Department of Commerce, Community, and Economic Development
Alaska Oil and Gas Conservation
Commission
HOME
EVENTS
DATA
Data List
Drilling
Production
Orders
Data Miner
Document Search
REPORTS
Reports and Charts
Pool Statistics
FORMS
LINKS
Links
Test Notification
Data Requests
Regulations
Industry Guidance Bulletins
How to Apply
ABOUT US
History
Staff
HELP
Loading...
The URL can be used to link to this page
Your browser does not support the video tag.
Home
My WebLink
About
195-204
1a. Well Status: GINJ Oil 1b. Well Class: 5 Exploratory Service BP Exploration (Alaska), Inc 14. Permit to Drill Number/Sundry 195-204 1/17/1996 1/25/1996 GL PRUDHOE BAY, PRUDHOE OIL 4a. Surface: Top of Productive Interval: Total Depth: 4969' FSL, 3902' FEL, Sec. 08, T10N, R15E, UM 1443' FSL, 3807' FEL, Sec. 06, T10N, R15E, UM 1534' FSL, 4032' FEL, Sec. 06, T10N, R15E, UM Surface: x- y- Zone -698697 5940612 ASP 4 11. Gas SPLUG 5Abandoned 20AAC 25.105 Suspended 20AAC 25.110 WINJ WAG WDSPL No. of Completions: 6/2/2020 15. 50-029-20063-01-00 16. PBU 01-03A Well Name and Number: Surface / Surface 39.30 17. TPI:y- Zone -693462 ASP 4x-5942230 Total Depth: x-y-Zone -693234 ASP 45942316 11500' / 9141' None DNR Approval Number:19. 79-179 5. Directional or Inclination Survey: Yes No Submit electronic and printed information per 20 AAC 25.050 (ft MSL) 20.Thickness of Permafrost MD/TVD: PDK, DIFL, DACK, CN, GR, Temp, CHT CASING WT. PER FT.GRADE SETTING DEPTH MD TOP BOTTOM HOLE SIZE CEMENTING RECORD AMOUNT PULLED Location of Well (Governmental Section): Field/Pool(s): Date Comp., Susp., or Aband.:6. Total Depth (MD/TVD): CASING, LINER AND CEMENTING RECORD TOP BOTTOM 22. SETTING DEPTH TVD 13-3/8" 9-5/8" 4-1/2" 157.5# 94#/133 72# 47#/40 12.6# H-40/K-55 N-80 L-80 Surface Surface Surface 7646' 2602' 7798' 11500' Surface Surface Surface 6498' 6603' 2602' 9141' 6" 12-1/4" 17-1/2" Fondu to Surface 400 sx Class 'G', 200 sx Fondu 3085 sx Class 'G' 300 sx Class 'G' 25. GRADE PACKER SET (MD/TVD) 26. 7644' DEPTH INTERVAL (MD)AMOUNT AND KIND OF MATERIAL USED PRODUCTION TEST27. Date First Production: Not on Production N/A Date of Test: Flow Tubing Press Oil-Bbl: Oil-Bbl: Gas-MCF:Water-Bbl: Oil Gravity - API (corr): Method of Operation (Flowing, gas lift, etc.): Gas-Oil Ratio:Choke Size: Water-Bbl: Surface Surface Open to production or injection?Yes No 524. If Yes, list each interval open (MD/TVD of Top and Bottom; Perforation Size and Number; Date Perfd): B 102'39"30" 20"Surface 1940'26"300 sx FonduSurface1940' 7585' / 6456' 170 Bbls AS I 586.2 Bbls Class 'G' Gas-MCF: Production for Test Period Calculated 24 Hour Rate Hours Tested: Casing Press: 102' ACID, FRACTURE, CEMENT SQUEEZE, ETC. TUBING RECORD DEPTH SET (MD) Yes No 5Was hydraulic fracturing used during completion? Per 20 AAC 25.283 (i)(2) attach electronic and printed information ADL 028329 320-094 Other 12. SSSV Depth (MD/TVD): Ref Elevations BFSuUface (attached) KB Form 10-407 Revised 3/2020 Sr Pet Eng Sr Pet Geo Sr Res Eng STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG Development Stratigraphic Test 2.Operator Name: 3.Address: P.O. Box 196612 Anchorage, AK 99519-6612 7. Date Spudded: 8. Date TD Reached: 9. 10. Plug Back Depth(MD/TVD): 4b. 4b. Location of Well (State Base Plane Coordinates, NAD 27): 62.80 Water Depth, if Offshore:13. N/A Zero API Number: Logs Obtained List all logs run and, pursuant to AS 31.05.030 and 20 AAC 25.071, submit all electronic data and printed logs within 90 days of completion, suspension, or abandonment, whichever occurs first. Types of logs to be listed include, but are not limited to: mud log, spontaneous potential, gamma ray, caliper, resistivity, porosity, magnetic resonance, dipmeter, formation tester, temperature, cement evaluation, casing collar locator, jewelry, and perforation record. Acronyms may be used. Attach a separate page if necessary 23. 18.Property Designation: 21.Re-drill/Lateral Top Window MD/TVD: 7798' / 6603' 1900' (Aprox.) 5 Submit within 30 days of Completion, Suspension, or Abandonment 56 6 [/ G By Samantha Carlisle at 10:48 am, Jun 15, 2020 RBDMS HEW 6/16/2020 Abandonment Date 6/2/2020 HEW xGDSR-6/16/2020SFD 6/17/2020DLB 06/16/2020 MGR06JUL2020 If yes, list intervals and formations tested, briefly summarizing test results. Attach separate sheets to this form, if needed, and submit detailed test information per 20 AAC 25.071. Permafrost - Base Formation at total depth: Contact Name:Smith, Travis T Contact Email: travis.smith1@bp.com Authorized Name:Lastufka, Joseph N Authorized Title:SIM Specialist Authorized Signature with Date:Contact Phone:+1 9075645412 32. I hereby certify that the foregoing is true and correct to the best of my knowledge. INSTRUCTIONS General: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. Submit a well schematic diagram with each 10-407 well completion report and 10-404 well sundry report when the downhole well design is changed. All laboratory analytical reports regarding samples or tests from a well must be submitted to the AOGCC, no matter when the analyses are conducted. Item 1a. Multiple completion is defined as a well producing from more than one pool with production from each pool completely segregated. Each segregated pool is a completion. Item 1b. Well Class Service wells: Gas Injection, Water Injection, Water-Alternating-Gas Injection, Salt Water Disp, Water Supply for Injection, Observation or Other. Item 4b. TPI (Top of Producing Interval). Item 9. The Kelly Bushing and Ground Level elevations in feet above mean sea level. Use same as reference for depth measurements given in other spaces on this form and in any attachments. Item 15. The API number reported to AOGCC must be 14 digits (ex: 50-029-20123-00-00). Item 20. Report true vertical thickness of permafrost in Box 20. Provide MD and TVD for the top and base of permafrost in Box 29. Item 22. Review the reporting requirements of 20 AAC 25.071 and, pursuant to AS 31.05.030, submit all electronic data and printed logs within 90 days of completion, suspension, or abandonment, whichever occurs first. Item 23. Attached supplemental records should show the details of any multiple stage cementing and the location of the cementing tool. Item 24. If this well is completed for separate production from more than one interval (multiple completion), so state in item 1, and in item 23 show the producing intervals for only the interval reported in item 26. (Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval). Item 27. Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut-in, or Other ( explain). Item 28. Provide a listing of intervals cored and the corresponding formations, and a brief description in this box. Submit detailed description and analytical laboratory information required by 20 AAC 25.071. Item 30. Provide a listing of intervals tested and the corresponding formation, and a brief summary in this box. Submit detailed test and analytical laboratory information required by 20 AAC 25.071. Item 31. Pursuant to 20 AAC 25.070, attach to this form: well schematic diagram, summary of daily well operations, directional or inclination survey, and other tests as required including, but not limited to: core analysis, paleontological report, production or well test results. 10741' 11032' 11123' 11181' 11354' 8637' 8840' 8898' 8935' 9047' Sadlerochit - Zone 4 CGL - Zone 3 Base of CGL - Zone 2C 23SB - Zone 2B 21TS - Zone 2A Zone 2A 28.CORE DATA Conventional Core(s) Yes No 5 Sidewall Cores Yes No 5 If Yes to either question, list formations and intervals cored (MD+TVD of top and bottom of each), and summarize lithology and presence of oil, gas or water (submit separate sheets with this form, if needed). Submit detailed descriptions, core chips, photographs and laboratory analytical results per 20 AAC 25.071. Well Tested? Yes 11354'9047' Top of Productive Interval 11181'8935' Form 10-407 Revised 3/2020 Submit within 30 days of Completion, Suspension, or Abandonment 30. FORMATION TESTS29. GEOLOGIC MARKERS (List all formations and markers encountered): NAME MD TVD Permafrost - Top No 5 31. Summary of Daily Work, Photo Documentation, Wellbore Schematic DiagramList of Attachments: Information to be attached includes, but is not limited to: summary of daily operations, wellbore schematic, directional or inclination survey, core analysis, paleontological report, production or well test results, per 20 AAC 25.070. Joseph N Lastufka Digitally signed by Joseph N Lastufka Date: 2020.06.14 20:51:45 -08'00' cemented annuli mgr ACTIVITYDATE SUMMARY 5/15/2020 SLB Cementers - TxIA Surface Cement Plug (PLUG AND ABANDONMENT) SLB Took control of the well upon arrival. SLB pumped 50/50 down tubing to verify injectivity. SLB Pumped the following down the tubing taking returns out the IA through the choke skid: 5 bbls fresh water, 586.2 bbls 15.8 ppg Class G Cement. ***SWAB, SSV, & IA Casing Valve shut in upon departure*** Est. TOC in TBG @ ~0' MD Est. TOC in IA @ ~0' MD Est. BOC in TBG & IA @ ~7550' MD 5/22/2020 T/I/O=0/0/0. Plug and abandon job. RD upper tree. RU tree cap and bonnet to MV. Torqued to API spec. RD 3" I/A working side valve. RD 3" I/A companion side valve. RU 3" 5000 blind on working side I/A. RU 3" 5000 blind on companion side I/A. Torqued to API spec. RD 2" O/A valve on working side. RU 2" 5000 blind flange on working side O/A. Torqued to API spec. Job Complete. See log. Final WHP,s 0/0/0. 6/2/2020 P&A **Job Complete** Perform cement top job on OA & OOA annuli. OA cement top at 52', OOA cement top at 132'. Pumped 170 bbls AS-1 to fill voids (encountered some losses through OOA) State witness cement top by Austin McLeod. Weld marker plate to top of cut casing. Pad elevation = 40.2', Tundra elevation = 35.0', Wellhead cut elevation = 28.2'. Wellhead is cut 6.8' below tundra grade. Pull shoring box and backfill excavation Daily Report of Well Operations PBU 01-03A MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: Jim Regg 6" ��`���� ✓ DATE: 6/2/20 P. I. Supervisor FROM: Austin McLeod SUBJECT: Surface Abandonment Petroleum Inspector Prudhoe Bay Unit 01-03A BPXA PTD 1952040; Sundry 320-094 6/2/20: Traveling to Drill site 01, 1 met up with BPXA representative Jon Arend to witness the surface abandonment of well 03A. The well appeared to be cut off well below tundra grade. Jon informed me it was cut six to seven feet below tundra grade. All strings were cemented to surface. Cement integrity was checked via sledgehammer. Some wood blocks had been wedged to help keep strings centered which caused two, 3 -inch cavities, which I was not concerned with. The marker plate had the proper information welded to it and did not extend past the outermost string. I found no issues with this inspection. Attachments: Photos (3) 2020-0602_Surface_Abandon_PBU_ 01-03 A_am.docx Page I of 3 Surface Abandonment — PBU 01-03A (PTD 1952040) Photos by AOGCC Inspector A. McLeod 6/2/2020 2020-0602_ Surface_ Abandon_ PBU_ 01-03A am.docx Page 2 of 3 2020-0602_ Surface _Abandon_PBU_01-03A_am.docx Page 3 of 3 MEMORANDUM TO: Jim Regg W�,s P. I. Supervisor FROM: Guy Cook Petroleum Inspector State of Alaska Alaska Oil and Gas Conservation Commission '-I "(Ze&c DATE: 5/29/2020 SUBJECT: Surface Abandonment PBU 01-03A BPXA , PTD 1952040; Sundry 320-094 5/29/2020: 1 arrived onsite and met with Jon Arend with BPXA. We discussed the well and talked about the cement top -job they were about to perform on this well. I was informed that the tubing and the IA were cemented to surface, but the OA and the OOA needed to be cemented to surface with the top job. Mr. Arend told me that the OA cement level was 132 ft below surface while the OOA was 52 ft below surface. witnessed him attempt toverify the measurements by dropping a brass plumb -bob down the hole suspended on some twine. The plumb -bob became stuck in the hole of the OOA and was left down -hole after the twine broke attempting to retrieve it. I decided that they could move forward with the cement job without further attempts to verify the level of cement inside the casing strings. Attachments: Photos (6) 2020-0529—Surface—Abandon Topjob_PBU_01-03A_gc Page 1 of 4 It - F , It - 2020-0529_Surface_Abandon_Topjob_PBU 01-03A_gc Page 3 of 4 a a Oak Operator Name:2. Development Exploratory Service 5 Permit to Drill Number:195-204 6.50-029-20063-01-00 PRUDHOE BAY, PRUDHOE OIL BP Exploration (Alaska), Inc 5. Well Name and Number:8. 10.Field/Pools: Well Class Before Work4. Present Well Condition Summary:11. Total Depth: measured feet feet Plugs measured feet feet Effective Depth: measured feet feet Packer measured feet feettrue vertical true vertical 11500 7646 6498 7585 11327 7646 6456 Casing: Length: Size: MD: TVD: Burst: Collapse: Structural Conductor 80 30" 22 - 102 22 - 102 880 Surface 1918 20" 22 - 1940 22 - 1940 1530 / 2320 520 / 1500 Intermediate 2583 13-3/8" 19 - 2602 19 - 2602 4930 2670 Intermediate 7781 9-5/8" 17 - 7798 17 - 6603 8150 / 6820 / 7510 5080 / 3330 / 4130 Perforation Depth: Measured depth: None feet True vertical depth: feet Tubing (size, grade, measured and true vertical depth)5-1/2" 17# x 4-1/2" 12.6# L-80 15 - 7644 15 - 6496 7585 6456Packers and SSSV (type, measured and true vertical depth) 4-1/2" TIW HBBP-T Packer Liner 3854 4-1/2" 7646 - 11500 6498 - 9141 8430 7500 12. Stimulation or cement squeeze summary: Intervals treated (measured): Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Shut-In Representative Daily Average Production or Injection Data Prior to well operation: Subsequent to operation: 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Name: Contact Email: Smith, Travis T travis.smith1@bp.com Authorized Name:Lastufka, Joseph N Authorized Title: Authorized Signature with Date:Contact Phone:+1 9075645412 Treatment descriptions including volumes used and final pressure: 13. SIM Specialist Operations Performed1. Abandon Plug Perforations Fracture Stimulate Pull Tubing GSTOR WINJ WAG GINJ SUSP SPLUG 16. Well Status after work:Oil 5 Gas Exploratory Development 5 Stratigraphic 15. Well Class after work: Service WDSPL 14. Attachments: (required per 20 AAC 25.070.25.071, & 25.283) Daily Report of Well Operations Copies of Logs and Surveys Run true vertical measured9141 Sundry Number or N/A if C.O. Exempt: 319-196 Junk Packer Printed and Electronic Fracture Stimulation Data 5 Secure Reservoir Operations shutdown Change Approved Program 5 Senior Pet Engineer:Senior Res. Engineer: STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS Suspend Perforate Other Stimulate Alter Casing Plug for Redrill Perforate New Pool Repair Well Re-enter Susp Well 3.Address: P.O. Box 196612 Anchorage, AK 99519-6612 7.Property Designation (Lease Number):ADL 028329 PBU 01-03A 9. Logs (List logs and submit electronic and printed data per 20AAC25.071): Stratigraphic Other: API Number: Form 10-404 Revised 03/2020 Submit Within 30 days of Operations 6KXW,Q By Samantha Carlisle at 11:12 am, May 27, 2020 Joseph N Lastufka Digitally signed by Joseph N Lastufka Date: 2020.05.27 10:51:16 -08'00' RBDMS HEW 5/27/2020 MGR27MAY20 DSR-5/27/2020 ACTIVITYDATE SUMMARY 5/3/2019 T/I/O/OO = 35/150/55/0. Temp = SI. WHPs (WIE Request). No wellhouse, AL or flowline. Temporary scaffolding installed. TP decreased 15 psi, IAP unchanged, OAP increased 5 psi, and OOAP unchanged since 04/17/19. SV, SSV = C. WV = LOTO. MV = O. IA, OA, OOA = OTG. 08:00 5/16/2019 T/I/O = 36/155/57. Temp = SI. WHPs (WIE request). No wellhouse, AL or flowline. Temp scaffold installed. TP increased 1 psi, IAP increased 5 psi and the OAP increased 2 psi since 5/3/19. SV, SSV = C. WV = LOTO. MV = O. IA, OA = OTG. 03:10 5/30/2019 T/I/O = 30/150/50. Temp = SI. WHPs (WIe request). No flowline, wellhouse or AL. Temporary scaffolding installed. 36" sombrero installed around conductor. The TP decreased 6 psi, IAP decreased 5 psi and the OAP decreased 7 psi since 5-16-19. SV, WV, SSV = C. MV = O. IA, OA = OTG. 1600 hrs. 6/14/2019 T/I/O/OO = 100/160/60/0. Temp = SI. WHPs (WIE request). Wellhouse, flowline, and scaffold removed. Temporary scaffold & secondary containment installed. TP increased 70 psi, increased 10 psi, OAP decreased 10 psi from 5/30/19. SV, WV, SSV = C. MV = O. IA, OA = OTG. 16:00 6/29/2019 T/I/O/OO = 197/159/62/0. Temp = SI. WHP's. (WIE Request). WH, flow line, WH scaffold removed. Temporary scaffold & secondary scaffold installed. TP increased 97 psi, IAP decreased 1 psi, OAP increased 2 psi, no change in OOAP since 6-14-19. SV, WV, SSV = C. MV = O. IA, OA, OOA = OTG. 15:55 7/25/2019 T/I/O/OO = 200/160/65/0. Temp = SI. WHPs (WIE Req). Well house, flowline and well head scaffolding removed. Temporary scaffold and secondary scaffold installed. TP increased 3 psi, IAP increased 1 psi, OAP increased 3 psi, & OOAP unchanged since 6-29-19. SV, WV, SSV = C. MV = O. IA, OA, OOA = OTG. 15:30 8/6/2019 ***WELLS/I ON ARRIVAL*** PULLED 4-1/2" WEATHERFORD ISO PLUG @ 4661' SLM ***JOB COMPLETE 06-AUG-2019*** 8/11/2019 T/I/O/OO = 1590/160/70/0. Temp = SI. WHPs (WIE Req). No well house, flow line or scaffold. Temporary scaffold installed. TP increased 1390 psi, IAP, OAP & OOAP unchanged since 07/25/19. SV, WV, SSV = C. MV = O. IA, OA, OOA = OTG. 04:00 8/25/2019 T/I/O/OO = 1590/160/70/0. Temp = SI. WHPs (WIE Req). No well house, flow line or scaffold. Temporary scaffold installed. WHPs unchanged 08/11/19. SV, WV, SSV = C. MV = O. IA, OA, OOA = OTG. 01:30 9/10/2019 T/I/O/OO = 1590/160/70/0. Temp = SI. WHPs (WIE Req). No well house, flow line or scaffold. Temporary scaffold installed. WHPs unchanged 08/25/19. SV, WV, SSV = C. MV = O. IA, OA, OOA = OTG. 08:30 4/22/2020 T/I/O= 1650/11/5 Temp= SI (LRS Unit-70 Injectivity Test Pre-Reservoir P&A) Pumped 2 bbls 60/40 meth followed by 58 bbls dsl to ensure water could be pumped down the tbg. Then pumped 5 bbls 60/40 meth spacer followed by 260 bbls 80* 1% KCL. Then pumped 58 bbls 30° DSL for TBG freeze protect. Hung FP tag SSV/WV/SV=Shut MV/IA/OA=Open. FWHPs= vac/19/13 Daily Report of Well Operations PBU 01-03A Daily Report of Well Operations PBU 01-03A 5/2/2020 T/I/O= vac/1/14/1 Temp= S/I LRS Unit 70: RESERVOIR P&A Heated diesel transport to 75degF for upcoming cement job. Pumped 5 bbl meth spear followed by 205 bbls 105* 1% KCl down Tbg at 5bpm for injectivity test. Schlumberger pumped cement down TBG. LRS dropped foam wiper balls and pumped 129 bbls 70* diesel down TBG to place TOC at 7600'. Master valve open and tag hung, all other tree valves closed. Casing valves open to gauges. FWHP vac/20/24/0 ***Job Complete*** 5/2/2020 SLB Fullbore Pumping Crew (RESERVOIR P&A) LRS loaded the well with 200bbl 1%KCl. SLB pumped 3bbl fresh water lead spacer, 60bbl 15.8ppg Class G Cement, 5bbl fresh water tail spacer. LRS launched 2 x 7" foam ball with 129 bbls of 75degF diesel. Estimate foam ball at 7,515' MD. Top of cement at 7,646'MD. ***Job Complete. Tagged well for cement plug in tbg.*** 5/4/2020 T/I/O=0/12/22 (LRS unit 76 Assist SL with AOGCC MIT) CMIT-TxIA to 2606/2675 ***INCONCLUSIVE*** witnessed by Brian Bixby. Pumped 28.2 bbls 60/40 down TBG/IA to reach test pressure (Max 2750 psi, Target 2500 psi) . Bled T/IAP and bled back ~14 bbls. Pumped 8.8 bbls 60/40 back down TBG/IA for CMIT-TxIA. 3rd 15 min T/IA lost 21/13 psi. 4th 15 min T/IA lost 18/11 psi for a total loss of 39/24 psi in 30 min. CMIT-TxIA PASSED BP criteria, but AOGCC called inclonclusive. Bled TBG/IAP, bled back ~ 8.8 bbls. RDMO. SL in control of well upon LRS departure. FWHP=30/50/23 ***Job Complete*** 5/4/2020 ***WELL S/I ON ARRIVAL***(P&A) RAN 2.25" CENT & 1.75" S.BAILER TAG TOC @ 7,629' SLM LRS PERFORMS CMIT-IA (AOGCC STATE WITNESSED, see lrs log for details) RAN 2.25" CENT, 4' x 1.75" DRIVE DOWN BAILER, TAG TOC @ 7,629' SLM ( AOGCC STATE WITNESSED) RAN BARBELLED 3.625"/3.70" CENT, 3.50" LIB TAG BAKER FLO GUARD PATCH @ 4,683' SLM / 4,692' MD (9' corr) ***CONT WSR ON 05/05/20*** 5/5/2020 ***CONT WSR FROM 05/04/20***(P&A) DRIFT W/ 20' x 1.75" BAILER DRIFT TO 7,629' SLM RAN SLB E-FIRE/TBG PUNCH @ 7,545-7,550' MD (shots fired) ***WELL LEFT S/I ON DEPARTURE*** 5/12/2020 Cost placeholder for foam wiper balls 5/13/2020 T/I/O=350/180/12 Temp=SI Circ to tanks (Circ Out) Pumped 5 bbls 60/40 meth, 99 bbls 130* surfactant w/ F103 and U067, 540 bbls 80* 9.8 brine and 10 bbls 60/40 meth down Tbg taking returns from IA to open top tanks. U-Tube 60/40 meth from Tbg to IA for half an hour. Bled Tbg/IA to 0 psi to tank. Freeze protected surface lines and choke trailer. FWHP's=0/0/40 SV,WV,SSV=C MV=O IA,OA=OTG Hardline & CT=SI 5/13/2020 Cement Control and Balance lines. Control line Pressure = 400 psi & Balance line Pressure = 800 psi. Pumped 2 gallons of Squeezecrete down Control line. Pumped ~1.2 gallons of Squeezecrete down Balance line when it locked up @ 4200 psi. MEMORANDUM TO: Jim Regg P.I. Supervisor l FROM: Brian Bixby Petroleum Inspector Section: 8 Township: Drilling Rig: n/a Rig Elevation: Operator Rep: Jerry Boyles Casing/Tubing Data (depths are MD) Conductor: 30" 'O.D. Shoe@ Surface: 20" 'O. D. Shoe@ Intermediate: 13 3/8" - O.D. Shoe@ Intermediate: 9 5/8" - O.D. Shoe@ Liner: 4 1/2" - O.D. Shoe@ Tubing: 5 1/2" x 4 1/2" O.D. Tail@ Plugging Data: Test Data: State of Alaska Alaska Oil and Gas Conservation Commission DATE: May 4, 2020 SUBJECT: Well Bore Plug & Abandonment PBU 01-03A BPXA PTD 1952040; Sundry 319-196! 