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
213-106
MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: Jim Reg g ��(z�,���� DATE: 12-07-2019 P. I. Supervisor FROM: Adam Earl SUBJECT: Surface Abandonment Petroleum Inspector PBU 01-04B ' BPXA PTD 2131060; Sundry 319-238 ' December 4, 2019 1 traveled out to PBU 01-04B to inspect the well cut off, the site, and marker plate. All strings were full of hard cement. The well was cut off at approximately 5 feet below tundra grade, and the correct information was verified on the marker plate. No issues. Attachments: 4 pictures 2019-1204_Surface_Abandon_PBU _ 01-04B_ae.docx Page 1 of 3 k U O b N �I a 0 0 ]I W a N, C� O b � � p N a. Q W My J W 7 O N Qi O N L a eQ6 e,sy7 ivs„r y W e' _ j STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION DEC 3 0 2019 WELL COMPLETION OR RECOMPLETION REPORT AND LOG la. Well Status: Oil ❑ Gas ❑ SPLUG ❑ Other ❑ Abandoned RI f Suspended ❑ 1bAr I06Cr`- 20AAC 25.105 20AAC 25.110 "CJ GINJ ❑ WINJ ❑ WAG ❑ WDSPL ❑ No. of Completions: Zero Development F+7,L E Exp oratory ❑ Service ❑ Stratigraphic Test ❑ 2. Operator Name: 6. Date Camp., Susp., or Abend.: 14. Permit to Drill Number/Sundry BE Exploration (Alaska), Inc 12/4/2019 213-106 • 319-238 ' 3. Address: 7. Date Spudded: 15, API Number: P.O. Box 196612 Anchorage, AK 99519-6612 10/10/2013 50-029-20070-02-00 - 4a. Location of Well (Governmental Section): 8. Date TO Reached: 16. Well Name and Number: 10/21/2013 PBU 01-04B - Surface: 429' FNL, 1399' FWL, Sec. 08, T10N, RI 5E, UM g Ref Elevations KB 88.70 17. Field/Pool(s): Top of Productive Interval: 388' FSL, 1930' FWL, Sec. 05, TION, R15E, UM GL 40.10 BE Surface PRUDHOE BAY, PRUDHOE OIL Total Depth: 2492' FSL, 1369' FWL, Sec. 05, T10N, R15E, UM 10. Plug Back Depth(MD/TVD): 1 B. Property Designation: Surface / Surface ADL 028329 4b, 4b. Location of Well (State Base Plane Coordinates, NAD 27): 11, Total Depth (MD/TVD): 19. DNR Approval Number: Surface: x- 698722 • y- 5940495 Zone - ASP 4 11402' / 8899' 79-179 TPI: x- 699228 y- 5941325 Zone - ASP 4 12. SSSV Depth (MD/TVD): 20 Thickness of Permafrost MD/IVD: Total Depth: x- 698605 y- 5943414 Zone - ASP 4 None 1900' (Approx.) 5. Directional or Inclination Survey; Yes ❑ (attached) No M 13. Water Depth, if Offshore: 21. Re-drill/Lateral Top Window MD/ D: Submit electronic and printed information per 20 AAC 25.050 N/A (ft MSL) 4981'/ 4958' 22. 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 MWD/GR/RES. MWD /GR/RES /NEU/DEN 23' CASING, LINER AND CEMENTING RECORD CASING Wf. PER FT. GRADE SETTING DEPTH MD SETTING DEPTH TVD HOLE SIZE CEMENTING RECORD AMOUNT PULLED TOP BOTTOM TOP BOTTOM 30" 157.5# a Surface 130' Surface 130' 39" Fondu 20" 94#/133# H4WK-55 Surface 1524' Surface 1524' 26" 930 sx Fondu 13-3/8" 72# N-80 Surface 2751' Surface 2751' 17-1/2" 242 sx Fondu, 545 sx Class 'G', 459 sx AS 1 9-5/8" 47#/40# L-80'500-96 Surface 4981' Surface 4958' 12-1/4" 1743 sx Class'G', 647 sx Class'G' 7" 26# L-80 4077' 8714' 4077' 8569' 8-1/2" 236 ax Class'G' 4-1/2" 12.6# 13cre0 1 8561' 1 11400' 1 8427' 1 8900' 6-1/8" 342 ax Class'G' 24. Open to production or injection? Yes ❑ No El 25. TUBING RECORD If Yes, list each interval open (MD/TVD of Top and Bottom; Perforation Size and Number; Date Perfd): GRADE DEPTH SET (MD) PACKER SET (MD/TV 4-1/2" 12.69 13Cr80 8569' 8446'/8320' I//( {/�I /` ^ 7 1 6C'/J t' 1 C� 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. FF Was hydraulic fracturing used during completion? Yes ❑ No RI Per AAC 25.283 (i)(2) attach electronic and printed (� information DEPTH INTERVAL (MD) AMOUNT AND KIND OF MATERIAL USED 2801'- 2806' Punch Tubing _JD Surface 224 Bible Class'G' Surface 10 Gal Cement 27. PRODUCTION TEST Date First Production: Not on Production Method of Operation (Flowing, gas lift, etc.): N/A Date of Test: Hours Tested: Production for Oil -Bbl: Gas -MCF: Water-Bbi: Choke Size Gas -Oil Ratio: Test Period --► Flow Tubing Press Casing Press: Calculated 24 Hour Rate --► Oil -Bbl: Gas -MCF: Water -Bbl: Oil Gravity - API(corn: Form 10.407 Revised 52017 CONTINUED ON PAGE 2 Submit ORIGINAL only RBDMS EC 3 0 2019 ,> . Yr. 28. CORE DATA Conventional Corals) Yes ❑ No RI Sidewall Cores Yes ❑ No IZ If Yes to either question, list formations and intervals cored (MD+TVD of top and bottom of each), and summarize lithology and presence of ail, gas orwater (submit separate sheets with this form, if needed). Submit detailed descriptions, core chips, photographs and laboratory analytical results per 20 AAC 25.071. 29. GEOLOGIC MARKERS (List all formations and markers encountered): 30. FORMATION TESTS NAME MD TVD Permafrost -Top Well Tested? Yes No Permafrost - Base If yes, list intervals and formations tested, briefly summarizing test results. Attach Top of Productive Interval 9140' 8916' separate sheets to this forth, if needed, and submit detailed test information per 20 AAC 25.071. Ugnu 5044' 5017' West Sak 6260' 6195' Colville Mudstone 6737' 6660' HRZ 8327' 8209' Base of HRZ 8515' 8384' LCU 8540' 8407' Sag River 8710' 8565' Shublik 8747' 8600' Sadlerochit-Zone 4 8825' 8671' CGL-Zone 3 9058' 8861' Base of CGL -Zone 2C 9140' 8916' 23SB - Zone 2B 9290' 8998' 21 TS - Zane 2A 9550' 9071' Zone 2B (Invert) 9850' 9073' Zone 2A (Revert) 10550' 9062' Zone 28 (Invert) 10820' 9063' Zone 2C 11150' 8992' Zone 3 11350' 8918' Formation at total depth: Zone 3 (From Base) 11350' 1 8918' 31. List of Attachments: Summary of Daily Work, Photo Documentation, Wellbore Schematic Diagram 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. 32. I hereby certify that the foregoing is true and correct to the best of my knowledge. Authorized Name. Lastufka, Joseph N Contact Name: Montgomery, Travis J Authorized Title =eciali Contact Email: Trevis.Montgomery@bp.cem Authorized Signature: Date:12-/1�0/I Contact Phone: +19075644127 INSTRUCTIONS General: This form is designed for submitti 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 in other given 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 coretl 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. Form 10-407 Revised 5/2017 Submit ORIGINAL Only T/I = 32/55. Temp = SI. WHPs (WIE request). No wellhouse or flowline. Dry hole tree. Temp scaffold installed. 5/16/2019 SV, MV = C. IA = OTG. 04:00 ***WELL SHUT IN ON ARRIVAL*** RIG UP HES ELINE UNIT 4863. 5/30/2019 ***JOB CONTINUED ON 31 -MAY -2019*** T/I = Vac/10. WHPs (WIE request). No wellhouse or flowline. Dryhole tree installed. Temporary scaffolding installed. The TP decreased 32 psi and the IAP decreased 45 psi 5/30/2019 since 5-16-19. ***JOB CONTINUED FROM 30 -MAY -2019*** (Plug and Abandonment) PUNCH TBG 2801'- 2806' MD W/ 2" x 5', 4 SPF, 0 DEG PHASE, TITAN 4C501 TUBING PUNCH. (good We pressure response) ALL LOGS TIED INTO TUBING TALLY DATED 26 -OCT -2013 5/31/2019 ***JOB COMPLETE ON 31 -MAY -2019*** T/I = 130/150. Temp = SI. WHPs (WIE request). Dryhole tree installed. Circ out rigged up. Temporary scaffold installed. 6/14/2019 SV, MV = C. IA = OTG. 15:30 Initial T/I/0 = 0/150/150 **`SLB Fullbore Pumping Crew*** Job Scope: Place TxIA Surface Cement Plug. SLB Pumped 5 bbls FW spacer 24 hnlc 5 8 pRg Class G CMT down TBG with IA returns to OTT. Flushed surface lines to OTT. SV / MV = C, IA CSG = C, OA CSG = OTG FWHPS = 98/49/49 15.8 ppg Class G CMT in Tx IA Est TOC in T x IA = Surface 6/17/2019 Est BOC in T x IA = 2801' MD / 2801' TVD TWO = 0/0/0. Temp = SI. Assist Ops bleed FL. No well house or flowline. FLP = 40 psi. Bled FLP from 33 psi to 0 psi in 0.5 hrs. Monitored for 30 minutes. During monitor flow line pressure increased to 5 psi. Job complete. 