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Home My WebLink About191-123David Douglas Hilcorp North Slope, LLC Sr. Geotechnician 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 Tele: (907) 777-8337 E-mail: david.douglas@hilcorp.com Please acknowledge receipt by signing and returning one copy of this transmittal. Received By: Date: Hilcorp North Slope, LLC Date: 5/23/2025 To: Alaska Oil & Gas Conservation Commission Natural Resource Technician 333 W 7th Ave Suite 100 Anchorage, AK 99501 SFTP DATA TRANSMITTAL T#20250523 Well API #PTD #Log Date Report Type AOGCC E-Set# PBU S-10APB1 50029207657000 191123 10/20/1991 Directional Survey PBU S-10APB2 50029207657100 191123 10/29/1991 Directional Survey PBU S-15PB1 50029211137000 184071 07/04/1984 Directional Survey PBU S-16PB1 50029211237000 184082 08/16/1984 Directional Survey Please include current contact information if different from above. 184-084 T40442 T40443 T40444 T40445 PBU S-10APB1 50029207657000 191123 10/20/1991 Directional Survey PBU S-10APB2 50029207657100 191123 10/29/1991 Directional Survey Gavin Gluyas Digitally signed by Gavin Gluyas Date: 2025.05.27 08:30:54 -08'00' Nolan Vlahovich Hilcorp Alaska, LLC Geotech 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 Tele: (907) 564-4558 E-mail: nolan.vlahovich@hilcorp.com Please acknowledge receipt by signing and returning one copy of this transmittal. Received By: Date: Date: 4/02/2025 To: Alaska Oil & Gas Conservation Commission Natural Resource Technician 333 W 7th Ave Suite 100 Anchorage, AK 99501 SFTP DATA TRANSMITTAL T#20250402 Well API #PTD #Log Date Log Company Log Type AOGCC E-Set# BCU 19RD 50133205790100 219188 3/20/2025 YELLOWJACKET GPT-PERF BCU 19RD 50133205790100 219188 3/16/2025 YELLOWJACKET PLUG BRU 212-26 50283201820000 220058 3/21/2025 AK E-LINE Perf BRU 212-26 50283201820000 220058 3/15/2025 AK E-LINE Perf CLU 7 50133205310000 203191 1/22/2025 YELLOWJACKET PLUG IRU 11-06 50283201300000 208184 3/20/2025 AK E-LINE Perf KALOTSA 10 50133207320000 224147 3/1/2025 YELLOWJACKET GPT-PLUG-PERF KBU 22-06Y 50133206500000 215044 1/25/2025 YELLOWJACKET GPT-PLUG-PERF KU 13-06A 50133207160000 223112 3/18/2025 AK E-LINE CIBP MPE-20A 50029225610100 204054 3/13/2025 READ CaliperSurvey MPI 1-39A 50029218270100 206187 3/4/2025 YELLOWJACKET PERF MPU C-01 50029206630000 181143 1/30/2025 YELLOWJACKET PERF MPU K-17 50029226470000 196028 2/7/2025 AK E-LINE Caliper MPU S-53 50029238110000 224159 3/7/2025 YELLOWJACKET SCBL MRU A-15RD2 50733201050200 202019 3/10/2025 AK E-LINE TubingCut PBU 18-27E 50029223210500 212131 3/15/2025 YELLOWJACKET RCT PBU B-30A 50029215420100 201105 3/7/2025 READ CaliperSurvey PBU S-10A 50029207650100 191123 11/18/2024 YELLOWJACKET CBL-TEMP PBU W-220A 50029234320100 224161 2/22/2025 YELLOWJACKET SCBL Revision explanation: Fixed API# on log and .las files Please include current contact information if different from above. T40256 T40256 T40257 T40257 T40258 T40259 T40260 T40261 T40262 T40263 T40264 T40265 T40266 T40267 T40268 T40269 T40270 T40271 T40272 PBU S-10A 50029207650100 191123 11/18/2024 YELLOWJACKET CBL-TEMP Gavin Gluyas Digitally signed by Gavin Gluyas Date: 2025.04.02 12:55:27 -08'00' 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 S-10A Re-enter Susp Well, Cut Tubing Hilcorp North Slope, LLC 3800 Centerpoint Dr, Suite 1400, Anchorage, AK 99503 191-123 50-029-20765-01-00 8868 Conductor Surface Intermediate Production Liner 8582 80 2647 7855 7320 20" x 30" 13-3/8" 9-5/8" 7195 32 - 112 32 - 2679 30 - 7885 32 - 112 32 - 2679 30 - 7759 Unknown 2670 4760 7320 5380 6870 None 4-1/2" 12.6# L-80 28 - 36 Structural No Packer No Packer Torin Roschinger Operations Manager Aras Worthington aras.worthington@hilcorp.com 907-564-4763 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 0028257 28 - 36 N/A N/A Well is Suspended 350 350 350 350 N/A 13b. Pools active after work:PRUDHOE OIL No SSSV Installed 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 By Grace Christianson at 11:02 am, Nov 25, 2024 Digitally signed by Torin Roschinger (4662) DN: cn=Torin Roschinger (4662) Date: 2024.11.23 09:50:24 - 09'00' Torin Roschinger (4662) WCB 2-7-2025 RBDMS JSB 120424 ACTIVITY DATE SUMMARY 11/17/2024 ***WELL SHUT IN ON ARRIVAL*** ( CALIPER, TUBING CUT, DRIFT) MIRU YJT E-LINE PT PCE 300PSI LOW, 3000PSI HIGH, FUNCTION WLVS LOG CALIPER TO 80' LOGGED TO SURFACE VERIFY TUBING ID 4.0" JET CUT TUBING AT 36' MD. CCL-CUT=4', CCL STOP=32'. DRIFT JUNK BASKET W/ 3.79" GAUGE RING, TAGGED @ 7260' LAY DOWN FOR THE EVEING ***WELL SHUT IN ON DEPRATURE*** JOB CONTINUES ON 18NOV24 WSR 11/18/2024 *** JOB CONTINUED FROM 11-17-24*** *** WELL SHUT IN ON ARRIVAL *** ( PRESSURE TEMP LOG, CEMENT BOND LOG) MIRU YJ E-LINE PT PCE 300 PSI LOW 3000 PSI HIGH, FUNCTION WLVS LOG TEMP AND PRESSURE LOG FROM SURFACE TO 7256' LOG CEMENT BOND LOG FROM 7256' TO SURFACE. TOC FOUND AT 6386'. RIG DOWN E-LINE JOB COMPLETE ***WELL SHUT IN ON DEPARTURE *** Daily Report of Well Operations PBU S-10A JET CUT TUBING AT 36' MD. Suspended Well Inspection Review Report Reviewed By: P.I. Suprv Comm ________ JBR 07/26/2024 InspectNo:susRCN240619195555 Well Pressures (psi): Date Inspected:6/17/2024 Inspector:Bob Noble If Verified, How?LAT / LONG Suspension Date:11/6/1991 Tubing:650 IA:650 OA:250 Operator:Hilcorp North Slope, LLC Operator Rep:Andy Ogg Date AOGCC Notified:6/16/2024 Type of Inspection:Subsequent Well Name:PRUDHOE BAY UNIT S-10A Permit Number:1911230 Wellhead Condition Wellhead was protected with a wellhouse and had no drips or leaks. Weellhead removed above maset valve Gauges on all blinds. Surrounding Surface Condition Good clean gravel. Condition of Cellar Good clean gravel and water. Comments Supervisor Comments Photos (4) attached Suspension Approval:Completion Report Location Verified? Offshore? Fluid in Cellar? Wellbore Diagram Avail? Photos Taken? VR Plug(s) Installed? BPV Installed? Friday, July 26, 2024         2024-0617_Suspend_PBU_S-10A_photos_bn Page 1 of 2 Suspended Well Inspection – PBU S-10A PTD 1911230 AOGCC Inspection Rpt # susRCN240619195555 Photos by AOGCC Inspector B. Noble 6/17/2024 2024-0617_Suspend_PBU_S-10A_photos_bn Page 2 of 2 PBU S-10A Hilcorp North Slope, LLC 3800 Centerpoint Dr, Suite 1400, Anchorage, AK 99503 191-123 50-029-20765-01-00 8868 8582 80 2647 7855 7320 20" x 30" 13-3/8" 9-5/8" 7195 32 - 112 32 - 2679 30 - 7885 32 - 112 32 - 2679 30 - 7759 Unknown 7320 5380 6870 None 4-1/2" 12.6# L-80 28 - 70 No Packer No Packer Torin Roschinger Operations Manager Andy Ogg andrew.ogg@hilcorp.com 907-659-5102 PRUDHOE BAY, PRUDHOE OIL ADL 0028257 28 - 70 N/A N/A 390 625 0 0 N/A PRUDHOE OIL No SSSV Installed STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS Digitally signed by Torin Roschinger (4662) DN: cn=Torin Roschinger (4662) Date: 2024.06.21 11:55:12 - 08'00' Torin Roschinger (4662) By Grace Christianson at 9:00 am, Jun 25, 2024 RBDMS JSB 062724 WCB 9-10-2024 DSR-6/26/24 ACTIVITY DATE SUMMARY 6/17/2024 T/I/O = 650/625/225. Temp = SI. AOGCC suspended well inspection. State witnessed by Bob Noble. Pictures taken. MV = LOTO. IA, OA = OTG. 11:45 Daily Report of Well Operations PBU S-10A AOGCC suspended well inspection. State witnessed by Bob Noble. Pictures taken Operator Name:2. Exploratory Development Service 5 Permit to Drill Number:191-123 6.API Number:50-029-20765-01-00 PRUDHOE BAY, PRUDHOE OIL Hilcorp North Slope, LLC 5. Field/Pools:9. Well Name and Number: ADL 028257 Property Designation (Lease Number):10. 8. PBU S-10A 7.If perforating: What Regulation or Conservation Order governs well spacing in this pool? Will planned perforations require a spacing exception? Stratigraphic Current Well Class:4. Type of Request:1.Abandon Plug Perforations Fracture Stimulate Repair Well Operations shutdown Suspension Renewal Op Shutdown GAS GSTORWAG SPLUG Abandoned Oil WINJ Exploratory Development 5StratigraphicService WDSPL 12. Attachments: PRESENT WELL CONDITION SUMMARY 8868 Effective Depth MD: 11. Commission Representative: 15. Suspended 5 Contact Name: Oliver Sternicki Contact Email: oliver.sternicki@hilcorp.com Authorized Name: Stan Golis Authorized Title:Operations Manager Authorized Signature: Plug Integrity BOP Test Mechanical Integrity Test Location Clearance Other: Yes No Spacing Exception Required?Subsequent Form Required: Approved by:COMMISSIONER APPROVED BYTHE COMMISSION Date: 5OtherAlter Casing Pull Tubing Conditions of approval: Notify Commission so that a representative may witness Sundry Number: COMMISSION USE ONLY 17. I hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approval. Detailed Operations Program Packers and SSSV Type: No SSSV Installed Packers and SSSV MD (ft) and TVD (ft): Perforation Depth MD (ft):Tubing Size: Size Total Depth MD (ft):Total Depth TVD(ft): 8582 Effective Depth TVD:Plugs (MD):Junk (MD): Other Stimulate Re-enter Susp Well Suspend Plug for Redrill Perforate Perforate New Pool No Packer No SSSV Installed Date: Liner Well Status after proposed work: 16. Verbal Approval: Change Approved Program 32 - 2679 32 - 2679 14. Estimated Date for Commencing Operations: BOP Sketch 32 - 112 Structural 6870 Proposal Summary 13. Well Class after proposed work: No Packer None None Production 7320 7194 7320 none 33 - 112 13-3/8" 9-5/8" Contact Phone:907-564-4891 Date: 4760 80 20" x 30"Conductor 2670 GINJ 5 Post Initial Injection MIT Req'd? Yes No 5 Comm. STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 Surface 2647 5380 Intermediate 7855 30 - 7885 30 - 7759 Address:3800 Centerpoint Dr, Suite 1400, Anchorage, AK 99503 3. No 5Yes Casing Length MD TVD Burst Tubing Grade:Tubing MD (ft):Perforation Depth TVD (ft): Collapse MPSP (psi): Wellbore Schematic Comm.Sr Pet Eng Sr Pet Geo Sr Res Eng Form 10-403 Revised 03/2020 Approved application is valid for 12 months from the date of approval. By Samantha Carlisle at 3:07 pm, Aug 12, 2020 320-334 Digitally signed by Stan Golis DN: cn=Stan Golis, ou=Users Date: 2020.08.12 14:53:55 - 08'00' Stan Golis DLB-08/12/2020MGR13AUG20 x DSR-8/13/2020 Yes Required? Comm 8/18/2020 dts 8/18/2020 JLC 8/18/2020 10-404 RBDMS HEW 8/18/2020 L... J ytiP Fes^ da'J STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations Performed Abandon ❑ Plug Perforations ❑ Fracture Stimulate ❑ Pull Tubing ❑ Operations shutdown ❑ Suspend ❑ Perforate ❑ Other Stimulate ❑ Alter Casing ❑ Change Approved Program ❑ Plug for Rednll ❑ Perforate New Pool ❑ Repair Well ❑ Re-enter Susp Well ❑ Other: Suspend Inspection A 2. Operator Name: BP Exploration (Alaska), Inc 4, Well Class Before Work Development 0 Exploratory ❑ 5. Permit to Dnll Number: 191-123 3. Address: P.O. Box 196612 Anchorage, AK 99519-6612 Stratigraphic ❑ Service ❑ 1 6. API Number: 50-029-20765-01-00 7. Property Designation (Lease Number): ADL 0028257 8. Well Name and Number: PBU S -10A 9. Logs (List logs and submit electronic and printed data per 20AAC25.071): 10. Field/Pools: PRUDHOE BAY, PRUDHOE OIL 11. Present Well Condition Summary: Total Depth: measured 8868 feet Plugs measured None feet true vertical 8582 feet Junk measured None feet Effective Depth: measured 7320 feet Packer measured None feet true vertical 7194 feet Packer true vertical feet Casing: Length: Size: MD: TVD: Burst: Collapse: Structural Conductor 80 20" x 30" 32-112 32-112 Surface 2647 13-3/8" 32-2679 32-2679 5380 2670 Intermediate. 