10N Range: 15E Meridian: Umiat Total Depth: 11,500 ft MD " Lease No.: ADL 028329 102 ' Feet 1,940 Feet 2,602 Feet 7,798 Feet 11,500 Feet 7644 Feet Suspend: XXX IP&A: Founded on Depth Btm Casing Removal: Csg Cut@ Feet Csg Cut@ Feet Csg Cut@ Feet Csg Cut@ Feet Csg Cut@ Feet Tbg Cut@ Feet Tvoe Pluq Founded on Depth Btm Depth To MW Above Ventied Perforation Bottom 11,410 ft MD' 7,629ftMD'I 7.1 ppg Wireline tag OA 24 24 24 24 Initial 15 min 30 min 45 min Result Tubing 2729 2672 2631 2597 IA 2758 2713 2688 2670 F ✓ OA 24 24 24 24 Initial 15 min 30 min 45 min 60 min Result Tubing 2728 2674 2645 2624 - 2606 IA 2756 2719 2699 2686 2675 P OA 25 25 25 25 25 Remarks: Class "G" 15.8 ppg cement was pumped and left with diesel above it to surface. I witnessed good hard cement from the SL sample bailer. CMIT TxIA #1: Pretest T/I/O Pressures 0/15/21 psi; pumped 28.3 bbls; deemed a FAIL for consistent pressure loss; bled back 14 bbls. CMIT-TxIA #2: Pretest TIO Pressures 38/55/23 psi; pumped 8.8 bbls; deemed Inconclusive for questionable pressure loss; bled back 8.8 bbls. Inspection Supervisor changed result to Pass and approved continuation of suspension work under the sundry. Attachments: none rev. 11-28-18 2020-0504_Plug_Verification_PBU_01-03A_bb THE STATE °fALASKA GOVERNOR MIKE DUNLEAVY Michael Hibbert Well Intervention Engineer BP Exploration (Alaska), Inc. PO Box 196612 Anchorage, AK 99519-6612 Re: Prudhoe Bay Field, Prudhoe Oil Pool, PBU 01-03A Permit to Drill Number: 195-204 Sundry Number: 320-094 Dear Mr. Hibbert: Alaska Oil and Gas Conservation Commission 333 West Seventh Avenue Anchorage, Alaska 99501-3572 Main: 907.279.1433 Fax: 907.276.7542 www.00gcc.alcska.gov Enclosed is the approved application for the sundry approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the AOGCC grants for good cause shown, a person affected by it may file with the AOGCC an application for reconsideration. A request for reconsideration is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. Sincerely, ere . Price r DATED this q day of March, 2020. ABDMS t"`j MAR 0 5 2020 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 RECEIVED CCn ')'7 nn.... 1. Type of Request: Abandon 121- Plug Perforations ❑ Fracture Stimulate ❑ Repair Well ❑ para o i Odom ❑ Suspend Perforate ❑Other Stimulate ❑ Pull Tubing ❑ �pLB}, [j2-0 Other Plug for Redrill ❑ Perforate New Pool ❑ Re-enter Susp WeII ❑ Alter Casing ❑ Oth_ `� ❑ 2. Operator Name: BP Exploration (Alaska), Inc 4. Current Well Class: Exploratory ❑ Development ®• 5. Permit to Drill Number 195-204 ' 3. Address: P.O. Box 196612 Anchorage, AK 99519-6612 Stratigraphic ❑ Service ❑ 6. API Number: 50-029-20063-01-00 7. If perforating: What Regulation or Conservation Order governs well spacing in this pool? 8. Well Name and Number: Will planned perforations require a spacing exception? Yes ❑ No EH PBU 01-03A - 9. Property Designation (Lease Number): 10. Field/Pools: ADL 028329 PRUDHOE BAY, PRUDHOE OIL ' 11. PRESENT WELL CONDITION SUMMARY Total Depth MD (ft): Total Depth TVD(ft): Effective Depth MD: Effective Depth TVD: MPSP (psi): Plugs (MD): Junk (MD): 11500 9141 11410 9083 None 11327 Casing Length Size MD TVD Burst Collapse Structural Conductor 80 30" 22-102 22-102 880 Surface 1918 20" 22-1940 22-1940 1530/2320 520 / 1500 Intermediate 2583 13-3/8" 1 19-2602 19-2602 4930 2670 Intermediate 7781 9-5/8" 1 17-7798 17-6603 8150 / 6820 / 7510 5080 13330 / 4130 Liner 3854 4-1/2" 7646-11500 6498-9141 8430 7500 Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): 11240- 11335 8973 - 9034 5-1/2" 17# z 4-1/2" 12.6# L-80 15-7644 Packers and SSSV Type: 4-1/2" TIW HBBP-T Packer Packers and SSSV MD (ft) and TVD (ft): 7585/6456 No SSSV Installed No SSSV Installed 12. Attachments: Proposal Summary m Wellbore Schematic p 13. Well Class after proposed work: Detailed Operations Program ❑ BOP Sketch ❑ Exploratory ❑ Stratigraphic ❑ Development 0 ' Service ❑ 14. Estimated Date for Commencing Operations: March 15, 2020 15. Well Status after proposed work: Oil ❑ WINJ ❑ WDSPL ❑ Suspended ❑ 16. Verbal Approval: Date: GAS ❑ WAG ❑ GSTOR ❑ SPLUG ❑ Commission Representative: GINJ ❑ Op Shutdown ❑ Abandoned m 17. 1 hereby certify that the foregoing is true and the procedure approved herein will not Contact Name: Hibbert, Michael be deviated from without prior written approval. Contact Email: Michael.Hibbert@BP.com Authorized Name: Hibbert, Michael Contact Phone: +1 907 564 4351 Authorized Title: Well Interven Bons E Veer Authorized Signature: Date: Z, Z ZO COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number: Plug Integrity ❑ BOP Test Mechanical IfnttegritytyTest ❑ Location Clearance 1❑ �L, /1 Other p1 e�O 1/oCV fil � • _N y1Fb 3BDMS 9W MAR 0 y 2020 Post Initial Innjj�e-c`t'iion MIT RReq'd? Yes ❑ No ❑ Spacing Exception Required? Y No Subsequent Form Required: ..� pr/APPROVED B �{ U Approved by: v COMMISSIONER COMMISSIONYTHE ao Date: ✓ r 00 Form 10403 Revised 04/2017 g_tc 312' Approved applicationywDIN L of ,, �vQarKArazo approval. ,'r3��2ozU Submit Form and Attachments in Duplicate 01-03A Permanent Abandonment Sundry Intervention Engineer Michael Hibbert (907) 564-4351 Production Engineer Finn Oestgaard (907) 564-5026 History Well has similar construction to 02-03 and 02-02. Surface casing is set in the permafrost. Well is currently secured with an Iso -plug above the patch at 4670'. The well house and flowline have been removed. There are no other known integrity related failures for this well. The cementing records for this well show that the exterior of the 9-5/8" casing is cemented from the shoe to 6300' MD, through a stage collar @ 2387' to 2130' MD, and through a stage collar @ 1376' to surface. The exterior of the 13-3/8" casing is cemented from the shoe to 575' MD, and a 155' top job with 33 bbls of AS1. The 20" casing was cemented with 117 bbls of Fondu cement with an estimated cement top of 605' MD. The 30" conductor is cemented from 115' to surface. The reservoir abandonment work is on-going under Sundry #319-196. A 10-404 will be submitted when that work is complete. The full abandonment will be completed under this sundry and a 10-407 will be submitted when all steps are complete. This plan is contingent on the CMIT-TxIA passing following the reservoir abandonment cement job. If that test fails, then a revision will be made. Objective Fully abandon tubulars, cutoff casings below grade and weld on a permanent marker plate. Procedural steps Fullbore 1. Pump cement down tubing and take returns from IA. Pump -550 bbls of Class G cement. This will place a continuous cement plug in the tubing and IA from the tubing punches @ 7545' to surface. 2. Pump at max rate and not to exceed 1500 psi. 3. Monitor returns to confirm cement returns @ approximately 535 bbls pumped. ✓ Special Projects - Final Excavation 1. Notify AOGCC Inspector of wellhead removal. (24-hour minimum notice) 2. Photo document all steps. 3. Cut off all casings and wellhead 3' below tundra. 4. Top off tubing and all annuli with cement if needed. Photo document cemented annuli. 5. Weld marker cap on outer-most casing string. The marker plate should have the follwing information bead welded onto it: a. BP Exploration Alaska b. PTD# - 195-204 c. Well Name - 01-03A d. API# - 50-029-20063-01 6. Photodocument welded on marker plate prior to backfilling. TREE= 5)7L FRC 120 WELLHEAD= MCEVOY ACTUATOR= BAKER OK&. R..EV = 73' REEELEV= 04109/18:: SiT'JRO Af>�FS(04104418) BF. &.EV = 44.12' KOP- 3OW Nbz Angie = Datum RD= D eum TVD= 51 011058' Yf064'� 8mg C.8I 5IV" 4-f r2" DS 01-03 Current WBS after Reservoir TOSEC71REwELL W1PKR USr Abandonment is Completed JFVKRCUETOI-I TIP 'G1> P RSR POSS O RESTRICTION IN 4 )CN-MPLM 7621' TO TOP OF 41/2" LNi ADDITIONAL 133!8"�t 0 7665'- CTU RAN 3.715" MILL TO 113W D913D1 IL — fIiSFKiNFOfANTpN / BPV PROFILE NOl4FUCTIONAL 105/02(07)'^ CPQ 1729 CP 7936' 1726' ? 713-31a- W PfO 2026' 73.318- W PKR BM RO GLWT4) PATCH, ID = 2.45^h 4692' - 47; Minimum ID = 2.45` 4692' BAKER FLO GUARD PATCH T BAKER ZXP FKR NV0- 4.562' -112' X 4 1r2' XO. 9- 3-376' W P1SR .� _ — GAS LFT MAN]RF3.S 3T hO NO GEV TYPE VLV LA.TCH Pill 1 3289 3282 1 5 MMG Ow RK 0 2 692815271 46 MMG OW RK 0 3 7517 8411 48 MMG Ow RK 0 7585' 9-5!8' X 4112' TW H&BP-T RQt, 7621' 41!7 HES XN NP, ID= 3.72" f 7�--)4-11T WIEG. I1=3.958" 7623' V%&M ELMO(LOGGED 0287196) &5'8'I4LLOUT INII`DOW X7798' FISH - T OF VIDEO CA MERA LEFT N WELL N VC*M OF TR 0 7623ON 07/2498 - NEVER RECOVERED OATH LI(OV123117 -5r8'CSG, 408 /43.5#Y/47#, 779V � h`1 I REV BY CS]M.B4lt- IWTE . REV SY CONMENTS RM1341NTIALCOMPLETION 04109/18:: SiT'JRO Af>�FS(04104418) =95c: 500-95 IIS95,D=8.681" 12/17/18' H,'JMDAEDrDREF&SFELEV .0dG &wf� Rx -L@ EVOTREVE FLIJC, (lowt 01107/19 MI}flJSETVVTT ISO RLK; (01104119) GIStfMl SEi FLOOUARD PA7CH(70/1&15) ) &P&plotation (Alaska) ZVIJNQ RA..I.®[SSSV 10/19117) FERFORATKIN SUM644RY i !EF LOGS DIGO ACOUSTILO ON 01126186 ANGLEAT TOP PERF 50-g11240' Woe: Refer to Production T)B for hlctarlcal perf data Sl7E' SPF NT6TNAL OWScg SWOT S(Y 244 4 11240 - 112 G 0910599 - 2" ' 6 1126E - 11278'1 C D4/02/18 FVTD 2-1r8'' 4 Y1232-11302 1 C 0229/98 � - 2-1tW, 4 11314-11320 C 02127196 2 118' 4 11325 - 11335 C 02!'27/96 412" L.NR 12.8k, 1 NV0- 4.562' -112' X 4 1r2' XO. 9- 3-376' W P1SR .� _ — GAS LFT MAN]RF3.S 3T hO NO GEV TYPE VLV LA.TCH Pill 1 3289 3282 1 5 MMG Ow RK 0 2 692815271 46 MMG OW RK 0 3 7517 8411 48 MMG Ow RK 0 7585' 9-5!8' X 4112' TW H&BP-T RQt, 7621' 41!7 HES XN NP, ID= 3.72" f 7�--)4-11T WIEG. I1=3.958" 7623' V%&M ELMO(LOGGED 0287196) &5'8'I4LLOUT INII`DOW X7798' FISH - T OF VIDEO CA MERA LEFT N WELL N VC*M OF TR 0 7623ON 07/2498 - NEVER RECOVERED OATH LI(OV123117 fRUD OE BAY LTIT WELL 01-03A FSTM 995XMl0 APINu: 50.029.20)03-01 SEC8,T10N. Ri5E310'HTL&1379'FWL I REV BY CS]M.B4lt- IWTE . REV SY CONMENTS RM1341NTIALCOMPLETION 04109/18:: SiT'JRO Af>�FS(04104418) N18E�RACK(01.03A) 12/17/18' H,'JMDAEDrDREF&SFELEV .0dG &wf� Rx -L@ EVOTREVE FLIJC, (lowt 01107/19 MI}flJSETVVTT ISO RLK; (01104119) GIStfMl SEi FLOOUARD PA7CH(70/1&15) ) &P&plotation (Alaska) ZVIJNQ RA..I.®[SSSV 10/19117) VAaL EAD= hCEVOY ACTUATOR= BAKERC OKB. R -EV = 73' WELOV _.—._._ 82.8' BE. ELEV = 44.22' NOF= 3000' Man An9k = St 1105@' Datum LID 11084' Datum TVD= 88CKY SS TES: `TO SECURE W E'LL, PM MUST DS 01-03—Proposed Abandonment EPKRDUETOH136PPWPIOI TPFISK POS91DRESTRICTIONIN4- 172" TBG FRDM XN-NP LM7621' TO TOP OF 41/2" LN2 ADDMONAL 133+8'—' , X @ 7665'. CTU RAN 3.715" MIL L 7011340' 0913019& CASWO 2•FORd4T)ON� �� \� RPV PROFILE NOKFLWCT10NAL(0&=07)"°' CP 1729 GP1938' \\ 2026' t3-316' W Plffi� 30' COf•DUCIOR, 157.57# 115' 20" CSG, 94#, K40, D =19.124' 2000' t_ 17#. L-80,.0232 bIW D=4.892"-1--{- ��-222Y Y w0° 72#, 480 BUR. U:-; FLO GUARD PATCH, D = 2.45' —j 4692' - 4724' Minimum ID s 2.45" @ 4692" BAKER FLO GUARD PATO D=3.958' to 7 9-58' CSO, 400143,5# 1147#, 00-95 A7&95, D a 8.681" 7644' 0 1M41 3 17517718411 146 I MMG j DMY RK5926 5271 46 MMr RK� 0 110106I131021 7565' 9-5/8'X41/2'TNV WORT PKR, D=4.183' 7621' 41/2' FES XN NP D i T2' 7623' WLEG13AD{L17G(�EDo227/ss) 9-518" RLLOUf WIPD6W 4Y17798' .0152 DATER2/BY FERFORATDNSIIAN ARY FEE LOG- MIT AODUSTC00N01126196 ANGLEAT TOPPERF150° @ 11240' NoW Refer to Rodwhon DB for historical Pert data SIZES SSEE NB7NAL OPNSgz SHDT SOZ 2-718'i 4 2' : 6 2-143', 4 2-11W, 4 2 1181 4 11240- 11246, G 11266 - 112781 C 11252 - 11302. C 11314 - 113201 C 11325- 11335 C 09105198 04102/18 0229196 0227/96 02!27196 I 0 1M41 3 17517718411 146 I MMG j DMY RK5926 5271 46 MMr RK� 0 110106I131021 7565' 9-5/8'X41/2'TNV WORT PKR, D=4.183' 7621' 41/2' FES XN NP D i T2' 7623' WLEG13AD{L17G(�EDo227/ss) 9-518" RLLOUf WIPD6W 4Y17798' .0152 DATER2/BY DATE RFV BY CO ANTNTS OGRW70 ROW 34 INTIAL COMPLETION 04109119'. SETfJAD ADfERF'S (04104118) 1217!18 JtilJkDA�Rff&8E©FV -- 02/07!88 NIKE SIDETRACK (Qi•OSA) 1007115 JMGI PU.L®PJOTREV E FLLIG (10/0311 1111015 CIWADSETROOlA4t7D PATCH(10f8175i 07107119 011 -YJ SEY WFT I`'I RLG (OIAM19 - - -- -- 05/01/17 tiCBJ SEF USSSV FLAG (0V3017) _ !023/17 ZV/.WD RJL1ID0SSSV (1019/17) FISH- 7' OF VB)EO CAMER& LEFT WELL N VICNf1Y OF TTL C 7623' ON 0724198- NEVER %3M ED WELL. 01.0m PFFW No 1952040 API No: 50029-2D363-01 SEC 8, T10K RI5E 310' FN_ & 1379FVVL BP EXPIMaUm 1Alaska) THE STATE °fALASKA GOVERNOR MIKE DUNLEAVY Michael Hibbert Well Interventions Engineer BP Exploration (Alaska), Inc. PO Box 196612 Anchorage, AK 99519-6612 Re: Prudhoe Bay Field, Prudhoe Oil Pool, PBU 01-03A Permit to Drill Number: 195-204 Sundry Number: 319-196 Dear Mr. Hibbert: Alaska Oil and Gas Conservation Commission 333 West Seventh Avenue Anchorage, Alaska 99501-3572 Main: 907.279.1433 Fax: 907.276.7542 v✓ww.a ogcc.alaska.gov Enclosed is the approved application for the sundry approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the AOGCC grants for good cause shown, a person affected by it may file with the AOGCC an application for reconsideration. A request for reconsideration is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. Sincerely, Daniel T. Seamount, Jr. Commissioner r DATED this day of April, 2019. RBDMS.� APR 2 3 2019 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 RECEIVED APR 17 ""`i 1. Type of Request. Abandon ❑ Plug Perforations 0 Fracture Stimulate ❑ Repair -Well ❑ Operations shutdown ❑ Suspend ❑ Perforate ❑ Other Stimulate ❑ Pull Tubing ❑ Change Approved Program ❑ Plug for Redrill ❑ Perforate New Pool ❑ Reenter Susp Well ❑ Alter Casing ❑ Other Secure Reservoir 0 2. Operator Name: BP Exploration (Alaska), Inc 4. Current Well Class: Exploratory ❑ Development 0' 5. Permit to Drill Number: 195-204 ' 3. Address: P.O. Box 196612 Anchorage, AK 99519-6612 Stratigraphic ❑ Service 11 6 API Number: 50-029-20063-01-00 7. If perforating: 18. Well Name and Number. What Regulation or Conservation Order governs well spacing in this pool? Will planned perforations require a spacing exception? Yes ❑ No 0 PBU 01-03A - 9. Property Designation (Lease Number): 10. Field/Pools: ADL 028329 PRUDHOE BAY. PRUDHOE OIL ' 11. PRESENT WELL CONDITION SUMMARY Total Depth MD (ft): Total Depth TVD(fo Effective Depth MD: Effective Depth TVD: MPSP (psi): Plugs (MD): Junk (MD): 11500 9141 4670 4421 4670 11327 Casing Length Size MD TVD Burst Collapse Structural Conductor 80 30" 22-102 22-102 880 Surface 1918 20" 22-1940 22-1940 1530 / 2320 52011500 Intermediate 2583 13-3/8" 19-2602 19-26024930 9-26024930 2670 Intermediate 7781 9-5/8" 17-7798 17- 69603 815016820 / 7510 5080 / 3330 / 4130 Liner 3854 4-1/2" 7846-11500 6498-9141 1 8430 1 7500 Perforation Depth MD (1t): Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): 1 11240 - 11355 8973-9034 5-1/2" 17# x 4-1/2" 12.6# L-80 15-7644 Packers and SSSV Type: alrt" TI W HBBP-T Parker Packers and SSSV MD (ft) and TVD (ft): 7585/6456 No SSSV Installed No SSSV Installed 12. Attachments: Proposal Summary 0 Wellbore Schematic ® 13. Well Class after proposed work: Detailed Operations Program ❑ BOP Sketch ❑ Exploratory ❑ Stretigraphic ❑ Development 0 • Service ❑ 14. Estimated Date for Commencing Operations: May 1, 2019 15. Well Status after proposed work: Oil 0- WINJ ❑ WDSPL ❑ Suspended ❑ 16. Verbal Approval: Date: GAS ❑ WAG ❑ GSTOR ❑ SPLUG ❑ Commission Representative: GINJ ❑ Op Shutdown ❑ Abandoned ❑ 17. 1 hereby certify that the foregoing is true and the procedure approved herein will not Contact Name: Hibbert, Michael be deviated from without prior written approval. Contact Email: Michael.HibbertQBP.com Authorized Name: Hibbert, Michael Contact Phone: +1 907 564 4351 Authorized Title: Well Interventions Engine Authorized Signature: �� \-•� Date: jJ Wdr COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number: I / BOP Test ❑ Mechanical Integrity Test ' Location Clearance ❑ Plug Integrity ftY CB Other: Post Initial Injecton MIT Req'd? Yes ❑ No ❑ iMMS11 ' APR 2 3 2019 Spacing Exception Required? Yes ❑ No Subsequent Form Required: B, APPROVED Approved by: � COMMISSIONER COMMISSION Date 9�&4'/kq ORIGINAL M&e jq elf P I Submit Form and Form 10-403 Revised 04/2017 Approved application is valid for 12 months from the date of approval ��jy�c in Duplicate yly(L/lYJ ti/�'-.�/ 01-03A Reservoir Abandonment Sundry Intervention Engineer Michael Hibbert (907) 564-4351 Production Engineer Finn Oestgaard (907) 564-5026 History Well has similar construction to 02-03 and 02-02. Surface casing is set in the permafrost. Well is currently secured with an Iso -plug above the patch at 4670'. The well house and flowline have been removed. This well is slated for full P&A in 2020. Objective Place a reservoir cement plug across perforations in the liner and circulate hydrocarbons out of tubing and IA. Procedural steps Slickline 1. Pull WFT Isoplug from 4670' Fullbore 1. Pump reservoir cement plug 2. Pump the following down the tubing, max pump pressure of 2000 psi: ➢ 5 bbls 60/40 meth spear ➢ 200 bbls KCL injectivity test ➢ 3 bbls FW spacer ➢ 30 bbls 15.8 ppg Class G cement ➢ 5 bbls FW spacer ➢ 155 bbls of diesel Cement Type/weight: Class G 15.8 ppg mixed on the fly or batch mix. Field blend to be =lab ppg +/- 0.1 ppg Slurry Temperature: between 800 and 110°F Fluid Loss: 100-200cc (50-100cc/30 min) Compressive Strength: 2000 psi in 48 hrs. Thickening Time: Minimum 5 hours Slickline/Fullbore 1. CMIT-TxlA to 2500 psi. AOGCC witnessed. Max applied pressure of 2750 psi. 2. Tag of TOC. AOGCC witnessed. 3. Attempt to pull GLV from Station #3 through 2.45" ID patch. Reference similar attempts on 14-44 and C-11. 4. If unable to pull GLV after 2-3 attempts then proceed with 5' of tubing punches from 7545'-7550'. 5. Pump 100 bbls of surfactant wash (hot freshwater + surfactant; 2 gal/mgal F103 and 2 gal/mgal UO67), followed by 518 bbls of 9.8 ppg brine down tubing taking returns from IA to a nearby flowline. Pump at max rate, max pressure of 1500 psi. 6. Place 150' meth freeze protect at surface in the tubing and IA. TFkF = 5XTL FW 120 WEJ.FfAD= MMVOY ACTUATOR= BM032C 010 B" 77 FNF ELEV = at8' BF. BPI = 4121' KOP= 3000' Max An* = Datum AU= 51' @ 1105V 47064' Dmtum ND= BBDO SS 3P COFDIX:TOR,157.50 115' IT, 12.34r BKR FLO GUARD PATCH, D= 2.45^ 9-5/8" Casing Cement: Cemented to 3150'w/ 30% washout. 1060 sxs of Class G w/ 10% Gel w/ yield of 2.0 ft3/sxs 1000 sxs of Class G neat w/ yield of 1.15 ft3/sxs Total volume cement pumped = 582 bbls. A1&95, U = 8681' PERFORATION SUWMRY NOTES: •TO SECURE WELL, PLUG MUST ANDLEATTOPPHB=. 50' @ 11240• DS 01-03 Current Status ET= W DUE TO HBBP TIW PKR SIZE PORT TP FISFL POS✓" ID RESTRICTION IN 4- INTERVAL OprdSgz FRDM WHIP 0 7621' TO TOP OF 41/2^ LN4 I SOZ ADDT"INL 1318' 4 11240- 11246 C 09KISS99 5926 5271 2' Q78110'.CNRAN3.715"MILLTO11340'09130198 ^' 11266-11278 CASING IF01aM,;0N 04102118 00/10/14 2-118' 4 11292 -11302 C DPW PROFILE NDKRACTKNNL (05102107)'•' RK CP § 1729 1938 4 11314-11320 C a227196 1726't}3W DV PKR CP to 11325 -11335 C 0227196 2026' 133!8' W PIff2 3P COFDIX:TOR,157.50 115' IT, 12.34r BKR FLO GUARD PATCH, D= 2.45^ 9-5/8" Casing Cement: Cemented to 3150'w/ 30% washout. 1060 sxs of Class G w/ 10% Gel w/ yield of 2.0 ft3/sxs 1000 sxs of Class G neat w/ yield of 1.15 ft3/sxs Total volume cement pumped = 582 bbls. A1&95, U = 8681' PERFORATION SUWMRY 14EF LOG: UGIT ACOUSTLO ON 01210106 ANDLEATTOPPHB=. 