6/21/2019 SV, WV = C. MV = O. IA, OA = OTG. 13:00 T/I = Vac/Vac. Temp = SI. WHPs. (WIE request). Mono bore well. Scaffold installed. Dry hole tree. No change in WHP's since 6-21-19. 6/29/2019 SV,MV = C. IA = OTG. 15:29 T/I = VacNac. Temp = SI. WHPs (WIE Req). Mono bore well. Scaffold installed. Dry hole tree. No change in WHPs since 6-29-19. 7/25/2019 SV, WV = C. IA = OTG. 15:10 T/I = VacNac. Temp = SI. WHPs (WIE Req). Monobore well. Dry hole tree. No well house, flow line or scaffold. Temporary scaffold installed. WHPs unchanged since 8/11/2019 07/25/19. T/I = VacNac. Temp = SI. WHPs (WIE Req). Dry hole tree. No well house, flow line or scaffold. Temporary scaffold installed. WHPs unchanged since 08/11/19. 8/25/2019 SV, MV = C. IA = OTG. 01:00 T/I = VacNac. Temp = SI. WHPs (WIE Req). Dry hole tree. No well house, flow line or scaffold. Temporary scaffold installed. WHPs unchanged since 08/25/19. 9/10/2019 SV, MV = C. IA = OTG. 08:15 12/2/2019 Job Scope: P&A NES - Excavate surface to 14'. ***In Progress*** Job Scope: P&A NES - Complete excavation to 15'+. Tundra level transition obvious and photo documented @ 7' below pad grade. Set and backfill shoring can. IH and Fire Dept approved ventilation plan and ERRP. Cut windows in 30, 20, 13-3/8, and partially into 9-5/8" 12/3/2019 casing. Daily Report of Well Operations PBU 01-04B Job Scope: P&A NES - Complete cutting off wellhead, Cement to surface in all strings except 4-1/2 Tbg. TOC in 4-1/2 @ 15'. Top off w/ 10 gal cement. WOC. AOGCC inspection completed by Adam Earl. Weld on marker plate. Wellhead stub 6'below tundra grade. Take 12/4/2019 final pics and backfill shoring can. ***In Progress*** 12/5/2019 Job Scope: Remove shoring can. Complete backfill. Demobe ***Job Complete*** qb r %.. I� " 40- lw v I ttIn f / _ r Rr� x � r _�..% _•�_ .q. 10 • �' Y I / DRYHOLE HEAD= F AOR= RFM ABANDONED ELEV = 73' -LEV= 8 CONDt1CTOR IP = 4339-1 CSG 1449' x A ie = 112' @ 11309' PATCH Wm MID= 9092' him ND = 8800' SS 20' CSG, 94#, 1+40 & 133#, K-55 1606' 9-5/8' CSG, 47#, L-80 TCI, D = 8.681' 2073' 13-3/8' CSG, 72#, N-80, D = 12.347' 2736' / TXIA TOC & BGC (06/17/19) SURFACE - 2801' TBG PUNCH, 4 SPF (05/31/19) 2801' - 2806' 9-5/8' X 7- BKR HRD ZXPN LTP, D = 6.19" 4077' -518'X 7' BKR FLEX LOCK HGF;, D = 624' 409$ Fimum ID = 3.725" 8551' 2" HES XN NIPPLE '8' CSG, 40# / 43.5# / 47#, SOO-95 BTRS , ^-4981 8_835'/ 8.755'18-681" ST TOP & BOT TBG & W CMT (04/19/19) 6745' -844 L TAGGED TOC 05/05/19 JTOPOFCEMENT�— 7214' j— ALLSTRINGS CUT 6' BELOW TUNDRA GRADE. CEMENTED TO ;URFACE & MARKER CAP WELE ON. 12/04/19 412' TBG, 12.6#, 13CR-80 VAM TOP, 8569' — .0152 bpf, D = 3.958' 7- LNR, 269, L-00 VAM TOP HC, .0383 bpf, ID = 6.276' 8690' 17' LNR 269, L-80 BTC -M, .0383 bpf, D = 6276' 1 PERFORATION SLVMARY R[F LOG: MAC ON 10/21/13 ANGLEAT TOP PSR: 87" @ 10570' Note: Refer to Production DB for historical perf data SIZE I SPF I INTERVAL I OprJSgz I IT SOZ 2.88" 6 10570 - 10820 C 10/25/13 2.88" 6 11250- 11255 C 1025/13 PBTD 12.8#, 13CR VAM TOP, D = 3.958' CHROMETBG&• •:• 11.11♦1t1w11V1V1V111•1T1V1, 11111111 .�161111111,1 • e ••- 11111611111111 64 4i IOi0��0000►100 ►11 ,® 111 !111111j�11111111111111►N 237,V 1--14-1/2- HES X NP, D = 3.813' GAS LFT MANDRELS ST MO I TVD I DEV I TYPE VLV LATCH I PORT DATE 6 3146 3146 1 MMC; OM1' RK 0 04/05/19 5 4748 4737 16 KBG DMY BK 0 1026/13 4 5858 5802 11 KBG2 SO BK 20 06/07/17 3 6798 6720 13 KBG2 DMY BK 0 10/26/13 2 7572 7475 12 KBG2 'DMY BK 0 1026/13 1 8221 8108 17 KBG2 'DMY BK 0 03/09/19 'STA # 2 & #1 = COVERED BY CMT MILLOUT WINDOW (01-046)4981'-4998' 1 8581' 1 1 11205' 1 PUNCH w 2' 4 SPF 3S NP, D=3.813' 7' X 4-12' FPS TNT NKR, D = 4-1/2' FEB X NP, D = 3-813- 4-1/2' HES XN NP, D = 3.725' 4-12' PXN PLUG (06107/17) / 11' TEBACK D=4.35" 1/2' WLEG, 3.958' .MD TT NOT LOGGED BKR RS PACKOFF SEAL NP, D = 4.25" X 5- BKR FLD( LOCK HGR, D = 4.31' X 412" XO, D= 3.920" TAG I PUP JOINT w / RA TAG I -DATE REV BY I COMMENTS DATE REV BY COMMENTS 07107170 INITIALCOMPLETKIN 04/12/19 MASIJMD, GLV C/O& TBG PUNCH (04A)5119 09101101 N3S SIDETRACK 01-0410 05/02/19 JJUJMD CEMENT PLUG (04/19/19) 05131106 N2ES CTD (014)4B) SUSPEND525106 05/09/19 JNUJMD UPDATED TXATOC PER SLTAC 1029113 PKR 272 SIDETRACK (01-046) 06105/19 TJS/JMD TBG PUNCH (05/31119) 0226119 KP/JMD DRYHOLE TREE 0624119 JJUJMD TXIH ESTTOC & BOC 06117/19 03/13/19 LG/JMD GLV C/O (03109/19) 12/09/19 AB/JMD ABANDONED (12/04/19) PRUDHOE BAY UNIT WELL: 01-046 PERMIT No:'1131060 API No: 50-029-20070-02 SEC 8, T10N, R15E, 430' FNL & 1399' TWL BP Exploration (Alaska) STATE OF ALASKA 1-ItCEi v ED ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS no 1. Operations Performed Abandon ❑ Plug Perforations m Fracture Stimulate ❑ Pull Tubing ❑ Operations shutdown ,.__P Suspend ❑ Perforate ❑ Other Stimulate ❑ Atter Casing ❑ Change Approved Program A❑ Plug for Repoli ❑ Perforate New Pool ❑ Repair Well ❑ Re-enter Susp Well ❑ Other: Secure Reservoir 2. Operator Name: BP Exploration (Alaska), Inc 4. Well Class Before Work 5. Permit to Onll Number 213-106 3. Address: P.O. Box 196612 Anchorage, Development ® Exploratory ❑ AK 99519-6612 Stratigraphic ❑ Service ❑ 1 6. API Number: 50-029-20070-02-00 7. Property Designation (Lease Number): ADL 028329 B. Well Name and Number: PBU 01-04B 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: Length: Size: MD: TVD: Burst: Collapse: Total Depth: measured 11402 feet Plugs measured 6745, 8551, 11205 feet true vertical 8899 feet Junk measured None reel Effective Depth: measured 6745 feet Packer measured 8446 feet true vertical 6668 feet Packer true vertical 8320 feet Liner 4367 Casing: Length: Size: MD: TVD: Burst: Collapse: Conductor 80 30" 50-130 50-130 880 Surface 1475 20" 49-1524 49-1524 2320 / 1530 15001520 Intermediate 2704 13-3/8" 47-2751 47-2751 5380 2670 Intermediate 4936 9-5/8" 45-4981 45-4958 6870/6820 4760/3330 Liner 4367 7" 4077-8714 4077-8569 7240 5410 Liner 2839 4-1/2" 8561-11400 8427 - 8900 8430 7500 Perforation Depth: Measured depth: 10570 - 11255 feet True vertical depth: 9063-8953 feet Tubing (size, grade, measured and true vertical depth) Packers and SSSV (type, measured and true vertical depth) 12. Stimulation or cement squeeze summary Intervals treated (measured): 4-1/2" 12.6# 13Cr80 42-8569 4-V2" HES TNT Perm Packer including volumes used and final pressure: 8446 42-8434 8320 13. Representative Daily Average Production or Injection Data Oil -Bbl Gas-Mcf Water -Bbl Casing Pressure T Tubing Pressure Prior to well operation: Shut -In Subsequent to operation: Shut -In 14. Attachments:(.,ui 4 aer zo Mc 25 070 25 071, s 25.2es) 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 ❑ IGSTOR ❑ WINJ ❑ WAG ❑ GINJ ❑ SUSP ❑ SPLUG ❑ 17. 1 hereby certify that the foregoing is true and correct to the best of my knowledge. I Sundry Number or N/A if C.O. Exempt: Authorized Name: Worthington, Area J 319-026 Contact Name: Montgomery, Travis J Authorized Title. Interventions & Integrity Engineer Contact Email: Travis.Montgomeryabp.cAm Authorized Signature: Date: Contact Phone: +1 907 564 4127 Form 10-404 Revised 04/2017 �9 M�o+�tAK15 IBDMSL*MAY 10 2019 Submit Onginal Only Daily Report of Well Operations 01-04B ACTIVITYnATF SUMMARY T/I/=200/450 R/U lubricator, Set 4" CIW "H" BPV #151 through production tree. R/D production tree. Installed Dryhole tree Temp #PNA2. Torqued to specs. R/U lubricator, PT'd against Master 300/low..5000/high.. pass see "Field Charted Tests" Pulled 4" CIW "H" BPV 2/21/2019 #151. shut barriers, R/D lubricator. FWP's 200/450 see log for details. T/I = 400/420. Temp = SI. WHPs (WIE request). No AL, flowline, wellhouse, or scaffold. Dryhole tree installed. 