7855 9-5/8" 30-7885 30-7759 6870 4760 Production Liner Perforation Depth: Measured depth: None feet True vertical depth: feet Tubing (size, grace, measured and true vertical depth) None Packers and SSSV (type, measured and None true vertical depth) 12. Stimulation or cement squeeze summary: Intervals treated (measured): Treatment descriptions including volumes used and final pressure: 13. Representative Daily Average Production or Injection Data Oil -Bbl Gas -Mc' Water -Bbl Casing Pressure Tubing Pressure Prior to well operation: Suspended Subsequent to operation: 14.Attachments:(Mquimdper2onac25.070.25.071,&25.283) 15. Well Class after work: Daily Report of Well Operations D Exploratory ❑ Development p Service ❑ Stratigraphic ❑ Copies of Logs and Surveys Run ❑ 16. Well Status after work: Oil ❑ Gas ❑ WDSPL ❑ Printed and Electronic Fracture Stimulation Data ❑ GSTOR ❑ WINJ ❑ WAG ❑ GINJ ❑ SUSP 0 SPLUG ❑ 17. 1 hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt: WA Authorized Name: Lastufka, Joseph N Contact Name: Montgomery, Travis J Authorized Title: SIM Spec lis Contact Email: Travis. Montgomerv(o�bp.com Authorized Signature: Date: A I 1 Contact Phone: +1 907 564 4127 Farm 10.404 Revised 0412017 V AAR4w• i!gDMS_ OCT 1 12019 Submit OnBinal Only Daily Report of Well Operations PBU S -10A 3/28/2019 T/1/0=250/250/300 LTT ON MV (PASSED) T/I/O = LOTO/390/370. Temp = SI. Pre AOGCC SU Inspection. No AL or flowline. Single valve tree. Wellhead and tree are clean, cellar grating is in excellent condition. Well cellar is dry and free of debris. Area surrounding wellhouse is clean and free of debris. Well ID sign installed on wellhouse. Overall condition of well and surrounding area is excellent. 9/10/2019 MV = LOTO C. IA, OA = OTG. 23:45 T/I/O = SSV/390/370. Temp = SI. AOGCC SU Inspection (Regulatory Compliance). State witnessed by Jeff Jones. Pictures taken. Will need to stop by and remove a few pieces of plywood that is staged in and around the wellhouse. 9/15/2019 1 MV = LOTO. IA, OA = OTG. 09:00 Suspended Well Site Inspection Form Initial Inspection Notify AOGCC Inspectors at least 10 days prior to inspection to allow witness Well Name: S-1 OA Field/Pool: Prudhoe Bay / Prudhoe Oil Permit # (PTD): 1911230 API Number: 50-029-20765-01 Operator: BP EXPLORATION (ALASKA) INC Date Suspended: 11/6/1991 Surface Location: Section: 35 Twsp: 12N Range: 12E Nearest active pad or road: S access road Take to Location Digital camera Brief well history Latest Sundry or Completion report Past Site Visit documentation Pressure gauges, fittings, tools Map showing well location /Aerial photos Wellbore diagram showing downhole condition Site clearance documentation Sample containers for fluids on or near pad Condition of Surface Location AOGCC requires: 1) a description of the condition of the surface location, including discoloration, fluids or sheens visible on the ground or in any nearby water, 2) photographs showing the condition of the location surrounding the well General location condition: Location cleanup needed: Pits condition: Surrounding area condition: Water/fluids on pad: Discoloration, Sheens on pe Samples taken: None Photographs taken (# and Condition of Wellhead AOGCC requires: 1) a description of the condition of the wellhead, 2) well pressure readings, where practicable, 3) photographs showing the wellhead condition Wellhead/tree/valve description, condition: l rom-,$ A , `egr Cellar description, condition, fluids: Rat Hole: Wellhouse or protective barriers: Well identification sign: Tubing Pressure (or casing Annulus pressures: Wellhead Photos taken (# a Work Required: None Operator Rep (name artd si natu e): Josh Prowant AOGCC Inspector: —5 AA P,j_ Other O rvers: Inspection Date: 9/15/2019 AOGCC Notice Date: Time of arrival: OP -10 Time of Departure: Site access method: Access road y S-122PBS ., 9.122PB2 r 5122PS! r, S-12-1PS-1 R -19A - C "x-103 S -41L7 { .:. - .. .S=tE,h S-1,3APE523 ' :' 5-15 &AI P61 S41 .- S_104 e t5P81 I. Sn9< 5-4A SS.t KL, PST ' '— .ria .��-1fl8PB1 - S-2^ - S-09A.F6" S-D3AP6.?. _ 509,AFE1 - 5-401 PE t... 5-42" _ - 541A -. E-401 -- .. 5108 578 - 5-110 : "'S201PB1 —;5-1106 _ 5228 ! � - 524. S-44 5-22 5-280 FA.PSI 52FA. � V S-41ALI _S_44Li - : S200P61 a-_5 .-, S-38 5f1� 4<..., ..5-n 1G _ 0-38 51t2L1. 112L i P82, S-1 _5A7 S-44L1PS7_ 5115 S-112LIP S-1 n.3FEt _S72 c aZFE' HC S,-tA1P6.1 ^ S -01A _ 50+5 1�S+109P61 S-1" �� S -1 4A 5504 !v° R-41 -. . SITALi & 18 S$2 5-04 5-n6APE1S7 S-�TEP t - S 17CPf�t 51`2.. S-27 C'' ht -126 5-12�PE.t S-2LP 5174 1PB1 �.��D' + F O5 � s,*PF1 tui -14 ._ 31 — - sa. �srti6; - s45A h1 -2e 5134 _' r,$.cEA S135P6i r, 528 E.P31 _ S-ry.8 .:528 ` S_ • 1 - ht -08 -S28A =.528 S -20A s-20 5129P61 _ S-112 53 511A 5-,15 - S729PBc' S09 _r' SINE . S-40 .., S-126 _.. S-21 :' S-02APS1 S-40AL $-13 527". �J27APB1 _'. ' 5-07,P— _ _hA S-129 5218y S-213AL3 3 S9e",? 5218 2 5213AlOS-213AL1 5-278 5 213AL2 S-07 hip3APE1 _ S-02AL1 PBt .. a±!2AL1 • • STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION Suspended Well Inspection Report Date Inspected: 09/11/10 Inspector: Chuck Scheve Operator: BPX Well Name: PBU S -10A Oper. Rep: Jack Winslow PTD No.: 1911230 Oper. Phone: 659 -5766 Location Verified? No Oper. Email: If Verified, How? Onshore / Offshore: Onshore Suspension Date: 11/06/91 Date AOGCC Notified: Sundry No.: Well Completion Rpt Type of Inspection: Initial Wellbore Diagram Avail.? Yes Well Pressures (psi): Tubing No tubing Photos Taken? Yes IA 470 by Operator OA 10 " Condition of Wellhead: Well house in place. Single master valve only. Condition of Surrounding Surface OK Location: Follow Up Actions none Needed: - Attachments: None REVIEWED BY: Insp. Supry .&2 - 1017 6l Comm ; PLB 08/2010 2010- 0911_Suspend_PBU_S- 10A_cs.xls ME BIT ALASKA SEAN PARNELL, GOVERNOR ALA OIL AND GAS 333 W. 7th AVENUE, SUITE 100 CONSERVATION CO1� USSION ANCHORAGE, ALASKA 99501 -3539 PHONE (907) 279 -1433 FAX (907) 276 -7542 Gary Preble Data Management Engineer , 4 `Lo BP Exploration (Alaska), Inc. P.O. Box 196612 Anchorage, AK 99519 -6612 Re: Prudhoe Bay Field, Prudhoe Bay Oil Pool, PBU S -10A Sundry Number: 310 -318 Dear Mr. Preble: 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, 0 Daniel T. Seamount, Jr. Chair hd DATED this 2 day of November, 2010. Encl. ` n • A • • by BP Exploration (Alaska) Inc. Attn: Well Integrity Coordinator, PRB -20 Post Office Box 196612 Anchorage, Alaska 99519 -6612 0 September 16, 2010 Mr. Daniel Seamount, Chairman Alaska Oil and Gas Conservation Commission ' 333 West 7 Avenue SEP 1 7 2010 Anchorage, Alaska 99501 Subject: Prudhoe Bay Unit Well S-1 OA (PTD #1911230) mthell Suspended Well Inspection Report (10 -404) Application for Renewal of Existing Suspension (10 -403) Dear Mr. Seamount, BP Exploration (Alaska) Inc. (BPXA) completed an AOGCC witnessed suspended well inspection of Prudhoe Bay Unit well S -10A on 9/11/10. Enclosed is a Report of Sundry Well Operations (10 -404) with attachments documenting the inspection and the current condition of the well (reference 20 AAC 25.110 (e) and (f)). Recent well events from this well indicate that this well is mechanically sound. Specific attachments include: • Suspended Well Site Inspection form documenting the well pressures and site condition • Wellbore diagram illustrating the current configuration of the well • Pad map and aerial photo showing well location and other wells within one - quarter mile radius of the surface location • Photographs showing the condition of the wellhead and the surrounding location Prudhoe Bay Unit well S -10A was suspended on 11/6/91. It is located on a pad with active wells and /or service wells. Based on this information, BPXA requests approval for renewal of the existing suspension status for this well. Attached is an Application for Sundry Approval (10- 403) with a technical justification summarizing the information on the current status and condition of the well (reference 20 AAC 25.110 (a), (b), (e), (h) and (i)). In summary, BPXA believes Prudhoe Bay Unit well S-1 OA is mechanically sound and secure and will meet the requirements for renewal of suspended status. If you require any additional information, please contact me at 564 -5637, Torin Roschinger /Jerry Murphy at 659 -5102 or Chris Stone 564 -5518. Sincerely, R. Steven Rossberg BPXA, Wells Operations Manager Attachments: Report of Sundry Operations (Form 10 -404) with attachments: Suspended Well Site Inspection form Wellbore Schematic Well location plat and aerial photo Pictures of wellhead and location Application for Sundry Approval (Form 10 -403) with attachment: Technical Justification Cc: Roschinger /Murphy Harry Engel Mike Bill Chris Stone Mohamed Sayed Gary Preble STATE OF ALASKA i A.-W AND GAS CONSERVATION COMMISSIA 1 10 APPLICATION FOR SUNDRY APPROVALS ' 20 AAC 25.280 1. Type of Request: Abandon ❑ Plug for Redrill ❑ Perforate New Pool[] Repair Well ❑ Change Approved Program ❑ Suspend ❑ Plug Perforations ❑ Perforate 11 Pull Tubing ❑ Time Extension ❑ Operation Shutdown ❑ Re -enter Susp. Well ❑ Stimulate❑ Alter Casing ❑ Other: RENEW SUSPENSION - 2. Operator Name: 4. Current Well Class: 5. Permit to Drill Number: BP Exploration (Alaska), Inc. Development O - Exploratory ❑ 191 -1230 3. Address: P.O. Box 196612 Stratigraphic ❑ Service ❑ 6. API Number: Anchorage, AK 99519 -6612 50- 029 - 20765- 01 -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: El S -10A - Spacing Exception Required? Yes El No 9. Property Designation (Lease Number): 10. Field / Pool(s): ADLO- 028257, 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): 8868 8582.22 7320 7194.2 7320' TOC NONE Casing Length Size MD TVD Burst Collapse Structural Conductor 139 20" 94.5# SURFACE 139 SURFACE 139 Surface 2679 13 -3/8" 72# L -80 SURFACE 2679 SURFACE 2679 4930 2670 Intermediate 7900 9 -5/8" 47# L -80 SURFACE 7900 SURFACE 7774 6870 4760 Production Liner Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): NONE- - NONE Packers and SSSV TVDe: NONE Packers and SSSV MD and TVD (ft): 12. Attachments: Description Summary of Proposal 13. Well Class after proposed work: Detailed Operations Program ❑ BOP Sketch ❑ Exploratory ❑ Development Q Service ❑ 14. Estimated Date for 15. Well Status after proposed work: Commencing Operations: 8/13/2010 Oil ❑ Gas ❑ WDSPL ❑ Suspended - ❑� 16. Verbal Approval: Date: WINJ ❑ GINJ ❑ WAG ❑ Abandoned ❑ Commission Representative: GSTOR ❑ SPLUG ❑ 17. 