50' @ 11240• NmM: Rarer to Ruduc5on OB for hstotwal perf data SIZE SPF INTERVAL OprdSgz SHOT I SOZ 2-718• 4 11240- 11246 C 09KISS99 5926 5271 2' 6 11266-11278 C 04102118 00/10/14 2-118' 4 11292 -11302 C 0229196 RK 2-116• 4 11314-11320 C a227196 2 118• 4 11325 -11335 C 0227196 4-iR 1 2209' H5-12'H13HRCf6VLNSSSVNP,O=4.582' I so reT 12■!.1W.::=a--1 ISTI X 4-12- TIW M3 -T PIOf. C DMW70 00*34 1NTTALCOMPLEION 04109/18 SER ACFI31F3 (04101/18) 7821• DATE 1 3269 3262 15 4-1r7WLBG,O=a958' OIaY RK 0 OWIDI14 2 5926 5271 48 MM OIAY RK 0 00/10/14 3 7517 6411 46 MMG OAaY RK 0 10/13102 7586•45!8• X 4-12- TIW M3 -T PIOf. C DMW70 00*34 1NTTALCOMPLEION 04109/18 SER ACFI31F3 (04101/18) 7821• 4-1rr HES XN NP, D= 3.72^ 10107/16 AVd PULLED EVOTREVE PLUG( iOf03t1 1!07119 Mr1YJ SET INFTISO RUG(01/OG19) 7644• 4-1r7WLBG,O=a958' 787J' VYIEE ELMD(LOGGED 02127198) 9-5/8' MLLOUT WIDOW 0 7798• DATE REV BY CORDAE 4TS DATE FZQV BY ODK&EM =' DMW70 00*34 1NTTALCOMPLEION 04109/18 SER ACFI31F3 (04101/18) 0?J0719B NIKE SaDEfRACK(01.03A) 12117f1$.R41 ADEM REF 8 BF EB/ 10107/16 AVd PULLED EVOTREVE PLUG( iOf03t1 1!07119 Mr1YJ SET INFTISO RUG(01/OG19) 11/10115 CJSIJLU SET FLOGUME PATCH (10!18115) 05401/17 ROSPJMO SET DSSSV RUGIGUNW17) 1023/17 ZVf,MU BILLED DSSSV (10/19117) Il VICINITY OF TR 0 7M' ON RB@DEBAY UNIT VAIL 01-03A pgwtb 1962040 APIW: 50.029-20363-01 NOR R15E 31O F L 81379• FWL SP 6lprmra8orr (Alaska) TREE = ML F'►C 120 NOTES:'TO SECURE W ELL, PLUG MUST 'D= SOY DS 01-03 Proposed Status ABOVE PKR DUE TO HBBP TIW PKR )R= BAKER C PORT' TP RSH P09S D RESTRICTION IN 4- V = 73' yr TBG FADN X74NP a 7621- TO TOP OF 4-172" LNR AOOffDW1L 1}yg• WCTURAN3.715"MB-LT01134909130198. ' 4475 WOfAMTION3000' RlF NDHLFl11CTIWNI (0510217)CASNG CPQ 1729Q 11099CP t;HWPvPLFl 13378• W R02 Q 193928' 09005199 ® 110610 2026' 13-3/e• D7 RCR D= 880055 11266 - 11278 30'OONIX1CT012, 157.58 116' 2288 5-112- HMS S7LNMSV NP. D=4.582" 20' CSG, 948, H40, D = 1IK 9.124• 2800' 2-118' o, 178, L-80_0232 Opf, D=4.897 2222' LL 2222' 5.1/2' X 4-12" XO. ID= 3.9W _ C 2633' u-3I6'OV PI07 BKR FLO GLIAR D Minimum ID -2.45"@4692' BAKER FLO GUARD PATCH 4-112• TBG,12.60, L-80-0152 hpf, 1) 9518' CSG, 4010143.58! /478, _ 7798' 500-95 xis -95,D=&681 - PERFORATION SUMMARY REE LOG: Mff ACOLISMO ON 01126196 ANGLEAT TOP PBiF: 50" Q 11240' Note- Refer to Production DB for Wtorical perf data SIZE SPF INTERVAL OprYSgz SHOT SOZ 2-78" 4 11240-11246 C 09005199 7 6 11266 - 11278 C 04002f18 2-118' 4 11292- 11302 C QWW98 2-118" 4 11314 -11320 C 0227196 2.118• 4 11325- 11335 C 0227199 4-1/7 3 I 46 RK a 75517I8411I 46 I M,GMW I OMY RK I O 7566' 0-58" X 4-117 TNN F$BRT ROT. 7621' 4-1/7 I+S XN NIP. D= 3.72' 7821. NA -!3i aND FT/79767)771 958" MIOUT WI DOW Q 7798' L -0O N6CT..0152 DATE REV BY CDM.QJTS DATE RLV BY COMMENTS 06104/70 ROW 34 INITIAL COMPLEnON 0410WIS SERJMD AWERFS(MI04M8) 02160086 N18E SIDETRACK (BI.03A) 12117/18 MJJMD ADDED REF d BF 9.EV 10007115 J1.fd RLL®EVOTREVE R-L1G(1BN3/1 1107119 WMMU 5ET VITT ISO R.UG(01AW19 11/10/75 C LWAV SET FLOGUARD PAT17f (10N8f15) 05001/17 R18/ SET DSSSV PLUG(04rM17) 1023/17 ZVAMD RJLLED SSSV (10179117) N VICINITY OF TTL Q 7823' ON 98 - NEVER RECOVERED F I.AOEBAY LHR WELL: 01 -MA PERMIT No: 9952010 ARNo: 50.029-20363-01 NOR RISE 310' RL 81379 FWL BP Bploratloe tAba ta) TREE = 5X7L FWD 120 N43LFEAD= MLEVOY ACTUATOR= BAKER OKB. ELLV = 73' REE E LEV = 62.8' BF. ALV = 44.27 KOP= 3000' Max Angle = 51° @ 11059 Datum MD= 11064' Datum TVD = 88W SS ADDrF)ORkL 13-318' i (ASM PFORM4T10N CP@ 1729 CP @ 1938' 30• CONDUCTOR 157.5# 11 115' 20' CSG, 94#, H40, D -19.124" - 2000' iv 5-7/7' TBG, 17#, L-80, .0232 6pf, D = 4.897 2222' 13-318• CSG, 72#, "0 BUTT, D = 12 347' 2612' 4-1/2• BKR FLO GUARD PATCH, D= 2 45• (10118115) Minimum ID = 2.45" @ 4692' BAKER FLO GUARD PATCH =3958" 1-1 7644' XT 9-5/8' CSG, 40# / 43.5# 1147#, 7798' — S00-95 /RS -95, D=8.681" P89FORATION SUMMARY SAFETY NOTES: *TO SECURE WELL, PLUG MUST 01 -03A BE SET ABOVE PKR DUE TO HBBP TIW PKR SIZE BI PORTTPFISKPOSSiDRESTRICTIONIN4- INTERVAL 112" TBG FROM XN-NP @ 7621' TO TOP OF 4112- LNR SHOT I SQZ @ 7665'. CTU RAN 3.715" MILL TO 11340' 09130198. 4 RPV PROFILE NOWFUNCTIOWIL(05102/07)'"" O 1726' 13-3/B• OV HCR 2• 2026' 13-318' -DVPKR O 2208" 5-V2'HES HRQSVLN SSSV NP, D=4.562" 04/02/18 2222' 5-112- X 4-112• XO, D = 3.958• 4 2633' 13-318• DV PKR 9-5/8' CSG, 40# / 43.5# 1147#, 7798' — S00-95 /RS -95, D=8.681" P89FORATION SUMMARY REY LOG: DIGIT AODUSTLO ON 01/26196 ANGLE AT TOP P62F: 50° @ 11240' Note: Rafer to Production DB for hnioncal perf data SIZE SPF INTERVAL Opn/Sgz SHOT I SQZ 2-7/8' 4 11240- 11246 O 09/05/99 2• 6 11266 - 11278 O 04/02/18 2-118" 4 11292 - 11302 O 02229/96 2-118' 4 11314 - 1132D O 02/27/96 2-18' 4 11325 - 11335 O 02/27/96 412• FBTD E E YL9i GAS LFT MANDRB-S STI MD I TVD DEV TYPE I VLV I LATCH PORT DATE 1 3269 3262 15 MMG DMV RK 0 08110114 2 5926 5271 46 MMG DMY RK 0 08/10/14 3 7517 6411 46 MMG DMtt RK 0 10/13!02 7585'9-5/8• X 4-112" TW F66RTPCR D=4.00• 762V 4112• FES XN NP, D --3 72 - 7644' -141/2" WLEf, D= 3.956" 7623'VZEG F LMD (LOG 02122/27/96) 9-518• MLLOLIT WINDOW @ 7798' 847E REV BY COMMENTS DATE I REV BY I ODWAENTS 0&04(70 ROW 34 INITIAL COMPLETION 04/09/18 SETIJMD ADPERFS (04104118) 02/07196 NISE SIDETRACK(01-03A) 12/17118 JFIJJMD ADDED REE 8 BE E LEV 10107/15 JMG3(^U PILLED EVOTRIEVE FLUG(I 010311E 01107119WH SET AFT ISO FLUG(01/04/19) 11110/15 CJS/JMD SEF FLOGtARD PATCH (10I18/15) 05101117 RCB/SET DSSSV PLUG (04/30/17) 102N17 ZVIJMD FUELED DSSSV(10119117) N V ICNTIY OF TTL @ 7623' ON 98 - NB/ ER RECOVERED ID=3.958" 1-1 1 PRUIHOE BAY UNIT WELL: 01-03A PE ONo:'1952040 AR No: 50029-2006101 SEC 8, T10N, R15E, 310' R18 1379 FWL BP Exploration (Alaska) 9 •F— W./FZa V M -1s STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS JAN 2 5 2LI}3 1. Operations Performed Abandon ❑ Plug Perforations ❑ Fracture Stimulate ❑ Pull Tubing ❑ Operations shutdown 11 Suspend ❑ Perforate ❑ Other Stimulate ❑ Alter Casing ❑ Change Approved Program ❑ Plug for Rednll ❑ Perforate New Pool ❑ Repair Well ❑ Re-enter Susp Well ❑ Other: Secure well I Shad Term Isolation Plug 2. Operator Name: BP Exploration (Alaska), Inc 4. Well Class Before Work Development 0 Exploratory ❑ 5. Permit to Drill Number: 195-204 3. Address: P.O. Box 196612 Anchorage, AK 99519-6612 Stratigraphic ❑ Service ❑ 1 6. API Number. 50-029-20063-0100 7. Property Designation (Lease Number): ADL 028329 8. Well Name and Number: PBU 01 -03A 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 11500 feet Plugs measured 4670 feet true vertical 9141 feet Junk measured 11327 feet Effective Depth: measured 4670 feet Packer measured 7585 feet true vertical 4421 feet Packer true vertical 8456 feet Casing: Length: Size: MD: TVD: Burst: Collapse: Conductor 80 30" 22-102 22-102 880 Surface 1918 20" 22-1940 22-1940 1530 / 2320 52011500 Intermediate 2583 13-3/8" 19-2602 19-2602 4930 2670 Intermediate 7781 9-518" 17-7798 17-6603 81501682017510 5080 / 3330 / 4130 Production Liner 3854 4-1/2" 7646-11500 6498-9141 8430 7500 Perforation Depth: Measured depth: 11240-11335 feet True vertical depth : 8973-9034 feet Tubing (size, grade, measured and true vertical depth) 5-1/2" 17# x 4-1/2" 12.6#, L-80 15-7644 15-6496 Packers and SSSV (type, measured and 4-1/2" TIW HBBP-T Packer 7585 6456 true vertical depth) NO SSSV Installed 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 -MG Water -Bbl Casing Pressure Tubing Pressure Prior to well operation: 913 47640 87 0 994 Subsequent to operation: Shut -In 140 0 14. Attachments: (required per20 MC 25 070,25.071 &252M) 15. Well Class after work: Daily Report of Well Operations 0 Exploratory ❑ Development 0 Service ❑ Stratigraphic ❑ Copies of Logs and Surveys Run ❑ 16. Well Status after work: Oil 0 Gas ❑ WDSPL ❑ Printed and Electronic Fracture Stimulation Data ❑ 1 GSTOR ❑ WINJ ❑ WAG ❑ GINJ ❑ SUSP ❑ 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: 318-568 Authorized Name: Hibbert, Michael Contact Name: Hibbert, Michael Authorized Title: Well Interventions Engineer Contact Email: Michael. Hibberbl%BP.com Authorized Signature: �•y / Date: '/Z .' Contact Phone: +1 907 564 4351 Form 10404 Revised 04/2017 A4&R4Z i4Rj4 RBDM EB 0 12016 Submit Original Only of Well DRIFTED TBG W/ 10'x 3.70" DUMMY WHIPSTOCK & 3.50" LIB, TAGGED PATCH @ 4692' MD.(impression of fishneck) LRS LOADED TBG W/ 280 BBLS OF CRUDE. SET 4-1/2" WFD ISO PLUG M.E. @ 4672' MD, TOP OF PLUG @ 4670' MD. LRS PERFORMED PASSING MIT -T TO 2500psi. 'WELL S/I ON DEPARTURE. DSO NOTIFIED OF WELL STATUS'*' Twr:F= 5X71 FMC 120 WELLHEAD= MCEVOY ACTUATOR= BAKB2C OKB. ELEV = 73' Rff ELEV = 62.8' BF. ELEV = 44.22' KOP= 3000' Max Angle = 51" @ 11059' Datum MD= 11064' Datum ND = 8800' SS CASING WOFWT10N CP @ 1729 CP TN 1938' CONDUCTOR 157.5# 01 0 3A SAFETY NOTES: *TO SECURE WELL, PLUG MUST BE SET ABOVE PKR DUE TO HBBP TIW PKIR BLEED PORT TP FISH POSS ID RESTRICTION IN 4- 112" TBG FROM XN-NP @ 7621' TO TOP OF 4-1/2" LN2 @ 7665'. CTU RAN 3.715" M ILL TO 11340'09130198. BPV PROFILE NOMRNCTIONAL (05102/07) — 1726' t3 -3B' w PKR 2026' 13-3/8.OV PKR 2209' 5-1/2' HES HR0 SV LN SSSV NP. ID = 4.562 20" CSG, 94#, H40, D=19.124" I- 2000' V 17#, L-80, .0232 bpf, D = 4.892" 2222' 2222' 5-1/2• X 4-1/2- XO, D = 3.958• 2633' t3 -3/b' W PKR iG, 72#, 1980 BUTT, D = 12.347" 2612' BKR FLO GUARD PATCH, ID= 2.45" I -J 4692' - 4724' Minimum ID = 2.45" @ 4692' BAKER FLO GUARD PATCH 4-1/2' TBG, 12.6#, L-80, .0152 bpf, D = 3.958" I 7644' 9-5/8" X 7• BAKER ZXP FKR ID = 6.313" 7646' 9-5/8" CSG, 40# 143.5# 1 /47#, 7798' — S00-95 /RS -95, D = 8.681" PHRFORATION SLRAM1RY REF LOG: DIG(T ACOUSTLO ON 01/26/96 ANGLE AT TOP PERF: 50` @ 11240' NateRefer to Production DB for historical pert data SIZE SPF 14TEWAL Opn/Sgz SHOT SOZ 2-718" 4 11240 - 11246 O 09/0559 DMY 2" 6 11266 -11278 O 04102/16 5271 2-11W 4 11292 -11302 0 02/2956 08/10/14 2-11W 4 11314 -11320 O 0272756 MMG 2-18" 4 11325-11335 O 022756 1 4670' 1 (SAS I FT MANDRR S ISTI MD TVD DEV TYPE VLV LATCH PORT DATE 1 3269 3262 15 MMG DMY RK 008/10/14 2 5926 5271 46 MMG DMY RK 0 08/10/14 3 7517 6411 46 MMG DMY RK 0 10/13/02 1b"- 1-1.9-5/8" X 4-1/2" TTN HBBP-T R(R, D = 4.00" 762'1' 4-1/2" FES XN NP, D = 3.72" { 764W 4-1/2" WLEG, D= 3.958• 7623' WLEG ELMD(LOGGED 0227f96) 9-5/6" MLLOUT WINDOW @ 7798' FISH - 7" OF VIDEO CAMERAFTTL @ 623 -EFT N Wf3L N V ICNTTI' OF TIL @ 7623' ON 07/24/98 -NEVER RECOV EED FBTD H 11410' 14-1/2- LNR 12.6#, L-80 NSCT, _0152 bPf, D=3.958• I DATE REV BY COMMENTS DATE REV BY COMM84TS 06104170 ROW 34 INITIAL COMPLETION 04/09/18 SEF/JA,D ADPEWS(04/04/18) 02/07196 MISE SIDETRACK(01-03A) 12/17/18 JNUJMD ADDED REF B BF ELEV 10/07/15 JWJMD FILLED EVOTREVE PLUG, (10103/1 01/07/19 MTHJM0 SEF WFT GO PLUG (01104/19) 11/10/15 CJS/JMD SEF FLOGUARD PATCH (10/18/15) 05/01/17 RCE1/JMD SEF DSSSV PL11G (04/30/17) 10/23117 ZV/JMD PULLED DSSSV(10/19/17) PRIDHOE BAY UNT WELL: 01-03A P84AT No '1952040 API No: 50-029-20063-01 SEC -8, T10K R15E, 310' FN_ 8 1379 FWL BP Exploration (Alaska) _lip 1 ' • STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION RECEIVEO REPORT OF SUNDRY WELL OPERATIONS )) /t 1. Operations PerformedR 2 4 2018 Abandon 0 Plug Perforations 0 Fracture Stimulate 0 Pull Tubing 0 Operations shutdown ❑', Suspend 0 Perforate I1 Other Stimulate ❑ Alter Casing 0 Change A re GG C Plug for Redrill 0 Perforate New Pool 0 Repair Well 0 Re-enter Susp Well 0 Other: 0 2. Operator Name: BP Exploration(Alaska),Inc 4. Well Class Before Work 5. Permit to Drill Number. 195-204 3. Address: P.O.Box 196612 Anchorage, Development ® Exploratory 0 AK 99519-6612 Stratigraphic 0 Service ❑ 6. API Number: 50-029-20063-01-00 7. Property Designation(Lease Number): ADL 028329 8. Well Name and Number: PBU 01-03A 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 11500 feet Plugs measured none feet true vertical 9141 feet Junk measured 11327 feet Effective Depth: measured 11410 feet Packer measured 7581,7642 feet true vertical 9083 feet Packer true vertical 6453.6495 feet Casing: Length: Size: MD: ND: Burst: Collapse: Structural 80 30" 21-101 21-101 880 0 Conductor 1920 20" 16-1936 16-1936 1530/2320 520/1500 , Surface 2575 13-3/8" 16-2602 16-2602 4930 2670 Surface 151 16" 1709-1860 1709-1860 1640 670 Intermediate 7811 9-5/8" 15-7798 15-6603 8150/6720/7510 5080/3330/4130 Liner 3854 4-1/2" 7642-11496 6495-9138 8430 7500 Perforation Depth: Measured depth: 11240-11335 feet True vertical depth: 8973-9034 feet Tubing(size,grade,measured and true vertical depth) 5-1/2"17#x4-1/2"12.6#L-80 14-7639 14-6493 Packers and SSSV(type,measured and 4-1/2"TIW HBBP-T Packer, 7"Baker ZXP Top Packer 7581,7642 6453,6495 true vertical depth) 5-1/2"HES HRQ SCSSV 2209 2209 12.Stimulation or cement squeeze summary: Intervals treated(measured): Treatment descriptions including volumes used and final pressure: , SCANNED JUN 1 1 2 18 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation: 743 25152 50 225 1028 Subsequent to operation: 1077 34996 53 270 1028 14.Attachments:(required per 20 AAC 25.070.25.071,8 25.283) 15.Well Class after work: Daily Report of Well Operations 0 Exploratory ❑ Development lI Service 0 Stratigraphic 0 Copies of Logs and Surveys Run 0 16.Well Status after work: Oil Q Gas 0 WDSPL 0 Printed and Electronic Fracture Stimulation Data 0 GSTOR ❑ WINJ 0 WAG 0 GINJ 0 SUSP 0 SPLUG 0 17.I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O.Exempt: N/A Authorized Name: FINN OESTGAARD Contact Name: FINN OESTGAARD Authorized Title: PRODUCTION ENGINEER Contact Email: FINN.OESTGAARD(ci3BP.COM f Authorized Signature: mo w_ ( _u.. Date: /L.i l id Contact Phone: +1 907 564 5026 1/7-1-- may /4 / Form 10-404 Revised 04/2017 1' / 1-" 67 f 18 RBD Submit Original Only • Alaska Oil and Gas Conservation Commission 333 West Seventh Avenue Anchorage, AK 99501-3572 RE: BP Exploration (Alaska), Inc. Report of Sundry Well Operations Summary April 23, 2018, To Whom it May Concern: Attached please find the Report of Sundry Well Operations for the addition of perforations in well 01-03A, PTD #195-204. Sincerely, BP Exploration (Alaska) Inc. P.O. Box 196612 Anchorage, AK 99519-6612 Attachment: - Form 10 404 BP Exploration (Alaska), Inc. P.O. Box 196612 Anchorage,AK 99519-6612 • Daily Report of Well Operations PBU 01-03A ACTIVITYDATE SUMMARY ***WELL FLOWING ON ARRIVAL***(SLB E-LINE DRIFT/PERFORATING) SHUT IN, INITIAL T/I/O = 1800/250/250 PSI RIH W/JARS/20'x2.0" DMY GUN, MAX OD=2.29" DRIFT CLEANLY TO 11320', DID NOT TAG BOTTOM RIH W/12'x2.0" PJ OMEGA HSD, 6 SPF, 60° PHASE, MAX OD=2.31" (GUN SWELL IN GAS) CCL STOP DEPTH = 11254.7', CCL TO TOP SHOT=11.3' PERFORATED INTERVAL 11266'-11278' ALL PASSES TIED INTO SLB JEWELRY LOG DATED 27-FEB-1996. WELL LEFT SHUT IN UPON DEPARTURE FINAL T/I/0=2540/175/0 PSI 4/2/2018 ***JOB COMPLETE, PAD OP NOTIFIED TO POP*** Fluids Summary Bbls Type no fluids VP • , TRS_ • 5X7L FMC 120 SAFETY NOTES:*TO SECURE WELL,PLUG MUST MCEV ACTUATOR= BAKE Y " 1 -03A BE SET ABOVE PKR DUE TO BLEED PORE TP FIS OSS DBRESTRICTIOONN 1N 14 ACTUATOR= BAKER C B�F. B_EV= 73' 1/2"TBG FROM XN-NIP ti 7621'TO TOP OF 4-1/2"IILNR ADDITIONAL 13-3/8' I I @ 7665'.CTU RAN 3.715"MILL TO 11340'09/30/98. """ CASINGKOP= 3000' CASING INFORMATION BPV PROFILE NON-FUNCTIONAL(05/02107)"" Max Angle= 51"@ 11059' CP @ 1729' — — Datum M3= 11064' CP @ 1938' — 1726' H13-3/8"DV PKR Datum TVD= 8800'SS _ _ 2025' H 13-3/8'DV PKR 30"CONDUCTOR,157.5# H 116' 2209' H 5-1/2"HES HRQ SV LN SSSV NP,D=4.562" CO 20"CSG,94#,1-40,D=19.124' —I 2000' 5-1/2"TBG,17#,L-80,.0232 bpf,D=4.892" — 2222' / 9999' —5-1/2'X 4-1/2"XO,D=3.958" 13-3/8"CSG,72#,N-80 BUTT,D=12.347" —I 2612' , 11 1 2633' H 13-3/8"DV PKR 4-1/2"BKR FLO GUARD PATCH,D=2.45' —I 4692'-4724' $ GAS LFT MANDRELS (10/18/15) $ $ ST MD TVD DEV TYPE VLV LATCH PORT DATE I- 1 3269 3262 15 MNG DMY RK 0 0 /10/14 2 5926 5271 46 MMG DMY RK 0 08/10/14 3 7517 6411 46 MNG DMY RK 0 1/13/02 Minimum ID =2.45" @ 4692' BAKER FLO GUARD PATCH S ?S 7 H9-5/8"X4-1/2"TAN HBBP-T PKR,D=4.00' I I 7621' —14-1/2"FES XN NP,D=3.72" 4-1/2'TBG,12.6#,L-80,.0152 bpf,D=3.958' —I 7644' / \ 7644' —141/2"WLEG,D=3.958' 9-5/8'X 7'BAKER ZXP PKR,13=6.313' —I 7646' \ 21 7623' —I WLEG ELM)(LOGGED 02/27/96) 9-5/8"MLLOUT WINDOW @ 7798' 9-5/8"CSG,40#/43.5#/147#, —I 7798' ? RSH-7"OF V DEO CAMERA LEFT N S00-95 /RS-95,D=8.681" %% .681" , WELL N VICINITY OF TTL @ 762310N 07/24/98-NEVER RECOVERED PERFORATION SUMMARY , REF LOG: DIGIT ACOUSTLO ON 01/26/96 , ANGLE AT TOP FBRF:50°@ 11240' % Note:Refer to Production DB for historical perf data SIZE SPF MBRVAL Opn/Sqz SHOT SQZ rio.. 2-7/8" 4 11240-11246 0 09/05/99 ,�� �, i 2" 6 11266-11278 0 04/02/18 PBTD —I 11410' �� 2-1/8" 4 11292-11302 0 02/29/96 2-1/8" 4 11314-11320 0 02/27/96 2-1/8" 4 11325-11335 0 02/27/96 I , 4-1/2'LNR,12.6#,L-80 NSCT,.0152 bpf,D=3.958" —I 11500' DATE REV BY COMMENTS DATE REV BY COMMENTS PRUDHOE BAY UNIT 06/04/70 ROW 34 INTIAL COMPLETION 10/07/15 JMG/JfMD PULLED EVOTREVE RUG(10/03/15) WB-L: 01-03A 02/07/96 N18E SIDETRACK(01-03A) 11/10/15 CJS/JMJ SET FLOGUARD PATCH(10/18/15) PERMIT No:'1952040 09/18/12 RKT/JM}GLV C/O(09/14/12) 05/01/17 RCB/JM3 SET DS-RSV PLUG(04/30/17) AR No: 50-029-20063-01 08/15/14 SWC:!PJC GLV C/O(08/10/14) 10/23/17 ZV/JWD PULL®DSSSV(10/19/17) SEC 8,T1 ON,R15E,310'FNL&1379 FWL 07/28/15 JMMVJND SET EVOTREVE PLUG(06/29/15) 04/09/18 SET/JM)ADPERFS(04/04/18) 09/10/15 FO/JMD MSC WBS EDITS BP Exploration(Alaska) • • Wallace, Chris D (DOA) From: AK, GWO Well Integrity Engineer <AKGWOWellSiteEnginee@bp.com> Sent: Friday, October 13, 2017 2:06 PM To: AK, GWO SUPT Well Integrity;AK, OPS FS1 OSM;AK,OPS FS1 Facility OTL;AK, OPS FS1 Field OTL;AK, OPS FS1 DS Ops Lead;AK, OPS FS1 DS1 Operator;AKOpsProdEOCTL; Cismoski, Doug A; Daniel, Ryan;AK, RES GPB West Wells Opt Engr;AK, RES GPB East Wells Opt Engr;AK, OPS EOC Specialists;AK, OPS PCC Ops Lead;AK, OPS Prod Controllers; G GPB FS1 Drillsites; Oestgaard, Finn; Regg,James B (DOA); Quick, Michael 1 (DOA) Cc: AK, GWO DHD Well Integrity;AK, GWO Projects Well Integrity;AK, GWO Completions Well Integrity;AK, OPS FF Well Ops Comp Rep;Wallace, Chris D (DOA);AK, GWO SUPT Special Projects; Kilfoyle,Jeffery A;AKIMS App User; Dempsey, David G; Hibbert, Michael;Janowski, Carrie; Montgomery,Travis J; Munk, Corey; Obrigewitch, Beau; Pettus,Whitney; Sternicki, Oliver R;Worthington,Aras J Subject: OPERABLE: Producer 01-03 (PTD#1952040) Engineering Analysis of Wellhead Complete - Mechanically Safe to Operate All; Producer 01-03 (PTD#1952040)was shut in on 04/23/17 and proactively made Not Operable due to having a McEvoy Generation 1 wellhead and was thought to be similar in well design and construction as 02-03. An engineering analysis of the McEvoy Generation 1 wellhead and construction has been completed that was a result of the unplanned release on well 02-03. We have since determined that 01-03 does not share the same completion risks associated with the failure on 02-03. This well is mechanically safe with competent barriers to operate. This well has been classified as Operable. Plan Forward: 1. Slickline: Pull tubing tail plug. Please respond with any questions. Matt Ross (Alternate: Josh Stephens) Well Integrity Engineering SCANNED FEB 2 1208 Office 907-659-8110 Cell 907-980-0552 Harmony 4530 From: A , - 0 SUPT Well Integrity Sent: Sunday, Apri 017 7:09 AM To: AK, OPS FS1 OSM; AK, •- Facility OTL; AK, OPS FS1 Field OTL; AK, OPS FS1 DS Ops Lead; AK, OPS FS1 DS1 Operator; AKOpsProdEOCTL; Cismoski, 1,•.