 31.138 44.561 25.144 39.939 72.997 38.569 26.976 37.857 32.375 44.443 47.214 47.593 38.019' 36.853 29:225 44.643 36.594 43.429 36.329 40.738 31.034 40.225 34.442 32.174 .17.958 31.4'04 23.14.3 35.294 52.368 42.485 17.762 39.367 24.210 32.898 19.520 41.702 30.997 0.063 29.997 0.056 29.997 0.053 29.997 0.061 29.997 0.061 29.997 0.065 29.997 0.067 29.997 0.068 29.997 0.061 30.233 0.0'58 30.997 0.069 30.997 "0.061 .. "~'0'..'997 0..062 30.997 0.064 30.997 0.065 30.997 0.077 30.997 0.078 30.997. 0.072 30.997 0.063 30.997 0.066 30.997 0.075 30'.997 0.063 373.759 0.000 144.408 1.000 67.347 0.000 54.939 19.000 43.678 1.000 4.347 3.000 19.316 1.000 -3.723 0.000 6.437 0.000 5.714 6.000 -47.967 0.000 -28.485 896.000 9.675 1.000 -6.116 0.000 0.267 2.000 -12.424 0.000 -4.720 57.000 9.156 0.0.0.0 1.126 0.000 4.317 0.000 -17.5'00 2.000 5.473 0.000 1198.950 35.201 1047.359 29.118 1080.775 26.919 1097.177 30.889 1202.382 35.003 1081.032 35.896 1165.982 38.750 1123.426 50.263 1155.639 34.407 1138.066 31.015 1047.801 47,085 1055.643 30.856 1125.197 40.758 1122.571 45.877 1070.135 47.00'4 1029.149 63.112 1048.281 60.553 1134.1.08 52.101 1100.565 43.217 1120.460 42.869 1031.344 58.443 1142.643 43.137 8.800 138.904 7.280 130.996 6.730 126.250 7.722 127.139 8.751 144.144 8.974 137.227 9.687 144.495 12.566 184.916 8.602 141.447 7.754 133.159 11.771 169.848 7..714 127.219 10.189 165.025 1'1.469 177.836 11.751 180.596 15.778 205.502 15.1.38 193.535 13.025 182.000 10.804 172,423 10.717 162.218 14.611 193.572 10.784 169.935 138.904 130.996 126.250 127.139 144.144 137.227 144.495 184.916 141.447 133.159 169.848 127.219 165.025 177.836 180.596 205.5.02 193.535 182.000 172.423 162.218 193.572 169.935 37.803 47.490 51.521 40.526 40.561 35.939 34.569 33.857 40.443 43.593 32.853 40.643 39.429' 36.738 .36.225 28.174 27.404 31.294 38.485 35.367 28.898 37.702 10345. 000 27. 254 30. 997 -12. 451 38.341 0.067 0.000 10320. 000 14. 661 30. 997 -20. 362 44.458 0. 061 3.000 1 D.S. 1-11 1073.495 11.764 47.056 174.718 1016. 854 10. 253 41.012 168.634 DEPT GR SPD TEN TTEN CLSN CNC CNRA CCL LSN SSN 10295.000 20.107 31.888 -14.700 31.818 0.077 0.000 10270.000 34.757 31.106 -0.335 34.287 0.073 2.000 10245.000 24.479 31.233 -15.134 34.747 0.072 2.000 10220.000 56.624 31.106 -16.457 32.151 0.077 2.000 10195.000 55.905 25.810 10180.000. -999.250 -999.250 WELL DATA FILE: 0.000 -100.000 0.091 200.000 -999,250 -999.250 -999.250 -999.250 C: \WDSDATA\W04398. WDF 4398.00 ARCO'ALA. SKA, INC,' D.S. 1-11 10180'..000 '10920.0.00 