1 hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Gary Preble Printed Name Gary Pre a Title Data Management Engineer Signature Phone Date 564 -4944 BIN Prepared by Gary Preble 564 -4944 COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number: �� C) Plug Integrity ❑ BOP Test 1 E] Mechanical Integrity Test F] Location Clearance Other: .y A i! +errt^; /(4 p/aC.G Zo AAG Z S i oCh Subsequent Form Required: MG Pt L * " APPROVED BY Approved by: COMMISSIONER THE COMMISSION Date: ROW N OV oa to I -Z y .Q -�"� /� Form 10-403 Revised 1/2010 Submit in Duplicate Pru Bay Oil Pool well S -10A Technical Justification for Application for Renewal of Suspension Status September 16, 2010 Well Status Prudhoe Bay Unit well S -10A (PTD #1911230) was suspended on 11/6/91 after losing the BHA three times during sidetrack attempts. The well was secured with a cement plug at 7320' M D. The 9 -5/8" casing was tested to 3000 psi. The wellbore was left with seawater from 7320'MD to 2035'MD and Diesel from 2035'MD to surface. A 40', 4 -1/2" kill string was left in the well. The well is mechanically sound with a cement plug at 7320' MD, above the sidetrack window at 7885 - 7899'. The well will not allow the migration of fluids, will not damage freshwater or producing or potentially producing formations, will not impair the recovery of oil or gas, is secure, safe, and not a threat to public health. The strata through which the well was drilled is neither abnormally geo- pressured or depleted. Condition of the Wellhead and Surface Location Prudhoe Bay Unit well S-1 OA is located on an active, well maintained pad with clean gravel. The pit and surrounding area are in good condition. There is no discoloration and no sheens on the pad, pits, or in nearby water. The well ressure readings are T /I /O = NA/470/10. The IA was bled to 0 psi on 9/12/10 p 9 p and is stable. �- Request BPXA requests approval for renewal of the existing suspension status for S-1 OA. A variance to the provisions of 20 AAC 25.110 (c) (2) is also requested under 20 AAC 25.112 (i) to allow the well to remain as suspended in its current condition. All hydrocarbon intervals are isolated and there are no underground sources of fresh water in this area. . , • a . • , ' - • . . -. ._ • .Alf '1'!`j 1'1'1'1y`1 1 1 / 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 • . • 1 , , 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 11111111111 11111111111 �111/111111�. X1111111111111., 1111111111111111. • • • • • X / 1 1 1 1 1 1 1 1 1 1 1 1 1 / s s ON�-* 1�1�1'1'1�1'1'1'1'1'1'� 1111111111111 / 1111111111111111111111111111111 ,� � 1 i�1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1�1�1�1�1�1�1�1�1�1�1�1�1�1�1�1�1�1�1 �i � k ` 1 .1 111111111111111111. • - • - • • - • � � � l�1�111111111111111111. ! �' 1 ' 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1�� . i i � �' 1 ` 1 1�1 1 1 1 1 1 1 1 1 1 1 1 1�1. . `1111111 111111111�. PA 1 AA',1'1 1 111111 111111N1. /11 ►111111 �` � 1 ` 1 1 A 1 1 / 1 1 1 1 1 1 1 1 1 1 , 1. . �1111RMW4 1111N1 • 1111111• I 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 '1 ►�: /1111.: 1111111 `1,11 1111111 X1111 111111 11 1�1 # `111111 • -• - � 111111♦ 1 •. 1 ..Af ♦111 111 A �' 111 ' 1► 1 OO /►1 � D ♦111111 111111 411 1111111 ♦ ►111111 1111111 �1 1� 11 �`�11111111111`� 1 1 1 1 1 1 1 1 1 111 1 111 1 111111 w . 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 # 1 , 111111111111111 - • 1 , . - _- 1 1 1 1 1 1 1 1 1 1 1 11 / ■■ --_ �i X1 X1 1 Sam - �� STATE OF ALASKA ALA AND GAS CONSERVATION COMMISS REPORT OF SUNDRY WELL OPERATIONS 1. Operations Abandon ❑ Repair Well ❑ Plug Perforations ❑ Stimulate ❑ Other 0 Performed: Alter Casing ❑ Pull Tubing ❑ Perforate New Pool ❑ Waiver[] Time Extension ❑ INSPECT Change Approved Program ❑ Operat. Shutdown ❑ Perforate ❑ Re -enter Suspended Well ❑ WELL 2. Operator BP Exploration (Alaska), Inc. 4. Well Class Before Work: 5. Permit to Drill Number: Name: Development Q Exploratory ❑ \ 191 -1230 3. Address: P.O. Box 196612 Stratigraphic❑ Service ❑ 6. API Number: Anchorage, AK 99519 -6612 *1 50- 029 - 20765 -01 -00 8. Property Designation (Lease Number) : 1- 9. Well Name and Number: ADLO- 028257 PBU S -10A 10. Field /Pool(s): PRUDHOE BAY FIELD / PRUDHOE BAY POOL 11. Present Well Condition Summary: Total Depth measured 88 68 feet Plugs (measured) 7320' T feet true vertical 8582. feet Junk (measured) None feet Effective Depth measured 7320 feet Packer (measured) true vertical 719 4.2 feet (true vertical) Casing Length Size MD TVD Burst Collapse Structural Conductor 139 20" 94.5# SURFACE - 139 SURFACE - 139 Surface 2679 13 -3/8" 72# L -80 SURFACE - 2679 SURFACE - 2679 4930 2670 Intermediate 7900 9 -5/8" 47# L -80 SURFACE - 7900 SURFACE - 7774 6870 4760 Production Liner Liner Perforation depth: Measured depth: NONE - True Vertical depth: Tubing: (size, grade, measured and true vertical depth) NONE 0 Packers and SSSV (type, measured and true vertical depth) NON NO j 12. Stimulation or cement squeeze summary: y7v J� /� Intervals treated (measured): R $EP 1 7 2010 Treatment descriptions including volumes used and final pressure: 13. Representative Daily Average Production or Injection Data Oil -Bbl Gas -Mcf Water -Bbl Casing Pressure Tubing pressure Prior to well operation: SI Subsequent to operation: 14. Attachments: 15. Well Class after work: Copies of Logs and Surveys Run Exploratory[ gaveopment Service ❑ Daily Report of Well Operations X 16. Well Status after we SUSPENDED Oil El Gas WDSPL GSTOR ❑ WAG ❑ GINJ ❑ WI NJ ❑ SPLUG ❑ 17. 1 hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt: NA Contact Gary Preble Printed Name Gary Preb!9 Title Data Management Engineer (► Signature ''L— Phone 564 -4944 Date I LI11 V • • Suspended Well Site Inspection Form Notify AOGCC Inspectors at least 10 days prior to inspection to allow witness Well Name: PRUDHOE BAY UNIT S-1 OA Field /Pool: PRUDHOE BAY / PRUDHOE OIL Permit # (PTO): 1911230 API Number: 50029207650100 Operator: BP EXPLORATION (ALASKA) INC Date Suspended: 11/6/1991 Surface Location: Section: 35 Twsp: 12N Range: 12E Nearest active pad or road: PRUDHOE BAY S -PAD Take to Location Digital camera Map showing well location /Aerial photos Brief well history Wellbore diagram showing downhole condition Latest Sundry or Completion report Past Site Visit documentation Site clearance documentation Pressure gauges, fittings, tools Sample containers for fluids on or near pad Condition of Surface Location AOGCC requires: 1) a description of the condition of the surface location, including discoloration, fluids or sheens visible on the ground or in any nearby water, 2) photographs showing the condition of the location surrounding the well General location condition: Good Pad or location surface: Dry Location cleanup needed: No Pits condition: Good Surrounding area condition: Good Water /fluids on pad: No Discoloration, Sheens on pad, pits or water: None Samples taken: No Access road condition: Good Photographs taken (# and description): (3) wellhouse, sign & pits Condition of Wellhead AOGCC requires: 1) a description of the condition of the wellhead, 2) well pressure readings, where practicable, 3) photographs showing the wellhead condition Wellhead /tree /valve description, condition: CIW wellhead and master valve - good condition Cellar description, condition, fluids: Water in cellar Rat Hole: N/A Wellhouse or protective barriers: Wellhouse Well identification sign: Yes Tubing Pressure (or casing if no tubing): No tubing Annulus pressures: IA: 470 psi OA: 10 psi 64a fa b s; 47 Z 1 �p • � Wellhead Photos taken (# and description): (1) wellhead Work Required: None Operator Rep (name and signature): Torin Roschinger AOGCC Inspector: Chuck Scheve Other Observers: Jack Winslow Inspection Date: 9/11/2010 AOGCC Notice Date: 9/812010 Time of arrival: 10:40 AM Time of Departure: 10:50 AM Site access method: Truck Amb TREE = 4- 1/16" CIW WELLHEAD = M;EVOY S 0A SA Y NOTES: WELL WAS P&A'DW /CMT BACK TO ACTUATOR = AXELSON 7320' AFTER 3 ATTEMPTS TO SDTRK. SEE DRLG KB. ELEV = 67.56' REPORTS FORDETALS. A SINGLEJT OF 4-1/2" TBG BF. ELEV = 39.26' WAS LEFT BELOW MCEVOY HANGER. KOP = 3100' Max Angle = 24 @ 3700' 40' 4 -1/2" TBG, 12.6 #, L 80, .0152 bpf, ID= 3.958" Datum MD= 8994' Datum TVD = 8800' SS 9 -5/8" DV PKR 2514' 13 -3/8" CSG, 72#, L -80, ID = 12.347" 2679' SAFETY NOTES: WELL FROZE PROTECTED TO 2035'W/ DIESEL AND HAS 8.5 PPG SEAWATER W/ COREXIT FROM Minimum D = 3.958" to 40' 2035' TOTOPOFP&A PLUG @7320'. SINGLE J OF 4 -1/2" 12.6# TBG TOC/ SDTRK P&A PLUG 7320' 9 -5/8" MILLOUT WINDOW 7885' - 7899' (OFF WHIPSTOCK) TOPOFWHIPSTOCK 7885' TOPOF WHIPSTOCK PKR 7900' TBG CUT 8020' TOC PLUG 8033' TOP OF T' LNR 8200' 9-5/8" CSG, 47 #, L -80, ID= 8.681" 8697' PERFORATION SUMMARY REP LOG: ANGLEAT TOP PERF: Note: Refer to Production DB for historical perf data SIZE SPF INTERVAL Opn /Sqz DATE 7" LNR, 26 #, L -80, D = 6.276" 9715' l DATE REV BY COMMENTS DATE REV BY COMMENTS PRUDHOE BAY UNIT 07/04/82 ORIGINAL COMPLETION WELL: S-10A 11/06/91 ATTEMPT RIG SIDETRACK PERMT No: 91 -1230 03/08101 SIS-MH OONVERTEDTOCANVAS API No: 50- 029- 20765 -01 03/12/01 SIS-MD FINAL 1644' SNL & 1745' EWL, Sec. 35, T1 2N, T1 2E 09/24/01 CH /KAK CORRECTIONS BP Exploration (Alaska) o - i 969' 229' -►i -4 - 261' — ►� ,04 1� I D O 20 1 � 1 03 t CC) 1 119101101 113 8 110 T � � 102 1 09 102 15 101 I 117 IV 120 213 J 1� 216 400 116 118 I O \\ 03 504 125 43 1 / / 401 41 I �r I — 7 504 • Q C ` ( Methanol Tank ` � � P � — — — — �— -(P — 57 I a ca I -; II I 551 II 93 NN { p Q I N N N N cv N a N co N 'n N N NNC9 ' n t'I N tl M f7 O ty N r CD I — 30' — — v- ' I I I 15 °�� ► I . I 215 I . I 134 I I QI I' 21118126 �b� I 1 17 I c II J II I I I I ao I I � 18 I II � I r 5 � I I .II Enter /Exit II / WELL PRODUCER ■ or i_=i WELL INJECTOR A DATE : 3/4/2010 SCALE: 1" = 300' MAP DATE: 2009 PBU - S PAD WELL SLOT W /CONDUCTOR 6, bs14495.dgn s � ]t Pad July 25, 2010 Approximate Scale: 1' =300' 2010- 19c -6 -35 RO E i 40 , r .4 0 AV Af qAv AF a � t r !f f • J 4 x 1 j 4 - t A t w n • • _______� - ��!' _ __..�__..._____. .__.�.�- -- -f��w� � { I # I � . f ": �, �� I i � ^.j— r'r �`- �� '^�-'- — � -e.. -- � �. � � I - ° -nS ^� � ! -� _. i - ;. .1. .ti- s �a� „. f +k � i � � S ^�.5,. 4., a � � k, . � a �� I� j `�;a` K "� h 4 vn r 'f �4 � �Y y t �.� Y � �S y �Y&� :9 3.�y� 7 a_� t � ,LflC � y `Ry ^t :t �� _. v,_ M".;iR .., r ,r tN', "Y. Srr 6��u: �r �a'ir:.aaaY:'.�:.tt�fs`6�y".T � a WELL NAME S m 10A OWNER Prudhoe Bay Unit OPERATOR BP Exploration (Alaska) Inc. API NUMBER 50- 029- 20765 -01 -00 SUR. LOCATION NW 1/4, Sec. 35, T1 2N, R12 DRILLING PERMIT 191 -123 r ».. , .. � � .�..._...._ _..�....w,...,..._�____. �.._ a ...�. 1 S- F�pW�IC1S�Plt S-1 OA (PTD # 1911230) TIO Plot W.# s -10 Tbg a w ° Q° . I ooa JA OOOA ,onrj � � /o•L7 is I 07!07/10 17n0n0 amino 07/24/10 07131/10 081W40 0.°!4 %1U] nuei;1n 09/29/10 09104/10 09111!10 09/18/10 09/25/10 10102110 ... .........._._.._........ BP EXPLORATION ARCO Alaska, Inc. To: From: David W. Johnston Chairman Alaska Oil & Gas Commission Steve Herren, Drlg Mgr Shared Services Drilling Date: 09~3 'ST^' ST,~ -'tLE Subject: Suspended wells Compliance with regulations In response to your letter dated August 15, 1994 regarding suspended wells attached are lists detailing well status and criteria for maintaining these wells in a suspended status. Plans for well inspections are in place for October 1 through October 3, 1994 as discussed with Blair Wondzell and John Spaulding. Updated reporting has been filed with the commission as listed. Yours Sincerely, Steve Horton Drilling Manager CCi Bill Bredar Patrick Collins Jim Farnsworth Mike Miller Bruce Policky Scott Sigurdson Marian Sloan RECEIVED ' 0CT 1 4 1994 Alaska 0ii & Gas Cons, Commission Anchor~a Suspended Wells, Request to retain suspension status The following wells are listed as suspended by the AOGCC under 20 AAC 25.110. These wells are requested to remain suspended for the reason(s) as indicated. Site inspections should be conducted as soon as possible. MPA-01; 029-20376-00 79-¢04 Potential recompletion in the Kuparuk C and/or B sand as a water injector. Decision hinges on 1994/95 development drilling results (E-13)in this area. MPB-02; 029-20662-00 81-/¢/142 This well is scheduled for initial completion in the Schrader Bluff late this year or early next year. MPA-03; 029-20891-00 83-~¢001 Future utility as a Schrader Bluff producer with producing utility when surface infrastructure is installed on A pad. MPN-01 B; 029-21053-02 84-OO 13 N-01B is a usable well in the Schrader Bluff, with producing utility when surface infrastructure is installed on N pad. The well should be retained in a suspended status until that time. MPC-16; 029-21364-00 85-011 0 C-16 has recompletion potential in the Kuparuk "C" sand and/or the Schrader Bluff horizons. Although additional evaluation must be performed to quantify reserves and production potential, C-16 is believed to be a viable workover and/or sidetrack candidate. NWM#1; 029-22231-00 91-0145 Northwest Milne #1 should remain suspended until the Northwest Milne Point development is better defined. The wellbore is strategically located on a gravel island and may. possess utility in either production or injection operations. DNR recently certified this well as capable of production. No Point #1; 029-22450-00 94-0027 No Point #1 will be utilized in the upcoming F- Pad development. Expectations are to complete the Kuparuk "A" zone and commence production 4Q95. Niakuk #4, 029-21217-00 84-0200 Niakuk #4 is requested to remain suspended until the viability of the well for monitoring is defined. Niakuk #5, 029-21290-00 85-0027 Niakuk #5 should remain suspended for observation purposes at this time. Sag Delta #33-12-16, 029-20176-00 75-0058 Area being drained by 1994 Alapah well NK-26 (HAW). Potential use as a monitor well for this new reservoir Would have to truck oil across winter ice road if resume production Produced 186 MBO in 1985 2 month production test. Sag Delta #5, 029-20527-00 80-0129 Area being drained by L5-26 (high gas well), L5-28, and L5-36 from south to west. Well tests indicated fairly tight, but productive rock; perhaps inadequate stimulation? Costs prohibitive for eventual tie-in to L5 (? via Heald Point). Potential for gas cap monitor well Sag Delta 31-11-16, 029-20011-00 69-0014 Area being drained by L4-36, 80 Acre offset to NW. Potential for service well (water injection?) Well is capable of production, but most Lisburne in water leg and costs likely prohibitive for tie-in to L4. Sag Delta #2A, 029-20234-01 77-0069 South of Sag Delta #1, in water leg of Alapah oil accumulation in NK-26 well~ Remote potential for pressure monitoring of Alapah offtake and the effect on the Alapah aquifer; though, costs would likely be prohibitive. Sag Delta #8, 029-20519-00 80-0121 Z-32A, 029-21924-01 93-0113 S-10A, 029-20765-01 91-0123 Sag Delta #8 should remain suspended until the development plan for the area is better defined. This well may possess utility for production or as an observation well. Z-32 was shut in due to high water production in 1992. In 1993 it was sidetracked to a new location. The oil column at the new location was less than prognosed and was not considered economic and the well was suspended. There is oil in the area that can be reached as a new sidetrack from this well. A specific location has not yet been identified, but we wish to retain this wellbore for a future sidetrack. S-10 was sidetracked in 1992. Drilling difficulties were encountered while drilling through a fault in the Kingiak and the well was suspended. There is oil in the area that can be reached as a new sidetrack from this well. A specific location has not yet been identified, but we wish to retain this wellbore for a future sidetrack. The West Sak formation, a non unitized formation in the PBU license area, is reachable from this wellbore. Work in ongoing on a facility sharing agreement. In the case that a satisfactory agreement is reached, this wellbore could be used to access oil in this formation. Y-22A, 029-21558-01 88-0115 Y-22 was sidetracked in 1988. The sidetrack was suspended due to drilling difficulties. There is oil in the region that can be reached as a new sidetrack from this well. A location has not been worked on but we wish to retain this wellbore for a future sidetrack. U-01, 029-22244-00 92-0011 There is oil in the area that can be reached as a new sidetrack from this well. A specific location has not yet been identified, but we wish to retain this wellbore for a future sidetrack. PR 33-12-13, 029-20047-00 69-0104 The well penetrates The West Sak and Ugnu formations in the aquifer. Work in ongoing on a facility sharing agreement with subsequent appraisal of the formations. This well could be used to test the aquifer properties. These wells are listed as suspended, action items are detailed. Ak Island #1,289°20018-00 81-0119 Alaska Island #1 was abandoned in 1988. The completion notice has been refiled with AOGCC on 9/15/94. The site is ready for inspection (priority 1 ). Niakuk #lA, 029-20156-01 76-OO28 Niakuk #lA was abandoned in 1991. A sundry application requesting status change was filed with AOGCC 9/20/94. A completion notice will follow when the sundry application is approved. The site is ready for inspection (priority 1 ). Niakuk #2A, 029-20180-01 76-0079 Niakuk #2A was abandoned in 1991. A sundry application requesting status change was filed with AOGCC 9/20/94. A completion notice will follow when the sundry application is approved. The site is ready for inspection (priority 1). PBU H-01, 029-20099-00 71-0015 The well was drilled in 1971 and hit a down thrown fault block with only 20ft of oil bearing Ivishak. This was not economic at the time. It was left suspended without tubing. Recent success in fraccing the Sag formation indicated that it might be an economic well. A rig workover was completed in April 1994 and the well was put on production 9/94. It is not necessary to inspect this site. Kemik Unit #1,223-20006-00 70-0060 Kemik Unit #1 is scheduled to be abandoned in the near future. Abandonment planning is now in progress. Site inspection will not be necessary at this time most likely should be scheduled for Spring of 1995. P2-59, 029-22096-00 90-0140 Arco Alaska Inc. is the operator of this well, they will be addressing the question of suspension. Sag Delta #3, 029-20233-00 79-0080 Well plugged and abandoned March, 1991. Well completion notice will be refiled with the Commission. Sag Delta #4, 029-20245-00 77-0015 Well plugged and abandoned March, 1991. Well completion notice will be refiled with the Commission. The following wells are not under BP Exploration ownership. A letter requesting the owners to respond regarding their wishes for these wells was sent on 9/30/94. MP 03-10-12, 029-20483-00 80-0066 MP 33-11-12, 029-20504-00 80-OO92 CHEV 18-11-12, 029-20511-00 80-0108 Term C 03-11-12, 029-20356-00 78-0102 MP 22-31-11-13, 029-20545-00 81-0010 MP 43-31-11-13, 029-20536-00 80-0139 MP 30-11-13, 029-20546-00 80-0152 MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: David~ DATE: October 2, 1994 Chairman THRU: Blair Wondzell, -~~ FILE NO: 2991jbbd.doc P. I. Supervisor FROM: John Spaulding,Q~. SUBJECT: Petroleum Insp. ])~;,l~ 3~, Suspended Wells Inspection North Slope, Alaska October 1,2&3, 1994: I accompanied Marian Sloan BPX representative on an inspection tour of BPX suspended wells at various North Slope locations. Travel was by pickup and helicopter. Marian Sloan Informed me that BPX is drafting a program with reasons for leaving wells listed below as suspended, this program will be available to the AOGCC in the very near future Oct. 1,1994 Y-22A ./... PBU..! pTD 88-115; well head on configuration, no pressure on tubing or annulus, area very clean, well is located on a producing drillsite. S-10A / PBU / PTD 91-123; wellhead on configuration, no pressure on tubing or annulus, area clean, well is located on a producing drillsite. U-01 / PBU / PTD92-11; wellhead on configuration, no pressure on tubing or annulus, area clean, well is located on a producing drillsite. Z-32A / PBU / PTD 93-11..3; wellhead on configuration, no pressure on tubing, 750 psi on inner annulus, 0 pressure on outer annulus, area clean, well is located on producing drillsite. Chevron 18-11-12 / PTD 80-108; wellhead on configuration, no pressure on tubing or annulus, area clean. MP 22-31-11-13 / PTD 81-10; wellhead on configuration, no pressure on tubing or annulus, area clean, reserve pit is still open. MP 32-30-11-13 / PTD 80-152; wellhead on configuration, nO pressure on tubing or annulus, area clean, reserve pit is still open. Oct. 2, 1994: A-01 / MPU / PTD 79-40; wellhead is removed with casing hanger still on, area clean, well is located on a active drillsite. A-03 / MPU / PTD 83-01; wellhead on configuration, no pressure on tubing or annulus, area clean, well is located on a active drillsite. B-02 /..MPU /..PTD ..8.1-142; wellhead on configuration, no pressure on tubing or annulus, area clean, well is located on a producing drillsite, C-16 / MPU / PTD 85-116; wellhead on configuration, no pressure on tubing or annulus, area clean, well is located on a producing drillsite. N-01B / MPU / PTD 84-13; wellhead on configuration, no pressure on tubing or annulus, area clean with timbers covering the cellar area and well guard around the wellhead. No Point #1 / MPU / PTD 94-27; wellhead on configuration, area clean, unable to land helicopter to check wellhead for pressures, No Point #1 is scheduled to become part of the F- pad construction at MPU. NW Milne #1 / MPU / PTD 91-145; wellhead on configuration, area clean, island is suffering from severe erosion on the North side. Oct. 3, 1994: Sa,q Delta 31-11-16 / PTD 69-14; wellhead on configuration, area clean, has wooden location marker, no pressure on tubing or annulus. Sa,q Delta #3 / PTD 76-80; wellhead on configuration, area clean no pressure on tubing or annulus. Sa.a Delta ~4 / PTD 77-15; wellhead on configuration, area clean, no pressures on tubing or annulus. Sa,q Delta #2A / PTD 77-69; wellhead on configuration, no pressures on tubing or annulus, timbers and cellar box material, reserve pit open. .Sa.q Delta #5 / PTD 80-129;. no wellhead; bell shaped affair was covering the supposed well surface location, area clean. Sag Delta #8 / PTD 80-121; wellhead on configuration, timbers and well guard, island is eroding. · Alaska Island #1 / PTD 81-119;. unable to land, area appeared clean from the air, marker post visible on South side of island. · Niakuk Cfa, / PTD 84-200; wellhead on configuration, concrete river weights, cellars open, island eroding. · Niakuk #5 / PTD 85-27; wellhead on configuration, concrete river weights, cellars open, island eroding. Location Clearances; Niakuk #lA / PTD 76-28; area is clean, no visible marker post, island is eroding as planned. ~l..iakuk #2A / PTD 76,~79;....area -is-clean;-.no-visible-marker-post; ..island-. is-eroding as planned. I recommend that the AOGCC consider Niakuk lA & 2A for final abandonment and location clearance. · Summary: I inspected locations of 28 BPX suspended wells. I also inspected 2 wells for final abandonment and location clearances. ALASKA OIL AND GAS CONSERVATION COMMISSION WALTER J. HICKEL, GOVERNOR 3001 PORCUPINE DRIVE ANCHORAGE, ALASKA 99501-3192 PHONE: (907) 279-1433 TELECOPY: (907) 276-7542 August 15, 1994 Steve Horton, Drlg Mgr BP Exploration (Alaska) Inc P O Box 196612 (MB12-1) Anchorage, AK 99519-6612 Re: Suspended Wells Compliance with regulations Dear Mr. Horton: BP Exploration and the predecessor Sohio companies have several suspended wells as shown on the attached lists: BP SUSPENDED WELLS PRIOR TO 1980 and BP SUSPENDED WELLS SINCE 1980. The applicable regulation is as follows: 20 7lAC 25.110 SUSPENDED WELLS (a) Upon application by the operator under 20 AAC 25.105(e), the commission will, in its discretion, approve the suspension of a well if the well (1) encounters hydrocarbons of sufficient quality and quantity to indicate the well is capable of producing in paying quantities as reasonably demonstrated by well tests or interpretive formation evaluation data; or (2) is reasonably demonstrated to have future value as a service well. For each well on the attached lists of suspended wells, please provide data showing that the well meets the criteria of (1) or (2) above, or advise as to your plans to abandon the well. Wells that meet the criteria of (a) above that you wish to maintain as suspended, as r~ui-re~by 20 AAC 25.110(e), must have well site inspections ~his~--~~ye~'r~Qr t~ snow covering the locations. David W.