• • Daniel, Ryan; AK, RES GPB West Wells Opt Engr; AK, RES GPB East Wells Opt Engr; AK, OPS EOC Specialists; AK, OPS PC •: ead; AK, OPS Prod Controllers; G GPB FS1 Drillsites; Oestgaard, Finn; 'Regg, James B (DOA) (jim.regg@alaska.gov)' (jim.r-•:(ii-laska.gov); michael.quick@alaska.gov Cc: AK, GWO DHD Well Integrity; AK, GWO Projects Well Integrity; • WO Completions Well Integrity; AK, GWO Well Integrity Engineer; AK, GWO SUPT Well Integrity; AK, OPS FF Well Ops Com• •-•• 'chris.wallace@alaska.gov' (chris.wallace@alaska.gov); AK, GWO SUPT Special Projects; Kilfoyle, Jeffery A; AKI` • •• User; Dempsey, David G; Hibbert, Michael; Janowski, Carrie; Montgomery, Travis J; Munk, Corey; Obrigewitch, Beau; • , s, Whitney; Sternicki, Oliver R; Worthington, Aras J Subject: NOT OPERABLE: Producer 01-03 (PTD #1952040) McEvoy Generation 1 Wellhead 1 PTC /95 A a1' Loepp, Victoria T (DOA) From: Quick, Michael J (DOA) Sent: Sunday,April 23, 2017 9:35 AM To: Foerster, Catherine P(DOA); Loepp,Victoria T (DOA);Schwartz, Guy L(DOA);Wallace, Chris D (DOA); DOA AOGCC Prudhoe Bay Subject: Fwd: NOT OPERABLE: Producer 01-03 (PTD#1952040) McEvoy Generation 1 Wellhead Follow Up Flag: Follow up n ', Flag Status: Flagged SCA** FYI. BP identified and shut in 5 wells with the same wellhead that is on 02-03 from the well control event last week. Begin forwarded message: From: "AK,GWO SUPT Well Integrity"<AKDCWelllntegrityCoordinator@bp.com> Date:April 23, 2017 at 7:08:55 AM AKDT To: "AK,OPS FS1 OSM"<AKOPSFSIOSM@bp.com>, "AK,OPS FS1 Facility OTL" <AKOPSFS1FacilityOTL@bp.com>, "AK,OPS FS1 Field OTL"<AK OPSFS1FieldOTL@bp.com>, "AK,OPS FS1 DS Ops Lead"<AKOPSFS1DSOpsLead@bp.com>, "AK, OPS FS1 DS1 Operator" <AKOPSFS1DS1Operator@bp.com>,AKOpsProdEOCTL<AKOPSPCCEOCTL@bp.com>, "Cismoski, Doug A" <CismosDA@BP.com>,"Daniel, Ryan"<Ryan.Daniel@bp.com>, "AK, RES GPB West Wells Opt Engr" <AKRESGPBWestWellsOpt@BP.com>, "AK, RES GPB East Wells Opt Engr" <AKRESGPBEastWellsOptEngr@bp.com>, "AK,OPS EOC Specialists"<AKOPSEOCSpecialists@bp.com>, "AK,OPS PCC Ops Lead" <AKOPSPCCOpsLead@bp.com>, "AK,OPS Prod Controllers" <sewellcr21@bp.com>, "G GPB FS1 Drillsites"<ggpbfsldrillsites@BP.com>, "Oestgaard, Finn" <Finn.Oestgaard@bp.com>, "'Regg,James B(DOA)(iim.regg@alaska.gov)'(jim.regg@alaska.gov)" <jim.regg@alaska.gov>, "michael.quick@alaska.gov"<michael.quick@alaska.gov> Cc:"AK,GWO DHD Well Integrity"<AKD&CDHDWeIIIntegri@bp.com>, "AK,GWO Projects Well Integrity"<AKDCProiectsWellIntegrityEngineer@bp.com>, "AK,GWO Completions Well Integrity" <AKDCWLCompletionsSupt@bp.com>, "AK,GWO Well Integrity Engineer" <AKGWOWeIISiteEnginee@bp.com>, "AK, GWO SUPT Well Integrity" <AKDCWeIIIntegrityCoordinator@bp.com>, "AK, OPS FF Well Ops Comp Rep" <AKOPSFFWeIIOpsCompRep@bp.com>, "'chris.wallace@alaska.gov' (chris.wallace@alaska.gov)" <chris.wallace@alaska.gov>, "AK,GWO SUPT Special Projects" <akdcWellservicesoperationssuperintendent@bp.com>, "Kilfoyle,Jeffery A"<Jeffery.Kilfoyle@bp.com>, AKIMS App User<akimsuser.service@bp.com>, "Dempsey, David G"<David.Dempseyl@bp.com>, "Hibbert, Michael"<Michael.Hibbert@BP.com>, "Janowski,Carrie"<Carrie.lanowski@bp.com>, "Montgomery,Travis 1"<Travis.Montgomery@bp.com>, "Munk,Corey"<Corey.Munk@bp.com>, "Obrigewitch, Beau"<BEAU.OBRIGEWITCH@bp.com>, "Pettus,Whitney"<Whitney.Pettus@bp.com>, "Sternicki,Oliver R"<Oliver.Sternicki@bp.com>, "Worthington,Aras J"<Aras.Worthington@bp.com> Subject:NOT OPERABLE:Producer 01-03(PTD#1952040)McEvoy Generation 1 Wellhead All, Producer 01-03 (PTD#1952040)has a McEvoy Generation 1 wellhead.While the cause of the unplanned release on well 02-03 is investigated,all other wells in GPB with this wellhead must be shut in.01-03 is reclassified as Not Operable. The complete list of affected wells is as follows: • 01-03 • • 01-06 • 04-01 • 04-05 • 04-06 Thanks, Adrienne McVey Well Integrity Superintendent—GWO Alaska (Alternate:Jack Lau) 0:(907)659-5102 C:(907)943-0296 H:2376 2 Wallace, Chris D (DOA) From: AK, D&C Well Integrity Coordinator <AKDCWeIlIntegrityCoordinator@bp.com> Sent: Saturday, November 14, 2015 12:59 PM To: AK, OPS FS1 OSM;AK, OPS FS1 Facility OIL; AK, OPS FS1 Field OTL; AK, OPS FS1 DS Ops Lead;AK, OPS PCC EOC IL;AK, D&C Well Services Operations Superintendent;AK, D&C Wireline Operations Superintendent; Cismoski, Doug A; Daniel, Ryan; AK, RES GPB West Wells Opt Engr;AK, RES GPB East Wells Opt Engr; AK, OPS EOC Specialists;AK, OPS PCC Ops Lead; AK, OPS Prod Controllers; G GPB FS1 Drillsites; Oestgaard, Finn; AK, OPS FS1 DS1 Operator; 'chris.wallace@alaska.gov' Cc: AK, D&C DHD Well Integrity Engineer;AK, D&C Well Integrity Coordinator;AK, D&C Projects Well Integrity Engineer; AK, OPS FF Well Ops Comp Rep; Sternicki, Oliver R; Morrison, Spencer; Sayers, Jessica; Dickerman, Eric; Regg, James B (DOA) Subject: OPERABLE: Producer 01-03A (PTD #1952040) MIT-IA Passed Post Patch Set All, Producer 01-03A (PTD#1952040) passed a MIT-IA on October 21, 2015 after setting a tubing patch to repair tubing x inner annulus communication. The outer annulus build up rate was—20 psi per day which is considered manageable by bleeds. The passing MIT-IA confirms two competent barriers in the wellbore. The well is reclassified as Operable. Please call with any questions or concerns. Thank you, Kevin Parks (Alternate: Whitt, t, r;, 1 nibBP Alaska-Well Integrity Coordinator S`Mp��� MAY 1 GVVGlobal Welds Organization Office: 907.659.5102 WIC Email:AKDCWeIlIntegrityCoordinator(a@bp.corn From: AK, D&C Well Integrity Coordinator Sent: Friday, October 23, 2015 12:54 PM To: AK, OPS FS1 OSM; AK, OPS FS1 Facility OTL; AK, OPS FS1 Field OTL; AK, OPS FS1 DS Ops Lead; AK, OPS PCC EOC TL; AK, D&C Well Services Operations Superintendent; AK, D&C Wireline Operations Superintendent; Cismoski, Doug A; Daniel, Ryan; AK, RES GPB West Wells Opt Engr; AK, RES GPB East Wells Opt Engr; AK, OPS EOC Specialists; AK, OPS PCC Ops Lead; AK, OPS Prod Controllers; G GPB FS1 Drillsites; Oestgaard, Finn; AK, OPS FS1 DS1 Operator; 'chris.wallace@alaska.gov' Cc: AK, D&C DHD Well Integrity Engineer; AK, D&C Well Integrity Coordinator; AK, D&C Projects Well Integrity Engineer; AK, OPS FF Well Ops Comp Rep; Sternicki, Oliver R; Morrison, Spencer; Sayers, Jessica; Dickerman, Eric; Regg, James B (DOA) (jim.reqg@alaska.gov) Subject: UNDER EVALUATION: Producer 01-03A (PTD #1952040) MIT-IA Passed Post Patch Set All, Producer 01-03A(PTD#1952040) passed a MIT-IA on October 21, 2015 after setting a tubing patch to repair tubing x inner annulus communication. The passing test confirms two competent barriers in the wellbore. The well was reported to have sustained outer annulus casing pressure above MOASP on June 27, 2015. The well is reclassified as Under Evaluation and may be brought on line to facilitate the evaluation. STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMIS N • REPORT OF SUNDRY WELL OPERATIONS 1. Operations Performed Abandon ❑ Plug Perforations 0 Fracture Stimulate 0 Pull Tubing 0 Operations shutdown 0 Suspend ❑ Perforate 0 Other Stimulate 0 Alter Casing ❑ Change Approved Program 0 Plug for Redrill 0 Perforate New Pool 0 Repair Well m Re-enter Susp Well ❑ Other:Tubing Patch 1Z1 2. Operator Name: BP Exploration(Alaska),Inc 4. Well Class Before Work 5. Permit to Drill Number: 195-204 • 3. Address: P.O.Box 196612 Anchorage, Development D Exploratory ❑ • AK 99519-6612 Stratigraphic 0 Service ❑ 6. API Number: 50-029-20063-01-00 7. Property Designation(Lease Number): ADL 0028329 • 8. Well Name and Number: PBU 01-03A o 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 11500 • feet Plugs measuredE feet RE � true vertical 9141 • feet Junk measured 11327 feet NOV Effective Depth: measured 11410 feet Packer measured 7581 feet N t'V 1 2 2015 true vertical 9083 feet Packer true vertical 7641.72 feet AOGCC Casing: Length: Size: MD: TVD: Burst: Collapse: Structural 80 30"157.5#B Grad 21-101 21-101 Conductor See Attachment See Attachment See Attachment See Attachment See Attachment See Attachment Surface See Attachment See Attachment See Attachment See Attachment See Attachment See Attachment Intermediate See Attachment See Attachment See Attachment See Attachment See Attachment See Attachment Production Liner 3854 4-1/2"12.6#L-80 7642-11496 6495-9138 8430 7500 Perforation Depth: Measured depth: 11240-11246 feet 11292-11302 feet 11314-11320 feet 11325-11335 feet True vertical depth: 8973-8977 feet 9007-9013 feet 9021-9025 feet 9028-9034 feet Tubing(size,grade,measured and true vertical depth) See Attachment See Attachment See Attachment Packers and SSSV(type,measured and See Attachment See Attachment See Attachment true vertical depth) 12.Stimulation or cement squeeze summary: Intervals treated(measured): Treatment descriptions including volumes used and final pressure: SC NP ; FEB 0 2C th 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation: 803 30684 74 820 934 Subsequent to operation: 1551 10501 16 840 924 14.Attachments:(required per 20 AAC 25.070.25.071,&25.283) 15.Well Class after work: 1 Daily Report of Well Operations ® Exploratory 0 Development IJ Service 0 Stratigraphic ❑ Copies of Logs and Surveys Run 0 16.Well Status after work: Oil El • Gas 0 WDSPL 0 Printed and Electronic Fracture Stimulation Data 0 GSTOR ❑ WINJ ❑ WAG 0 GINJ 0 SUSP ❑ SPLUG 0 17.I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O.Exempt: N/A Contact Catron,Garry R(Wipro) Email Garry.Catron@bp.com Printed Name Catron,Garry R(Wipro) Title PDC Principal Engineer Signature Phone +1 9075644424 Date 11/11/15 Form 10-404 Revised 5/2015 J/7 01�1 �� 1��J tZ 15— /,' RBDMS f1� L J Submit Original Only a) o 0 0 0 0 0 0 0 0 0 0 0 cN O N r N- D M M 00 O m O '— N M N Lo M d' Lo ti CO I- U N o 0 0 0 0 0 0 0 0 0 0 0 0 M N C0 M LC) N '— LU M v- M 7 Cp LU M O) CO O) c- 00 Ln ' r- Nr m — = N r- cf 00 m 00 00 I- 00 ao Co 6) O N M O N CO N- M M O CO O Ln co N- O) co C) O) f- CO CO CA O c- CA c- N 't c- c- c- N r CO CO CO O) N CO • I , , I I I I I I I I , H - 0) O 0- 000111 - O N- cCCO O N Ln N M I� O) V .- c— CO 00 CO N w c--- M (DO) ON - 1- O DooCA M O M O LC) O) O= m O) N- 00 CO O) O) 0 N O r r r N r O• 0 - Nr Cq 00 O — CO M CO O N Ln N Off) (3) N �r N r I� O) O . CO � M � � N O SID aLo asCD LU co C oo , O 00 00 Ur .TLX' Z ZW ° 0cn � J00 J O 00 = *k = * W � UW *k k (� l * M r LC) I- *k LL N N • W U O M (Ni M - - •• 7 - CV N Lo OV c- O M CO M a0 00 Co0\0 7 O N V O) O L r+ CO 01 CD CO CD CV CD O N c- W N M CO O) 0- L41 O N d 00 w CO - CD O) O O = OMD N 41 J W W W W o w 0 0 WW < < < < o D1- 1-' W W W0000 O 1- ° ° 000 U DOOLLIi_ u_ W W W W c _ZZ_ w Z Z W W W W W W W W m m HOODDDt- � � Z » CDUUu) Cl) Cl) ZZZZ � � � • • Packers and SSV's Attachment PBU 01-03A SW Name Type MD TVD Depscription 01-03A TBG PACKER 7580.71 6452.83 4-1/2" TIW HBBP-T Packer 01-03A PACKER 7641.72 6494.83 7" Baker ZXP Top Packer II • Oc Q < i o I- ~U) w 0 Q v —O Qrn <I- cO c .§v _c) O z = • a) ozs Ln cri Lf) w U) H ❑ L -n M O Z U I— w Q> < O W W CO w < u)1 J J J W (n - (n 0 10 t O w O n @ W a N W RS ` @ z < a) O ' m 20 J J Q � � Pp- W0-• Q _ U) W- I- HI- 0 00 Z W � O 0 .. 0-o W J H I- W in N .- O in 0 Q Q Q 2 < o 0 ry r o N c� I` O O o O 0 W' U 0 ❑ c O) II N OM . oZ II i Lu a w a wl— 1— 00) Cu � orS N n � O F- � � J = Z � 2ia ,- C a) O N < .._) W ❑ LL I— W r0 II :17.•• CK o w CT 0 8- U W W U U m W m W V _ <CU cpm N II H ❑ m Z IU � -I -/ COto L 2 N- - a� a) < 0 J z ~ c() o Q eL a) u_ C. co 0 = aria U ~ W Oa Y o . W o) 00 < m a� oM W W OW Z ❑W Ya 0 o ' cn O .S Ui c M CM X J — J � V) a > � * * Q — W Maw a E � s TD O rn M W LL W > U * Li Z Cif L0rn • a _o � YwQ IL � za = a_ Lnp W I— O co II C g r N U) Z m ° 0 II F- O e - OO ❑ oa > °0 QW02 WN1- 2a0 2 U) JO v .6 c OM *waa5 civ)• oQNu_ ¢ UO � aZQ w 2 ,-m : m .c E < CD J > 2w n II u • . > c� JU) c62toD •0 � c000 � i c,_ 4- HI > z E w E Ei_ V > ZzO X4D0 v • wMol Eao E0 >' u) a) a) Z II E � O � Nrn � w WvII„, N , � xs p Q > Do � o �: � OpQww � � F- � Y U II 2- 21-) � � O Z W o - o Z Q W U 2 W OU) N- cn � .:`' M � OzOO >> ZZLLN 11 LH0 j $ Q a. W M O U) O >> *k Q a a 0 Z o 0 2 - � N II N M C = O m > Z Z m _i - Y `s ❑ 1— 0 0 0) 0 n (nNN Jcnp O ow - 0000 ON L, cna0a ( r � m J 7 J .- _ V J ♦- Z U U _H O X Z m O m F— J 0 U) J V J O .s J J ❑ - m m I- "' w I- O r- J r - �- J- LLO � UO .) cpQ2OOZI- WawJJQO .-c (N,,,, vi a. ❑ : F- @�c>nF- i W : zccn1- : « FeF- U) wmec -JUUL: H o2 U W Q cn cn Lo cn cn ❑ r o 0 o 0 0 0 N N N N N N (` co ,- 5 > V co - r r N P o O O O O O r r r r r ,- 0 U Q IHI±= 5XJL FMC 120 • S NOTES:'TO SECURE WELL,PLUG MUST WELLFEAD= MCEVOY 0 1 _0 3 A BE ABOVE PKR DUE TO FEW 71W PKR ACTUATOR= BAKER C BLEED PORT TP ASH.POSS ID RE5TRICT1ON IN 4- OKB.ELEV= 73' BF.HSV= ? 1/2"TBG FROM XN-PIP a 7621'TO TOP OF 4-1/2" R LN ADDITIONAL 13-3/8" I I Q 7665'.CTU RAN 3.715"MILL TO 11340'09130/98. KOP= 3000' CASNG NFORMATION BPV PRORLE NON-FUNCTIONAL(05/02/07)e. Max Angle= 51°( 11059' CP a 1729' [)alien MD= 11064' Cp 1938. 1726' —13-3/8'DV PKR Datum ND= 8800'SS i ..... — 2025' H 13-3/8'LAI Fi(R 30'CONDUCTOR, 157.5# H 115 ( ® 2209' —5-1/2'I-ES FRO SV LN SSSV NP,D4.567 = 20'CSG,94#,14-40,D=19.124' - 2000' / r--------'.5-1/2"TBG, 17#,L-80,.0232 bpf,ID=4.892" h 79Y1' / 2227 —X1/2"X 412"XO,D=3.958' —. — 2533' —13-3/8"DV PKR 13-3/8"CSG,72#,N-80 BUTT,D=12.347" — 2617 I 11 4-12"BKR FLO GUARD PATCH,D=2.45' — 4692'-4724' GAS LFT MANDRELS (10/18/15) a 2 ST MD ND DEV TY FE VLV LATCH FST DATE Li ' 1 3269 3262 15 MMG DMY RK 0 08/10/14 2 5926 5271 46 MNG DMY RK 0 08/10/14 3 7517 6411 46 Ivf,IG DMY RK 0 10/13/02 g >‹, 7585' —19-5/8'X 4-1/2"TNV IABP-T FXR ID=4.00" Minimum II) =3.726" a@ 7621' 1 1 7621' —4-1/2'FES XNMP,D=3.72" 4-1/2" HES XN NIPPLE 4-1/7 TBG,12.6#,L-80,.0152 bpf,D=3.958" —1 7644' / \ 1 7644' —4-1/2"W. 3.D=3.958' 9-5/8"X T BAKER ZXP FKR, =6.313' — 7646' aN A 7623' —WLEG ELME)(LOGGED 02/27/96) J 9-5/8"CSG,40#/43.5#/147#, — 7798' I 1 500-95 /12S-95,D=8.681' 9-5/8-hiLOUT W>rDOW @ 7798' JI ? --FISH-7'OF VIEO CAMERA LEFT IN 4Nf3L N VICA#TY OF TTL r 7623'ON PERFORATION SUMMARY , 0724/98-NEVER RECOVERED REF LOG: C*GfT ACOUSTLO ON 01/26/96 ANGLE AT TOP FERF:50°@ 11240' Ibte:Refer to Production DB for historical perf data % SIZE SPF NTE?/AL Oprr/Sgz SHOT SOZ 2-7/8" 4 11240- 11246 0 09/05/99 i��t 2-1/8" 4 11292- 11302 0 02/29/96 olio 2-1/8' 4 11314-11320 0 02/27/96 FBTD — 11410' �'''I 2-1/8" 4 11325-11335 0 02/27/96 I 16 N-1/7'LNR, 12.6#,L-80 NSCT,.0152 bpf,ID=3.958' 1— 11500' DATE REV BY COMMENTS DATE REV BY (X*J,ENTS PRUDHOE BAY MT '06/04/70 ROW 34 L INITIAL COMPLETION 10/07/15 JMG/JMD PULLED EVO I KEVE PLUG(10/03/15) WELL: 01-03A 02/07/96 NI BE SIDETRACK(01-03A) 11/10/15 CJS/..111C SET FLOGUARD PATCH(10/18/15) PERMTNo: 1952040 09/18/12 RKT/.M)GLV C/O(09/14/12) AR No: 50-029-20063-01 08/15/14SSV'ICJ P *GLV GO(08/10/14) SEC 8,T10N,R15E,310'FM_8 1379'RAI_ 07/28/15 AMM/..MD SET EVOTRIEVE PLUG(06/29/15) 09/10/15 FO/JMD MSC WBS EDITS BP Exploration(Alaska) • • Wallace, Chris D (DOA) From: AK, D&C Well Integrity Coordinator <AKDCWelllntegrityCoordinator@bp.com> Sent: Friday, October 23, 2015 12:54 PM To: AK, OPS FS1 OSM; AK, OPS FS1 Facility OTL; AK, OPS FS1 Field OTL; AK, OPS FS1 DS Ops Lead;AK, OPS PCC EOC TL;AK, D&C Well Services Operations Superintendent; AK, D&C Wireline Operations Superintendent; Cismoski, Doug A; Daniel, Ryan; AK, RES GPB West Wells Opt Engr; AK, RES GPB East Wells Opt Engr; AK, OPS EOC Specialists;AK, OPS PCC Ops Lead;AK, OPS Prod Controllers; G GPB FS1 Drillsites; Oestgaard, Finn;AK, OPS FS1 DS1 Operator; 'chris.wallace@alaska.gov' Cc: AK, D&C DHD Well Integrity Engineer; AK, D&C Well Integrity Coordinator;AK, D&C Projects Well Integrity Engineer; AK, OPS FF Well Ops Comp Rep; Sternicki, Oliver R; Morrison, Spencer; Sayers, Jessica; Dickerman, Eric; Regg, James B (DOA) Subject: UNDER EVALUATION: Producer 01-03A (PTD#1952040) MIT-IA Passed Post Patch Set All, Producer 01-03A(PTD#1952040) passed a MIT-IA on October 21, 2015 after setting a tubing patch to repair tubing x inner annulus communication. The passing test confirms two competent barriers in the wellbore. The well was reported to have sustained outer annulus casing pressure above MOASP on June 27, 2015. The well is reclassified as Under Evaluation and may be brought on line to facilitate the evaluation. Plan forward: 1. Operations: Bring well on line 2. DHD: Monitor outer annulus pressure and obtain outer annulus build up rate 3. WIE: Additional diagnostics as needed Please use caution while placing well on production due to fluid packed annuli and the potential for annular fluid expansion. Thank you, SCANNED AUG 1 7 2016 Kevin Parks (Alternate: Whitney Pette_ BP Alaska-Well Integrity Coordinator GAir Global Wells Organization Office: 907.659.5102 WIC Email:AKDCWeIllntegrityCoordinator@bp.com From: AK, D&C Well Integrity Coordinator Sent: Sunday, June 28, 2015 114q,AM To: AK, OPS FS1 OSM; AK, OPS FS1 Facility OTL; AK, OPS FS1 Field OTL; AK, OPS FS1 DS Ops Lead; AK, OPS PCC EOC TL; AK, D&C Well Services Operations Team Lead; AK, D&C Wireline Operations Team Lead; Cismoski, Doug A; Daniel, Ryan; AK, RES GPB West Wells Opt Engr; AK, RES GPB East-WIIs Opt Engr; AK, OPS EOC Specialists; AK, OPS Prod Controllers; G GPB FS1 Drillsites; Oestgaard, Finn; AK, OPS FS1 DS1 Ope�tor; 'chris.wallace@alaska.gov' Cc: AK, D&C DHD Well Integrity Engineer; AK, D&C Well Integrity Coordinator; AK, D&�jects Well Integrity Engineer; 1 1q5-2_oy • • 2-Co 2-4t WELL LOG TRANSMITTAL II. PROACTIVE DIAgNOSTIC SERVICES, INC. DATA LOGGED 9 irti2oiS M.K.BENDER To: AOGCC Makana Bender 333 W. 7th Ave Suite 100 Anchorage, Alaska 99501E (907) 793-1225 RE : Cased Hole/Open Hole/Mechanical Logs and/or Tubing Inspection(Caliper/MTT) The technical data listed below is being submitted herewith. Please acknowledge receipt by returning a signed copy of this transmittal letter to the attention of: BP Exploration (Alaska), Inc. Petrotechnical Data Center Attn: Analisa Steger , LR2- 1 900 Benson Blvd. Anchorage, AK 99508 dancpdc@bp.com and ProActive Diagnostic Services, Inc. 7N,.,.. Attn: Robert A. Richey " = 130 West International Airport Road i`.V4 Suite C "' -� Anchorage, AK 99518 A; Fax: (907) 245-8952 °..; 0, *'" 1) LeakPointTM Survey 05-Aug-15 01-03A BL/CD 50-029-20063-01 2) Revised 11-Sep-15 Due to town engineer requesting depth shift Signed : /'2'2VdL4$it_. -/) %+N'. Date : Print Name: PROACTIVE DIAGNOSTIC SERVICES, INC., 130 W.INTERNATIONAL AIRPORT RD SUITE C, ANCHORAGE, AK 99518 PHONE: (907)245-8951 FAx: (907)245-8952 E-MAIL: PDSANCHORAGE@MEMORYLOG.COM WEBSITE:WWW.MEMORYLOG.COM D:\Achives\MasterTemplateFiles\Templates\Distribution\TransmittalSheets\BP_Transmit.docx 9s-z0 41 WELL LOG TRANSMITTAL -24Q ‘2A24 I.. PROACTIVE DIAGNOSTIC SERVICES, INC. DATA LOGGED Y.24/2015 iv1.K.BENDER To: AOGCC Makana Bender a 333 W. 7th Ave Suite 100 4Uat Anchorage, Alaska 99501 907 793-1225 RE : Cased Hole/Open Hole/Mechanical Logs and /or Tubing Inspection(Caliper/MIT) The technical data listed below is being submitted herewith. Please acknowledge receipt by returning a signed copy of this transmittal letter to the attention of: BP Exploration (Alaska), Inc. Petrotechnical Data Center Attn: Analisa Steger LR2— 1 900 Benson Blvd. Anchorage,AK 99508 gancpdc(a bp.com SCANNED and ProActive Diagnostic Services, Inc. Attn: Robert A. Richey 130 West International Airport Road Suite C Anchorage, AK 99518 Fax: (907) 245-8952 1) LeakPointTM Survey 05-Aug-15 01-03A BL/CD 50-029-20063-01 2) Signed : �' 6..eoteat Date : Print Name: PROACTIVE DIAGNOSTIC SERVICES, INC., 130 W.INTERNATIONAL AIRPORT RD SUITE C, ANCHORAGE, AK 99518 PHONE: (907)245-8951 FAx: (907)245-8952 E-MAIL: PDSANCHORAGEaMEMORYLOG.COM WEBSITE:WWW.MEMORYLOG.COM D:\Achives\MasterTemplateFiles\Templates\Distribution\TIansmittalSheets\BP_Transmit.docx Wallace, Chris D (DOA) From: AK, D&C Well Integrity Coordinator <AKDCWellIntegrityCoordinator@bp.com> Sent: Sunday, June 28, 2015 11:10 AM To: AK, OPS FS1 OSM; AK, OPS FS1 Facility OTL; AK, OPS FS1 Field OTL; AK, OPS FS1 DS Ops Lead; AK, OPS PCC EOC TL; AK, D&C Well Services Operations Team Lead; AK, D&C Wireline Operations Team Lead; Cismoski, Doug A; Daniel, Ryan; AK, RES GPB West Wells Opt Engr; AK, RES GPB East Wells Opt Engr; AK, OPS EOC Specialists; AK, OPS Prod Controllers; G GPB FS1 Drillsites; Oestgaard, Finn; AK, OPS FS1 DS1 Operator; Wallace, Chris D (DOA) Cc: AK, D&C DHD Well Integrity Engineer;AK, D&C Well Integrity Coordinator; AK, D&C Projects Well Integrity Engineer; AK, OPS FF Well Ops Comp Rep; Sternicki, Oliver R; Morrison, Spencer; Regg, James B (DOA) Subject: NOT OPERABLE: Producer 01-03A (PTD #1952040) Sustained Outer Annulus Casing Pressure Above MOASP Attachments: image001.png; Producer 01-03A (PTD #1952040) TIO Plot.docx All, Producer 01-03A (PTD#1952040) was reported to have sustained outer annulus casing pressure above MOASP on 06/27/2014. The pressures were reported to be tubing/inner annulus/outer annulus of 2460/1750/1080 psi. The well failed an subsequent MIT-IA on 06/27/15.The failing test indicates a lack of competent well barriers. The well is reclassified as Not Operable until down hole barriers can be restored. A copy of the TIO plot is included for reference. Kevin Parks SCANNED JUL 0 1 2015 (i frern!Ite Whitney Pettus BP Alaska -Well Integrity Coordinator GI�j� Global Wells 1 Organization Office: 907.659.5102 WIC Email:AKDCWeIlIntegrityCoordinator@bp.com 1 • Producer 01-03A(PTD#1952040)TIO Plot -�-S 11111101101r- 11.11 �M • om. • •a you.