0.500 ECC: COMPANY NAME: WELL NAME: FIELD: LOCATION:' Top of Well: Bottom of Well: Level Spacing: 1066.394 14.126 56.505 182.423 1062.521 13.769 55.078 188.251 1027.033 12.946 51.782 178.777 1025.862 14.009 56.035 182.358 0.000 19.010 76.040 208.961 -999.250 -999.250 -999.2.50 -999.250 174.718 168.634 CSSN 182.423 188.251 178.777 182.358 208.961 -999.250 34.341 40.458 CN 27.818 30.287 30.747 28.151 21.810 -999.250 NUMBER OF CURVES: 13 DEPTH CCL CLSN LSN SPD SSN CN CNC · TEN TTEN css. GR FILE:PASS 3.003 FILE INTERVAL: START= 10920..000 END= 10180.000 DEPT GR SPD TEN TTEN CNC CNRA LSN SSN 10920.000 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 108.95.000 46.647 29.997 352.743 1200.062 45.357 0.060 33.441 139.297 CLSN CCL -999.250 8.360 1.000 · . CSSN -999.250 139.297 CN -999.250 41'.357 10870.000 10845.000 10820.000 10795.000 10770.000 10745.000 10720.000 10695.000 10670.000 10645.000 10'62'0.000 10595.000 10570.000 10545.000 10520.000 10495.000 10470.000 10445.000 10420.000 10395.000 10370.000 10345.000 33 51 40 55 42 47 26 42 28 44 70 41 31 38 31 46 48 41 34 34 2'7 46 27 '45 38 44 25 42 30 35' 18 3O 21 34 49 45 18 43 2'5 '30 22 39 26 35 .062 .429 .813 .641 .758 .467 517 .937 .302 .137 .795 .777 .817 .588 .180 .943 .897 .980 .053 .511 .8'6.6 .623 .740 .103 .833 .147 .627 .18.9 .038 .572 .668 .596 .991 .413 .511 .856 .858 .399 .803 .715 .349 .645 .256 .497 29.997 0.056 30.397 0.053 29.997 0.058 30.003 0.062 29.997 0.061 30.033 0.063 30.961 0.067 30.597 0.059 30.561 0.063 30.997 O. 073 '30.997 0..059 30,997 0.060 30.997 0.061 30.997 0.'063 30.997 O. 071 30.439 O. 080 30.597 0.073 30.997 0.060 30.997 0.062 30.961 0.080 30.997 0.066 30.997 O. 071 139.189 29.615 93.417 26.569 45.004 30.669 31.145 35.333 12.553 32.906 25.455 36.641 -6.430 51.654 16.178 33.490. 19.297 33.174 4.394 47.770 -28.489 30.074 2.846 3'9.451 26.149 40.639 11.067 '44.133 21.842 58.562 5.329 62.435 14.379 53.307 26.788 41.157 6.139 40.520 8.155 59.785 5.809 45.10'0 -4.728 50.621 1085.629 133.141 1139.320 124.750 1123.223 131.458 1130.362 141.976 1074.850 134.663 1177.327 144.522 1072.697 192.686 1140.401 142.566 1146.089 131.284 1133.80.2 164.077 '1019.059 127.481 1116.210 163.7'40 1228.751 166.336 1164.452 175.24.6 1173.514 205.778 1135.947 195.580 1204.593 182.705. 