(Johnston / - - ..... Attachments c: Blair Wondzell bew/llbpsusp 3/15/94 BP SUSPENDED WELLS SINCE 1980 PAGE 1 AUGUST 1994 PERMIT 79-0040-0 80-0066-0 80-0092-0 80-0108-0 80-0121-0 80~0129-0 80-0139-0 80-0152-0 81-0010-0 81-0119-0 81-0142-0 83-0001-0 84-0013-0 84-0200-0 85-0027-0 85-0110-0 88-0115-0 90-0140-0 91-0123-0 91-0145-0 92-0011-0 93-0113-0 94-0027-0 API NUMBER 029-20376-00 029-20483-00 029-20504-00 029-20511-00 029-20519-00 029-20527-00 029-20536-00 029-20546-00 029-20545-00 089-20018-00 029-20662-00 029-20891-00 029-21053-02 029-21217-00 029-21290-00 029-21364-00 029-21558-01 029-22096-00 029-20765-01 029-22231-00 029-22244-00 029-21924-01 029-22450-00 WELL WELL WELL NAME CLASS STATUS MILNE POINT UNIT A-01 EXP SUSP PRUDHOE BaY UNIT 3-10-12 DEV SUSP PBU MP 11-33-11-12 I DEV SUSP PRUDHOE BaY UNIT TR 18-11-12 DEV SUSP SAG DELTA 8 EXP SUSP SAG DELTA 5 EXP SUSP PRUDHOE BaY UNIT 31-11-13 DEV SUSP PBS MP 32-30-11-13 1 DEV SUSP PBU MP 22-31-11-13 2 DEV SUSP ALASKA ISLAND 1 EXP SUSP MILNE POINT UNIT B-02 DEV SUSP MILNE POINT UNIT a-03 DEV SUSP MILNE POINT UNIT N-01B DEV SUSP NIAKUK 4 EXP SUSP NIAKUK 5 EXP SUSP MILNE POINT UNIT C-16 DEV SUSP PRUDHOE BaY UNIT Y-22A DEY SUSP PT MCINTYRE P2-59 EXP SUSP PRUDHOE BaY UNIT S-10A DEV SUSP NORTHWEST MILNE i EXP SUSP PRUDHOE BAY UNIT U-01 DEV SUSP PRUDHOE BaY UNIT Z-32A DEV SUSP NO POINT 1 DEV SUSP STATUS DATE 4/15/8o lo/11/8o 4/29/81 12/24/80 4115181 4/13/81 2/20/81 1/18/81 2/14/81 6/08/82 5/27/82 12/10/83 4/27/84 2/17/85 4/18/85 10/27/93 10/29/88 12/22/90 11/06/91 3/30/92 3/16/92 8/31/93 4/08/94 SECT 23 33 33 O7 27 36 O5 3O 3O 11 19 23 3O 25 25 10 33 14 35 25 18 19 O6 TWP 13N 11N 11N liN 12N 12N llN liN I0N 13N 13N 13N 12N 12N 13N 11N 12N 12N 14N liN llN 13N RNG 010E 012E 012E 012E 016E 01SE 013E 013E 013E 022E 011E 010E 010E 015E 015E 010E 013E 014E 012E 009E 013E 012E 010E MER U U U U U U U U U U U U U U U U U U U U U U U :/15/94 BP SUSPENDED WELLS PRIOR TO 1980 PAGE 1 AUGUST 1994 PERMIT 69-0014-0 69-0104-0 70-0060-0 71-0015-0 75-0058-0 76-0028-0 76-0079-0 76-0080-0 77-0015-0 77-0069-0 78-0102-0 API NU1ZBER 029-20011-00 029-20047-00 223-20006-00 029-20099-00 029-20176-00 029-20156-01 029-20180-01 029-20233-00 029-20245-00 029-20234-01 029-20356-00 WELL WELL WELL NAME CLASS STATUS SAG DELTA 31-11-16 EXP SUSP PRUDHOE BAY I//qIT 33-12-13 DEV SUSP KEMIK UNIT 1 DEV SUSP PRUDHOE BaY UNIT H-01 DEV SUSP SAG DELTA 33-12-16 EXP SUSP NIAKUK 1-A EXP SUSP NIAKUK 2-a EXP SUSP SAG DELTA 3 EXP SUSP SAG DELTA 34633 4 EXP SUSP SAG DELTA 28337 2-A EXP SUSP PRUDHOE BaY UI~IT TERM C DEV SUSP STATUS DATE 4/28/69 12/20/69 6/17/72 6/22/71 4/28/76 4/30/76 3/30/77 3/23/77 3/22/78 12/27/77 4/25/79 SECT 31 33 17 21 O4 26 26 35 35 10 O3 TWP llN 12N 01N llN llN 12N 12N 12N llN lin RNG 016E 013E 020E 013E 016E 015E 015E 016E 016E 016E 012E IV~ER U U U U U U U U U U U INDIVIDUAL WELL GEOLOGICAL INVENTORY REPORT PERMIT DATA DETAIL 09/14/1993 PAGE: 1 91-123 CL 91-123 407 91-123 91-123 Are well tests required? Was well cored? Yes No... DAILY WELL OP SURVEY Yes No RI , 5" , 7714-7978 COMP DATE:Il/06/91 10/16/91-11/06/91 SS DIRECTIONAL If yes, was the core analysis & description received? Yes No Are dry ditch samples required? Yes No WELL IS ON COMPLIANCE. INITIAL COMMENTS: BP EXPLORATION ARCO Alaska, Inc. To: Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Date' May 15, 1992 Attention' Steve McMahans Subject' S-10A Revised Completion Notice (10-407) Enclosed, in triplicate, is a revised copy of Form 10-407, Completion Notice for well S-10A correcting the Bottom Hole Location. Yours Sincerely, G. W. Kirton GWK/MS Enclosures (6) cc. Well file RECEIVED MAY 1 8 1992 Alaska 0il & (~as Cons. Commissio~ Anchorage · STATE OF ALASKA ' 0 I11G I ALASKA ,,.)IL AND GAS CONSERVATION CL,,,'IMISSION WELl COMPLETION OR RECOMP LETION REPORT AND LOG 1. Statds of Well Classilicalion of Service Well OIL [] GAS !-1 SUSPENDED I~ ABANDONED [] SERVICE I-] 2. Name of Operator 7. Permit Number BP Exploration 91-123 3. Address 8. APl Number P. O. Box 196612, Anchorage, Alaska 99519-6612 5o- 029-20765-01 4. Location of well at surface 1644'SNL, 1745'EWL, SEC. 35, T12N, R12E ! i'i':i:' i: "' :'? 9.PrudhoeUnit or LeaSeBayNameunit 10. Well Number At Top Producing Interval S- 10A N/A ~-.~.~ 11. Field and Pool At Total Depth Prudhoe Bay Field/Prudhoe Bay Pool 654' SNL, 2528' EWL, SEC. 35, T12N, R12E 5. Elevation in feet (indicate KB, DF, etc.) 16. Lease Designation and Serial No. KBE= 67.56 I ADL 28257 12. Date Spudded 13. Date T.D. Reached 14. Date Comp., Susp. or Aband. 115. Water Depth, il offshore 116. No. el Completions ~ox2~x.~ ~x3/~ ~.~ Il' G- ~ I ~ .~I N/Aeet MSL I NONE 22. Type Electric or Other Logs Run None 23. CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD CASING SIZE WT. PER FT. GRADE TOP BOTTOM HOLE SIZE CEMENTING RECORD AMOUNT PULLED 20' 94.5# Cond. Surface 139' 30" 8 cu yds concrete 13-3/8' 72# L-80 Surface 2679' 17-1/2" 3787 cufl Arcticset II 9-5/8' 47# L-80 Surface 7900' 12-1/4" 1199 cuft Class "G"/130 cu 1 Arcticset I 24. PeHoradons open to Production. (MD+TVD of Top and Bottom and 25. TUBING RECORD interval, size and number) SIZE DEPTH SET (MD/ PACKER SET (MDI None None 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED 8720'-7320' 635 CUft Class "G" 7900' Whipstock Packer 27. PRODUCTION TEST Date First Production Method of Operation (Flowing, gas lilt, etc.) None N/A Date of Test Hours Tested PRODUCTION FOR OIL-BBL ,.GAS-MCF . WATER-BBL CHOKE S[ZE IGAS-OIL RATIO TEST PERIOD I~ I Flow Tubing Casing Pressure CALCULATED OIL-BBL GAS-MCF WATER-BBL OIL GRAVITY-APl (corr) Press. 24-HOUR RATE [28. CORE DATA Brief description el lithology, porosity, lractures, apparent dips, and presence el oil, gas or water. Submit core chips. RECEIVED MAY 1 B 1992 ' Alaska 0ii & Gas Cons. CommissiOr~ Anchorage Form 10-407 Submit in duplicate Rev. 7-1-80 CONTINUED ON REVERSE SIDE z9. 30. GEOLOGIC MARKERS h.,RMATION TESTS NAME Include interval tested, pressure data, all fluids recovered and gravity, MEAS. DEPTH TRUE VERT. DEPTH GOR, and time of each phase. NONE 31. LIST OF ATTACHMENTS 32. I hereby certify that the foregoing is true and correct to the best of my knowledge Signed /'/~.~'~ ?~-'~ Tit lo Workover Engineer Suoervisor Date :~"JJ (¢/,~ ~ INSTRUCTIONS General: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. Item 1' Classification of Service Wells: Gas injection, water injection, steam injection, air injection, salt water disposal, water supply for injection, observation, injection for in-situ combustion. Item 5: Indicate which elevation is used as reference (where not otherwise shown) for depth measurements given in other spaces on this form and in any attachments. Item 16 and 24 · If this well is completed for separate production from more than one interval (multiple completion), so state in item 16, and in item 24 show the producing intervals for only the interval reported in item 27. Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval. Item 21' Indicate whether from ground level (GL) or other elevation (DF, KB, etc.). Item 23: Attached supplemental records for this well should show the details of any multiple stage cement- ing and the location of the cementing tool. Item 27: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water In- jection, Gas Injection, Shut-in, Other-explain. Item 28: If no cores taken, indicate "none". Form 10-407 ACTIVITY SUMMARY for WELL .{OJECT 4P0044 COMPANY: BP/AAI SHARED SERVICE, NORTH SLOPE, AK FIELD : PRUDHOE BAY WELL : S-10A U 1~ I 13 i ili /% L Page: 1 DRLG RIG : NABORS 2ES WO/COMP RIG: NABORS 2ES 10/16/91 (1) TD: 8020 PB: 8020 SUPV:LAP POOH W/ TBG. MW: 0.0 MOVE RIG TO S-10A. RIG ACCEPTED @ 08:00 HRS, 10/15/91. PULL BPV. DISP DIESEL W/ SEAWATER. N/D TREE. TEST PACKOFF. N/U BOPE. ATTEMPT TO TEST BOPE TEST FAILED. PULL TBG FREE. L/D HGR, 1 JT TBG. TEST BOPE. POOH W/ 4-1/2" X 3-1/2" TBG. (4P0044) DAILY: $ 22,584 CUM: $ 22,584 EFC: $ 1,292,000 10/17/91 ( 2) TD: 8020 PB: 8020 SUPV:LAP PREP TO RIH W/ PKR. MW: 8.9 OBM L/D TBG. RIH W/ BHA #1 TO 7825' REV CIRC. TEST CSG. DISP SEAWATER W/ 8.9 PPG OBM. P~OH. R/U ATLAS. RUN GR/JB. PREP TO RUN TIW 'SS' WHIPSTOCK PKR. (4P0044) DAILY: $ 40,957 CUM: $ 63,541 EFC: $ 1,292,000 10/18/91 ( 3) TD: 7900 ~' PB: 7900 SUPV:LAP 10/19/91 (4) TD: 7900 PB:'7900 SUPV:LAP RIH W/ WINDOW MILL. MW: 8.9 OBM RUN GR/JB. RIH W/ TIW SS'WS PKR. SET @ 7900' RIH W/ ORIENTING STINGER & GYRO. INSERT INTO PKR. ORIENT WHIPSTOCK. RIH W/ WHIPSTOCK. LATCH INTO PKR @ 7900' SHEAR OFF RET BOLT. START CUT WINDOW @ 7885' CIRC. POOH. RIH W/ WINDOW MILL. (4P0044)~ DAILY: $ 58,962 CUM: $ 122,503 EFC: $ 1,292,000 POH TO CHANGE MILL RIH. MILLED TO 7893' MILLED FROM 7893'-789~' MW: 8.9 OBM CBU, PUMPED DRY JOB. POH. RIH, (4P0044) DAILY: $ 29,912 CUM: $ 152,415 EFC: $ 1,292,000 10/20/91 (5) TD: 7900 PB: 7900 SUPV:LAP REAMING WINDOW IN 9-5/8" CSG MW: 9.0 OBM CIRCULATE, PUMP DRY JOB. POOH. MILLED AND REAMED WINDOW IN 9-5/8" CASING. CBU. POOH. RIH P/U KELLY. REAM TO EXTEND WINDOW ANOTHER 2' ABOVE TOP OF WHIPSTOCK. WINDOW LENGTH 7883'-7899'. (4P0044) DAILY: $ 167,034 CUM: $ 319,449 EFC: $ 1,292,000 (S1P1) CIRC: 2.0 DRIL: 7.0 OLD PROB: 0.5 SURV: 5.0 TRIP: 9.5 10/21/91 ( 6) RUNNING GYRO S~RVEY TO ORIENT MW: 9.0 VIS: 45 TD: 7970' (7970) FINISHED REAMING (7883'-7899'. CBU. POOH. RIH. RU SUPV:LAP E-LINE UNIT. ORIENT BHA. POOH W/GYRO. SPUD WELL @ 2300 HOLE ANGLE:52 12 HRS 10-20-91. DRILLED TO 7970' CBU. RIH W/GYRO SURVEY & ORIENT. (4P0044) DAILY: $ 31,031 CUM: $ 350,480 EFC- $ 1,292,000 (S1P1) DRIL: 14.5 OLD PROB: 6.0 10/22/91 ( 7) TD: 8380' ( 410) SUPV:LAP HOLE ANGLE:52 12 SURV: 3.5 DRILLING 8-1/2 HOLE MW: 9.0 VIS: 42 CONTINUED RIH WITH RATE-SEEKING SURFACE READ-OUT GYRO ON CAMCO E-LINE. ATTEMPTED TO SURVEY. DATA TRANSMISSION CEASED. POOH & FOUND SHORT CIRCUIT IN E-LINE CONDUCTOR. ROTATE FROM 7970 - 8000. RIH WITH SINGLE SHOT GYRO ON SLICKLINE. SURVEYED. POOH. BAD DAT~. RIH WITH SURFACE READ-OUT GYRO.POOH. SURVEYS INVALID. RIH WITH SINGLE SHOT GYRO. SURVEYED AND POOH. (4P0044) DAILY: $ 48,598 CUM: $ 399,078 EFC: $ 1,292,000 (S1P1) CIRC: 1.0 DRIL: 13.0 SURV: 3.5 TRIP: 6.5 10/23/91 ( 8) MW: 9.0 VIS: 42 TD: 8865' ( 485) SUPV: DLW HOLE ANGLE:52 12 CONT E SLIDE DRLG W/BIT #1 ON DYNA- ~LL F/8380-8770 AND M~4D SURVEY. CBU @120 SPM 2000 PSI, PUMP PILL, BLOW DN KELLY. POOH TO CHANGE BHA. DN LOAD MWD & L/D MUD MOTOR #1. P/U MUD MOTOR #2 W/ 1-3/4 BENT SUB, MWD W/BARIOD RLL TOOL. RIH W/BIT #2. PAUSE TO TEST MWD @ WINDOW. RIH TO 8770 NO FILL HOLE IN GOOD CONDITION. CONTINUE SLIDE DRLG ,-TO BUILD ANGLE F/8770-8865' -- · - (4P0044) DAILY: $ 35,784 CUM: $ 434,862 EFC: $ 1,292,000 RE£EIVED MAY 1 2 1992 Alasl~a 011 & Gas Cons. ~omm~ss~on Anchorage ACTIVITY SUMMARY for WEL' ROJECT 4P0044 COMPANY: BP/AAI SHARED SERVICE, NORTH SLOPE, AK