---•.1� _ � xx,. maw OMI( wun mash mm.:e ma» OMNI mun Min mmn Pages NOT Scanned in this Well History File XHVZE This page identifies those items that were not scanned during the initial scanning project.' They are available in the original file and viewable by direct inspection. /¢-~-'~-~ File Number of Well History File PAGES TO DELETE Complete RESCAN [] Color items - Pages' Grayscale, halftones, pictures, graphs, charts- Pages: Poor Quality Original- Pages: [] Other- Pages: DIGITAL DATA [] Diskettes, No. [] Other, No/Type OVERSIZED [] Logs of various kinds [] Other COMMENTS: Scanned by: Beverly Diann~ Nathan Lowell [] TO RE-SCAN Notes: Re-Scanned by: Be,~edy Dianna Vincent Nathan Lowell Date: Is~ • bp BP Exploration (Alaska) Inc. Attn: Well Integrity Coordinator, PRB -20 Post Office Box 196612 Anchorage, Alaska 99519 -6612 May 11,2012 Mr. Jim Regg 40tikitte0 AUG 1 7 Z111 Alaska Oil and Gas Conservation Commission 333 West 7 Avenue Anchorage, Alaska 99501 /q a--°J) Lt. Subject: Corrosion Inhibitor Treatments of GPB DS -01 ot f 03/ Dear Mr. Regg, Enclosed please find multiple copies of a spreadsheet with a list of wells from GPB DS- 01 that were treated with corrosion inhibitor in the surface casing by conductor annulus. The corrosion inhibitor is engineered to prevent water from entering the annular space and causing external corrosion that could result in a surface casing leak to atmosphere. The attached spreadsheet represents the well name, API and PTD numbers, top of cement depth prior to filling and volumes of corrosion inhibitor used in each conductor. As per previous agreement with the AOGCC, this letter and spreadsheet serve as notification that the treatments took place and meet the requirements of form 10 -404, Report of Sundry Operations. If you require any additional information, please contact me or my alternate, Gerald Murphy, at 659 -5102. Sincerely, _1 Mehreen Vazir BPXA, Well Integrity Coordinator • • BP Exploration (Alaska) Inc. Surface Casing by Conductor Annulus Cement, Corrosion inhibitor, Sealant Top -off Report of Sundry Operations (10 -404) DS-01 01/20/12 Corrosion Initial top of Vol. of cement Final top of Cement top off Corrosion inhibitor/ Well Name PTD # API # cement pumped cement date inhibitor sealant date ft bbls ft NA gal 01 -01C 2070920 50029210070200 0.8 NA 0.8 NA 8.5 10/22/2011 01-02 1691190 50029200530000 4.8 NA 4.8 NA 78.2 9/17/2010 01 -03A 1952040 50029200630100 2.3 NA 2.3 NA 22.2 10/10/2010 01 -04A 2011520 50029200700100 Dust Cover NA NA NA NA NA 01 -05B 2070480 50029200760200 1.5 NA 1.5 NA 5.1 1/20/2012 01 -06A 1950080 50029201120100 Sealed conductor NA NA NA NA NA 01 -07A 1940820 50029201570100 Sealed conductor NA NA NA NA NA 01 -08A 2051950 50029201600100 Sealed conductor NA NA NA NA NA 01 -09A 1940330 50029201640100 Dust Cover NA NA NA NA NA 01 -10 1750430 50029201690000 Sealed conductor NA NA NA NA NA 01 -11 1770570 50029202680000 Sealed conductor NA NA NA NA NA 01 -12A 2021920 50029202690100 Sealed conductor NA NA NA NA NA 01 -13 1770590 50029202700000 Sealed conductor NA NA NA NA NA 01 -14A 2091290 50029202810100 Sealed conductor NA NA NA NA NA 01 -15A 1952100 50029202870100 Sealed conductor _ NA NA NA NA 01 -16 1780080 50029202880000 Sealed conductor NA NA NA NA NA 01 -17B 2040120 50029202890200 Sealed conductor NA NA NA NA NA 01 -18A 2090720 50029203030100 Sealed conductor NA NA NA NA NA 01 -19B 2081770 50029208000200 0.1 NA 0.1 NA 0.9 9/16/2010 01 -20 1821460 50029208210000 0.1 NA 0.1 NA 9.4 10/22/2011 01 -21A 2081310 50029208270100 41.0 2.0 0.4 7/8/2011 9.4 10/22/2011 01 -22B 2100340 50029208480200 0.2 NA 0.2 NA 1.7 10/11/2010 01 -23 1821800 50029208540000 0.2 _ NA 0.2 NA 11.1 10/21/2011 01 -24A 1921320 50029208600100 0.3 NA 0.3 NA 3.4 10/10/2010 01 -25 1822030 50029208740000 0.0 NA 0 NA 10.2 10/25/2011 01 -26A 1990120 50029208850100 0.0 NA 0 NA 7.3 10/21/2011 01 -28A 2091250 50029215970100 0.0 NA 0 NA 8.5 10/22/2011 01 -29 1861050 50029216040000 Dust Cover NA NA NA NA NA 01 -30 1861110 50029216060000 1.9 NA 1.9 NA 11.9 10/11/2010 01 -31 1861320 50029216260000 0.0 NA 0 NA 9.4 10/21/2011 01 -32 2021850 50029216220100 15.0 NA 15 NA 15.3 10/11/2010 01 -33 1861220 50029216170000 3.0 NA 3 NA 34.0 10/11/2010 01 -34A 2081250 50029216090100 Sealed conductor NA NA NA NA NA • 09/05/08 ~/ ~ca~u6erger Alaska Data & Consulting Services 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2838 ATTN: Beth Wpll .Inh B N0.4865 Company: State of Alaska ft Alaska Oil & Gas Cons Comm ~y~? ~)r~ 1 ~~ ~ll~~ Attn: ChristineMahnken 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Inn rtaerrinfinn rtsfe RI r`nlnr r`fl L-205Ltr 40016965 OH MWD/LWD EDIT ~ 06/08/08 1 B-37 - 40017206 OH MWD/LWD EDIT 06/15/08 2 1 N-01A~ 12014032 RST 07/05/08 1 1 B-036 ' 12083399 MCNL - CfL 06/07/08 1 1 01-03A • 12017505 RST / -aOG~ ~ (p$Gf 07/15/08 1 1 01-23 12057631 RST ~j c(p 07/16/08 1 1 F-05A ~ 12083402 MCNL ~(Q 07/12/08 1 1 09-30 11962609 RST G( 07/24/08 1 1 YLtAAt HGKIVVVVLCUGt HtGtlt' I t3Y ,ItiNlNli ANU Htl UHNING UNt GUPY tAGH I U: BP Exploration (Alaska) Inc. Petrotechnical Data Center LR2-1 900 E. Benson Blvd. Anchorage, Alaska 99508 ' Date Delivered: ,`,i~ .., ~k ~; Y~ `~ Y.4 ~~ Alaska Data & Consulting Services 2525 Gambell Street, Suite 400 Anchorage, AK 9950 2838 ATTN: Beth Received by: • • l~ 07/23/08 $ChCuderger N0.4786 Alaska Data & Consulting Services Company: State of Alaska 2525 Gambell Street, Suite 400 Anchora e, AK 99503-2838 ~ ~ ~ ~) ~~U~ Alaske Oil & Gas Cons Comm 9 ~~'~ ~~ ~, Attn: Christine Mahnken ATTN: Beth 333 West 7th Ave, Suite 100 Anchorage, AK 99501 lR 5-a°`f Well .Inh S 1 .... rtes :..t:.,.. ns.e m .._~__ .... WB-05 12021166 MEM SBHPS / (p 06/13/08 1 G-16 11982438 PRODUCTION P OFILE ~ /.- ~ 06/21/08 1 R-12 12034908 PRODUCTION PROFILE ~ - ~~ 07/14/08 1 1 01-03A 12017505 PRODUCTION PROFILE ~J ~(O 07/15/08 1 1 J-15B 11970838 SCMT 07/17/08 1 1 01-23 12057631 PRODUCTION PROFILE 07/16/08 1 1 B-18 12071875 LDL ~ 07/20/08 1 1 4-04/T-26 11999025 LDL ~ 07/12/08 1 1 J-14A 12066524 MCNL ~ p (- 05/25/08 1 1 G-156 11963096 MCNL '`/j-(~(p ' 05/30/08 1 1 L3-19 11968944 RST '~j`J - 06/07/08 1 1 L2-11 12014019 RST t' 06/05/08 1 1 .+v... v.~~waac ncvc~r ~ v ~ JI~ilYI1\t1 hl\Y nc ~ vn~Ylnu VIYC l.Vr'T GNlil'1 1 V: BP Exploration (Alaska) Inc. Petrotechnical Data Center LR2-1 900 E. Benson Blvd. Anchorage, Alaska 99508 Date Delivered: Alaska Data & Consulting Service 2525 Gambell Street, Suite 40~ Anchorage, AK 99 3-2838 ATTN: Beth _~--~~ Received by: r~ 01-03A (PTD #1952040) Internal Waiver caiation - Normal Well . All, An internal waiver was issued for IAxOA communciation on well 01-03A (PTD #1952040) on 12/10/05. The well passed an MITIA on 05/06/07 proving two compentent barriers. The status of this well has been changed to Normal until June 1,2007. At that time, the new WI System Policy will be in place and the well will then be classified as Operable. The pressure limits are 2000 psi on the IA and 1000 psi on the OA. The well is reclassified as a Normal well. Please remove all waivered well signs and the laminated copy of the waiver from the well house. Thank you, Andrea Hughes Well Integrity Coordinator Office: (907) 659-5102 Pager: (907) 659-5100 x1154 S'~ MAY 1 6 2007 I of I 5/8/2007 4:49 PM C:TL~O~M'DOC 2F- 17, 19, 1Q-02A Stares Change Subject: 2F-17, 19, 1Q-02A Status Change Date: Thu, 18 May 2000 10:33:33 -0900 From: "Eric L Zuspan" <N1052~ppco.com> To: steve_mcmains~admin, state.ak.us, blair_wondzell@admin, state.ak.us As per Blairs request this e-mail is to notify the AOGCC of status changes on the following Kuparuk wells. Please disreguard the 403's sent in previously. The sundry for 3Q-08A was a 404 report of a conversion done last year. If you have any questions please call me at 659-7285 Eric Well PTD Permitted Status Current Status As of 1Q-02A 95-0194-0 Prod Inj 8/1/96 ~-~2F-17 96-0204-0 Prod Inj 11/1/97 ~.42F-19 96-0201-0 Inj Prod 6/1/97 5/18/00 10:52 AM STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: Operation shutdown_ Stimulate_ Plugging _ Perforate _X Pull tubing _ Alter casing _ Repair well_ Other _ 2. Name of Operator 5. Type of Well: 6. Datum elevation (DF or KB feet) ARCO Alaska, Inc. Development__X RKB 63 feet 3. Address Explorato~ 7. Unit or Property name P. O. Box 100360 Stratigraphic__ Anchorage, AK 99510-0360 Service__ Prudhoe Bay Unit 4. Location of well at surface 8. Well number 307' FNL, 3902' FEL, Sec. 8, T10N, R15E, UM 01-03A At top of productive interval 9. Permit number / approval number 1312' FSL, 3519' FEL, Sec. 06, T10N, R15E, UM 95-204 / 96-006 / 96-009 At effective depth 10. APl number 50-029-20063-01 At total depth 11. Field / Pool 3744' FNL, 4029' FEL, Sec. 6, T10N, R15E, UM Prudhoe Bay Oil Pool 12. Present well condition summary Total depth: measured 11500 feet Plugs (measured) Tagged PBTD @ 11335' MD (9/05/1999) true vertical 9143 feet Effective depth: measured 11335 feet Junk (measured) true vertical 9037 feet Casing Length Size Cemented Measured Depth True vertical Depth Structural 115' 20" Fondu 115' 115' Conductor 1888' 20" 3o0 Sx Fondu 1950' 1950' Surface 2549' 13-3/8" 400 Sx Class G & 200 Sx Fondu 2612' 2612' Production 7735' 9-5/8" 3085 Sx Class G 7798' 6605' Liner 3862' 4-1/2" 300 Sx C~ass G 11500' 9143' Perforation depth: measured 11240' - 11246'; 11292' - 11302'; 11314' - 11320'; 11325' - 11335'. true vertical 8975' - 8979'; 9006' - 9013'; 9021' - 9024'; 9028' - 9034'. Tubing (size, grade, and measured depth) 5-1/2"17.3#, L-80 Tbg @ 2222' MD; 4-1/2"12.6#, L-80 Tbg @ 7644' MD. /~Jaska Oil & #as Cons. Cornmissior~ Packers & SSSV (type & measured depth) 9-5/8" X 4-1/2" TIW HBBP-T PACKER @ 7586' MD. 5-1/2" HES HRQ SVLN SSSV @ 2210' MD. 13. Stimulation or cement squeeze summary ORiI INAL Intervals treated (measured) (see attached) Treatment description including volumes used and final pressure 14. Representative Daily Avera.qe Production or Injection Data OiI-Bbl Gas-Mcr Water-Bbl Casing Pressure Tubing Pressure Prior to well operation (shut in) Subsequent to operation 1155 3202 0 - 196 15. Attachments 16. Status of well classification as: Copies of Logs and Surveys run __ Daily Report of Well Operations __X Oil .__X Gas __ Suspended __ Service 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed ~~ __ Title ARCO Engineering S up er visor Date/'c='/~,~ Erin Oba Prepared by Paul Rauf 263-4990 Form 10-404 Rev 06/15/88 · SUBMIT IN DUPLICATE 01-03A DESCRIPTION OF WORK COMPLETED PERFORATING OPERATIONS Date Event Summary 9/03/1999: 9/05/1999: RIH & drifted w/dummy perf guns to 11345' MD. MIRU ELU & pressure tested equipment to 3000 psi. RIH w/perf guns & shot6' of Add Perforations @: 11240'- 11246' MD (Zone 2B) Reference Log: DA 1/26/1996. Used 2-7/8" carriers & all shots @ 4 SPF, random orientation, & 60° phasing. Tagged PBTD @ 11335'. POOH w/guns. ASF. RD. Returned well to production & obtained a valid welltest. PERMIT DATA AOGCC Individual Well Geological Materials Inventory T DATA PLUS -- 95-204 DIFL ~'~EPIA 95-204 CN ~ SEPIA 95-204 DAC ~ SEPIA 95-204 SSVD 95-204 7255 J~SEPIA ~DIFL/DAC/CN/GR Page: 1 Date: 02/25/98 RUN RECVD 02/08/96 02/08/96 02/08/96 02/08/96 02/08/96 10-407 q~OMPLETI ON DATE ~/~ '~ / ~, / DAILY WELL OPS R i/~ /~6/ TO r2/ ~- /qb/ Are dry amEcn samp±es requmred? yes~ And received? Was the well cored? yes Are well tests required? ~ ~es Well is in compliance Initial COMMENTS ~... Analysis & description received? ., Received? ye~ no GeoQuest 500 W. International Airport Road Anchorage. AK 99518-1199 ATTN: Sherrle NO. 10286 Company: Alaska Oil & Gas Cons Comm Attn: Howard Okland 3001 Porcupine Drive Anchorage, AK 99501 7/12/96 Field: Prudhoe Bay ' Anadrlll Anadrill Anadrill Floppy Well Job # Log Description Date BL RF Sepia Survey Program Performance Disk Calculation Letter q¥.,?,~({ D.S. 1-3A ~-~. PERFRECORD 960227 I 1 D.S. 1-3A c / JEWELRY LOG 960227 I 1 =1~'~ ~L~) D.S. 1-15A ~/ PERFRE~RD 960326 1 1 ~J~)' D.S. 1-22A ~ / PERFRE~RD 960312 I 1 ]~ - Oy~ D.S. 2-05 ~/ PERFRE~RD 960326 1 1 ~- ~1.., D~S. 2-10 ~' PERFRE~RD 960417 I 1 D.S. 2-22 ~ / PERFRE~RD 960227 I 1 , D.S. 2-22 ~/ INFLATABLE BRIDGE PLUG 960405 I 1 ~-0~j D.S. 3-10 u / PERFRE~RD 960225 I 1 . 'H-IIg . D.S. 3-33 ~/ PERFRE~RD 960225 I 1 5-~!~ D.S. 3-36 ~/ PERFRE~RD 960411 I 1 tl-0~1 D.S. 4-36 ~' ~PERFRE~RD 960325 I 1 ~]-a~ D.S. 5-8 / / JTUBING PATCH SE~NG RECORD 96041 4 I 1 D.S. 6-12A ~ ' PERF RE.RD 96031 8 I 1 D.S. 6-12A · / PERFRE~RD 96041 4 I 1 J~-'~}0 _ D.S. 6-13 ~ ~ PERFRE~RD 96031 8 I 1 ~~ D.S. 6-14A ~ / PERFRE~RD 960317 I 1 ~- 0~ D.S. 9-01 ~ CHEMClAL ~BING C~ RECORD 960303 I 1 ~-~Z D.S. 9-10 / PERFRE~RD 960409 I 1 ~$- f¢~{~ D.S. 9-29 u / INFLATABLE BRIDGE PLUG 96041 0 I I ,. o°/- ~ ~ I~D.S. 16-12 ,~/ TUBING PUNCHER RECORD 960321 I 1 ~' -J~;~'~ D.S. 16-16 " PERFRECORD 960226 I 1 ~I?0E~.~ D.S. 17-1 .-f PERFRECORD 960312 1 1 ~0~ D.S. 17-4 ' J JETCUTI'ER RECORD 960309 I 1 ~JJl.T.~ D.S. 18-1A f '~ PACK OFF GAS LIFT MANDREL 960224 1 1 ~7-o0'/ ..D.S. 18-11 ," PERFRECORD 960404 I 1 ~/-~ll" D.S. 15-39,.,// 96136 DUAL BURSTTDT-P (BORAX) 960429 I --~ · Please sign and return one copy of this transmittal to Sherrie at the above address. Thank you. JUL .1 2 199.3 0il & Gas Cons. Cd'mission Anchorage STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMP LETION REPORT AND LOG 1. Status of Well Classification of Service Well OIL [] GAS [] SUSPENDED [] ABANDONED [] SERVICE [] ;2. Name of Operator 7. Permit Number i ARCO Alaska, Inc. 95-204 / 96-006 / 96-009 13. Address 8. APl Number P. 0. Box 196612, Anchorage, Alaska 99519-6612 5o-029-20063-01 4. Location of well at surface ~%---~i~ 9. Unit or Lease Name 4969' NSL, 3902' WEL, SEC. 8, TION, RI~E.'.':'i~-._.:~i, ?~.7i i~¢~~~ ,_.~~ ~ Prudhoe Bay Unit ; ....... ' lO. Well Number At Top Producing Interval and Pool At Total Depth i ~: ~-- ; ........ Prudhoe Bay Field/Prudhoe Bay Pool 1534' NSL, 4040' WEL, SEC. 6, TION, R15E 5. Elevation in feet (indicate KB, DF, etc.) 6. Lease Designation and Serial No. KBE = 62.80 ADL 028329 12.01/17/96Date Spudded 13.01/25/96Date T.D. Reached 14.02/27/96Date Comp., Susp. or Aband. 15. Water Depth,N/A iffeetOffshoreMSL 16.oneNO. of Completions 17. Total Depth (MD+TVD) 18. Plug Back Depth (MD+TVD) 19. Directional Survey 120. Depth where SSSV set 121. Thickness of Permafrost 11500'MD/9140'TVD 11410'MD/9083'TVD YES [] NO []I 2209 feet MDI 1900'(Approx.) 22. Type Electric or Other Logs Run PDK, DIFL, DACK, CN, GR, Temp, CHT 23. CASING, LINER AND CEMENTING RECORD SE'fTING DEPTH MD CASING SIZE WT. PER FT. GRADE TOP BO1-I'OM HOLE SIZE CEMENTING RECORD AMOUNT PULLED 30" 157.5# B Surface 115' 39" Fondu to Surface 20" 94# / 133# H-40 / K-55 Surface 1950' 26" 300 sx Fondu 13-3/8" 72# N-80 Surface 2612' 17-1/2" 400 sx 'G', 200 sx Fondu 9-5/8" 40#/43.5#/45# S00-95 Surface 7798' 12-1/4" 3085 sx Class 'G' 4-1/2" 12. 6# L-80 7638' 11500' 6" 300 sx Class 'G' 24. Perforations open to Production (MD+TVD of Top and Bottom and 25. TUBING RECORD interval, size and number) SIZE DEPTH SETIMD) PACKER SET IMD) 5-1/2" 2222' 3-3/8" Gun Diameter, 6 spf 4-1/2" 7644' 7585' MD TVD 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED 11292' - 11302' 9006' - 9013' Freeze Protect w/147 Bbls of Diesel 11314'- 11320' 9021'- 9024' 11325' - 11335' 9028' - 9034' 27. PRODUCTION TEST Date First Production Method of Operation (Flowing, gas lift, etc.) February27, 1996 Gas Lift Date of Test Hours Tested PRODUCTION FOR OIL-BBL GAS-MCF WATER-BBL CHOKESIZE IGAS-OIL RATIO TEST PERIOD 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 of lithology, porosity, fractures, apparent dips, and presence of oil, gas or water. Submit core chips. u i AL f~ Submit in duplicate Form 10-407 Rev. 7-1-80 CONTINUED ON REVERSE SIDE 30. GEOLOGIC MARKERS FORMATION TESTS NAME Include interval tested, pressure data, all fluids recovered and gravity, MEAS. DEPTH TRUE VERT. DEPTH GOR, and time of each phase. I Sadlerochit Zone 4B 10741' 8637' Sadlerochit Zone 3 11032' 8839' Sadlerochit Zone 2C 11123' 8898' Sadlerochit Zone 2B 11181' 8935' i Sadlerochit Zone 2A 11354' 9046' 31. LIST OF A'FI-ACHMENTS 32. I hereby certify that the foregoing is true and correct to the best of my knowledge Signed '~]~I~ Title SeniorDrillingEngineer Date ~/l~f/f~' INSTRUCTIONS General: This form is designed for submitting a complete and correct well completion report and Icg on all types of lands and leases in Alaska. Item 1' Classification of Service Wells: Gas injection, water injection, steam injection, air injection, salt water disposal, water supply for injection, observation, injection for in-situ combustion. Item 5: Indicate which elevation is used as reference (where not otherwise shown) for depth measurements given in other spaces on this form and in any attachments. Item 16 and 24: If this well is completed for separate production from more than one interval (multiple completion), so state in item 16, and in item 24 show the producing intervals for only the interval reported in item 27. Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval. Item 21' Indicate whether from ground level (GL) or other elevation (DF, KB, etc.). Item 23: Attached supplemental records for this well should show the details of any multiple stage cement- ing and the location of the cementing tool. Item 27: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water In- jection, Gas Injection, Shut-in, Other-explain. F.~ ~ ¢"i~ ~ '"'..] [: r~ Item 28: If no cores taken, indicate "none". Form 10-407 SUMMARY OF DALLY OPERATIONS SHARED SERVICES DRILLING - BPX / ARCO Well Name: Accept Date: 01-03A Rig Name: Nabors 2ES AFE: 01/08/96 Spud Date: 01/1 7/96 Release Date: 4J8033 02/01/96 Jan 9 1996 (1) Rig moved 100 %. Rigged up Additional services. Held safety meeting. Held drill (H2S). Fill pits with Seawater. Held safe- ty meeting. Held drill (Spill). Rigged up High pressure lines. Rigged up Lubricator. Retrieved Hanger plug. Rigged down Lubri- cator. Bleed down well. Jan 10 1996 (2) Reverse circulated at 9970 ft. Held safety meeting. Circulated at 9970 ft. Installed Hanger plug. Removed Xmas tree. Rigged up BOP stack. Jan 11 1996 (3) Rigged up BOP stack. Tested Well control. Rigged up Wellhead connector. Tested Well control. Removed Hanger plug. Made up BHA no. 1. Worked toolstring at 18 ft. Prepared & fired cut- ting charge at 9926 ft. Made up BHA no. 2. Worked toolstring at 18ft. Jan 12 1996 (4) Worked toolstring at 18 ft. Ran electric logs. Prepared & fired cutting charge at 8000 ft. Made up BHA no. 3. Worked tool- string at 18 ft. Circulated at 8000 ft. Laid down Tubing to 8000 ft. Tested Well control. Jan 13 1996 (5) Tested Well control. Made up BHA no. 4. Circulated at 800 ft. R.I.H. to 8013 ft. Circulated at 8013 fl. Pulled out of hole to 6000 ft. Operations Summary for: 01-03A Jan 14 1996 (6) Pulled Made Pulled R.I.H. Milled out of hole to 800 ft. Pulled BHA. Tested Bottom ram. up BHA no. 5. R.I.H. to 8010 ft. Circulated at 8010 ft. out of hole to 0 ft. Pulled BHA. Made up BHA no. 6 . to 3000 ft. Serviced Block line. R.I.H. to 7798 ft. Casing at 7798 ft. Jan 15 1996 (7) Milled Casing at 7853 ft. Circulated at 7853 ft. Pulled out of hole to 800 ft. Pulled BHA. Held safety meeting. Made up BHA no. 7. R.I.H. to 7790 ft. Washed to 7953 ft. Circulated at 7953 ft. Mixed and pumped slurry - 40 bbl. Displaced slurry - 114 bbl. Held 900 psi pressure on 2 bbl squeezed cement. Pulled out of hole to 1000 ft. Jan 16 1996 (8) Pulled out of hole to 0 ft. Removed Wear bushing. Removed Seal assembly. Installed Seal assembly. Installed Accessories. Tested Well control. Jan 17 1996 (9) Tested Well control. Made up BHA no. 8. R.I.H. to 7680 ft. Held drill (Kick (well kill)). Drilled cement to 7800 ft. Cir- culated at 7800 ft. Pulled out of hole to 800 ft. Pulled BHA. Made up BHA no. 9. R.I.H. to 3500 ft. Serviced Block line. R.I.H. to 7800 ft. Jan 18 1996 (10) Drilled to 7853 ft. Drilled to 8826 ft. Jan 19 1996 (11) Drilled to 8846 ft. Circulated at 8846 ft. Pulled out of hole to 7800 ft. Serviced High pressure lines. Pulled out of hole to 650 ft. Pulled BHA. Made up BHA no. 10. R.I.H. to 8846 ft. Drilled to 9140 ft. Jan 20 1996 (12) Drilled to 10177 ft. Page 2 Operations Summary for: 01-03A Jan 21 1996 (13) Drilled to 10406 ft. Circulated at 10406 ft. Pulled out of hole to 450 ft. Pulled BHA. Made up BHA no. 11. Serviced Block line. R.I.H. to 10330 ft. Jan 22 1996 (14) R.I.H. to 10355 ft. Reamed to 10410 ft. Drilled to 10583 ft. Circulated at 10583 ft. Pulled out of hole to 9900 ft. R.I.H. to 10583 ft. Drilled to 10836 ft. Jan 23 1996 (15) Drilled to 11054 ft. Circulated at 11054 ft. Pulled out of hole to 200 ft. Pulled BHA. Made up BHA no. 12. R.I.H. to 7800 ft. Reamed to 7813 ft. R.I.H. to 11045 ft. Drilled to 11077 ft. Jan 24 1996 (16) Drilled to 11222 ft. Circulated at 11222 ft. Pulled out