1237.930 172.642 1190.860 163.989 187.840 1'161.422 171.512 1134.346 177.592 7.404 0.000 6.642 0.000 7.667 0.000 8.833 0.000 8.226 1.000 9.160 1.000 12.914 0.000 8.372 0.000 8.293 0.000 11.942 0.000 7.519 9.0.00 '9.863 3.000 10.160 1.0'00 11.033 101.000 14.641 61.000 15.609 1.000 13.327 0.0.00 10.289 0.000 10.130 0.0.00 14.946 2.000 11.275 0.000 12.655 0.000 133.141 124.750 131.458 141.976 134.663 144.522 192.686 142.566 131.284 164.077 127.481 163.740 166.336 175.246 205.778 195.580 182.705 172.642 163.989 187.840 171.512 177.592 47.429 51.641 43.467 38.937 40.137 37.777 34.588 42.943 37.980 30.511 42.623 41.103 40.147 38.189 31.572 2.6.596 30.413 41.856 39,399 26.715 35.645 31.497 10320.000 12.873 30.997 -9.700 46.183 0.059 40.159 1 D.S. 1-11 DEPT 1124.166 169.216 10.040 9.000 GR SPD TEN TTEN CLSN CNC CNRA LSN SSN CCL 10295.000 21.763 31.033 -2.738 28.555 0.084 61.996 10270.000 40.821 30.997 -14.172 33.929 0.074 55.036 10245.000 26.696 31.033 0.949 33.067 0.075 53.800 10220.000 62.817 30.997 16.496 30.312 0.080 60.210 10195.000 64.081 0.000 -100.000 0.000 0.000 0.000 1201.811 184.126 10180.000 -999.250 .-999.250 -999.250 -999.250 -999.250 -999.250 1158.851 186.618 1184.273 178.890 1215.071 187.260 0.000 50.000 -999.250 -999.250 Thu 28 JUN 90 9:41am End of execution: Elapsed execution time = 15.16 seconds. SYSTEM RETURN CODE'= 0 15.499 59.000 13.759 3.000 13.450 1.000 15.052 0.000 0.000 150.000 -999.250 -999.250 169.216 CSSN 184. 126 186. 618 178.890 187.260 50.000 -999.250 42.183 CN 24.555 29.929 29.067 26.312 0.000 -999.250 .LIS TAPE VERIFICATION LI S'T IN'G IP 010.HOZ VERIFICATION LISTING P~GE 1 ~ R=EL HEADER '~'~ ~RVICE N~ME :E21T ~T= :86/11/23 ~iGIN : EEL NAME :23267~ 3NTINUAT~N. ~ :01 REVIOUS REEL : 2MMENTS :LIBRARY T~PE ~ T~PE w~ADER *"' ERVICE NAME :EDIT ATE : RIGIN :FSiA APE NAME ONTINUATION ~ :01 REVIOUS TAPE : OMMENTS :LIBRARY TAPE ~* FILE HEADER "*~ ILE NAME :EDIT .001 ERVICE NAME : E'RSI~N e : ATE : AXIMUM LENGTH : 102~ ILE TYPE : REVIOUS FILE : * INFORMATION RECORDS NE M ¢ 0 N'T EN T S 'N : ARCO~ALASKA.~ INC. N : DS # 1-11 N : PRUOHOE BAY ANG:. OWN: 1ON ECT: 8 OUN: NORTH SLOPE TAT: ALASKA NEM CONTENTS RES: E ~~ COMMENTS' ~g UNI'T TYPE CATE SIZE CODE 000 00'0 018 065 000 000 010 065 000 000 012 0'65 000' 000 00. 065. 000 000 00.~m' 065 000 '000 002 065 000 000 012 065 · 000 000 006 065 uNIT TYPE CATE SIZE CODE 000 000 001 065 IP OlO.HOZ VErIFICaTION LISTING P.~G~ Z SCHLUMBERGER ALASKA COMPUTING CENTER ~-.-' DMPANY = ARCO GL~SK'A INC ~LL : DS ~1-11 £ELD : PRUOHO:~ BAY )UNTY : NORTH SLOPE BOROUGH r~TE = ALASK~ 28 NUMBER AT ACC: 72064 JN ~3t DATE LOGGED: 13-NOV-86 )P: L. B. CUDNEY ~SiNG ~SING GSING YPE FLUID LUID LEVEL IT SIZE 20,000" SURFACE TO 120,0 13,375" SURFACE TO 2718 9,625" SURFACE TO 10980 PRDDUCEO mLUIDS FULL 8.5" IP OIO.HOZ VERIFICATIGN LISTIN<~ PIGE 3 SCHLUMBERGER LOGS INCLUDED WITH THIS MAGNETIC TAPE: COMPENSATED NEUTRON LOG - CASED HOL~ (CNL 3 PASSES) DATA FORMAT RECORD NTRY BLOCKS TYPE SIZE REPR CODE ·ENTRY 2 1 66 0 8 ~ 7~ 60 9 ~ 6~ .lin 0 ! 