3/1/2019 SV = C. MV = O. IA = OTG. 1530 hrs. ***WELL S/I ON ARRIVAL***(P&A) SET WHIDDON ON PX PLUG @ 8521' SLM. RAN GAMMA RAY AND PDS 40 ARM CALIPER PER PROGRAM FROM 2000' MD TO SURFACE. PULLED DMY GLV FROM STA#1 AT 8221' MD. 3/8/2019 ***CONT ON 3-9-19 WSR*** T/1/0=110/vac/vac (LRS Unit 72 -Assist Slickline: Circ Well / AOGCC CMIT) Pumped the following down the IA, up the TBG, to surface return tanks: 5 bbls 60/40 meth, 50 bbls 150* Freshwater w/ F103+UO67, 490 bbls 9.8 ppg NaCl brine. Sample pulled, clean 9.8 ppg brine. 5 bbls neat meth. U -Tube for 30 min between TBG & IA for freeze protect. 3/8/2019 ***Job Cont to 03-09-2019 WSR*** ***Job Cont from 03-08-2019 WSR*** (LRS Unit 72 - Assist Slickline: Circ Well / AOGCC CMIT) Finished U-tube for IA and Tbg. Pumped 5 bbls 60/40 meth through hardline and choke skid to FP surface lines. AOGCC (rep Adam Earl) CMIT-TxIA to 2160 psi PASS Target psi= 2000 Max Applied psi = 2200 psi. Pumped 4 bbls 60/40 meth down Tbg/IA to bring psi up to 2210/2215 psi for CMIT- TxIA. Tbg/IA lost 32/32 psi in 1st 15 mins and 18/18 psi in 2nd 15 mins for a total loss of 50/50 psi in 30 min test. Bled Tbg/IA to 20/30 psi and got back -4.2 bbls. Sline in control of well per LRS departure. FWHPs=20/30 3/9/2019 1**Tags hung on master and IA casing. AFE sign already on well ***CONT FROM 3-8-19 WSR***(P&A) SET DMY-GLV IN STA#1 AT 8221' MD. PULLED EMPTY CSUB. TAGGED TOP OF PRONG AT 8521' SLM (AOGCC WITNESSED BYADAM EARL) LRS PERFORMED PASSING CMIT TxIA TO 2000#. 3/9/2019 ***WELL S/I ON DEPARTURE, DSO NOTIFIED OF WELL STATUS*** T/I = Vac/Vac. Temp = SI. WHPs (WIE Req). Dry hole tree and temporary scaffold installed. No well house or flowline. 3/15/2019 SV, MV = C. IA = OTG. 13:45 T/I = VACNAC. Temp = SI. WHPs (WIE request). No wellhouse, AL or flowline. Temporary scaffolding installed. Dry hole tree. 4/2/2019 SV, MV = C. IA = OTG. 23:30 ***WELL S/I ON ARRIVAL*** (Plug and Abandonment) HES RELAY UNIT #46 RIH TO 8500' MD w/ 2" x 5' 0 DEG PHASE 4 SPF TITAN 4C631 TUBING PUNCH ATTEMPT TO PRESSURE TBG TO 500 PSI & THE IA TRACKED. INSTRUCTED NOT TO FIRE. POOH & RDMO. WELL LEFT S/I ON DEPARTURE. FINAL T/I/O = 0/0/0. 4/3/2019 ***JOB INCOMPLETE 04 -APR -2019°"* Daily Report of Well Operations 01-04B ***WELL S/I ON ARRIVAL` (Plug and Abandonment) HES RELAY UNIT #46 RAN 4-1/2" D&D HOLE FINDER TO 8551' SLM (leak found between stops @ 4650'& 3040' slm, suspect st #6 glv) SET SLIP STOP C -SUB @ 3340' SLM ATTEMPT TO PULL LGLV FROM STA # 6 AT 3146' MD (only core & fish neck of latch recovered). RAN 1.5" LIB ON OM -1 TO STA#6 @ 3146' MD, (EMPTY POCKET) 4/4/2019 ***JOB CONTINUED ON 05 -APR -2019*** ***JOB CONTINUED FROM 04 -APR -2019*** (Plug and Abandonment) HES RELAY UNIT #46 FISH LGLV STA#6 FROM C -SUB @ 3360' SLM SET RK-DGLV STA #6 @ 3146' MD PRESSURE UP TBG TO 500 PSI (ia not tracking) PULLED 4-1/2" SLIP STOP CATCHER FROM 3340' SLM (recovered spring & wobble ring) SWAP OVER FROM SLICKLINE TO RELAY PUNCH TBG 8436'- 8441' MD W/ 2", 0 DEG PHASE, 4 SPF TITAN 4C631 TUBING PUNCH is pressure response . ALL RUNS TIED INTO TUBING TALLY DATED 26 -OCT -2013 4/5/2019 ***JOB COMPLETE ON 05 -APR -2019*** TWO = MV/10/10. Temp = SI. WHPs (WIE request). Wellhouse & scaffold removed. Dryhole tree & P&A RU with ball loaded & temporary scaffold installed. 4/17/2019 SV, MV = C. IA, OA = OTG. 16:30 SLB Fullbore Pumping Crew Job Scope: Plug and Abandonment (place lateral cement plug in TBG and IA) Rig up and spot equipment. Troubleshoot ice plug in hardline. 