of hole to 4006 ft. Serviced Block line. Pulled out of hole to 250 ft. Pulled BHA. Tested Well control. Jan 25 1996 (17) Made up BHA no. 13. R.I.H. to 10647 ft. Reamed to 10687 ft. R.I.H. to 11222 ft. Drilled to 11500 ft. Circulated at 11500 ft. Pulled out of hole to 7800 ft. Jan 26 1996 (18) Pulled out of hole to 7800 ft. R.I.H. to 11500 ft. Circulated at 11500 ft. Pulled out of hole to 250 ft. Pulled BHA. Ran electric logs. Made up BHA no. 14. Serviced Block line. R.I.H. to 10594 ft. Reamed to 10815 ft. Jan 27 1996 (19) Reamed to 10953 ft. R.I.H. to 11500 ft. Circulated at 11500 ft. Pulled out of hole to 10500 ft. R.I.H. to 11500 ft. Circulated at 11500 ft. Pulled out of hole to 450 ft. Pulled BHA. Ran electric logs. Made up BHA no. 15. R.I.H. to 11500 ft. Circu- lated at 11500 ft. Page 3 Operations Summary for: 01-03A Jan 28 1996 (20) Circulated at 11500 ft. Pulled out of hole to 450 ft. Pulled BHA. Ran Casing to 3854 ft (4.5 in OD). Circulated at 3854 ft. Ran Casing on landing string to 7800 ft. Circulated at 7800 ft. Ran Casing on landing string to 11500 ft. Circulated at 11500 ft. Pumped spacers - volume 70 bbl. Mixed and pumped slurry - 63.7 bbl. Displaced slurry- 185 bbl. Pulled Drillpipe in stands to 6589 ft. Circulated at 6589 ft. Pulled Drillpipe in stands to 3000 ft. Jan 29 1996 (21) Pulled Drillpipe in stands to 0 ft. Ran Drillpipe in stands to 3500 ft. Laid down Drillpipe to 3500 ft. Made up BHA no. 16. R.I.H. to 7640 ft. Set Liner hanger at 7640 ft with 3000 psi. Tested Casing - Via annulus and string. Pulled out of hole to 975 ft. Pulled BHA. Made up BHA no. 17. Circulated at 3800 ft. Jan 30 1996 (22) R.I.H. to 11340 ft. Drilled cement to 11410 ft. Circulated at 11410 ft. Circulated at 11410 ft. Jan 31 1996 (23) Circulated at 11410 ft. Tested Casing - Via annulus and string. Laid down 7640 ft of 5 in OD drill pipe. Serviced Block line. Laid down 3180 ft of 2.875 in OD drill pipe. Pulled BHA. Re- trieved Bore protector. Rigged up Tubing handling equipment. Ran Tubing to 200 ft (4.5 in OD). Held safety meeting. Serviced Block line. Ran Tubing to 3000 ft (4.5 in OD). Feb I 1996 (24) Ran Tubing to 5500 ft (4.5 in OD). Rigged up sub-surface equip- ment - SCSSSV. Tested Dual control line. Ran Tubing to 7644 ft (5.5 in OD). Held safety meeting. Held drill (H2S). Installed Tubing hanger. Reverse circulated at 7585 ft. Rigged up sub- surface equipment - SCSSSV control line. Tested SCSSSV control line. Ran Tubing on landing string to 7643 ft. Set packer at 7585 ft with 4000 psi. Tested Tubing - Via string. Tested Per- manent packer - Via annulus. Laid down Tubing to 40 ft. Rigged down Tubing handling equipment. Installed Hanger plug. Rigged down BOP stack. Held safety meeting. Rigged down BOP stack. Page 4 Operations Summary for: 01-03A Feb 2 1996 (25) Rigged down BOP stack. Installed Adapter spool. Tested Adapter spool. Installed Manual master valve. Held safety meeting. In- stalled Swab cap. Removed Hanger plug. Installed Hanger plug. Tested Manual master valve. Removed Hanger plug. Tested Per- manent packer - Via annulus. Freeze protect well - 147 bbl of Diesel. Installed Hanger plug. Rigged down High pressure lines. Page 5 S~:RRY-SUN DRILLING SERVICES ANCHORAGE ALASKA PAGE SHARED SERVICES DRILLING PBU/1-3A 500292006300 NORTH SLOPE BOROUGH COMPUTATION DATE: 2/ 7/96 DATE OF SURVEY: 012596 MWD SURVEY JOB NUMBER: AK-MW-60006 KELLY BUSHING ELEV. = 62.80 FT. OPERATOR: ARCO ALASKA INC TRUE SUB-SEA MEASD VERTICAL VERTICAL DEPTH DEPTH DEPTH COURS INCLN DG MN 7790.00 6597.00 6534.20 46 0 7805.00 6607.43 6544.63 45 50 7923.00 6691.55 6628.75 43 17 8017.00 6757.78 6694.98 47 5 8048.00 6778.90 6716.10 47 0 COURSE DLS TOTAL D I RE CT I ON RE CTANGULAR COORD I NATES DEGREES DG/100 NORTH/SOUTH EAST/WEST N 76.00 W .00 770.78N 2947.31W N 75.85 W 1.23 773.40N 2957.76W N 67.70 W 5.30 799.13N 3036.33W N 67.60 W 4.04 824.49N 3098.00W N 67.50 W .40 833.15N 3118.97W VERT. SECT. 3010.53 3021.17 3103.48 3170.15 3192.84 8142.00 6843.42 6780.62 46 17 8237.00 6909.24 6846.44 46 0 8332.00 6973.60 6910.80 48 42 8425.00 7035.40 6972.60 48 0 8519.00 7098.84 7036.04 47 5 N 65.80 W 1.51 860.24N 3181.73W N 66.00 W .35 888.21N 3244.26W N 64.50 W 3.07 917.48N 3307.70W N 64.10 W .82 947.61N 3370.32W N 64.10 W .96 977.91N 3432.71W 3261.19 3329.69 3399.54 3468.97 3538.27 8612.00 7162.68 7099.88 46 12 8707.00 7229.09 7166.29 45 5 8739.00 7251.72 7188.92 44 54 8831.00 7316.54 7253.74 45 30 8924.00 7380.44 7317.64 47 42 9019.00 7444.13 7381.33 9115.00 7507.87 7445.07 9208.00 7569.31 7506.51 9301.00 7630.81 7568.01 9395.00 7692.73 7629.93 48 5 48 42 48 35 48 35 49 0 N 63.70 W 1.02 1007.66N 3493.44W N 63.30 W 1.20 1037.97N 3554.23W N 63.00 W .91 1048.19N 3574.42W N 61.00 W 1.67 1078.83N 3632.04W N 63.60 W 3.12 ll10.21N 3691.87W N 64.30 W .69 1141.16N 3755.20W N 66.00 W 1.46 1171.32N 3820.33W N 67.50 W 1.22 1198.88N 3884.47W N 65.30 W 1.77 1226.80N 3948.39W N 67.60 W 1.89 1255.05N 4013.21W 3605.82 3673.65 3696.24 3761.31 3828.68 3899.09 3970.85 4040.66 4110.41 4181.12 9490.00 7755.18 7692.38 48 47 9583.00 7816.80 7754.00 48 12 9676.00 7879.27 7816.47 47 24 9772.00 7944.50 7881.70 47 0 9867.00 8010.01 7947.21 45 47 N 67.50 W .22 1282.39N 4079.37W N 66.70 W .91 1309.49N 4143.54W N 68.20 W 1.47 1335.91N 4207.15W N 65.70 W 1.96 1363.48N 4271.95W N 67.20 W 1.70 1390.97N 4335.01W 4252.70 4322.34 4391.22 4461.64 4530.43 9961.00 8075.66 8012.86 45 35 10056.00 8142.94 8080.14 44 12 10119.00 8188.26 8125.46 43 47 10182.00 8233.35 8170.55 44 47 10244.00 8277.00 8214.20 45 42 N 68.60 W 1.09 1416.28N 4397.34W N 70.20 W 1.89 1439.88N 4460.09W N 69.30 W 1.18 1455.03N 4501.15W N 69.60 W 1.62 1470.47N 4542.35W N 68.20 W 2.16 1486.33N 4583.42W 4597.68 4664.64 4708.34 4752.28 4796.27 10306.00 8320.38 8257.58 10401.00 8386.55 8323.75 10494.00 8452.25 8389.45 10558.00 8499.44 8436.64 10652.00 8570.22 8507.42 45 30 46 12 43 54 41 5 41 12 N 68.80 W .76 1502.56N 4624.64W N 70.60 W 1.55 1526.20N 4688.56W N 67.30 W 3.52 1549.80N 4749.98W N 64.50 W 5.28 1567.42N 4789.45W N 61.90 W 1.82 1595.31N 4844.64W 4840.54 4908.59 4974.32 5017.55 5079.28 Oil & G:~s Go,%. C.'cmmission Ar~chol'&cjo · .,RRY-SUN DRILLING SERVICES ANCHORAGE ALASKA PAGE SHARED SERVICES DRILLING PBU/1-3A 500292006300 NORTH SLOPE BOROUGH COMPUTATION DATE: 2/ 7/96 DATE OF SURVEY: 012596 MWD SURVEY JOB NUMBER: AK-MW-60006 KELLY BUSHING ELEV. = 62.80 FT. OPERATOR: ARCO ALASKA INC TRUE SUB-SEA COURS COURSE DLS MEASD VERTICAL VERTICAL INCLN DIRECTION DEPTH DEPTH DEPTH DG MN DEGREES DG/100 TOTAL RECTANGULAR COORDINATES NORTH/SOUTH EAST/WEST VERT. SECT. 10715.00 8617.44 8554.64 41 42 N 61.30 W 1.0 10745.00 8639.87 8577.07 41 30 N 61.90 W 1.4 10778.00 8664.55 8601.75 41 42 N 61.90 W .6 10809.00 8687.59 8624.79 42 17 N 63.10 W 3.2 10839.00 8709.49 8646.69 43 54 N 63.80 W 5.5 1 1615.14N 4881.33W 5120.83 9 1624.61N 4898.85W 5140.67 1 1634.93N 4918.17W 5162.51 3 1644.51N 4936.57W 5183.20 7 1653.67N 4954.91W 5203.67 10870.00 8731.54 8668.74 45 24 N 64.30 W 4.9 10902.00 8753.81 8691.01 46 24 N 65.00 W 3.5 10933.00 8774.89 8712.09 47 54 N 66.30 W 5.7 10964.00 8795.41 8732.61 49 12 N 66.80 W 4.3 10996.00 8816.24 8753.44 49 35 N 67.10 W 1.4 7 1663.20N 4974.50W 5225.43 0 1673.04N 4995.26W 5248.40 3 1682.40N 5015.97W 5271.12 6 1691.65N 5037.28W 5294.35 4 1701.16N 5059.64W 5318.65 11059.00 8856.69 8793.89 50 30 N 69.20 W 2.9 11153.00 8916.73 8853.93 50 5 N 68.20 W .9 11218.00 8958.56 8895.76 49 47 N 67.00 W 1.4 11281.00 8999.22 8936.42 49 47 N 68.90 W 2.3 11374.00 9059.37 8996.57 49 35 N 68.70 W .2 3 1719.13N 5104.46W 5366.92 2 1745.40N 5171.84W 5439.18 9 1764.36N 5217.84W 5488.93 0 1782.42N 5262.43W 5537.03 7 1808.07N 5328.56W 5607.90 11448.00 9107.09 9044.29 50 5 N 66.80 W 2.08 11500.00 9140.36 9077.56 50 19 N 66.85 W .43 1829.48N 5380.90W 5664.44 1845.21N 5417.63W 5704.40 THE CALCULATION PROCEDURES ARE BASED ON THE USE OF THREE-DIMENSION MINIMUM CURVATURE METHOD. HORIZONTAL DISPLACEMENT = 5723.25 FEET AT NORTH 71 DEG. 11 MIN. WEST AT MD = 11500 VERTICAL SECTION RELATIVE TO WELL HEAD VERTICAL SECTION COMPUTED ALONG 293.46 DEG. TIE IN POINT 7790' WINDOW POINT 78005' INTERPOLATED DEPTH 11500' S~RRY-SUN DRILLING SERVICES ANCHORAGE ALASKA PAGE SHA/{ED SERVICES DRILLING PBU/1-3A 500292006300 NORTH SLOPE BOROUGH COMPUTATION DATE: 2/ 7/96 DATE OF SURVEY: 012596 JOB NUMBER: AK-MW-60006 KELLY BUSHING ELEV. = 62.80 OPERATOR: ARCO ALASKA INC FT. INTERPOLATED VALUES FOR EVEN 1000 FEET OF MEASURED DEPTH TRUE SUB-SEA MEASD VERTICAL VERTICAL DEPTH DEPTH DEPTH TOTAL RECTANGULAR COORDINATES NORTH/SOUTH EAST/WEST MD-TVD VERTICAL DIFFERENCE CORRECTION 7790.00 6597.00 6534.20 770.78 N 2947.31 W 1193.00 8790.00 7287.80 7225.00 1064.66 N 3606.47 W 1502.20 309.20 9790.00 7956.77 7893.97 1368.90 N 4283.95 W 1833.23 331.03 10790.00 8673.51 8610.71 1638.69 N 4925.22 W 2116.49 283.26 11500.00 9140.36 9077.56 1845.21 N 5417.63 W 2359.64 243.15 THE CALCULATION PROCEDURES ARE BASED ON THE USE OF THREE-DIMENSION MINIMUM CURVATURE METHOD. S~RRY-SUN DRILLING SERVICES ANCHORAGE ALASKA PAGE SH3LRED SERVICES DRILLING PBU/1-3A 500292006300 NORTH SLOPE BOROUGH COMPUTATION DATE: 2/ 7/96 DATE OF SURVEY: 012596 JOB NUMBER: AK-MW-60006 KELLY BUSHING ELEV. = 62.80 FT. OPERATOR: ARCO ALASKA INC INTERPOLATED VALUES FOR EVEN 100 FEET OF SUB-SEA DEPTH TRUE SUB-SEA MEASD VERTICAL VERTICAL DEPTH DEPTH DEPTH TOTAL RECTANGULAR COORDINATES NORTH/SOUTH EAST/WEST MD-TVD VERTICAL DIFFERENCE CORRECTION 7790.00 6597.00 6534.20 770.78 N 2947.31 W 7883.22 6662.80 6600.00 789.37 N 3010.63 W 8024.39 6762.80 6700.00 826.55 N 3103.01 W 8170.05 6862.80 6800.00 868.55 N 3200.22 W 8315.74 6962.80 6900.00 912.28 N 3296.71 W 8465.95 7062.80 7000.00 960.90 N 3397.69 W 8612.17 7162.80 7100.00 1007.71 N 3493.55 W 8754.65 7262.80 7200.00 1053.20 N 3584.26 W 8897.96 7362.80 7300.00 1101.58 N 3674.78 W 9046.95 7462.80 7400.00 1150.19 N 3773.95 W 9198.16 7562.80 7500.00 1196.06 N 3877.65 W 9349.39 7662.80 7600.00 1241.92 N 3981.39 W 9501.57 7762.80 7700.00 1285.72 N 4087.42 W 9651.67 7862.80 7800.00 1329.26 N 4190.52 W 9798.84 7962.80 7900.00 1371.56 N 4289.84 W 9942.62 8062.80 8000.00 1411.49 N 4385.11 W 10083.69 8162.80 8100.00 1446.44 N 4478.24 W 10223.69 8262.80 8200.00 1480.95 N 4569.93 W 10366.70 8362.80 8300.00 1517.97 N 4665.22 W 10508.55 8462.80 8400.00 1553.72 N 4759.20 W 10642.14 8562.80 8500.00 1592.25 N 4838.91 W 10775.65 8662.80 8600.00 1634.20 N 4916.80 W 10915.12 8762.80 8700.00 1677.03 N 5003.95 W 11068.61 8862.80 8800.00 1721.76 N 5111.39 W 1193.00 1220.42 27.42 1261.59 41.17 1307.25 45.66 1352.94 45.69 1403.15 50.21 1449.37 46.22 1491.85 42.48 1535.16 43.31 1584.15 48.99 1635.36 51.20 1686.59 51.23 1738.77 52.18 1788.87 50.10 1836.04 47.17 1879.82 43.79 1920.89 41.06 1960.89 40.00 2003.90 43.01 2045.75 41.85 2079.34 33.59 2112.85 33.52 2152.32 39.47 2205.81 53.48 11224.57 8962.80 8900.00 1766.32 N 5222.46 W 2261.77 11379.29 9062.80 9000.00 1809.53 N 5332.31 W 2316.49 11500.00 9140.36 9077.56 1845.21 N 5417.63 W 2359.64 55.97 54.71 43.15 THE CALCULATION PROCEDURES USE A LINEAR INTERPOLATION BETWEEN THE NEAREST 20 FOOT MD (FROM MINIMUM CURVATURE) POINTS AL:,_,:(a Oil & ¢_.,~ Co OF:IICI_lNG S I:: !:i ~/I C I~ S February 7, 1996 AOGCC Larry Grant 3001 Porcupine Dr Anchorage, AK 99501 Dear Mr. Grant, Re: Survey Data 1-3A and 4-29A Enclosed are two hard copies of the above memioned file(s). Well 1-3A MWD survey, tie in point 7790', window point 7805', interpolated depth 11500' Well 4-29A MWD survey, tie in point 10179', window point 10200', interpolated depth 13870'. Please call me at 563-3256 if you have any questions or concerns. Regards, Sandr~Lufkin Dept. Specialist Attachments. 5631 Silverado Way, Suite G · Anchorage, Alaska 99518 · (9.07) 563-3256 · Fax (907) 563-7252 A Dresser Industries, Inc. Company LARRY GRANT Attn. ALASKA OIL + GAS CONSERVATION 3001 PORCUPINE DRIVE ANCHORAGE AK, 99501. Date: RE: 2 February 1996 Transmittal of Data ECC #: 6584.00 Sent by: HAND CARRY Data: OH-LDWG Dear Sir/Madam, Reference: 1-03A PRUDHOE BAY NORTH SLOPE, AK Enclosed, please find the data as described below: Tapes/Diskettes: 1 LDWG TAPE+LIS Run # 1 Please sign and return to: Attn. Rodney D. Paulson Western Atlas Logging Services 5600 B Street Suite 201 Anchorage, AK 99518 Received by: ~ O~~7 (907) 563-7803 RECEIVED Date: FEB 0 8 199~ Alaska Oil & Gas Cons. Commission Anchorage LAP~RY GRANT Attn. ALASiZ~% OiL ~ GAS CONSERVATION 3001 PORCUPINE DRIVE AK, 99501. Date: 2 February 1996 RE: Transmittal of Data Sent by: HAND CARRY Dear Sir/Madam, Enclosed, please find the data as described below: 7~LL # DESCRIPTION i DLL FINAL BL+RF i CN FINAL BL+RF 1 DAC FINAL BL+RF ~-~ 1 SSVD FINAL BL+RF~ 1 DIFL FINAL BL+RF-'~ 1 CN FINAL BL+RF c-/ 1 DAC FINAL BL+RF ~ ! SSVD FINAL BL+RF~ Run # 1 Run # 1 Run # 1 Run # 1 Run # 1 Run # 1 Run # 1 Run # 1 ECC No. 6581.00 6584.00 Please sign and return to: Attn. Rodney D. Paulson Western Atlas Logging Services 5600 B Street Suite 201 Anchorage, AK 99518 //~ / Or FAX.to (907) 563-7803 Received by: /::i~L.?',,/~,.,,,_./:? / ~/_/n.~_./~ Date: STATE OF ALASKA AL~oKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 1. Type of Request: Abandon __ Suspend __ Operation Shutdown __ Re-enter suspended well __ Alter casing __ Repair well __ Plugging __ Time extension __ Stimulate __ Change approved program __ Pull tubing __ Variance __ Perforate __ Other X __ KOP Change 2. Name of Operator ARCO Alaska, Inc. 3. Address P. 0. Box 196612, Anchorage, Alaska 99519-6612 5. Type of Well: Development x Exploratory __ Stratigraphic __ Service 4. Location of well at surface 4969' NSL, 3902' WEL, SEC. 8, TION, R15E At top of productive interval 1449' NSL, 3869' WEL, SEC. 6, T1ON, R 15E At effective depth At total depth 1642' NSL, 4270' WEL, SEC. 6, TION, R15E ORIGINAL 6. Datum elevation (DF or KB) Plan RTE = 62.80 7. Unit or Property name Prudhoe Bay Unit 8. Well number 1-03A 9. Permit number 95-204 10. APl number 50- 029-20063-01 11. Field/Pool Prudhoe Bay Field~Oil Pool feet 12. Present well condition summary Total depth: measured true vertical Effective depth: measured true vertical Casing Length Structural Conductor Surface Intermediate Production Liner Perforation depth: measured true vertical Tubing (size, grade, and measured depth) Packers and SSSV (type and measured depth) feet Plugs (measured) feet feet Junk (measured) feet Size Cemented Measured depth True vertical depth JAN 1 6 Ala~k,a 0i! & Gas Cons Coram, issiort Anchorage 13. Attachments Description summary of proposal X Detailed operations program BOP sketch 14. Estimated date for commencing operation January 12, 1996 16. If proposal was verbally approved Oil X Gas __ Name of approver Date approved Service 17. I hereby cCf~,)that t~ue and correct to the best of my knowledge. /? ~- Signed /_U/'~ Title Senior Drilling Engineer 15. Status of well classification as: Suspended__ FOR COMMISSION USE ONLY Conditions of approval: Notify Commission so representative may witness Plug integrity __ BOP Test __ Location clearance __ Mechanical Integrity Test __ ,., .Subs¢clM,ent fo,rr~required 10- /'1[ O~' urlg]nal u gneauy David W. Johnston Approved by order of the Commission Form 10-403 Rev 06/15/88 ~J Approval No. -~pproved Returned Commissioner ~Date SUBMIT IN TRIPLICATE BP EXPLORATION ARCO Alaska, Inc. To: A~ Anchorage From: Z. Runje ~ BPX - MB 8-1 Subject: DS 1-3A Permit Rev#£. Date: January 12, 1996 We request that the following changes be allowed in the already issued permit for this well. 1. Due to the fill on the back side of 4.5" tbg inside of 9-5/8 annuli we were only able to recover tbg string from the depth of 8000' MD. 2. Already approved permit per revision #1 ) calls for the section to be cut from 8800' - 8850' MD. 3. We are now requsting that you approve this section to be cut at 7800' MD to 7850' MD. as per new directional plan #3 which is enclosed. 4. We will set permanent bridge plug at the depth of 8790' MD. Surnmaru of changes: a. KOP has changed. b. Bridge plug will be set at 8790' MD. Thanks, Oil & G~ ConS, commissioD Anchorage Anadrill Schlumberger Alaska District 1111 East 80th Avenue Anchorage, AK 99518 (907) 349-4511 Fax 344-2160 DIRECTIONAL WELL PLAN for SHARED SERVICES DRILLING Well ......... : DS 01-03A (P3) Field ........ : PRUDHOE BAY, DS-01 Computation..: Minimum Curvature Units ........ : FEET S¥ ~ace Lat..: 70.24181873 ~ S~ .ace Long.: 148.39516414 W JAN 6 ~aska 0ii a Ga~s CoDs. Commission LOCATI~0[DD~KA Zone: 4 Legal Description X-Coord Y-Coord Surface ...... : 4969 FSL 3902 FEL $08 T10N R15E UM 698697.13 5940611.96 Tie-in/KOP...: 459 FSL 1567 FEL S06 T10N R15E UM 695730.69 5941304.74 TARGET ....... : 1449 FSL 3869 FEL S06 T10N R15E UM 693400.00 5942235.00 BHL .......... : 1596 FSL 4206 FEL S06 T10N R15E UM 693058.27 5942372.72 PROPOSED WELL PROFILE STATION IDENTIFICATION TIE-IN SURVEY TOP OF WINDOW ~o~ 'u~v's 6/~oo ENI) 6/100 CURVE MEAS INCLN DIRECTION VERT-DEPTHS SECT DEPTH ANGLE AZIMUTH TVD SUB-S DIST 7790 46.00 7800 45.90 7805 45.85 7900 46.67 7919 46.89 284.00 6597 6534 3011 284.10 6604 6541 3018 284.15 6608 6545 3021 291.96 6673 6611 3090 293.46 6686 6623 3103 FOP SAG RIVER 10615 46.89 ~HUBLIK 10658 46.89 FSAD/ZVISHAK/ Z4/4B 10767 46.89 ~0NE 4A / X-RAY 10925 46.89 ~P ZONE 3 11060 46.89 Prepared ..... : 01/11/96 Vert sect az.: 293.46 KB elevatfon.: 62.8.0 ft Magnetic Dcli~.; ~R8.674 (E) Scale Factor.: 0.99994485 Convergence..: +1.51040081 ANADRILL AKA-DPC APPROVED JAN 1 ! 1996 COORDINATES- FROM STATE-PLANE TOOL DL/ WELLHEAD X Y FACE 100 770.78 N 2947.31 W 695730.69 5941304.74 145R <TIE 772.56 N 2954.42 W 695723.53 5941306.33 145R 1.23 773.43 N 2957.90 W 695720.03 5941307.12 84R 1.23 794.70 N 3023.05 W 695654.35 5941326.66 79R 6.00 799.94 N 3035.56 W 695641.71 5941331.56 6.00 293.46 8529 8466 5072 1583.72 N 4841.55 W 693815.79 5942067.43 293.46 8558 8495 5103 1596.06 N 4869.98 W 693787.05 5942079.01 293.46 8633 8570 5183 1627.96 N 4943.49 W 693712.73 5942108.97 293.46 8741 8678 5298 1673.90 N 5049.34 W 693605.71 5942152.10 293.46 8833 8770 5397 1713.03 N 5139.50 W 693514.55 5942188.84 0.00 0.00 0.00 0.00 0.00 ?0P ZONE 2/2C 11143 46.89 293.46 8890 8827 5458 1737.28 N 5195.37 W 693458.07 5942211.60 0.00 Anadrill (c)96 0103AP3 2.5b.04 11:58 AM P) 0 DS 01-03A (P3) 01/.11/96 Page 2 , STATION IDENTIFICATION BUILD 14/100 TOP ZONE 2B/TANGO END 14/100 CURVE PGOC T~' ~ET-100 FT RADIUS Tu_ HOT ?op zoNE 2A/~OHEO OOWC / POWC TZON~ I~/LOW~.~ ~O~ZO BASE MEAS DEPTH 11168 11194 11200 11226 11226 11226 11363 11409 11414 11522 11635 11675 INCLN ANGLE 46.89 50.60 51.42 55.00 55.00 55.00 55.00 55.00 55.00 55.00 55.00 55.00 DIRECTION AZIMUTH PROPOSED WELL PROFILE VERT-DEPTHS SECT TVD SUB-S DIST 293.46 8906 8844 5475 293.46 8924 8861 5495 293.46 8927 8865 5500 293.46 8943 8880 5520 293.46 8943 8880 5520 293.46 8943 8880 5520 293.46 9022 8959 5633 293.46 9048 8'985 5670 293.46 9051 8988 5674 293.46 9113 9050 5763 293.46 9178 9115 5856 293.46 9201 9138 5889 COORDINATES-FROM WELLHEAD 1744.32 N 5211.59 W 1752.24 N 5229.84 W 1754.05 N 5234.03 W 1762.20 N 5252.80 W 1762.20 N 5252.80 W STATE-PLANE TOOL X Y FACE ---- ~- ____~ 693441.66 5942218.21 HS 693423.22 5942225.64 HS 693418.98 5942227.35 HS 693400.00 5942235.00 693400.00 5942235.00 1762.20 N 5252.80 W 693400.00 5942235.00 1807.12 N 5356.30 W 693295.36 5942277.17 1821.90 N 5390.36 W 693260.92 5942291.05 1823.61 N 5394.29 W 693256.95 5942292.65 1858.86 N 5475.52 W 693174.83 5942325.75 1895.81 N 5560.68 W 693088.73 5942360.44 1908.89 N 5590.81 W 693058.27 5942372.72 DL/ 100 0.00 14.00 14.00 14.00 14.00 14.00 0.00 0.00 0.00 0.00 0.00 0.00 ANADRILLAKA. DPC APPR ' ' OYED JAN 1 NITJAL e LO 0 0 (Anadrill [c)96 0103AP3 2.5b.04 1I:58 AM P) S'HARED SEAVICES' DRILLING AKA-DPC Section at' 293 46 iiii · i ii i~ i i i Anadr J ] ] Schlumberger . _. DS 01-03A (P3) VERTICAL SECTION VIEW i i i i i ' ' ..... i ~ ! ~-'~ i ~ imp scale.' I inch = 500 feet . ,~--~'~'I ?~_..~-,. i Drawn ..... · 01/11/@6 , , ~ x~ _~- "'~. ~- -~': .... ~ ~LL - DS 01-03A [P~N 031 . , . . . : .... ~ ,o~,~,.~.. o~~.~-. ~ ~ ' F~ I~O 48.8~° 10 I~ ~.00', O~ ~ I ' '~ ~ 11168' 11226' BUILDi4"I100'DLTOTARGET~ ~- . ..... , FRM 8906' ~D TO 8943' ~ (8880, SS) I HOLD INC 55.00", ON AZ 293.46", :::::::::::::::::::::::::::::::::::: ~~;~';;:~:;;~;~;;;~ ;~~;' :::::::::::::::::::::::::-.x:--?--:y~- ............ ::::::,:::::..~ ...... ~ - .... ~ .......... ¢ ...... x---' }-~ ....... ~ ..... _ "[-' '~r~,m~?~,.~. .:.2_.._3~" .... ~ ._. . , _..F.__~,. H ...... 