FIELD : PRUDHOE BAY WELL : S-10A Page: 2 DRLG RIG : NABORS 2ES WO/COMP RIG: NABORS 2ES (S1P1) DRIL: 2.5 10/24/91 ( 9) TD: 8965' ( 100) SUPV:DLW HOLE ANGLE:52 12 OLD PROB: 21.5 WORKING STUCK PIPE MW: 9.2 VIS: 42 DRILLED 8-1/2 HOLE TO 8939'. WORKED THROUGH TIGHT HOLE. HOLE PACKING OFF AT 8950'. STUCK PIPE AT 8939' (4P0044) DAILY: $ 36,019 CUM: $ 470,881 EFC: $ 1,292,000 (SlP1) OLD PROB: 24.0 10/25/91 (--10) RIH WITH FISHING STRING MW: 9.3 VIS: 46 TD: 8965' ( 0) CONTINUED TO JAR ON STUCK PIPE. RECOVERED XO, RIH WTIH SUPV:DLW FISHING STRING HOLE ANGLE:52 12 (4P0044) DAILY: $ 39,137 CUM: $ 510,018 EEC: $ 1,292,000 (S1P1) OLD PROB: 24.0 10/26/91 (--11) RUNNING FREE POINT AT 8720 MW: 9.3 VIS: 42 TD: 8965' ( 0) ATTEMPTED TO'JAR BHA FREE. PERFORATED DP TO ALLOW SUPV:DLW CIRCULATION BELOW ESTIMATED STUCK POINT (8834'-8838' W/ 6 HOLE ANGLE:52 12 SPF) . LOST PERF GUNS INSIDE DP, TOP AT 8802'. FREE POINT AT TOP STAB 8720'. (4P0044) DAILY: $ 37,728 CUM: $ 547,746 EFC: $ 1,292,000 (S1P1) OLD PROB: 24'.0 -- 10/27/91 ( 12) TD: 8965' ( 0) WORKING"STUCK PIPE SUPV:DLW HOLE ANGLE:52 12 (4P0044) DAILY: $ 60~541 CUM: $ MW: 9'~3 VIS': 44 608,287 EFC: $ 1,292, 000 (S1P1) OLD PROB: 24.0 ' 10/28/91 (--13) RIH WITH BHA %3 MW: 9.4 VIS: 45 TD: 7902' ( 0) PU 3-1/2 TUBING. RIH WITH 3-1/2 TUBING AND 4-1/2 DP TO SUPV:DLW 8718' CIRCULATE AND RECIPRICATE. PUMPED CEMENT. REVERSE HOLE ANGLE:52 12 OUT CEMENT. LAY DOWN 4-1/2 DP. LAY DOWN 3-1/2 TUBING. PULL WEAR RING.TEST BOPS. RIH WITH BHA #3. (4P0044) DAILY: $ 99,338 CUM: $ 707,625 EFC: $ 1,292,000 10/30/91 (15) TD: 8833' ( 240) SUPV:GIG HOLE ANGLE:52 12 (S1P1) OLD PROB: 24.0 10/29/91 (--14) DRILLING AT 8593 MW: 9.4 VIS: 43 TD: 8593' ( 691) RIH WITH BHA %3. DRILL FIRM CEMENT TO 7907' GYRO. DRILL SUPV:DLW CEMENT TO 7912' CONTINUE DRILLING SLIDING FROM 7912 - HOLE ANGLE:52 12 8593' (4P00~4) DAILY: $ 520,864 CUM: $ 1,228,489 EFC: $ 1,292,000 .. (S1P1) OLD PROB: 24.0 REAMING MW: 9.7 VIS: 44 SURVEY & CIRCULATE LOW/HIGH VIS SWEEP AROUND BHA. DRILL TO 8817' ROATET TO 8910' DRILL INTO TIGHT SPOT. HOLE PACKED OFF. STUCK WITH PUMP ON. POOH TO 7734' PUMP SWEEP & DRY JOB. POOH. WASH & REAM TO 8833' . STARTED PACKING OFF AT 8833'. CONTINUE REAM & WASH. ., (4P0044) DAILY: $ 47,196 CUM: $ 1,275,685 EFC: $ 1,292,000 (S1P1) OLD'PROB: 24.0 10/31/91 (--16) CIRC TO INCR MUD WT MW:10.3 VIS: 45 TD: 8872' ( 39) CONTINUE TO PACKOFF AT~ 8844'. WASH &.REAM TO 8854' WASH SUPV:GTG & REAM TO 8872'. WASH & REAM TO 8865'. PUMP LOW/HIGH VIS HOLE ANGLE:52 12 SWEEP. SMALL CUTTINGS CONTINUE OVER SHAKER. (4P0044) DAILY: $ 40,468 CUM: $ 1,316,153 EFC: $ 1,292,000 ~CTIVI~Y SUMMARY for WEL'~ .... ROJECT 4P0044 COMPANY: BP/AAI SHARED SERVICE, NORTH SLOPE, AK FIELD : PRUDHOE BAY WELL : S-10A Page: 3 DRLG RIG : NABORS 2ES WO/COMP RIG: NABORS 2ES (SlP1) OLD PROB: 24.0 11/01/91 ( 17) WASH & REAM AT 8854 TD: 8916' ( 44) WASH & REAM TO 8854' SUPV:GTG HOLE ANGLE:52 12 (4P0044) DAILY: $ MW:10.9 ViS: 42 35,233 CUM: $ 1,351,386 EFC: $ 1,292,000 (S1P1) OLD PROB: 24.0 11/02/91 (--18) CIRC TO COND MUD TD: 8916' ( 0) WASH & REAM TO 8843' SUPV:GTG OFF & STUCK. CBU. HOLE ANGLE:52 12 (4P0044) DAILY: $ MW:10.9 VIS: 50 STUCK PIPE. REAM TO 8874' PACKED 44,760 CUM: $ 1,396,146 EFC: $ 1,292,000 (SlP1) OLD PROB: 24.0 11/03/91 (19) WORK STUCK PIPE MW:ll.0 VIS: 54 TD: 8868' ( 0) SIDETRACK AT 8700'. DRILL TO 8759'. WORK & REAM. DRILL SUPV:GTG TO 8790'. DRILL TO 8868'. HOLE PACKED OFF & PIPE STUCK AT HOLE ANGLE:52 12 8868'. (4P0044) DAILY: $ 46,483 CUM: $ 1,442,629 EFC: .$ 1,292,000 (SlP1) OLD PROB: 24.0 11/04/91 (20) LD BHA MW:ll.0 VIS: 56 TD: 8868' ~ 0) WORK STUCK PIPE AT 8869'. .. SUPV:GTG ......... · HOLE ANGLE:52 12 (4P0044) DAILY: $ 77;965 CUM: $ 1,520,594 EFC: $ 1,292,000 (SlP1) OLD PROB: 24.0 11/05/91 (21) TAG CMT. ' MW:ll.0 VIS: 54 TD: 8868' ( 0) L/D BHA. TEST BOPE. RIH W/ MULE SHOE. CIRC THRU WINDOW ~ SUPV:GTG 7900'. RIH TO 8800' PUMP 18 BBLS MUD, 113 BBLS 'G' CMT. HOLE ANGLE:52 12 DISP DN DP. POOH TO 6896'. CBU. POOH. TEST BOPE. RIH W/ CSG SCRAPERS. R/U TO TEST CSG. (4P0044) DAILY: $ i86,853 CUM: $ 1,707,447 EFC' $ 1,292,000 (S1P1) OLD PROB: 24.0 11/06/91 (--22) MW: 0.0 VIS: 0 TD: 7320' ( 0) CBU. TEST 9-5/8 CASING. POOH L/D 4-1/2 DP. PUMPED DIESEL SUPV:DLW TO FREEZE PROTECT. RELEASED 0600 HRS. 11/6/91. HOLE ANGLE:52 12 (4P0044) DAILY: $ 27,647 CUM: $ 1,735,094 EFC: $ 1,292,000 RE( EIVED MAY 1 2 1992 Alaska Oil & Gas Cons. Comm~SS'~on :Anchorage ORIGINAL BP EXPLORATION CTUWO OPERATIONAL SUMMARY REPORT TO: OLDENBURG FROM: MULLIN/CAMPBELL LOCATION: ANCHORAGE DATE: 1 0/4/9 1 OPERATION: S-10A PRE-RWO CMT PLUG SUMMARY BULLHEADED DIESEL DOWN BS TO LIGHTEN OVERBALANCE. ATTEMPTED TO LAY IN 12 BBLS OF CLASS G CMT (UN-RETARDED) ACROSS PERFS. HESITATE UNTIL HEATED SURFACE SAMPLE HARD. RIH THROUGH PERFS WITHOUT TAG. MIXED UP SECOND BATCH (15 BBLS) OF UN-RETARDED CLASS G CMT AND LAY IN ACROSS PERFS, DISPLACE W/DIESEL POOH 1000' CT TO REDUCE HYDROSTATIC. WAIT UNTIL SRF SAMPLE HARD. TAG TOC AT 8780' CTD. STATE REPRESENTATIVE VISITED SITE AND GAVE PERMISSION FOR OPERATION TO PROCEED UN-WITNESSED. ATTEMPTED TO CUT TAIL.PIPE THREE TIMES WITHOUT SUCCESS. RECEIVED VERBAL FROM STATE TO CONTINUE P&A WITHOUT DROPPING TAILPIPE. PLACED 9.6 PPG BRINE FROM PERF PLUG AT 8780 TO 8500' AND LAYED PLUG FROM 8500' TO 8050' AND REVERSED OUT 1 BBL CMT. RELEASED FRACMASTER AND RU SCHL. TAGGED CMT AT 8044' EL.MD AND CUT TUBING AT 8025' ELMD( TIED IN TO GLM ,/Y2 ). CIRCULATED WELL TO SW AND FP TO 2000' WITH DSL. OCT 91 7'00 MI.RU. FM#6009. SIWHP= 0PSIG,. lAP= 1200PSIG, OAP= 0 PSIG, GLP= 2000PSIG, G/L OFF.... 7:35 P/T CT/BOPS TO 4000 PSIG 7:44 ClRC OUTAND RECOVER ME-OH 7:58 RIH W/CT/2.4" SWIRL NZL ,, w' 'l I' o.T'"j I' " .... J.DEPTHJ.(B,PM . PUMPED NOZZLE. RET.URN . 8: 40 2743 0 0 3 5 STOP CT TO SHOOT FL ,, , , ,, 8: 53 CONT RIH , , 9:24 61 60 5.2 0 0 35/0 SW TO DIESEL DOWN BS 9:32 6760 0 0 0 42 S/D , 9 '36 4.0 0 0 ST PUMP 9'37 6870 STTO GETWHP , , 9:40 7287 0 0 1000 56 S/D TO MONITOR 9:43 0 0 0 RIH , , 9:44 7429 1.0 STTO PUMP DIESEL DOWN BS ,, ,, RECEIVED MAY 1 8 1992 Alaska Oil & Gas Cons. Commissio~ Anchorage CTUWO OPERATIONAL SUMMARY REPORT BP EXPLORATION TO: FROM: OLDENBURG MR. MULLIN/CAMPBELL LOCATION: ANCHORAGE DATE: 2 OCTOBER 1991 OPERATION: S-10A RWO CMT PLUG SUMMARY ATTEMPTED TO LIQUID PACK WELL. LOST RTNS WHEN RATE REDUCED TO 1 BPM. DISPLACED 16 BBLS CLASS G CMT (NON RETARDED) TO PERFS WITH NO SQUEEZE PRESS AND NO RTNS. WAITED UNTIL HEATED SAMPLE HARDENED. PUMPED 40 BBLS WITHOUT FILLING WELL. RIH THROUGH PERFS WITHOUT TAG. NO EVIDENCE OF CEMENT PLUG. STATE INSPECTOR VISITED SITE AND GAVE PERMISSION FOR OPERATION TO PROCEED UN-WITNESSED. - . 12'00 MIRU FM#6009 ,, SIWHP=500 PSIG~ lAP--1160 PSIGT OAP=780 PSIG~, SIWHT=110 Fy GLp=2000 PSIGT G/L OFF · 3'40 P/T CT/BOPS TO 4000 PSIG 13:52 CIRC MEOH FROM CT , · 14:00 S/I WELL & G/L 14:20 RIH W/ CT/2.4" SWIRL NZL , !DEPTHI(BPM IP,UMPED NOZZLE. RETURN 14:25 1 3 0 ST MIX CMT .... ,, .!.,4:54 2.,0O0 4.6 300 30 0 ST PUMP PW(W/SURF') DOWN BS 15:20 5 4 8 0 6.1 4 0 0 1 2 4 INC RATE TO CLEAR LNR , ,, 15:27 6225 6.2 40 600 169 WHP INC ,, 15'35 7087 1.0 197/0 SW TO PUMP DOWN CT ,,. 16'03~ 9678 2.5 1150 0 27 TAGTD. POOH. INCRATE 1.6'06~ 9494 32 SWTO HOWCO ., 16 '08 0 START EW. 10 MIN FL=58 CC , 16'10 9320 2.3 1600 0 5/0 START CMT 16'13 9130 2500 5 16'18 3500 1 6/0 SW TO EW. , 16:23 1.0 400 10 RED RATE TO 1.0. 30 MIN FL= 60 ,, 1 6: 2 9 3 3 5 1 6 / 0 0 SW TO PW. CMT TO NZL , , ~16:30 - 1 1 16'31! " 2 2 ORIGINAL PRUDHOE BAY DRILLING S10-A GREAT LAND DIRECTIONAL DRILLING, INC. REPORT OF SUB-SURFACE DIRECTIONAL SURVEY PRUDHOE BAY DRILLING COMPANY S-10A WELL NAME PRUDHOE BAY LOCATION AL1091D39 MWD 11/19/91 JOB NUMBER LYNN HENSLEY TYPE SURVEY DIRECTIONAL SUPERVISOR TITLE NAME DATE SIGNATURE 7860 FT. 8852 FT. DEPTH INTERVAL FROM TO 10/26/91 11/03/91 DATE SURVEY TAKEN FROM TO THIS IS A RECORD OF A SUB-SURFACE SURVEY OF YOUR WELL WE HAVE RETAINED A COPY OF YOUR SURVEY REPORT IN OUR FILES FOR YOUR CONVENIENCE; HOWEVER, SHOULD YOU SO DESIRE, ALL COPIES OF THE SURVEY REPORT WILL BE FORWARDED TO YOU ON WRITTEN REQUEST. ALL SURVEYS ARE KEPT IN A LOCKED FILE AND ARE HELD IN STRICTEST CONFIDENCE. ] ] I ] ] I ] ! I I I I I ! I I '1 I ] GREAT LAND DIRECTIONAL DRILLING, Client .... : Field ..... : Well ...... : Section at: Engineer...' PRUDHOE BAY DRILLING PRUDHOE BAY S-10A N,10.44,E LYNN HENSLEY INC. Computation...: Survey Date...: RKB Elevation.: Reference ..... : Magnetic Dcln.: 11/19/91 MINIMUM CURVATURE 11/03/91 55.50 ft 30.00 E S MEAS INCLN C DEPTH ANGLE 8 7860 1.40 3 8069 9.50 3 8101 9.50 3 8131 9.80 3 8164 10.80 RECORD OF SURVEY (Calculated from a tie-in station at 7860 MD) VERTICAL-DEPTHS SECTION DIRECTION RELATIVE-COORDINATES BKB SUB-SEA DISTNCE BEARING FROM-WELL-HEAD CLOSURE DL DISTNCE BEARING /100 7734.0 7678.5 708.3 S 16.50 W 598.1 N 662.9 E 892.8 N 47.94 E <TIE 7942.1 7886.6 710.0 N 86.30 E 596.8 N 679.4 E 904.3 N 48.71 E 4.82 7973.6 7918.1 711.8 N 74.20 E 597.7 N 684.6 E 908.8 N 48.88 E 6.23 8003.2 7947.7 714.6 N 59.50 E 599.6 N 689.2 E 913.5 N 48.98 E 8.25 8035.7 7980.2 718.9 N 47.30 E 603.1 N 693.9 E 919.4 N 49.00 E 7.25 3 8194 12.10 8065.1 8009.6 724.0 N 35.30 E 607.6 N 697.8 E 925.2 N 48.95 E 9.02 3 8227 13.40 8097.3 8041.8 730.9 N 23.20 E 614.0 N 701.3 E 932.1 N 48.80 E 8.98 3 8258 14.80 8127.4 8071.9 738.3 N 13.90 E 621.1 N 703.6 E 938.5 N 48.57 E 8.58 3 8289 17.30 8157.1 8101.6 746.9 N 9.40 E 629.5 N 705.3 E 945.4 N 48.25 E 9.00 3 8318 19.50 8184.7 8129.2 756.0 N 8.50 E 638.5 N 706.8 E 952.5 N 47.90 E 7.65 3 8349 21.90 8213.7 8158.2 767.0 N 10.80 E 649.3 N 708.6 E 961.1 N 47.50 E 8.17 3 8381 24.50 8243.1 8187.6 779.6 N 11.80 E 661.7 N 711.1 E 971.3 N 47.06 E 8.22 3 8412 27.20 8271.0 8215.5 793.1 N 11.40 E 674.9 N 713.8 E 982.4 N 46.60 E 8.73 3 8445 30.10 8299.9 8244.4 808.9 N 12.70 E 690.4 N 717.1 E 995.4 N 46.09 E 8.99 3 8477 32.80 8327.2 8271.7 825.6 N 12.50 E 706.7 N 720.8 E 1009.4 N 45.56 E 8.44 3 8509 35.60 8353.7 8298.2 843.6 N 11.90 E 724.3 N 724.5 E 1024.5 N 45.01 E 8.81 3 8541 38.30 8379.3 8323.8 862.8 N 11.80 E 743.1 N 728.5 E 1040.6 N 44.43 E 8.44 3 8573 40.90 8403.9 8348.4 883.2 N 11.70 E 763.1 N 732.7 E 1057.9 N 43.84 E 8.13 3 8604 43.20 8426.9 8371.4 904.0 N 11.50 E 783.4 N 736.8 E 1075.5 N 43.24 E 7.43 3 8633 45.90 8447.6 8392.1 924.3 N 12.50 E 803.3 N 741.1 E 1092.9 N 42.69 E 9.62 3 8664 48.50 8468.6 8413.1 947.0 N 12.00 E 825.5 N 745.9 E 1112.6 N 42.10 E 8.47 ^Survey Codes: 3/MWD 8/TIE-IN (PS10AD B1.24) ! } ) ! } ! ! ! ! ! } ! I I ! I ! } ) S-10A S MEAS INCLN C DEPTH ANGLE 3 8694 50.90 3 8726 53.60 3 8757 56.10 3 8789 58.90 3 8822 60.50 RECORD OF SURVEY (Calculated from a tie-in station at 7860 MD) VERTICAL-DEPTHS SECTION DIRECTION RELATIVE-COORDINATES BKB SUB-SEA DISTNCE BEARING FROM-WELL-HEAD Page 2 CLOSURE DISTNCE BEARING 8488.1 8432.6 969.9 N 13.60 E 847.8 N 751.0 E 1132.6 N 41.53 E 8507.6 8452.1 995.2 N 12.00 E 872.5 N 756.6 E 1154.8 N 40.93 E 8525.5 8470.0 1020.5 N 11.10 E 897.3 N 761.6 E 1177.0 N 40.32 E 8542.7 8487.2 1047.5 N 12.40 E 923.8 N 767.1 E 1200.8 N 39.71 E 8559.3 8503.8 1075.9 N 13.00 E 951.6 N 773.4 E 1226.2 N 39.10 E 3 8852 60.10 8574.2 8518.7 1102.0 N 13.90 E 976.9 N 779.5 E 11/19/91 ^Survey Codes: 3/MWD 1249.7 N 38.59 E DL /lOO 8.97 9.32 8.41 9.40 5.10 2.93 I ] } ] ] I } I I I I } } i ] I I I ] S-10A Page 3 11/19/91 DATA INTERPOLATED FOR 100 FT SUBSEA INTERVAL (Calculated from a tie-in station at 7860 MD) SUBSEA MEAS INCLN TVD MD-TVD VERT DIRECTION RELATIVE COORDINATES DEPTH DEPTH ANGLE BKB DIFF CRRT BEARING FROM WELL HEAD 