4/18/2019 ***AWGRS continued on 04/19/19*** 1 ***Continued from AWGRS 04/18/19*** SLB Fullbore Pumping Crew Job Scope: Plug and Abandonment (place lateral cement plug in TBG and IA). Pumped 5 bbis 60/40 to verify flow path down the TBG taking returns from IA to production via 01-36 FL. Pumped 3 bbls FW spacer, 44 bbis 15.8 ppg Class G cement and 2 bbls FW spacer. Launched 7" foam wiper ball down TBG. Displaced CMT with 104 bbis 9.8 ppg NaCl and 10 bbis 60/40. U -tubed TxIA. ***Job Complete*** 15.8 ppg Class G cement in TxIA Est. TOC in TBG and IA Q 7,140' MD / 7 053' TVD 4/19/2019 Est. BOC in TBG and IA T/I = VACNAC. Temp = SI. WHPs (WIE request). No wellhouse, AL or flowline. Temporary scaffolding installed. Dry hole tree. 5/3/2019 SV, MV = C. IA(X2) = OTG. 02:30. ***"WELL S/I UPON ARRIVAL**** (Plug and abandonment) R/U SLICKLINE SWCP #4522 FOR AOGCC D&T TOC 5/4/2019 ****CONT JOB ON 5/5/19"" T/1/0=0/0 Temp=S/1 (LRS Unit 76 - Assist Slickline: Plug and Abandonment) Spotted Unit. 5/4/2019 **Continued on 05-5-19 WSR** ****CONT. JOB FROM 5/4/19**** (Plug and abandonment) DRIFTED W/ 2.25" CENT, S -BAILER TO TOC @ 6,745' SLM (Good sample, AOGCC witnessed Bob Noble) LRS PERFORMED PASSING CMIT-TxIA TO 2,500 psi (Passed per AOGCC criteria, witnessed Bob Noble) LRS PERFORMED PASSING CMIT-TxIA TO 2,500 psi Passed per BP criteria) 5/5/2019 ****DSO NOTIFIED OF STATUS UPON DEPARTURE**** Daily Report of Well Operations 01-04B **Continued from previous WSR** (LRS Unit 76 - Assist Slickline: AOGCC CMIT-AA) AOGCC CMIT-TxIA PASSED 2650/2587 psi Perr AOGCC C iteria Witnessed by Bob Noble. Max applied=2750 psi. Target pressure= 2500 psi. Pressured up T/IA to 2730/2743 psi with 4.6 bbls 60/40. 1st 15 mini/IA lost 33/59 psi. 2nd 15 min T/IA lost 20/38 psi, 3rd 15 min T/IA lost 15/32 psi, 4th 15 min T/IA lost 12/27psi for a total loss of 80/156 psi in 60 min. CMIT-TxIA PASSED @ 2714/2684 (Per BP Criteria). Repressuered T/IA with .06 bbis 60/40. 1 st 15 min T/IA lost 9/25 psi. 2nd 15 min T/IA lost 7/21 psi. 3rd 15 min T/IA lost 6/17psi for a total loss of 22/63 psi in 45 min. Bled pressures to 5/30 psi and recovered -3 bbls. Slickline in control of well upon departure. Tags hung 5/5/2019 1 Final Whp's=5/30 TREE= DRY HOLE W3-LFEAD= FMCS ACTUATOR= REIVIOVED OKB. ELEV = 73' REF ALIT =_ 88.7' BF. ELEV = 43.67' KOP= 4339" 'Max Angle = 112' @ 11309" I Datum MD= 9092'1 20" CSG, I' CSG, 4' CONDUCTOR 13-3/8' CSG PATCH '31 01 -04B SAFETY NOTES: WELL ANGLE > 70' @ 9375'•' CHROME TBG & LNR ••• MONOBORE COMPLETION - NO OA TM' 9 ig r-1' CUT BLOW SURFACE 1449' 2058' 9-5/8 ES CRKN R 19-5/8"X 7' BKR FRO ZXPN LTP, D = 6.19' 4077 9-5/8' X 7' BKR FLEX LOCK HGR D = 6.24' 4093' Minimum ID = 3.725" @ 8551' 4-1/2" HES XN NIPPLE 9-5/8' CSG, 40# / 43.5# / 47#, SOO-95 BTRS , —4981 D = 8.835' / 8.755'/8681' EST TOP & BOT TBG & A CMT (04/19/19)6745 - 8440' SL TAGGED TOC 05/05/19 TOPOFTFE4-1/2-LNR 8561 4-1/2' TBG, 12.6#, 13CR-80 VAM TOP, 8569' .0152 bpf, D = 3.958' L-80 VAM TOP HC, .0383 bpf, D = 6276' LNR 26#, L-80 STC -M, .0383 bpf, D = 6.276' —j 8714 PERFORATION SLMMARV REF LOG: MWD ON 10/21/13 ANGLE AT TOP PERF: 87'@ 10570' Note: Refer to Production DB for historical perf data SIZE SPF INTERVAL I Opn/Sgz I SHOT I SOZ 2.88" 6 10570- 10820 C 10/25/13 2.88' 6 11250 -112551 C 10/25/13 PBTD LNR, 12.6#, 13CR VAM TOP, bpf, D = 3.958- 1 11314' 1 2374' —14-1/2' FES X NP, D= GAS LIFT MANDRELS ST MD TVD DEV TYPE VLV LATCH PORT DATE 6 3146 3146 1 MMG DMYJKO 4-1/2' WLEG, 3.958' 10/29113 04/05/19 5 4748 4737 16 KBG2 OMY10/26/13 9429' PUPJONT wI RATAG 4 5858 5802 11 KBG2 SO06/07/17 3 6798 6720 13 KBG2 DMY10/26/13 2 7572 7475 12 KBG2 'DMY10/26/13 1 8221 8108 17 KBG2 'DMV03/09/19 `STA # 2 & #1 = COVERED BY GMT 9-8/5' FOC MILLOUT WINDOW (01-04B) 4981' - 4998' 436'-8441' I—iTBG PUNCH w/2-4 SPF (04405/19)_] 8418' 4-112' FES X NP, D = 3.813' DATE T X 4-1/2' HES TM PKR D = 3.856' 8481' 4-1/2' FES X NP, ID 8661' 4-112' HES XN NP, D = 3.725' 8661' 4-1/2" PXN RUG (06/07/17) 8561' T X 5' BKR HRD-E ZXPN UP] 05131106 w/ 1 T TEBACK, D = 4.35' 8569' 4-1/2' WLEG, 3.958' 10/29113 EEMD TT NOT LOGGED 8581' 5- BKR RS PACKOFF SEAL NP, D = 4.25' 8583' 7- X 5- BKR RIX LOCK HGR D = 431- 31'5'X 5'X4-1/2' XO, D = 3.920' 9429' PUPJONT wI RATAG 1 10309' 1 11205' 6/4-1/2'WFDCRP(o1/11/15) DATE REV BY COMWBJTS DATE REV BY CONIAENTS 07107!