2750 3000 3250 3500 3750 4000 4250 4500 4750 5000 5250 5500 5750 6000 6250 6500 6750 7000 Sect ion Departure (AnadrJl] (c]96 O~03AP3 2.5b.04 t~,08 PM P) '~":' 2500 F O SHARED SERVICES Narker Id:entifjcation ND N/S A) TIE-IN SURVEY 7790 77t B] TOP OF WINDOW 7800 '773 C} K0P CURVE 6/J00 7805 773 D} END 6/100 CURVE 7919 800 E} BUILD t4/100 11168 1744 F) END 14/100 CURVE t1226 1762 GJ IARGEI-100 FT RADIUS 11226 1762 H) TD 11675 1909 2947 2954 2958 3036 52i2 5253 5253 5591 DR ILL I NG Anadri] ] Sch]umberger DS OI-03A (P3) PLAN VIEW CLOSURE ' 5908 feet at Azimuth 288.85 DECLINATION.' +28.674 (E) SCALE · I inch = BOO feet DRAWN '01/11/96 ANADRILL AKA-DFC APPROVED .,, 6800 6400 6000 5600 5200 4800 4400 4000 3600 3200 2800 2400 2000 1600 1200 ,J~O0 400 0 400 <- NEST' EAST -> (c) ~ 0103A~3 2.~.04 IZ 03 ~ P) ' "' O Anadrill DPC go7 344 2160 ~.. P .04 SHARED SERVICES DRILLING VERTICAL SECTION VIEW ,, Section at: 293.46 I TVD Scale.' ~ ~nch = ~200 feet )o-- AN.~.n~lli AKA-['PC Dep Scale.' 1 ~nch = 1200 feet ' 0 .................. ' [1'ti!~:~ 4nadrj]]Schlumberger ,0-- ~ "'"~ '~ (~ ~. X Mar~er Ident,f,cat,on .D BKB SECTN INCLN - " "- / ....... A} lIE-IN SUgVEY 77~0 65~7 gOal 46.00 , 8) TOP OF NINDOW 7800 6604 30~8 45.90 CI KOP CUgVE 6/~00 7805 6608 302~ 45.85 ~,, E) BUILD ~4/t00 tt~68 8906 5475 46.69 ~ F) END 14/100 CURVE 11226 6943 5520 55.00 - ~ ) G) TARGET-t00 FI RADIUS 11226 8943 5520 55.00 ~ H) TD 11675 9201 5889 55.00 , n c~ ~200 1BO0 2400 3000 3600 4200 4600 5400 6000 G600 7200 7800 Section MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: David Johnsto_o.~ DATE: Chairma~" THRU: Blair Wondzetl, ~ .-~,-~ FILE NO: P. 1. Supervisor" ', FROM: Bobby Fostei:,i? ? :~ SUBJECT: / ' Petroleum Inspector January 10, 1995 AEMIAJDD.doc BOPE Test- Nabors 2ES ARCO - PBU - DS 1-03A PTD # 95-0204 Prudhoe Bay Field Wednesday, .January 10, 1995: i traveled this date to ARCO's PBU DS1-3A and witnessed the bope test on Nabors dg 2ES. As the attached AOGCC BOPE Test Report shows there were no failures. The upper and lower kelly valves and the lower pipe rams could not be tested until the tubing is pulled out of the hole due to the height of the tubing head. After the tubing is pulled, the bottom rams will be changed from 4.5" to 3.5" to fit the drill pipe to be used to drill with. The rig was clean and ali equipment seemed to be in good working order. The location was clean and there was good access to all areas of the dg. Summary: I withessed the BOPE test on ARCO's DS 1-03A being drilled by Nabors 2ES - test time 2.5 hours - No failures. Attachment: AEMIAJDD.XLS STATE OF OIL AND GAS CONSERVATION COMMISSION BOPE Test Report OPERATION: Drlg: Drig Contractor: Operator: Welt Name: Casing Size: 7" Test: Initial X Workover: NABORS Rig No. 2ES PTD # g5-0204 ARCO Rep.: DSI-O3A Rig Rep.: Set @ 10,020' Location: Sec. X Weekly Other DATE: 1/10/96 Rig Ph.# 65g-4836 GENE BECK ROBERT FRENCH 8 T. 1ON R. 15E Meridian Urn. ! MISC. INSPECTIONS: LocaUon Gen.: OK Housekeeping: 0k' (Gen) PTD On Location YEs Standing Order Posted YES Well Sign OKi Dri. Rig OK ' Hazard Sec. YES . ! FLOOR SAFETY VALVES: Upper Kelly / IBOP Lower Kelly / IBOP Bail Type Inside BOP Quarl. NOTE NOTE 1 1 Test Pressure 500/5,000 500/5,000 500/5,000 o/5,.oo0., P/F IP BOP STACK: Annular Preventer 1 Pipe Rams , , Lower Pipe Rams 1 Blind Rams 1 . Choke Ln. Valves , , HCR Valves 2 Kill Une Valves _ . Check Valve Quan. Test Press. 300/3,000 5oo ,ooo 500/5,000 N/A , ,, P/F P p- VOTE P P P MUD SYSTEM: Visual Alarm Trip Tank YES YES Pit Level Indicators YES ~'~-S' Flow Indicator ~'ES ~S' Meth Gas Detector '~ES YES~ H2S Gas Detector YES YES CHOKE MANIFOLD: No. Valves 14 No. Flanges 35 Manual Chokes f Hydraulic Chokes ~ Test Pressure 500/5,000 500/5,000 Functioned Func~'onecl PIF ACCUMULATOR SYSTEM: System Pressure 3,000 ~ P Pressure After Closure 1,650 ~, P 200 psi Attained After Closure 0 minutes 30 sec. System Pressure Attained ''/''minutes '40 sec. ,,L ~ Blind Switch Covers: Master: YES Remote: YES Nitgn. Bt's: 4 ~, 2000 Psig. Number of Failures: 0 ,Test Time: 2.5 Hours. Number ofvatves tested 20 Repair or Replacement of Failed Equipment wilt be made within 0 , ,. da~,s. Notify the Inspector and follow with Written or Faxed verification to the AOGCC Commission Office at! F'a~ N01 276-7S42 Inspector North Slope Pager No. 659-3607 or 3687 If your call is not returned by the inspector within 12 hours please contact the P. I. Supervisor at 279-1433 [ I !_ __ I I I' IlIIII [11 I I · . . I II I .... I II I II I II[ II_ _11 I .... IllIIIIlL_ IIII.II II I REMARKS: NOTE: The upper and lower kelly valves and the lower pipe,r,a, rn, s' w, ill be tes, ted after,t, he, ,,t,ubi, n~7 is pulled out of the hole ~'nd an inspector will be nonfat,,,,; ......",' , , ,, Distribution: odg-Weli File c - Oper./Rig c - Database c - Tdp Rpt File c - Inspector STATE WITNESS REQUIRED? YES X NO 24 HOUR NOTICE GIVEN YES X NO Waived By: Witnessed By: BOBBY D. FOSTER , F1-021L (Rev. 12/94) AEMtAJ DD.XLS STATE OF ALASKA ALA~r,,A OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 1. Type of Request: Abandon __ Suspend __ Operation Shutdown __ Re-enter suspended well __ Alter casing x Repair well __ Plugging __ Time extension __ Stimulate __ Change approved program Pull tubing __ Variance __ Pedorate __ Other 2. Name of Operator 5. Type of Well: 6. Datum elevation (DF or KB) ARCO Alaska, Inc. Development x Plan RTE = 62.80 feet Exploratory __ 3. Address Stratigraphic__ 7. Unit or Property name P. O. Box 196612, Anchorage, Alaska 99519-6612 Service __ Prudhoe Bay Unit 4. Location of well at surface 8. Well number 4969' NSL, 3902' WEL, SEC. 8, TION, R15E At top of productive interval 1449' NSL, 3869' WEL, SEC. 6, TION, R15E At effective depth At total depth 1642' NSL, 4270' WEL, SEC. 6, TION, R15E 1-03A 9. Permit number 95-204 10. APl number 50- 029-20063-01 11. Field/Pool Prudhoe Bay Field~Oil Pool 12. Present well condition summary Total depth: measured true vertical feet Plugs (measured) feet Effective depth: measured true vertical feet Junk (measured) feet Casing Structural Conductor Surface Intermediate Production Liner Perforation depth: measured Length Size Cemented Measured depth True vertical depth true vertical Tubing (size, grade, and measured depth) Packers and SSSV (type and measured depth) 13. A~achments Description summary of proposal × Detailed operations program BOP sketch 14. Estimated date for commencing operation January 8, 1996 16. If proposal was verbally approved Name of app. L.rover 17. I hereby~y that t~foT~true Signed 15. Status of well classification as: Oil X Date approved Service and correct to the best of my knowledge. Title Senior Drilling Engineer Gas FOR COMMISSION USE ONLY Suspended__ Conditions of approval: Notify Commission so representative may witness Plug integrity_ BOP Test__ Location clearance __ Mechanical Integrity Test __ Subsequent form required 10- Original Signeo ~ Approved by order of the Commission David W. Johnstor, /Approva, No. ~, Approved C~py Returned Commissioner Date Form 10-403 Rev 06/15/88 SUBMIT IN TRIPLICATE BP EXPLORATION ARCO Alaska, Inc. To: AOGOC Anchorage From: Z. Runje ~ BPX - MB 8-1 Subject: DS 1-3A Permit Rev#1. We request that the following changes be allowed in the already issued permit for this well, 1. Original permit: 8,5" hole / 7" liner Requested changes: 6" hole and 4.5" liner Please see enclosed diagram. If you have any questions please call at 564-4825. Thanks. Date: January 4, 1996 ALASK& OIL AND GAS CONSERVATION COMMISSION TONY KNOWLE$, GOVERNOi~ 3001 PORCUPINE DRIVE ANCHORAGE, ALASKA 99501-3192 PHONE: (907) 279-1433 FAX: (907) 276-7542 December 18, 1995 Terry Jordan, Senior Drilling Engineer ARCO Alaska, Inc. P O Box 196612 Anchorage, AK 99519-6612 Re: Well # Prudhoe Bay Unit 1-03A Company ARCO Alaska, Inc. Permit # 95-204 Surf Loc 4969'NSL, 3902'WEL, Sec. 8, T10N, R15E, UM Btmhole Loc 1642'NSL, 4270'WEL, Sec. 6, T10N, R15E, UM. Dear Mr. Jordan' Enclosed is the approved application for permit to re-drill the above referenced well. The permit to re-drill does not exempt you from obtaining additional permits required by law from other governmental agencies, and does not authorize conducting re-drilling operations until all other required permitting determinations are made. Blowout prevention equipment (BOPE) must be tested in accordance with 20 AAC 25.035. Sufficient notice (approximately 24 hours) must be given to allow a representative of the Commission to witness a test of BOPE installed prior to drilling a new hole. Notice may be given by contacting the Commission's petroleum field inspector on the North Slope pager at 659-3607. · Chairman ~ BY ORDER OF THE COMMISSION dlf/encl c: Dept of Fish & Game, Habitat Section - w/o encl Dept of Environmental Conservation - w/o encl STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION PERMIT TO DRILL 2O AAC 25.005 la. Type of work Drill [] RedrillFitlb. Type of well. Exploratoryr-I Stratigraphic Test [] Development Oil [] Re-Entry [] Deepen []1 Service [] Development Gas [] Single Zone [] Multiple Zone [] 2. Name of Operator 5. Datum Elevation (DF or KB) 10. Field and Pool ARCO Alaska, Inc. Plan RTE = 62.80 feet Prudhoe Bay Field/Prudhoe 3. Address 6. Property Designation Bay Pool P. O. Box 196612, Anchorage, Alaska 99519-6612 ADL 028329 4. Location of well at surface 7. Unit or property Name 11. Type Bond(see 20 AAC 25.025) 4969' NSL, 3902' WEL, SEC. 8, TION, R15E Prudhoe Bay Unit At top of productive interval 8. Well number Number 1449' NSL, 3869' WEL, SEC. 6, TION, R15E 1-03A U-630610 At total depth 9. Approximate spud date Amount 1642' NSL, 4270' WEL, SEC. 6, TION, R15E 01/01/96 $200,000.00 12. Distance to nearest 13. Distance to nearest well 4. Number of acres in property15. Proposed depth (MD and TVD) property line ADL028311 762 feet NoCIoseApproach feet 2560 11797'MD/9138'TVDfeet 16. To be completed for deviated wells 17. Anticipated pressure (see 20 AAC 25.035 (e)(2)) Kickoff depth 9940 feet Maximum hole anglesg. 93 o Maximum surface 3330 psig At total depth (TVD) 8800'/4390 psig 18. Casing program Specifications Setting Depth s~ze Top Bottom Quantity of cement Hole Casing Weight Grade Coupling Length MD TVD MD TVD (include stage data) 8-1/2" 7" 29# L-80 NSCC 1948' 9850' 8130' 11798' 9138' 250 sx Class 'G' 19. To be completed for Redrill, Re-entry, and Deepen Operations. Present well condition summary Total depth: measured feet Plugs (measured) true vertical feet Effective depth: measured feet Junk (measured) true vertical feet Casing Length Size Cemented " Measured depth True Vertical depth Structural Conductor Surface Intermediate Production Perforation depth: measured true vertical 20. Attachments Filing fee [] Property plat [] BOP Sketch [] Diverter Sketch [] Drilling program[] Drilling fluid program [] Time vs depth plot [] Refraction analysis [] Seabed report[] 20 AAC 25.050 requirements[] hereb, that th_e.fore,o,n, is true and correct to the est Signed /,,....-/ Title SeniorDrillin~t Engineer Commission Use Only iPermit Number APl number Approval date See cover letter /?_'~-'-2..0/7Z 50- 02_?-- ~---Oc::~',~---~c~/ Z"~ '//~- ¢''~- for other requirements Conditions of apl~roval Samples required [] Yes j~ No Mud Icg required []Yes [] No Hydrogen sulfide measures ~ Yes [] No Directional survey required ]~ Yes [] No Required working pressure for BOPE []2M; r-13M; 1~5M; I-Il OM; I-I15M; Other: Original Signed By by order of ~,/~¢//~/~ Approved by David W. Johnston Commissioner me commission Date/ Form 10-401 Rev. 12-1-85 Submit in I WellName: IDS 1-3A Redrill Plan Summary Type of Redrill (producer or injector): I Shut In Producer Surface Location: 4969' FSL, 3902' FEL, S08, T10N, R15E, UM Target Location: 1449' FSL, 3869' FEL, S06, T10N, R15E, UM Bottom Hole Location: 1642' FSL, 4270' FEL, S06, T10N, R15E, UM ! ]AFE Number: l unknown I I Estimated Start Date: [ Jan 1, 96 I IMD: I 11797' ] I TVD: Well Design (conventional, slimhole, etc.): I Rig: [ Nabors 2ES '" Operating days to complete: 121 9138ss I [KB Elv. 162.80 [Twin Sidetrack I I I I Objective: [ Replace leaking tubing string. Better understand fluid contacts. Mud Program: A 9.8 - 10.20 ppg Biozan polymer / KC1 water based mud will be used. Special design considerations [none I Depth Density PV YP INT 10MIN FL OIL SOLIDS (TVD) (PPG) (CP) (#/FT) GEL GEL cc/30min (%) (%) KOP' 9.8 10 15 5 10 10 0 5 to to to to to to to to to Target 10.2 18 30 15 29 5 0 8 Directional'. IKOP: [ 9940' MD Maximum Hole Angle: 1 59-93° from KOP to TD Close Approach Well: ] none DS 1-3A Redrill Plan Summary Page 1 Casing/Tubing Program: Hole Size Csg/ Wt/Ft Grade Con Length Top Btm Tbg O.D. n MD]TVDss MD/TVDss 8.5" 7" liner 29# L-80 NSCC 1948 9850/8130 11798/9138 N/A 4.5" tbg 12.6# L-80 NSCT 10664 Surface 10664/8570 Cement Calculations: [ Liner Size: [ 7" drilling liner I 50% open hole excess, 80' shoe joint, 1000' MD above the Sag River. Total Cement Volume: [ 250[ sxs of Class G Blend @ 1.17 ft3/sx ( Estimated Volume ) Well Control: Well control equipment consisting of 5000 psi W.P. pipe rams, blind rams, and annular preventer will be installed and is capable of handling maximum potential surface pressures. Diverter, BOPE and mud fluid system schematics on file with AOGCC. Hazards Sadlerochit pressure is @ 3500 psi at @ 8800' TVDss or EMW of 7.64 ppg Sag River at 10456 MD / 8466' TVDss, is in communication with Sadlerochit therefore it will have same BHP of 3500 psi or 7.95 ppg EMW. No other hazards are expected. DS 1-3A Redrill Plan Summary Page 2 Operations Summary: Rig-Work: 1. Move in drilling rig. 2. Pull BPV. Circulate out freeze protection cap from inner and outer annuli and recover for future use. 3. Install a TWC and test from below to 1000 psi. ND the production tree. 4. N/U BOP's. Test BOP's to 250 / 5000 psi against TWC. Test annular to 250 /2500 psi. Remove the test plug. . Pull and lay down the .4-1/2" tubing. Inspect for NORM. ( Check the location and' depth of the cut on production handover form ) NOTE: It is not clear as to what the running threads are on this hanger thus it is recommended that spear be used ) . P/U Section Mill on 4.1/2" DP & RIH. Displace to milling fluid after spotting 18 ppg pill from @ 10200' MD and up to 9995' MD. Cut window from 9940' to 9995'. POOH after ensuring the hole is cleaned and free of metal cuttings. , RIH open ended to 10345' MD and spot a kick-off plug from 100' below the base of the section to - 200' above the top of the section which is about 30 bbls of slurry ( @ 10095' MD to 9740' MD ). Pull 12 stands, shut in and perform hesitation squeeze. Attempt to achieve a 1000-2000 psi squeeze but do not displace TOC below 100' above section top. . Run in with an 8-1/2" steerable assembly (MWD - directional) and dress the cement to-5' below the section top. Circulate hole clean. Kickoff and directionally drill to the target at 11797' MD ( 9138' TVDss ). See attatched directional plan #1. , After DP conveyed logs / or E-Line are ran ( logging program is SP/GR/DIL/CNL/Density and Sonic is recommended) make a conditioning trip with a 8 1/2" hole-opener for the open hole section with a 9 5/8" casing scraper spaced to clean the casing. If hole conditions allow consider omitting this step ( this is rig supervisors call ). Rabbit the drill string. Note: Prefer method of logging is E-Line however that may not be possible due to hole angle therefore DPC set up should be available just iun case. 10. Run a 7" 29#, L-80, NSCC liner with 9 5/8 x 7" packer / hanger to bottom in the 8-1/2" hole and space out for about 150' of lap. Refer to Standard Recommended practices for liner running procedure. Reciprocrate liner 20- 30' during circulation and cementaiton. ~-__.? i,-~-- ~.~. ...... ,, DS 1-3A Redrill Plan Summary Page 3 11. Cement the liner in place with the total cement volume based upon 30% open-hole enlargement plus the 80' shoe volume, (TOC 1000 ft MD above the TSAD ( this depth is @ 9664' MD ) which in this case means about 250 sks but this number must be reconfirmed after the hole is drilled ). Set liner hanger / packer with 4200 psi. Reverse out clean. 20. P/U 6" clean out bit on 3.5 x 4.5 DP. RIH and clean out 7" liner to landing collar. Circulate hole clean. Pressure test the liner lap to 3500 psi for 30 min. Displace the hole with filtered seawater. POOH. .Note: Refer to Standard Completion Running Procedure as well as Proposed completion diagram for more details. 21. Run the 4-1/2", L-80, NSCT completion assembly spaced out to place end of tail pipe above the TSAD. ( TT tb be spaced out @ 10660' MD ) Tubing detail as follows: ( Refer to Proposed Completion Diagram for more details ) · 4 1/2" WLEG · 4 1/2", 12.6#, L-80, NSCT 10 ft pup joint · 4 1/2", 12.6#, Otis "XN" Nipple (3.750" ID) · 4 1/2", 12.6#, L-80, NSCT 10 ft pup joint · 4 1/2", 12.6#, L-80 NSCT full joint · 4 1/2", 12.6#, L-80 NSCT 10 ft pup joint · 4 1/2" X 7" Packer · 4 1/2", 12.6#, L-80 NSCT 10 ft pup joint · 4 1/2", 12.6#, L-80 NSCT tubing joint · 4 1/2", 12.6#, L-80 NSCT tubing with GLM's GLM's Depths to be determined later. · 4 1/2", L-80 Tubing Retrievable SSSV @ 2,200' MD · 4 1/2", 12.6#, L-80 NSCT tubing to surface · 4 1/2" tubing hanger 22. Space out, test the SSSV and circulate with corrosion inhibitor prior to setting packer. Drop the packer setting ball. Pressure the tubing to 4000 psi and set the packer. 23. Close the SSSV, install a TWC, and test to 1000 psi. Remove BOP's. 24. Install and test the production tree to 5000 psi. Pull the TWC valve. 25. While holding the 1500 psi on the tubing, pressure test the annulus to 3500 psi for 30 minutes. First bleed off the annulus, then the tubing to 0 psi. 26. Open the SSSV and shear the RP on the upper GLM with 2900 psi annulus pressure. Bleed off pressure and freeze protect with diesel to 2200' MD. 27. Set a BPV. Close the SSSV and secure the well. Release rig. 28. Complete appropriate documentation and hand-over to Production. DS 1-3A Redrill Plan Summary Page 4 Anadrill Schlumberger Alaska District 1111 East 80th Avenue Anchorage, AK 99518 (907) 349-4511 Fax 344-2160 DIRECTIONAL WELL PLAN for SHARED SERVICES DRILLING Well ......... : DS 01-03A (P1) Field ........ : PRUDHOE BAY, DS-01 Computation..: Minimum'Curwature Units ........ : FEET -''rface Lat..: 70.24181873 N ~rface Long.: 148.39516414 W LOCATIONS - ;tLASKA Zone: 4 X-coord Y-Coord Legal Description Surface ...... : 4969 FSL 3902 FEL S08 T10N R15E UM 698697.13 5940611.96 Tie-in/KOP...: 932 FSL 2809 FEL S06 T10N R15E UM 694474.'92 5941745.77 TARGET ....... : 1449 FSL 3869 FEL S06 T10N R15E UM 693400.00 5942235.00 BHL .......... : 1642 FSL 4270 FEL S06 T10N R15E UM 692993.59 5942417.91 PROPOSED WELL PROFILE STATION IDENTIFICATION TIE-IN SURVEY TOP OF WINDOW ~ CURVE 14/100 Prepared ..... : 12/08/95 Vert sect az.: 295.74 KB elevation.: 62.80 ft Magnetic Dcln: +28.683 (E) Scale Factor.: 0.99994485 Convergence..: +1.51040081 ANADRILL AKA-DPC END 14/100 CURVE APPROVED DEC 0 ? 1995 MEAS INCLN DIRECTION VERT-DEPTHS SECT COORDINATES-FROM STATE-PLANE DEPTH ANGLE AZIMUTH TVD SUB-S. DIST WELLHEAD X Y 9890 39.00 299.00 8214 8151 4316 1244.78 N 4191.09 W 694474.92 5941745.77 9935 41.03 299 47 8249 8186 4345 1258.98 N 4216.45 W 694449.20 5941759.30 TOOL DL/ FACE 100 9R <TIE 8R 4.55 9940 41.26 299.'52 8253 8190 4348 1260.60 N 4219.31 W 694446.29 5941760.84 ' 10L 4.55 10000 49.54 297.58 8295 8232 4391 1280.95 N 4256.83 W 694408.26 5941780.20 9L 14.00 1007~. 59.93 295.74 . 8338 8275 4452 1308.33 N 4311.49 W 694352.89 5941806.13 14.00 TOP SAG RIVER 10456 59.93 '295.74 8529 8466 4782 1451.58 N . 4608.59 W 694052.15 5941941.49 SHUBLIK 10514 59.93 295.74 8558 8495 4832 1473.34 N 4653.71 W 694006.46 5941962.05 TSAD/IVISHAK/ Z4/4B 10664 59.93 295.74 8633 8570 4961 1529.61 N 4770.42 W 693888.32 5942015.22 ZONE 4A / X-RAY 10879 " 59.93 295.74 8741 8678 5148 1610.64 N 4938.47 W 693718.20 5942091.79 TOP ZONE 3 11063 597.~?.~':?. 295.74 8833 8770 5307 1679.67 N 5081.63 W 693573.28 5942157.01 11177 5~.:!93 295.74 8890 8827 5405 1722.43 N 5170.33.: W 693483.~9 5942197.42 (knadrill (c)95 0103AP1 2.5b.04 12:41 PM P) '~ TOP ZONE 2/2C 0.00 0.00 0.00 0.00 0.00 0.00 -g (3 DS 01-03A (P1) 12/08/95 PaHe 2 STATION IDENTIFICATiON ---- TOP ZONE 2B/TANGO PGOC TARGET-100 FT RADIUS: TOP HOT TOP ZONE 2A/ROMEO ZONE 1B/LOWER ROMEO BASE SAD/KAVIK TD MEAS DEPTH 11245 11282 11282 11440 11492 11498 11622 11752. 