66 0 ATUM SPECIFICATION·BLOCKS NEM SERVICE SERVICE UNIT API AP1 API APt FILE SIZE SPL 'REPR ID ORDER # LOG TYPE ·CLASS MOD NO. CODE · . PROCESS (OCTAL) . . CP 010.H02 VERIFICATION LISTING 24GE 4 EPT FT O0 R PS1 G&mI O0 PHI PS1 PU O0 RAT PS1 O0 CNL PS1 CPS O0 CNL PSI CPS O0 R PS2 GAPI O0 PHI PS2 PU O0 RAT PS2 O0 CNL PS2 CPS O0 CNL PS2 CPS O0 R PS3 GHPI O0 PHI PS3 PU O0 RAT PS3 O0 CNL PS3 CPS O0 CNL PS3 CPS O0 000 310 890 420 330 330 310 890 420 330 330 310 890 420 330 330 DATA EPT 10912.0000 GR CNL -999.2500 FCNL RAT -999.2500 NCNL PHI -999.2500 NRA'T -999.2500 -999.2500 -999.2500 -999.2500 EPT 10900,0000 GR CNL 1486.0000 FCNL RA'T -999.2500 NCNL PHI -999.2500 NRAT 35.2813 450.7500 -999.2500 -999,2500 EPT 108'00.0000 GR CNL 939.5000 FCNL RAT 3.2285 NCNL PHI 34.3750 NRAT 25.2500 232.'7500' 922.0000 3.2891 EP'T 10700.0000 GR ' CNL 1028.0000 FCNL RA'T 3.1094 NCNL PHI 34.6191 NRAT 27.82'81' 320.2500 1034.0000 3.3027 E'PT 1,0600.0000 GR CNL 1048.0000 FCNL RAT 2.9863 NCN.L PHI 29-2969 NRAT 22. 4844 380.5000 i045.0000 3.0117 EPT 10500.0000 GR C'NL 2056,0000 FCN.L RAT 3.0059 NCNL PHI. 29.7363 NRAT 17.2344 609.5000 19.27.0000 3.0352 EPT 10400.0000 GR CN.L 2126.0000 FCNL RAT 2.7637 N'CNL PHI 23.5840 NRAT 24.9062 703.0000 2114.0000 2..6953 O0 O1 O0 Ol 31 30 Ol O0 O1 31 30 O1 O0 O1 31 3O NPHI GR FCNL NCNL NPHI GR FCNL NCNL NPHI GR FCNL NCNL NPHI GR FCNL NCNL NPHI GR F.CNL NCNL NPHI GR FCNL NCNL NPHI GR FCNL NCNL 4 I 68 4 1 68 4 1 68 4 i 6~ 4 I 68 4 1 68 4 1 68 4 1 68 4 1 68 4 1 68 4 1 68 4 1 68 4 1 68 4 1 68 4 1 68 4 1 6~ -999.250'0 NRAT -999.2500 NPHI -999.2500 GR -999.2500 FCNL 33.0566 NRAT -999.2500 NPHI -999.2500 GR -999.2500 FCNL 47.4509 NRAT 23.6'719 NPHI 265'5000 GR 927.5000 FCNL 3.2.373.0 .NR.AT 21.4688 NPHI 289.5000 GR 1022.5000 FCNL 27.4414 NRAT 23.5625 NPHI 362.0000 GR 1.102.0000 FCNL 31..5918 NRA'T 15.3203 NPHI 57.9.0000 GR 1955'0000 FCNL 24.3652 NRAT 22.6094 NPHI 719,0000 GR 2236.0000 FCNL 00000000000000 00000000000000 00000000000000 00000000000000 00000000000000 00000000000000 00000000000000 00000000000000 00000000000000 00000000000000 00000000000000 00000000000000 00000000000000 00000000000000 00000000000000 00000000000000 -999.2500 -999.2500 -9'99.2500 -999.2500 3.2148 -999,2500 -999.2500 -999.2500 4.0078 