/0 INITIAL COMPLETION 03/13/19 LG'JMD GLV CJO (03/09/19) 09/01101 N3S SIDETRACK (01-04A) 04/12/19 S/J GLV CJO & TBG RJNCH (04/05/19) 05131106 N2E3 CTD (01-048) SUSPEND 512510 05/02/19 JJL/JMD CEVBJT RUG (04119/19) 10/29113 PKR 272 SIDETRACK(01-04B) 05/09/19 JNL/JMD UPDATEDTXIN TOC PER SL TAG 01/23/19 JN./JIVD ADDED REF & BF ELEV 02/26/19 KP/JMD DRY HOLE TREE PRUDHOE BAY UNIT WELL 01-04B PERMT No: `2131080 API No: 5D-029-20070-02 SEC 8, T1 ON, R1 5F 430' FNL & 1399' FWL BP Exploration (Alaska) MEMORANDUM TO: Jim Regg P.I. Supervisor FROM: Bob Noble Petroleum Inspector Section: 8 Township: Drilling Rig: NA Rig Elevation: Operator Rep: Jerry Boyles Casing/Tubing Data (depths are MDI Conductor 30" 0. D. Shoe@ Surface: 20" 0. D. Shoe@ Intermediate: 13 3/8" 0. D. Shoe@ Production: 9 5/8" 0. D. Shoe@ Liner: 7" 0. D. Shoe@ Liner: 41/2" - 0. D. Shoe@ Tubing: 41/2" 0. D. Tail@ Plugging Data: Test Data State of Alaska Alaska Oil and Gas Conservation Commission DATE: May 5, 2019 SUBJECT: Well Bore Plug & Abandonment PBU 01-04B BPXA , PTD 2131060; Sundry 319-026 10N Range: 15E Meridian: Umiat MW Above NA Total Depth: 11402 ft MD Lease No.: ADL 0028322 " 6745 ft MD - 9.8 brine - Suspend: P&A: X Casino Removal: 130 - Feet Csg Cut@ Feet 1524 - Feet Csg Cut@ Feet 2751 - Feet Csg Cut@ Feet 4981 Feet Csg Cut@ Feet 8714 Feet Csg Cut@ Feet 11400 Feet Csg Cut@ Feet 8569 Feet Tbg Cut@ Feet Type Plug Founded on Depth Btm Depth To MW Above Verified Perforation Balanced 8440 ft MD 6745 ft MD - 9.8 brine - Wireline tag Initial 15 min 30 min 45 min Result Tubing 2736 2697 2677 2662- A 2743 2684 - 2646 2614 " P OA Initial 15 min 30 min 45 min Result Tubing IA OA Remarks: Reservoir abandonment plug - Attachments: none rev. 11-28-18 2019-0505_Plug_Verification_PBU_01-04B_bn THE STATE °fALASKA GOVERNOR MIKE DUNLEAVY Travis Montgomery Interventions & Integrity Engineer BP Exploration (Alaska), Inc. P.O. Box 196612 Anchorage, AK 99519-6612 Re: Prudhoe Bay Field, Prudhoe Oil Pool, PBU 01-04B Permit to Drill Number: 213-106 Sundry Number: 319-238 Dear Mr. Montgomery: Alaska Oil and Gas Conservation Commission 333 West Seventh Avenue Anchorage, Alaska 99501-3572 Main: 907.279.1433 Fax: 907.276.7542 www. aogcc.olaska.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 DATED this 17 day of May, 2019. '-ABDMSiLv- MAY 2 0 2919 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 ies � l V "U MAY 0 9 2019 1. Type of Request: Abandon 0 • Plug Perforations ❑ Fracture Stimulate ❑ Repair Well ❑ OperetiA 0 Suspend Perforate ❑ Other Stimulate ❑ Pull Tubing ❑ Change Approved Program [I Plug for Redrill ❑ Perforate New Pool ❑ Re-enter Susp Well ❑ Alter Casing ❑ Other ❑ 2. Operator Name: BP Exploration (Alaska), Inc 4. Current Well Class: Expl"tory ❑ Development 5. Permit to Drill Number. 213-106 3_ Address: P.O. Box 196612 Anchorage, AK 99519-6612 Stratigraphic ❑ Service ❑ 6. API Number: 50-029-20070-02-00 - 7. If perforating: 8. Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? Will planned perforations require a spacing exception? Yes ❑ No 0 PBU 01-04B 9. Property Designation (Lease Number): 10. Field/Pools: ADL,W0529— /' b '!'4. F% 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): 11402 8899 - 6745 6668 6745.8551.11205 None Casing Length Sim MD TVD Bunt Collapse Conductor 80 30" 50-130 50-130 880 Surface 1475 20" 49-1524 49-1624 2320 / 1530 15001520 Intermediate 2704 13-3/8" 47-2751 47-2751 5380 2670 Intermediate 4936 9-5/8" 45-4981 45-42 58 6870/6820 4760 13330 Liner 4367 7" 4077 - 8714 4077 - 8569 7240 5410 Liner 2839 4-1/2" 8561-11400 8427-8900 8430 7500 Perforation Depth MD (ft): Perforation Depth TVD (ft). 