7900 8083 9.50 7956 127 127 N 81.15 E 597.01 N 681.66 E 8000 8184 11.68 8056 129 2 N 39.22 E 606.01 N 696.56 E 8100 8287 17.16 8156 132 3 N 9.65 E 628.99 N 705.26 E 8200 8395 25.70 8256 139 7 N 11.62 E 667.40 N 712.27 E 8300 8511 35.79 8356 156 17 N 11.89 E 725.55 N 724.82 E 8400 8644 46.86 8456 189 33 N 12.32 E 811.41 N 742.84 E 8500 8814 60.13 8556 259 70 N 12.86 E 945.00 N 771.89 E ! } ! ! ! ! ! ! ! ! ! } ! ! ! ! ! ! ) S-10A Page 4 11/19/91 DATA INTERPOLATED FOR 1000 FT MEASURED DEPTH INTERVAL MEAS INCLN VERT-DEPTHS SECT DIRECTION REL-COORDINATES CLOSURE DL/ DEPTH ANGLE BKB SUB-S DIST BEARING FROM-WELLHEAD DIST BEARING 100 8000 6.83 7874 7818 703 S 57.32 E 592 N 669 E 894 N 48.51 E 4.7 PRUDHOE BAY DRtLLIN6 ] ~1 TO ~D TVO 8ECTN INCLN 8852 8574 il02 60.i0 S-IOA VERTICAL SECTION VIEW Section at: N 10.44 E TVD Scale.: ! inch = 200 feet Oep Scale.: I inch = 200 feet Drawn ..... : ~1/22/§~ Great Land Dirgctional Dril]in9 7600- 7700- 7800- 7900- 8000- 8i00- 8800- 8300- 8400- 8500- 8600- 8700- KOP 7850 MO 7734 TVO \ %, S-lO ~S-IO 8800 800 700 800 900 iOOO i~O0 ~200 i300 i400 i500 i600 1700 i800 Section Departure Marker Identification MD N/S E/N A] KB 0 0 N 0 E B) ID 8852 977 N 778 E t300~ t800-I- S- OA PLAN VZEN CLOSURE ..... : t250 ft N 38.59 E DECLINATION.: 30.00 E SCALE ....... : I inch = 200 feet DRANN ....... : ~1/22/9~ tiO0- i000- 900- 800- 700- 600- 500- 400- 300- 200- t00- 0- /ORIGINAL S-lO ~00 0 100 200 300 400 500 600 700 800 900 t000 tt00 <- NEST: EAST -> I ....... AOGCC GEOLOGICAL MATERIALS iNVENTORY LIST [ check off or list,data as it is received ! cored intervals core anal~fsis I~ d~ ditch intervals digital data ~i~¢ ~~ ~i~ , ,. " LOG TYPE RUN iNTERVALS scALE NO. ii i ,, . , , , ,,. , 8! 9! .~'o) 11) i, 1,11) -~) 17'] i i 1 §) i i i ii i i iii iii BP EXPLORATION BP Exploration (Alaska) 900 East Benso~ Boulevard F~D. Box 196612 Anct~orage, Alaska 99519-6612 (907) 561-5111 DATE: 11/07/91 T9 82983 BP CASED HOLE FINALS Enclosed is your copy of the materials listed below. If you have any questions, please contact BP Well Records at (907) 564-4004. InformatiOn Control Well Records Adrian J. Martin 10/17/91 ~! 10/27/91 #1 10/24/91 91 10/13/91 $1 10/30/91 $1 10/30/91 ~1 11/01/91 #1 10/24/91 91 10/31/91 ~1 - 10150.00-10688.00 ATLAS 5 " 10335.00-10700.00 ATLAS 5 " 2300.00- 9295.00 ATLAS 5 " 11750.00-12410.00 ATLAS 5 " 10400.00-10736.00 ATLAS 5 " 13700.00-13890.00 ATLAS 5 " 10850.00-11308.00 ATLAS 5 " 2300.00- 9292.00 ATLAS 5 " 10600.00-10970.00 ATLAS 5 " ALASKA OIL AND GAS CONSERVATION COMMISSION WALTER J. HICKEL, GOVERNOR 3001 PORCUPINE DRIVE ANCHORAGE, ALASKA 99501-3192 PHONE: (907) 279-1433 TELECOPY: (907) 276-7542 October 15, 1991 Karen M Thomas Senior Technical Assistant BP Exploration (Alaska), Inc. P O Box 196612 Anchorage, AK 99519-6612 Re: Prudhoe Bay Unit S-10A BP Exploration (Alaska), Inc. Permit No. 91-123 Sur. Loc. 1644'SNL, 1745'EWL, Sec. 35, T12N, R12E Btmnhole Loc. 5069'SNL, 2641'WEL, Sec. 26, T12N, R12E Dear Ms. Thomas: Enclosed is the approved application for permit to redrill the above referenced well. The permit to redrill does not exempt you from obtaining additional permits required by law from other governmental agencies, and does not authorize conducting drilling operations until all other required permitting determinations are made. The Commission will advise you of those BOPE tests that it~wishes to witness. David W. xJohns~o'l~"-C hairman Alaska Oil~a~as Conservation Commission BY ORDER OF THE COMMISSION dlf/Enclosures CC: Department of Fish & Game, Habitat Section w/o encl. Department of Environmental Conservation w/o encl. STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION PERMIT TO DRILL 20 AAC 25.005 la. Type of work Drill [] Redrill [[]llb. Type of well. Exploratory[] Stratigraphic Test [] Development Oil [] Re-Entry [] DeepenI-II Service [] Development Gas [] SingleZone [] Multiple Zone[] 2. Name of Operator 5. Datum Elevation (DF or KB) 10. Field and Pool BP Exploration KBE = 67.56feet Prudhoe Bay Field/Prudhoe 3. Address 6. Property Designation Bay Pool P. O. Box 196612. Anchoraae. Alaska 99519-6612 ADL 28257 4. Location of well at surf-ace 7. Unit or property Name 11. Type Bond(see 20 AAC 25.025) 1644' SNL, 1745' EWL, SEC. 35, T12N, R12E Prudhoe Bay Unit At top of productive interval 8. Well number Number 5260' SNL, 2676' WEL, SEC. 26, T12N, R12E S-IOA (24-26-12-12) 2S100302630-277 At total depth 9. Approximate spud date Amount 5069' SNL, 2641' WEL, SEC. 26, T12N, R12E October 15, 1991 $200,000.00 12. Distance to nearest 13. Distance to nearest well 14. Number of acres in property 15. Proposed depth(UDandTVD) property line ADL 28258 @ 2637' feet S-09 @ Surface 35' feet 2560 9969'MD/9155'TVD~eet 16. To be completed for deviated wells 17. Anticipated pressure (see 20 AAC 25.035 (e)(2)) Kickoff depth zD~6'~eet Maximum hole ancjle 69 o Maximum surface 3330pslg At total depth (TVD) ~00'/4390PS1~ 18. Casing program Setting Depth s~ze Specifications Top Bottom Quantity of cement Hole Casing Weight Grade Coupling Length MD TVD MD TVD (include stage data) 20" Cond. 110' Surface 139' 139' 8 cu yds 17-1/2" 13-3/8" 72# L-80 Butt 2651' Surface 2679' 2679' 3787 cufl Arcticset II Cement 12-1/4" 9-5/8" 47# L-80 Butt 8668' Surface 8697' 8571' 1329 cufl Class G Cement 8-1/2" 7" 26# NT-80$ NSCC 2219' 7750' 7356' 9969' 9155' 441 cufl Class G 10. To be completed for Rodrill, Re-entry, and Deepen Operations. K'~,~' ~ !' V Present well condition summary Total depth: measured 9715'feet Plugs (m sur d) OCT ]99t true vertical 9588'feet Effective depth: measured 9672'feet Junk (measured)~aS~j~.~.~.~a$~l:itls,~[~~~ true vertical 9545'feet ~ ~ Casing Length Size Cemented Measured depth True Vertical depth Structural Conductor 110' 20 x 30" 8 cu yds 139' 139' S u rf ace 2651' 13-3/8" 3787 cu ft 2679' 2679' Intermediate 8668' 13-3/8" 1329 cu ft 8697' 8571' Production Li ne r 1515' 7" 780 cufl 8200'-9715' 8074'-9588' Perforation depth: measured 9002'-9042', 9103'-9130' true vertical 8808'-8848', 8909'-8936' 20. Attachments Filing fee [] Property plat [] BOP Sketch [] Diverter Sketch [] Drilling program[] Drilling fluid procjram [] Time vs depth plot [] Refraction analysis[] Seabed report[] 20 AAC 25.050 requirements[] 21. I hereby ce~i~y that the foregoing is true and correct to the best of my knowledge Sig ned "~ ~ '~"4'-~-'7-~ '~7~~-q"~--J? -~ Commission Titleuse SeniorTochnicalAssistant Only Date/~v /~/~/ ' ' Permit Number IAPI number ,Appr, pval date JSee cover letter ~/'-/~.~ ]50-4~'2,~-- 2_.~ ?~4'-0/] /U '"'/ ,,~----'-'~/' ]for other requirements Conditions of approval Samples required [] Yes ~i~No Mud log required []Yes~'NO Hydrogen sulfide measures [] Yes -~]~No Directional survey requ~recl .~l~Yes [] Required~~3r..e.~Fre~; 1-13M; ~5M; I-I10U; ~15M; Other: ("- '-~'",,. ~',,.~',,t" ~'. \ Approve~ ~"-')~'~~ Commissioner by order of tne commission Date Form 10-401 Rev. 12-1-85__\ Submit ;ate PROPOSE~--"DRILLING AND COMpLETIO'~"~'PROGRAM WELL S-10A _!'41-35-1.~-12] OBJECTIVE: A side-track redrill has been proposed to reposition the bottom hole location of the subject well further from a thieving fault, increase the light oil column (LOC) and to prepare it for improved volumetric sweep when converted to injection in the near future. CURRENT STATU~;: S-10 is currently a producer in the northern portion (non-waterflood) of S Pad. The current BHL is just north of a major fault. The light oil column (LOC) is limited to only 30' TVT in the Ivishak. The well was drilled to 9715' in June, 1982. The 13-3/8" surface casing is set from surface to 2679'; the 9-5/8" intermediate casing is set from surface to 8697'; and the 7" liner is set from 8200' to 9715'. The well is completed with 4-1/2" x 3-1/2" tubing and a 9- 5/8" permanent packer with a 3-1/2" tailpipe assembly. PROPOSED PRE-RI(~ PROGRAM; (Operation to be Approved Under Sundry Notice) Rig up coiled tubing unit. Cement squeeze all existing perforations and leave 100' of cement above the upper perforation at 9002'. Pressure test squeezed perforations to 2000 psi for 15 minutes. RU slickline unit. RIH and confirm cement top. Cut the tubing tail just below the 9-5/8" packer with E-line cutter and allow to fall down to the top of previous cement plug. Spot cement plug from 100' below the 7" liner top to 100' above the 9-5/8" production packer at 8155' with coiled tubing. RIH with jet cutter, locate TOC and cut 4-1/2" tubing just above cement top. Circulate well over to seawater and freeze protect well to 2000'. Set 4" BPV. PROPO~;ED DRILLING PROGRAM: (Operations to be Approved Under Drilling Permit) The milling/drilling fluid program will consist of a 8.8 - 9.0 ppg diesel base invert emulsion mud in the 8-1/2" hole. Well control equipment consisting of 5000 psi W.P. pipe rams, blind rams, and annular preventer will be installed and will be capable of handling "worst case" situations as follows: Maximum possible bottomhole pressure is 4390 psi at 8800' TVDss based PROPOSr~-'''~DRILLING AND COMPLETICi~-'~PRO(~RAM WELL ~;-10A [41-35-12-12] upon original reservoir pressure. Maximum possible sudace pressure is 3330 psi based upon a gas column to surface from 8600' TVDss and an oil column to 8800' TVDss. The plan is to pull 4-1/2" x 3-1/2" tubing. Set a whipstock packer and cut a 8-1/2" window at 7900' MD. Directionaily drill an 8-1/2" hole to TD. Run a 7" liner from TD to 250' inside the 9-5/8" casing kickoff point and cement with Class G cement. Clean out the liner to the 7" landing collar, Change over to filtered and inhibited seawater completion fluid. Test the casing and liner lap to 3000 psi. Run a 9-5/8" production packer on 5-1/2" tubing and set same about 30' above the 7" liner top. A subsurface safety valve with dual control lines will be located about 100' below the base of permafrost. Install and test the production tree. Freeze protect with diesel. Set and test the packer. The well will be perforated after the rig as been released. Fluids incidental to the drilling of a well will be removed by truck and disposed down CC-2A. Tubing Size' 5-1/2", 17#, L-80, IJ4S tubing with 4 GLM's. PRELIMINARY WELL PLAN Well' S-10A [41-35-12-12] APl No.' 50-029-20765 LOCATION: Surface: Target: T.D.: ESTIMATED START: OPR. DAYS TO COMPLETE: CONTRACTOR: PBU 1644' SNL, 1745' EWL, Sec. 35, T12N, R12E 5260' SNL, 2676' WEL, Sec. 26, T12N, R12E 5069' SNL, 2641' WEL, Sec. 26, T12N, R12E 15 October, 1991 15 (6 days prep & mill, 4 days drill, 5 days complete) Nabors 2ES MAX ANGLE / SECTION COURSE / KOP / BUILD RATE: 60° / N10.44°W / 7916 / 6° Item TVDss MD(BKB) 20" CONDUCTOR 110' 13-3/8" SHOE 2679' BASE WEST SAK FORMATION N/A 9-5/8" SHOE 8570' TOP SAG RIVER SANDSTONE 8752' CURRENT GCC N/A TOP SADLEROCHIT 8876' TARGET 8921' TOTAL DEPTH 9087' 110' 2679' N/A 8697' 9299' N/A 9547' 9638' 9969' Mud Wt. N/A N/A N/A 9.0 9.0 N/A 9.0 9.0 9.0 LOGGING PROGRAM: O0en Hole - Record all logs on magnetic tape where applicable. 8-1/2" Hole' DGR / EWR / CNO / SFD Cased Hole Gyro survey after rig release. MUD WEIGHT CALCULATIONS WELL S-10A (4!