11797 INCLN ANGLE 59.93 59.93 59.93 59.93 59.93 59.93 59 '93 59.93 59 '93 PROPOSED WELL PROFILE DIRECTION VERT-DEPTHS AZIMUTH TVD SUB-S SECT DIST 295.74 8924 8861 5464 295.74 8943 8880 5497 295.74 , 8943 8880 5497 295.74 9022 8959 5633 295.74 9048 8985 5678 905i 8988 5683 9113 9050 5791 9178 9115 5903 9201 9138 5943 295.74 295.74 295.74 295.74 COORDINATES-FROM WELLHEAD 1747.94 N 1762.20 N 1762.20 N 1821.47 N 1840.98 N 5223.24 W 5252.80 W 5252.80 W 5375.73 W 5416.19 W 1843.23 N 1889.75 N 1938.52 N 1955.78 N 5420.86 W 5517.33 W 5618.48 W 5654.27 W STATE-PLANE X Y 693429.93 5942221.53 693400.00 5942235.00 693400.00 5942235.00 693275.56 5942291.01 693234.61 5942309.44 693229.88 5942311.57 693132.22 5942355.52 693029.83 5942401.61 69'2993.59 5942417.91 TOOL FACE DL/ 100 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 '1 ANADRILL AKA-DPC A'PPROVED 0 ',4 (Anadrill (c)95 0103A?l 2.5b.04 12:41 PM P) 17:02 Anadrill DPC. 907 344 2160 P.04 i m m __ i__ __ S 0 -03A ., ' VERTICAL SECTION VIEW ~ .......... ' ........ Section at: 2@5.74 AN, kDRILL~ -AKA-DPC TVD Scale' ~ inch = ]200 feet I , ~~, ~r~ Dep Scale 1 inch 1200 feet ~~.U ~ ~LJ Drawn · 12/08/95 ~ ...... DECO~ 9~5 .~_. ' AnadrJ ]1 SchYumberger ' ~, ....-,L . .......... ~ ~arker Identification ~ ~B SECTN INCLN I A) TIE-IN SURVEY gBgO 82t4 4316 39.00 . B) TOP ~ WINDOW 9935 8~49 4345 4~.03 C) KOP CURVE 14/t00 9940 8253 4348 ....41.26 ) ....................... D) END ~4/~00 CURVE ~0075 8338 445~ 59.93 ~ El TARGET-tO0 FT RADIUS ~282 8943 5497 59.93 ' ~ F) ID ~797 g20t 5943 59.93 ~ J I ,: ~ ......................... I '. . . ...... ~ .... -~ - ......... ~ .... ~. ... ~ . ~ - ~ ..... ~ ~ , ' I ,, ' . ~ ..~% .................. ... . ~ ....... ; .... ~ =2:~ ............. . -. , . .... .~ .... 0 600 ~200 1800 2400 3000 3600 4200 4800 ~00 6000 6600 7200 7800 Section i ii I I I I I I II I i ~ ii ii il i i SHARED DRILLING I sc~rubber, er II ii iiiii i ii iiii iiiiii III II - I II II 'SERV IcES ,. ~ .......... , ~~"~.'~.;_ .. ·. ~. ~ -.---~ IDECL]NATZ0N.: +~8.683 (E) ~ ',I. SCALE ....... : 1 inch: 800 feet ~_ : ] : DEC 0 ~ ~G95 i IDRAKN ..... :..: ]2/07/95 ) ......... :':. '" HaPke~ ]denL~f ~cation HD N/S E/~ ', , A) .TIE-IN 9690 t2~5 4~9~ , ~ B) TOP OF . , ; , C) KOP C~VE 14/100 9940 1281 4219 ): ,, ) ...... ,~ ' D) END 14/t00 CURVE 10075 i308 4311 I I ....... J E) TARGET-tO0 FI RADIUS 11282 176~ 5253 .I '} ~~ F) TO ]1797 t956 5654 ~ '" I ' ' '. ' ~ " ~ ....... . ~._ ~, . ....... " ' ~ ' ~ ' ' 6800 , DS O'I-03A (Pi) PLAN .VIEW ANADRILL AKA-DPC .......... [~,naClrd]. (c]95 0103~1 2.50,03 4:26 Pr4 P] 6400 6000 5600 5200 4800 4400 4000 3600 3200 2800 2400 2000 ~600 ~200 800 400 0 400 <- NEST ' EAST -> II i i i i I I I i i i I II I I '0 STATE OF ALASKA Al, .A OIL AND GAS CONSERVATION COMMISSi, , APPLICATION FOR SUNDRY APPROVALS 1. Type of Request: Abandon ~ Suspend Operation Shutdown ~ Re-enter suspended well ~ Alter casing ~ Repair well Plugging X Time extension ~ Stimulate ~ Change approved program Pull tubing __ Vadance ~ Perforate __ Other X Plugback for Sidetrack 2. Name of Operator ARCO Alaska, Inc. 3. Address P. O. Box 196612, Anchorage, Alaska 99519-6612 4. Location of well at surface 311' SNL, 1378' EWL, SEC. 8, TION, R15E At top of productive interval 1167'NSL, 2124'EWL, SEC. 6, TION, R15E At effective depth At total depth 1555' NSL, 1657' EWL, SEC. 6, TION, R15E 5. Type of Well: Development X Exploratory __ Stratigraphic __ Service 6. Datum elevation (DF or KB) Plan RTE = 62.80 feet 7. Unit or Property name Prudhoe Bay Un/t 8. Well number 1-03 9. Permit number 70-16 10. APl number 50- 029-20063 11. Field/Pool Prudhoe Bay Field/Oil Pool 12. Present well condition summary Total depth: measured true vertical 11320. feet '9207 feet Plugs (measured) Fill at 11026' MD (12/23/94) Effective depth: measured true vertica. I 11026 feet Junk (measured) 9008 feet Casing Structural Conductor Surface Intermediate Production Liner Perforation depth: Length Size Cemented 115' 30" Fondu to Surface 1877' 20" 300 sx Fondu 2539' 13-3/8" 400 sx Cl G & 2OO sx Fondu Measured depth True vedicaldepth 115' 115' 1950' 1950' 2612' 2612' 11207' 9-5/8" 3085 sx Class G 455' 2-7/8" 20 bbls LARC measured 10983' - 10998', 11022' - 11026' true vertical 8978'- 8988~ 9005'- 9007' i, 11280' ~ ~.--- ,~'", ~'-'.'-' '-.:, .~ ..:., ~ 8,0 10983' 1995 Tubing (size, grade, and measured depth) 4-1/2", 12.6#, L-80, NPCT at 10544' MD; 3-1/2", 10.3#, N-80, NPC tail at 10600' MD Packers and SSSV (type and measured depth) 4-1/2", Otis DBE SSSV at 2363' MD; Baker DB Packer at 10550' MD 13. Attachments Description summary of proposal 'x' Detailed operations program __ BOP sketch 14. Estimated date for commencing operation December 19, 1995 16. If proposal was verbally approved Name of approver Date approved 15. Status of well classification as: Oil X Gas Suspended __ Service 17. I hereby certify that the foregoin, g is true and correct to the best of my knowledge. Signed "~¢¢~ ~'~ TitleSeniorDrillingEngineer FOR COMMISSION USE ONLY Date Conditions of approval: Notify Commission so representative may witness Plug integrity_ BOP Test __ Location clearance ~ Mechanical Integrity Test Subsequent form required 10- JApproval No. ¢,~'-_ ~ ~ Approved by order of the Commission Commissioner Date Form 10-403 Rev 06/15/88 SUBMIT IN TRIPLICATE FIELD & POOL _..,.,,, HECKLIST UNIT# PROGRAM: exp [] dev [] redrll/~ serv [] ON/OFF s~o~ <iD~J ADMINISTRATION 1. Permit fee attached .................. 2. Lease number appropriate ............... 3. Unique well name and number .............. 4. Well located in a defined pool ............. 5. Well located proper distance from drlg unit boundary. ENGINEERING 6. 7. 8. 9. 10. 11. 12. 13. Y Y .Y Well located proper distance from other wells ...... Y Sufficient acreage available in drilling unit ..... Y If deviated, is wel!bore plat included ........ ~ Y Operator only affected party .............. t.Y Operator has appropriate bond in force ......... /.Y ! Permit can be issued without conservation order .... ~ Y ~ t Permit can be issued without administrative approval.. ~Y ~ Can permit be approved before 15-day wait ....... .IY ~ ~REMA3~S "GEOlOgy " 14. Conductor string provided ................ Y N~ 15. Surface casing protects all known USDWs ......... Y N 16. CMT vol adequate to circulate on conductor & surf csg.. Y N 17. CMT vol adequate to tie-in long string to surf csg . . . Y N 18. CMT will cover all known productive horizons ...... ~ N 19. Casing designs adequate for C, T, B & permafrost .... .~ N 20. Adequate tankage or reserve pit ............. ~ N 21. If a re-drill, has a 10-403 for abndrunnt been approved.~ N 22. Adequate wellbore separation proposed .......... ~ N 23. If diverter required, is it adequate .......... 24. Drilling fluid program schematic & equip llst adequate .~ N 25. BOPEs adequate .............. ,~ ...... Y~ N 26. BOPE press rating adequate; test to ~ ~-cj~ psig.~ N 27. Choke manifold complies w/API RP-53 (May 84) ....... 28. Work will occur without operation shutdown ....... ~ N 29. Is presence of H2S gas probable ............ ~ Y~ N / 30. Permit can be issued w/o hydrogen sulfide measures .... Y N 31. Data presented on potential overpressure zones ..... Y/~N' 32. Seismic analysis of shallow gas zones .......... 33. Seabed condition survey (if off-shore) ........ 34. Con%act name/phOne for weekly progress reports . . ./ . Y N [exploratory only] 'GEOLOGY: 'ENGINEERING: c~MMIssION ~ ................................ Commen~s / Instructions: HOW/lib - A:%FORMS%cheklist rev 11/95 Well History File APPENDIX Information of detailed nature that is not particularly germane to the Well Permitting Process but is part of the history file. To improve the readability of the Well History file and to simplify finding information, information of this nature is accumulated at the end of the file under APPENDIX. No special effort has been made to chronologically organize this category of information. ' I RCO ALASKA i ~ O.S. 1 - 03A ! PRUDHOE BAY Run 1' 26 - January. - 1996 D!FL/DAC!CN!GR 10331 ! 1483 F~B 0 8 ;99(~ , ' co~,~ging Services AJasxa oil & ~as Cons. ~chorage WESTERN ATLAS rape Subfile 2 is type: _IS · TAPE HEADER PRUDHOE BAY UNIT OPEN HOLE WIRELINE LOGS WELL NAME: API NUMBER: OPERATOR: LOGGING COMPANY: TAPE CREATION DATE: JOB DATA JOB NUMBER: LOGGING ENGINEER: OPERATOR WITNESS: SURFACE LOCATION SECTION: TOWNSHIP: RANGE: FNL: FSL: FEL: FWL: ELEVATION(FT FROM MSL 0) KELLY BUSHING: DERRICK FLOOR: GROUND LEVEL: WELL CASING RECORD 1ST STRING 2ND STRING 3RD STRING PRODUCTION STRING RUN 1 6584.00 R. ECK SEE REMARKS REMARKS: D.S. 1-03A 500292006301 ARCO ALASKA INCORPORATED WESTERN ATLAS LOGGING SERVICES 01-FEB-96 OPEN HOLE RUN 2 RUN 3 8 I0N 15E 4969 3902 70.27 68.87 38.85 CASING DRILLERS BIT SIZE (IN) SIZE (IN) DEPTH (FT) 9.625 7798.0 6.000 11500.0 DIFL/DAC/CN/GR. CIRCULATION STOPPED AT 1330, 26-JAN-96. LOGS WITNESSED BY: K. ST.GEMME & G. BECK. REMOVED 1.5" STAND-OFF IN ORDER TO GET DOWN. RILD & RILM INVASION PROFILE IS AFFECTED BY SALINITY OF BOREHOLE FLUID & RUGOSITY OF WELLBORE. PULLED TIGHT SEVERAL TIMES THROUGH LOGGED INTERVAL. REPEAT PASS WAS MADE WHILE GOING IN THE HOLE DUE TO POOR BOREHOLE CONDITIONS. GR TOOL FAILED WHILE PULLING OUT OF HOLE. NO AFTER LOG VERIFICATION AVAILABLE FOR GR. PER CLIENT'S REQUEST, BOREHOLE & TORNADO CHART CORREC- TIONS WERE APPLIED TO THE DIL DATA. THE DIL DATA WAS BOREHOLE CORRECTED (6.0"). THE CORRECTED DATA WAS THEN USED IN THE ATLAS TORNADO CHART TO GET "RT" & "DI" CURVES. RT = TRUE FORMATION RESISTIVITY. DI = DEPTH OF INVASION. NEUTRON I PARAMETERS: SANDSTONE MA [X, CALIPER CORRECTION = 6.00" , CHISM FILTERING OFF, CASING CORRECTIONS OFF, SALINITY = 0 PPM. FILE HEADER ~ FILE NUMBER: 1 EDITED OPEN HOLE MAIN PASS All tool strings; hole data. DEPTH INCREMENT: FILE SUMMARY PBU TOOL CODE GR DAS DIL 2446 $ BASELINE CURVE FOR SHIFTS: GR CURVE SHIFT DATA (MEASURED DEPTH) depth shifted and clipped curves; .5000 START DEPTH STOP DEPTH 10331.0 '11419.0 10365.0 11436.0 10395.0 11483.0 10394.0 11426.0 all EQUIVALENT UNSHIFTED DEPTH BASELINE DEPTH LL8 ILD DT NPHI 10429.0 10428.5 10428.5 10495.5 10495.5 10502.5 10503.0 10503.5 10503.0 10508.0 10508.0 10531.0 10531.0 10557.5 10557.5 10557.5 10560.0 10560.0 10591.0 10590.5 10599.5 10600.0 10604.5 10605.0 10605.0 10605.0 10604.5 10615.5 10615.0 10615.5 10641.5 10641.0 10645.0 10644.0 10649.5 10650.0 10649.0 10649.0 10655.5 10655.0 10656.0 10662.5 10663.0 10667.5 10667.0 10667.0 10673.5 10673.5 10678.5 10678.5 10679.5 10679.0 10679.0 10687.0 10687.0 10687.0 10687.0 10694.5 10694.0 10693.0 10700.5 10700.5 10700.5 10700.5 10704.0 10704.0 10705.0 10705.0 10705.5 10705.5 10705.5 10707.5 10708.0 10708.0 10709.0 10708.5 10708.5 10714.5 10714.5 10719.5 10719.0 10719.0 10725.0 10724.5 10724.5 10726.5 10727.0 10727.0 10727.0 10727.0 10732.0 10732.0 10732.0 10731.5 10735.0 10735.0 10735.0 10735.0 10735.0 10738.5 10738.5 10743.5 10742.5 10745.0 10744.0 10745.5 10745.0 10745.0 runs merged; no case 10755.5 10756.0 10764.0 10771.5 10772.0 10785.5 10792.5 10805.0 10806.0 10812.0 10821.5 10825.0 10825.5 10837.5 10846.0 10857.0 10864.0 10878.5 10889.0 10903.0 10905.0 10930.0 10932.5 10957.0 10971.5 10975.0 10977.5 10983.0 10986.0 10988.5 10998.5 11004.0 11007.0 11012.5 11016.0 11019.0 11033.5 11040.0 11040.5 11047.5 11063.0 11079.5 11084.0 11101.0 11141.0 11143.5 11164.0 11181.0 11181.5 11245.0 11250.0 11252.5 11259.0 11273.5 11277.0 11283.0 11299.5 11301.5 11318.5 11319.0 10755.0 10771.5 10903.0 10932.0 10998.0 11002.5 11040.5 11083.5 11181.0 11277.0 10755.0 10771.5 10785.0 10804.0 10812.5 10821.0 10845.0 10903.0 10905.5 10932.0 10955.0 10998.0 11002.5 11011.0 11016.0 11031.5 11040.5 11047.0 11063.0 11083.5 11100.5 11139.5 11162.5 11181.0 11272.5 10755.0 10763.0 10769.5 10792.5 10825.0 10836.0 10857.0 10863.5 10878.0 10889.0 10957.0 10972.0 10975.0 10986.0 10989.0 10998.5 11040.5 11079.0 11180.0 11250.0 11299.5 11318.5 10755.0 10771.0 10806.0 10824.5 10930.0 10978.0 10983.0 11003.0 11006.5 11017.5 11040.0 11143.5 11181.0 11244.5 11252.5 11258.0 11282.0 11301.0 11318.0 11323.0 11326.0 11336.0 11338.0 11352.0 11362.0 11366.0 11375.5 11376.0 11382.0 11402.0 11402.5 11448.5 $ MERGED DATA SOURCE PBU TOOL CODE GR DAS DIL 2446 $ REMARKS: 11334.5 11322.5 11338.0 11352.0 11361.5 11325.0 11365.0 11365.0 11365.5 11374.5 11375.5 11375.5 11375.0 11382.0 11401.5 11401.5 11402.5 11448.0 RUN NO. PASS NO. MERGE TOP 1 7 10331.0 1 7 10365.0 1 7 10395.0 1 7 10394.0 MAIN PASS. MTEM, SP, TEND, & TENS WERE SHIFTED WITH LL8. ILM, RT, & DI WERE SHIFTED WITH ILD. FUCT & NUCT WERE SHIFTED WITH NPHI. MERGE BASE 11419.0 11436.0 11483.0 11426.0 CN WN FN COUN STAT / ? ?MATCH1. OUT / ? ? MATCH2. OUT / ? ? MATCH3. OUT / ? ?MATCH4. OUT $ : ARCO ALASKA INC. : D.S. 1-03A : PRUDHOE BAY : NORTH SLOPE * FORMAT RECORD (TYPE# 64) ONE DEPTH PER FRAME Tape depth ID: F 14 Curves: Name Tool Code Samples Units GR DAS 68 1 GAPI DT DAS 68 1 US/F TEND DAS 68 1 LB TENS DAS 68 1 LB LL8 DIL 68 1 OHMM ILM DIL 68 1 OHMM ILD DIL 68 1 OHMM API API API API Log Crv Crv Size Length Typ Typ Cls Mod 4 59 310 01 1 4 59 530 16 1 4 59 995 99 1 4 59 995 99 1 4 08 995 99 1 4 08 995 99 1 4 08 995 99 1 8 RT DIL 6~ 1 OHMM 9 DI, DIL 68 1 IN 10 SP DIL 68 1 MV 11 MTEM DIL 68 1 DEGF 12 NPHI 2446 68 1 PU-S 13 FUCT 2446 68 1 CPS 14 NUCT 2446 68 1 CPS * DATA RECORD (TYPE# 0) Total Data Records: 151 4 4 4 4 4 4 4 966 BYTES * _ 08 995 99 4 08 995 99 4 08 995 99 4 08 995 99 4 47 995 99 4 47 995 99 4 47 995 99 56 Tape File Start Depth = 11520.000000 Tape File End Depth = 10313.000000 Tape File Level Spacing = 0.500000 Tape File Depth Units = Feet **** FILE TRAILER **** LIS representation code decoding summary: Rep Code: 68 36226 datums Tape Subfile: 2 375 records... Minimum record length: Maximum record length: 62 bytes 966 bytes Tape Subfile 3 is type: LIS TOOL STRING NUMBER: PASS NUMBER: DEPTH INCREMENT: FILE SUMMARY FILE HEADER FILE NUMBER: 2 RAW OPEN HOLE MAIN PASS Curves and lo9 header data for each run and tool strin9 in separate files; Tool Strin9 #1 for Sadlerochit run presented first (primary depth control strin9 used to depth shift the Sadlerochit interval) followed by files for other main pass tool strings per run. RUN NUMBER: 1 1 7 .2500 VENDOR TOOL CODE START DEPTH STOP DEPTH GR 10331.0 11454.0 DAC 10362.0 11469.0 DIFL 10394.0 11516.0 2446 10338 . 0 11460 . 0 $ LOG HEADER DATA DATE LOGGED: SOFTWARE VERSION: TIME CIRCULATION ENDED: TIME LOGGER ON BOTTOM: TD DRILLER (FT) : TD LOGGER (FT): TOP LOG INTERVAL (FT) : BOTTOM LOG INTERVAL (FT) : LOGGING SPEED (FPHR): 26-JAN-96 ECLIPS 2.1 1330 26-JAN-96 100 27-JAN-96 11500.0 11488.0 10330.0 11486.0 1800.0 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE CHT TTRM COMR GR CN KNJT KNJT DAC SLAM DIFL $ CABLEHEAD WTS SENSOR SUB COMMON REMOTE GAMMA RAY COMPENSATED NEUTRON KNUCKLE JOINT KNUCKLE JOINT DIGITAL ACOUSTILOG WTS SLAM ADAPTER DUAL INDUCTION TOOL NUMBER CABL338 3981XA 3510XA 1329XA 2446XA 3923XA 3923XA 1667EA/1680MA 3516XA 1503XA BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE(IN): DRILLER' S CASING DEPTH (FT) : LOGGER' S CASING DEPTH (FT) : 6.000 7798.0 .0 BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PM: FLUID LOSS (C3): MAXIMUM RECORDED TEMPERATURE (DEGF): KCL / POLY 10.00 65.0 9.7 6.4 175.0 RESISTIVITY (OFIMk AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT BOTTOM HOLE TEMPERATURE (BHT) : MUD FILTRATE AT MT: MUD FILTRATE AT BHT: MUD CAKE AT MT: MUD CAKE AT BHT: NEUTRON TOOL TOOL TYPE (EPITHERMAL OR THERMAL): MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): REMARKS: MAIN PASS. $ CN WN FN COUN STAT : ARCO ALASKA INC. : D.S. 1-03A : PRUDHOE BAY : NORTH SLOPE : ALASKA .127 .051 .185 .000 .000 .000 THERMAL SANDSTONE .00 6.000 .0 71.0 175.0 71.0 .0 .0 .0 * FORMAT RECORD (TYPE# 64) ONE DEPTH PER FRAME Tape depth ID: F 21 Curves: Name Tool Code Samples Units API API API API Log Crv Crv Size Length Typ Typ Cls Mod 1 2 3 4 5 6 7 8 9 10 11 12 13 14 15 16 17 18 19 20 21 GR DAC 68 1 GAPI DT24 DAC 68 1 US/F SFA1 DAC 68 1 US SFA2 DAC 68 1 US SFA3 DAC 68 1 US SFA4 DAC 68 1 US CHT DAC 68 1 LB TTEN DAC 68 1 LB SPD DAC 68 1 F/MN RFOC DIFL 68 1 OHMM RILM DIFL 68 1 OHMM RILD DIFL 68 1 OHMM RT DIFL 68 1 OHMM DI DIFL 68 1 IN SP DIFL 68 1 MV WTBH DIFL 68 1 DEGF CNC 2446 68 1 PU-S CNCF 2446 68 1 PU-S CN 2446 68 1 PU-L LSN 2446 68 1 CPS SSN 2446 68 1 CPS 4 4 56 310 01 1 4 4 56 520 99 1 4 4 56 995 99 1 4 4 56 995 99 1 4 4 56 995 99 1 4 4 56 995 99 1 4 4 56 635 99 1 4 4 56 635 99 1 4 4 56 636 99 1 4 4 07 220 06 1 4 4 07 120 44 1 4 4 07 120 46 1 4 4 07 120 46 1 4 4 07 120 44 1 4 4 07 010 01 1 4 4 07 995 99 1 4 4 47 995 99 1 4 4 47 995 99 1 4 4 47 890 01 1 4 4 47 334 31 1 4 4 47 334 30 1 84 * DATA RECORD (TYPE# 0 ) Total Data Records: 439 974 BYTES * Tape File Start Depth = 11520.000000 Tape File End Depth = 10313.000000 Tape File Level Spacing = 0.250000 Tape File Depth Units = Feet **** FILE TRAILER **** LIS representation code decoding summary: Rep Code: 68 106239 datums Tape Subfile: 3 520 records... Minimum record length: 62 bytes Maximum record length: 974 bytes Tape Subfile~4 is type: LIS RUN NUMBER: TOOL STRING NUMBER: PASS NUMBER: DEPTH INCREMENT: FILE SUMMARY FILE HEADER FILE NUMBER: 3 RAW OPEN HOLE REPEAT PASSES Curves and log header data for each pass, tool string, and run in separate files. 1 1 6 -.2500 VENDOR TOOL CODE START DEPTH STOP DEPTH GR 10514.0 11433.0 DAC 10544.0 11468.0 DIFL 11580.0 11495.0 2446 11580.0 11439.0 $ LOG HEADER DATA DATE LOGGED: SOFTWARE VERSION: TIME CIRCULATION ENDED: TIME LOGGER ON BOTTOM: TD DRILLER (FT) : TD LOGGER (FT) : TOP LOG INTERVAL (FT) : BOTTOM LOG INTERVAL (FT) : LOGGING SPEED (FPHR) : 26-JAN-96 ECLIPS 2.1 1330 26-JAN-96 1600 26-JAN-96 11500.0 11488.0 10330.0 11486.0 1800.0 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE CHT TTRM COMR GR CN KNJT KNJT DAC SLAM DIFL $ CABLEHEAD WTS SENSOR SUB COMMON REMOTE GAMMA RAY COMPENSATED NEUTRON KNUCKLE JOINT KNUCKLE JOINT DIGITAL ACOUSTILOG WTS SLAM ADAPTER DUAL INDUCTION TOOL NUMBER CABL338 3981XA 3510XA 1329XA 2446XA 3923XA 3923XA 1667EA/1680MA 3516XA 1503XA BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER' S CASING DEPTH (FT) : LOGGER' S CASING DEPTH (FT) : 6.000 7798.0 .0 BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: FLUID LOSS (C3) : MAXIMUM RECORDED TEMPERATURE (DEGF): RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT) : KCL / POLY 10.00 65.0 9.7 6.4 175.0 .127 71.0 MUD AT BOTTOM 3LE TEMPERATURE (BHT) : MI/D FILTRATE AT MT: MI/D FILTRATE AT BHT: MUD CAKE AT MT: MUD CAKE AT BHT: NEUTRON TOOL TOOL TYPE (EPITHERMAL OR THERMAL): MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): REMARKS: REPEAT PASS (LOGGED GOING IN HOLE). $ CN WN FN COUN STAT : ARCO ALASKA INC. : D.S. 1-03A : PRUDHOE BAY : NORTH SLOPE : ALASKA' * FORMAT RECORD (TYPE# 64) ONE DEPTH PER FRAME Tape depth ID: F 20 Curves: 051 .185 .000 .000 .000 THERMAL SANDSTONE .00 6.000 .0 175.0 71.0 .0 .0 .0 Name Tool Code Samples Units API API API API Log Crv Crv Size Length Typ Typ Cls Mod 1 GR DAC 68 1 GAPI 4 2 DT24 DAC 68 1 US/F 4 3 SFA1 DAC 68 1 US 4 4 SFA2 DAC 68 1 US 4 5 SFA3 DAC 68 1 US 4 6 SFA4 DAC 68 1 US 4 7 CHT DAC 68 1 LB 4 8 SPD DAC 68 1 F/MN 4 9 RFOC DIFL 68 1 OHMM 4 10 RILM DIFL 68 1 OHMM 4 11 RILD DIFL 68 1 OFIMM 4 12 RT DIFL 68 1 OHMM 4 13 DI DIFL 68 1 IN 4 14 SP DIFL 68 1 MV 4 15 WTBH DIFL 68 1 DEGF 4 16 CNC 2446 68 1 PU-S 4 17 CNCF 2446 68 1 PU-S 4 18 CN 2446 68 1 PU-L 4 19 LSN 2446 68 1 CPS 4 20 SSN 2446 68 1 CPS 4 4 56 995 99 1 4 56 995 99 1 4 56 995 99 1 4 56 995 99 1 4 56 995 99 1 4 56 995 99 1 4 56 995 99 1 4 56 995 99 1 4 07 995 99 1 4 07 995 99 1 4 07 995 99 1 4 07 120 46 1 4 07 120 44 1 4 07 995 99 1 4 07 995 99 1 4 47 995 99 1 4 47 995 99 1 4 47 995 99 1 4 47 995 99 1 4 47 995 99 1 80 * DATA RECORD (TYPE# 0) 1014 BYTES * Total Data Record~o 334 Tape File Start Depth = 11498.000000 Tape File End Depth = 10498.000000 Tape File Level Spacing = 0.250000 Tape File Depth Units = Feet **** FILE TRAILER **** LIS representation code decoding summary: Rep Code: 68 120248 datums Tape Subfile: 4 413 records... Minimum record length: Maximum record length: 44 bytes 1014 bytes Tape Subfile .~ 5 is type: LIS 96/ 1/31 01 **** REEL TRAILER **** 96/ 2/ 2 01 Tape Subfile: 5 2 records... Minimum record length: 132 bytes Maximum record length: 132 bytes End of execution: Fri 2 FEB 96 10:06a Elapsed execution time = 4.12 seconds. SYSTEM RETURN CODE = 0