33.2520 25.03.13 289.7500 3-1777 31.1035 23-796.9 272.0000 2.9082 2'8.857.4 18.2500 334.0000' 3.1367 29.1992 15.3281 632.0000 2.7402 24.8047 22.6719 762.0000 IP 010.H02 VERIFICATION LISTING PAGE 5 EPT 10300.0000 GR 2NL 2033.0000 FCNL ~AT 2.9746 NCNL ~HI 29.5875 N.RAT EPT lOZO0.O000 GR SNL 2276.0000 FCNL ~AT 2.5059 NCNL PHI 21.9238 NRAT EPT 10195.5000 GR CNL -999.2500 FCNL RAT 2.0313 NCNL PHI -999.2500 NRAT 20.8437 601.5000 1911.0000 3.0313 4~.4375 807.5000 2078.0000 2.6055 -999.2500 -999.2500 2550.0000 -999.2500 NPHI GR FCNL NCNL NPHI GR FCNL NCNL NPHI GR FCNL NCNL ~ FILE TRAILER ILE NAME :EDIT .001 ERVICE NAME : ERSION ~ : ATE : AXIMUM'LENGTH : 1024 ILE TYPE EXT FILE NAME : ¢.FILE HEADER .-~.:~ ILE NAME :'EDIT .002 ERVICE NAME ERSION # : ATE : AXIMUM LENGTH : 1024. [:L'E TYPE : · REVIOUS FILE : DATA FORMAT RECORD~.,, N. TRY BLOCKS ATUM NEM..SERVICE 'SERVICE TYPE' 2. 8 9 16 0 SPECIFICATION BLOCKS UNIT API ID ORDER SIZE I 1 4 1 1 API API LOG TYPE CLASS O0 000 O0 O0 150 O1 0'0 150 O1 EPT CL PS1. CL PS2 FT REPR CODE '66 66 73 65 66 66 API FILE MOD NO. 0 0 0 0 0 0 29.3945 17.3125 628.5000 1955.0000 ' 20.4102 39.8125 78~.$000 2350.0000 -999.2500 33.0625 1136.0000 -999.2500 NRAT NPHI GR FCNL NRAT NPHI GR FCNL NRAT NPHI GR FCNL ENTRY 0 1 10 .liN 1 0 SIZE.SPL REPR CODE 4 ! 68 1 68 4 1 6.8 3.0156 28.6621 22.5781 671.5000 2.5117 20.3613 43.0313 837.0000 -999.2500 13.5254 -999.2500-999.2500 PROCESS (OCTAL) 00000000000000 00000000000000 000000'00000000 CP 010.H02 VERIFICATION LISTING PAGE 6 CL PS3 O0 150 O1 0 0 · ,- DATA .... EPT 10912.4160 CCL -999.2500 CCL 0.0010 CCL -0.0352 CCL 0.1865 CCL 0.0085 CCL -0.0039 CCL 0.0342 CCL -0,0029 CCL -0.0117 CCL -999.2500 CCL EPT 10900.2500 CCL EPT 10800.2500 CCL EPT 10700.2500 CCL EPT 10600.2500 CCL EPT 10500.2500 CCL EPT 10400.2500 CCL EPT 10300.2.500 CCL EPT 10200.2500 CCL EPT 10195.5078 CCL ~ FILE TRAILER ** ILE NAME :EDIT .002 ER'VICE NAME : .ERSION # : ATE : AXI'MUM LENGTH : 1024 ILE TYPE 'EXT FILE NAME :*' TAPE TRAILER'** 'E. RV'ICE NAME :EDIT ATE :86/11./23 :RIGIN :FS1A 'APE NAME · ONTINUATION # :01 I.EXT TAPE NAME : ;.OMMENTS :LIBRARY TAPE 1 68 00000000000000 -999.2500 CCL -999.2500 CCL -0.0117 CCL 0.1650 CCL 0,0967 CCL -0.0029 CCL 0.1182 CCL -0.6543 CCL 0.0029 CCL -0.0283 CCL -999.2500 -999.2500 0.0000 0.0850 0.0566 -0.0068 0,0693 -0.0059 -0.0254 -999.2500 :* REEL TRAILER ;ER'VI'CE NAME :EDIT DATE :B6/11/23 IRIGIN : :'EEL. NAME :2.326781t ;DNT'INUATION # :01 VP 010.H02 VERIFICATION LISTING PAGE ? EXT REEL NAME : OMMENTS :LIBRARY TAPE