-35-12-12~ Mud Wt. (8-1/2" Hole): 9.0 ppg. P Sag River: P Sadlerochit: P Top Sadlerochit: 3800 psi. 3600 psi. 3600 psi. OB Sag River: OB Top Sadlerochit: Current GOC: 328 psi. 586 psi. N/A Top Sag River Top Sadlerochit 8820' TVDbkb 8944' TVDbkb Cement Calculations Measured Depth: Basis: Total Cement Vol: 7650' (Hanger) - 9969' (Shoe) 1.5 X Annular volume to KOP + 100 cuft 441 (cu ft) 380 Sx Neat G @ 1.16 Cu ft/Sk S-10A MUD PROGRAM DEPTH DENSITY PV YP INT 10 MIN FL OIL SOLIDS MUD (TVD) (PPG) (CP) (#/FT) GEL GEL cc/30min (%) (%) TYPE 7900' 8.8 10 8 3 6 2 80 5 Oil to to to to to to to to to Base 9969' 9.0 18 12 8 12 4 90 6 Mud NABORS RIG NO. 2ES MID SOLIDS CONTROL EQUIPMENT 2 - Continental Emsco Fl000 Mud Pumps 1 - Derrick FioLine Cleaner Shale Shaker 1 - Mud Cleaner 1 - DRECOGas Buster 1 - Pioneer Sidewinder Mud Hopper 1 - 5 HP Flash Mixer Agitator 3 - Abcor 10 H P Agitators 1 - 50 bbl. Trip Tank 1 - Recording frilling fluid pit level indicator with both visual and audio warning devices at driller's console. 1 - Drilling fluid flow sensor with readout at driller's console PRUDHOE BAY DRILLING 7200 7§00- 7B00- 8100- 8400-i 8700.- 9000- 9300- 9600- 600 I ORIGINAL L ! ! ! I - - ,;IDEIRACi KOP 7790 BUILD 6.0/I00 1 REDRILL · . ORI'GINAL NE L S-10 VERTZCAL REDRZLL SECTZON VZEN Section at: U 10.44 E TVD Scale.: ! inch = 300 feet Oep Scale.: i inch = 300 feet grain ..... : t0/03/91 Great Land DJrectJonaJ DrY ]YYn9 ' i ~ { ~arker Identification HO fYO ~ECTN INCLN ; iJ KOP BUILD 6.0/i00 79i6 7790 707 i.41 B] END 6.0/i00 BUILD B939 8640 liB4 60.00 i i C)fO 9969 9i5§ 2076 60.00 ' DJ TARGET 9637 8989 i789 60.00 AVERAGE ANGLE BO].O0 OE6R~ES I ' 900 i200 i500 Section Oeuar~ure i800 2i00 2400 PRUDHOE BAY 'EiF~iLLiNG /V Marker Iden[lftca~ton MO N/S E/W BI KOP BUILO 6.0/100 79t6 597 N 662 E C) ENO 6.0/t00 BUILD B939 t066 N 748 E O~ TARGET 9637 166~ N 85B E ~ TO 9969 ~944 N 910 E S-I0 REDRILL PLAN VIEW CLOSURE ..... : 2146 fi N 25.09 E DECLINATION.: 3~.30 E SCALE ....... : I inch = 300 fee[ DRAWN ....... : t0/03/9~ £r' e a ~ /..and D j r' e c t: .f o n a J ,OP .i J / .i n.a A I t800- t500- i200- 900- 600- 300- / KB 0 WEST · EAST -> /. 3OO 600 gOO ~200 1500 TREE: 4-i/16'-5000 psi/CIW ACTUATOR: AXELSON ~.-~n R.T. ELEV= 67.56' WELLHEAD: 13-5/8'-5000 psi / McEvo~..~,,..,.,o/u B.F. ELEV = 39.26_' non-IPC, I.D. = 3.958" Drift I.D. = 3.833" 13-3/8', 72#/It, L-80, Btrs Csg ~ !., _ __ 4-1/2- sssv L^ND,N~ I NIPPLE,OTIS 2083 3-1/2', 9.2#//t, L-80, TDS Thread I.D. = 2.992", Ddft I.D. 2.867" ~ 3, L i NO. MD-BKB TVDSS ; I 4 2967 2966.73 ' 3 5638 5519.51 i 2 7426 7299.11 I [ 1 8085 7957.63 ' 3-1/2' 'X' NIPPLE 8145 I I ] [ k "~ Baker Latch Assembly , 9-5/8' PACKER ~ 3-1/2', 9.2#//t L-80, TDS, TAILPIPE TOP OF 7' LINER 9-5/8', 47#/1t, L-80, Butt Oils (2.750' I.D.) 8221 I (Drillers Deplh) 8232 (Elec. Line Deplh) PERFORATIONS: g,002' - 9,042' PRI, IDHOE BAY WELL: S-10 DATE BY COMMENTS APl NO. 50-02~)-20765 08/09/89 F.~/' POST WORKOVER Sec 35. T-12N, R-12E 09/13/89 HF RWO- PE (mac by bab) COMPLETION DIAGRAM I BP EXPLORATION (ALASKA) Inc. 4 2967 2966.73 3 5638 5519.51 ,, 2 7426 7299.11 1 8O85 7957.63 NABORS 2ES MUD PIT SYSTEM Trip Tank 55 BBLS PIT #1 170 BBLS PIT #2 175 BBLS PIT #3 180 BBLS Pill Tank 60 BBLS 13-57 5000 PS1 BO . STACK ANNULAR PREVENTER 7 PIPE RAMS 6 BLIND RAMS 5 DRILLING SPOOL PIPE RAMS 3 TUBING HEAD 2 1.13,3/8' CASING HEAD 2. 5000 PSI TUBING HEAD 3.13-51r . 5000 PSI PIPE RAM~ 4. 5000 PSI DRILLING SPOOL 5. 13.53' - 5000 PSi BLIND RNV~ 6. 13-5/~ . 5000 PSi PIPE RAM~ 7. 13-5~' - 5000 PSi AN~ ACCUMULATOR CAPACITY TEST 1. CHECK ANI3 FILL ACCUMU.ATOR RESERVOIR TO PROPER LEVEL wrrH HYDRAULIC FLUID. 2. ASSURE THAT ACCtJ~LATOR PRESSURE iS 3000 PS! WITH 1500 PSl DOWNSTREAM OF THE REGULATOR. 3. OBSERVE TII~_ THEN CLO~E ALL UNITS SIMULTANEOUSLY AND RECOI=~ THE TIIVE AND PRESSURE REMAINING AFTER ALL UNrTS ARE CLOSED WITH CHARGING PUIVP OFF. 4. RECORD ON THE IADC REPORT. THE~r',~F~'~EII~LOWER LIMIT PRESSURE. 1 199t STACK TEST 1. FILL BOP STACK AND hiANIFOLD WITH ARCTIC DIESEL IN WINTER OR SEAWATER DURING SUMMER MONTHS. 2. CHECK THAT ALL HOLD-DOWN SCREWS ARE FULLY RETRACTED. PREDETERMINE DEPTH THAT TEST PLUG WILL SEAT AND SEAT IN WELLHEAD. RUN IN LOCK.DOWN SCREWS IN HEAD. 3. CLOSE ANNULAR PREVENTER AND CHOKES AND BYPASS VALVES ON THE MANIF~. 4. TEST ALL COMPONENTS TO 250 PSI AND HOLD FOR 10 MINUTES. 5. INCREASE PRESSURE TO 2500 PSl AND HOLD FOR 10 MINUTES. BLEED TO ZERO PSI. 6. OPEN ANNULAR PREV~ AND CLOSE TOP SET OF PIPE RAMS. 7. INCR~ PRESSURE TO 5000 PSi AND HOLD FOR 10 MINU3~S. 8. CLOSF_ VALVES DIRECTLY UPSTREAM OF CHOKES. BLEED DOWNSTREAM PRE~SURE TO Z~RO PSl TO TEST VALVES. TEST REMAINING UNTESTED MANI~ VALVES, IF ANY, WITH 5000 PSI UPSTREAM OF VALVE AND WITH ZERO PSI ~E. AM. BIPED SYSTEM TO ZERO PSI. 9. OPEN PIPE R,aJ~S. BACKOFF RUNNING JT AND PULL OUT OF HOLE. CLOSE BUND RAM~ AND TEST TO 5000 PSi FOR 10 MINUTES. BLEED TO ZERO PSI. 10. OPEN BUND RANIS AND RECOVER TEST PLUG. MAKE SURE MANIFOLD AND LINES ARE FULL OF ARCTIC DIESEL AND ALL VALVES ARE SET IN THE DRILLING POSITION. 11. TEST STANDPIPE VALVES TO 5000 PSI. 12. TEST KELLY COCKS AND INSIDE BOP TO 5000 PS1 WITH KOOMEY PUMP 13. RECORD TEST INFORMAT1QN ON BLQWOUT PREVF_NTT=R TEST FORM. $.G.~ AND SEND TO DRILLJNG SUPERVISO¢L 14. ~M COM=LE3~ BC~ TEST CNCE A WEEK AND FUNCTIONALLY OPERATE BOPE DAILY FOR DRILLING OPERATIONS. FOR COMPLETIC.~ WORKOVEFI OPERATION~, PERFORM CO~ BOP TEST EVERY 2 ~ DAYS AND FUNCTION TEST BOP WEEKLY. DAM 11/20f89 BOP SCH (FOR: NAB 2ES) COMPARTME]qT CAPACITY 'CAPA(~ ITY / ~'*~ /'"° I I :' '~ I / / ~ ~ ,. I[ .... ~ ....1- I . '.....- .... ~ ~ ~,~ ~:~ ~ ' I ~:';~ ~'~ , ~} ......... ~ ~ ~ ~ L .-~ ~ / m ,~.~' · .~ n T .-, ..... ~ ...................................................................................... ~ ................. ~ ~ -~ - , ~ .~.' ~ -~. . - ...... ~ .... ~ ....................... z ........................... ~ ..................................................... ~ ~. ..... :::~L~F~.}"~t~L~7}ZLL;:~L~.:~F~`.~:`~}LZ~.~.LLLF::~::-::..:::.:::`::::;::::x-::;:: :;::::::': :;--_-:-..-: ~_ . ............................... : 7: ~-'7-:: :~: -': .... T-77'7: ......... 77 ~'F-77~ :~--T.TZ~':-'-7:'7-7:-'77 7Z:7.:-7'TT: :Z TT--7~TT.7 :Z~Z~7: ................ ~.L...~_L__ ~:t7 Z-~&L ..._~ ..... ~ _,. : --7': ........ 7 ~:: -; :' 7: :: ......................... ' .......... - .................... · . . / ,KA OIL AND GAS. CONSERVATION COMM 3N LICA rlON FOR SUNDRY APPROVALS pe of Request: Abandon. x Suspend Operation Shutdown Re-enter suspended well Aller casing ~ Repair well~ Plugglng x Change approved program ~ Pull lublng Time extension Stimulate Variance Perlorate ...... C~ther 2. Name of Operalor BP Exploration 3. Address P. O. Box 196612, Anchorage, Alaska 99519-6612 4. Location of well at surface 1644'SNL, 1745'EWL, SEC. 35, T12N, R12E UPM At top of productive interval 1070' SNL, 2394' EWL, SEC. 35, TI2N, R12E, UPM (Sag R) At effective depth 1071' SNL, 2376' EWL, SEC. 35, T12N, R12E, UPM At tolal depth 1071' SNL, 2371' EWL, SEC. 35, T12N, R12E, UPM 5. Type of Well: Development, X Exploratory ~ Stratigraphic ~ Service. 6. Datum elevatio~ (DF or KB) KBE,, 67.56 AMSL feet 7. Unit or Property name Prudhoe Bay Unit 8. Well number S- 10 (21-35-12-12) PBU 9. Permit number 82-95 10. APl number 50- 029-20765 11. Field/Pool Prudhoe Oil Pool 12. Present well condition summary Total depth: measured true vertical Effective depth: measured true vertical Casing Structural Conductor Surface Intermediate Production Liner Perforation depth: 9715 feet BKB 9588 feet 9580 feet BKB 9453 feet Length Size o. 110' 20"x 30" 2651' 13-3/8" 8668' 9-5/8 Plugs (measured~' Junk (measured) Cemented 8 cu yds 3787 cu ft 1329 cuft 1515' 7" measured 9002'-9042' (Sag R) 9103'-9130' (Ivishak) true vertical 8808'-8848' (Sag R) 8909'-8936' (Ivishak) Fill at 9580' MD (10/88) Measured depth 139' 2679' 8697' 780 cuft 8200'-9715' Tubing (size, grade, and measured depth) 3-1/2" L-80 to 8155' with 3-I/'2" tailpipe to 8233' Packers and SSSV (type and measured depth) 9-5/8" Baker Packer at 8155'; 4-1/2" SSSV at 2083' True vertical depth BKB 139' 2679' 8571' 8074'-9588' RECEIVED S EP 0 1991 ~.la$.ka.0il & Gas Cons. ~.lalll~ .... 13. Attachments Description summary of proposal _Z__ Detailed operations program BOP skelch X 14. Estimated date for commencing operation October 4, 1991 16. If proposal was verbally approved Name of approver Date approved 15. Stalus of well classification as: Oil X Gas Suspended Sen/ice 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed~~'~.~,_.~....., ~ ~ ~,~ ~., ~ Title Senior TechnicalAssistant FOR COMMISSION USE ONLY Date 09-26-91 Conditions of approval: No,,lif. y Commission so representative may witness Plug integrity .~ BOP Test Location clearance Mechanical Infegr~ty Test Subsequ, enl form required i0'. Approved by order of the Commission ..~ Form 10-403 Rev 06/15/88 L./" I Approval No. Commissioner Date ,/'~ - ~ - <'~'/ SUBMIT IN TRIPLICATE ITEM (1) Fee (2) Loc [9 thru 15']' ' ' ' [10 & 13] ** CHECK LIST FOR NEW WELL PERMITS ** APPROVE DATE [2 thru'8~' ' ' 3. 4. 5. 6. 7. 8. [14 thru 22] [23 thru 28] [29 thrU'3/1_ ] (6) Add l '~,~'-~:~ ?~°L,"-' e" 9,~ 10. 11. 12. 13. 14. 15. 16. 17. 18. 19. 20. 21. 22. 23. 24. 25. 26. 27. 28. 29. 30. 31. 32. Company ~/~~ Is permit fee attached ............................................... Is well to be located in a defined pool .............................. Is well located proper distance from property line ................... Is well located proper distance from other wells ..................... Is sufficient undedicated acreage avai.lable in this pool ............. Is well to be deviated & is wellbore plat included ................... Is operator the only affected party .................................. Can permit be approved before 15-day wait ............................ Does Operator have a bond in force ................................... Is a conservation order needed ....................................... Is administrative approval needed .................................... Is lease nL~nber appropriate .......................................... Does we l 1 have a unique name & n~nber ................................ Is conductor string provided ......................................... Will surface casing protect all zones reasonably expected to serve as an underground source of drinking water .................. Is enough cement used to circulate on conductor & surface ............ Will cement tie in surface & intermediate or production strings ...... Wi l 1 cement cover al 1 known productive horizons ..................... Will all casing give adequate safety in col lapse, tension, and burst. Is well to be kicked off from an existing wellbore ................... Is old wel 1bore abandonment procedure included on 10-403 ............. Lease $ We ll ~ ..,~~ .~_~ 2..~',~ ,.' ,~4~------~ YES NO ]~MARKS Is adequate wellbore separation proposed ............................. · ~ Is a diverter system required ........................................ Is drilling fluid program schematic & list of equil~nent adequate ..... Are necessary diagrams & descriptions of diverter & BOPE attached .... Does BOPE have sufficient pressure rating -- test to Sooc~ psig ..... Does choke manifold comply w/API RP-53 (May 84) ...................... Is presence of H2S gas probable ...................................... FOR EXPLORATORY & STRATIGRAPHIC WELLS: Are data presented on potential overpressure zones ................... Are seismic analysis data presented on shallow gas zones ............. If offshore loc, are survey results of seabed conditions presented... Additional requirements ............................................. rev 03/29/91 jo/6.011 INITIAL GEOI UNIT ON/OFF POOL CLASS STATUS AREA ~ SHORE Additional remarks'