1 Tubing Size: Tubing Grade: Tubing MD (ft): 10570 - 11255 9063 - 8953 4-1/2" 12.6# 13Cr80 42-8569 Packers and SSSV Type: 4-12" HES TNT Penn Packer Packers and SSSV MD (ft) and TVD (ft): 8446/8320 No SSSV Installed No SSSV Installed 12. Attachments: Proposal Summary 0 Wellbore Schematic 0 13. Well Class after proposed work: Detailed Operations Program ❑ BOP Sketch ❑ Exploratory ❑ Stratigraphic ❑ Development 0 ' Service ❑ 14. Estimated Date for Commencing Operations: June 1, 2019 15. Well Status after proposed work: Oil ❑ WINJ ❑ WDSPL ❑ Suspended ❑ 16. Verbal Approval: Date: GAS ❑ WAG ❑ GSTOR ❑ SPLUG ❑ Commission Representative: GINJ ❑ Op Shutdown ❑ Abandoned 0 17. I hereby certify that the foregoing is true and the procedure approved herein will not Contact Name: Montgomery, Travis J be deviated from without prior written approval. Contact Email: Travis.Montgomery@bp.com Authorized Name: Montgomery, Travis J Contact Phone: +1 907 564 4127 Authorized Title: Interventions & Integrity Engineer Authorized Signature: Z0 Date: 90 COMMISSION USE ONLY (_AI Conditions of approval: Notify Commission so that a representative may witness Sundry Number: ��� 0 Location Clearance Plug Integrity ❑ BOP Test ❑ Me1s,h chanical Integrity Test 11 Other: �kn JrOCEOC V V %e-%4- 1� 4.S 470eQ( Post Initial Injection MIT Req'd? Yes ❑ No ❑/ Spacing Exception Required? Yes ❑ No 6 Subsequent Form Required: f O - Lil APPROVED BYTHE J I O Approved by. COMMISSIONER COMMISSION Date S �/c 611glLti Form 10-403 Revised 04/2017 ORIGINAL IBDMS� MAY 202019 •�� Submit Farm and Approved application is valid for 12 months from the date of approval. Attachments in Duplicate 01-04 P&A sundry Rev 3 5/14/19 Intervention Engineer Travis Montgomery (907) 564-4127 Production Engineer Finn Oestgaard (907) 564-5026 History 01-04B was completed in 1971 with a three -string casing design. The outer casing string is set in permafrost. GWO has determined that these wells are at risk for sudden wellhead movement, as demonstrated by 02-03A and 02-02A. As such, the AOGCC has requested this well be plugged and abandoned to mitigate HSSE consequence associated with this potential risk. Objective Place a lateral surface cement plug in the wellbore. The cement top in the tubing and IA will be at surface. Procedural steps Wireline/Fullbore — DONE 1. Pull the deepest accessible DGLV. 2. Circulate down tubing and up IA with surfactant wash followed by 9.8 ppg brine. ➢ 5 bbls MEOH ➢ 50 bbls hot (160 deg) freshwater + surfactant; 2 gal/mgal F103 and 2 gal/mgal UO67 ➢ 460 bbls 9.8 ppg brine 3. AOGCC-witnessed CMIT-TxIA to 1500 psi. 4. AOGCC-witnessed tag of XN plug @ 8551' MD. 5. Run GR log and caliper survey from 2000' MD to surface for future subsidence surveillance/analysis. Wireline — DONE 1. Punch tubing —8440' MD. Fullbore — DONE 1. Pump cement job down tubing while taking returns from IA. Target TOC —7140' MD in tubing and IA. ➢ 5 bbls MEOH ➢ 3 bbls FW spacer ➢ 44 bbls of Class G cement per design ➢ 2 bbls FW spacer ➢ Foam wiper ball ➢ 106 bbls of 9.8 ppg brine displacement ➢ Consider U -tubing methanol to fill TBG and IA down to 150' for freeze protection. Cement Type/weight: Class G 15.8 ppg mixed on the fly or batch mixed. Field blend to be =lab ppg +/- 0.1 ppg Slurry Temperature: I between 800 and 110°F Fluid Loss: 40-200cc (20-100cc/30 min) Compressive Strength: 2000 psi in 48 hrs. Thickening Time: Minimum 5 hours Wireline/Fullbore — DONE 1. AOGCC-witnessed CMIT-TxIA to 2500 psi. 2. AOGCC-witnessed tag of TOC. The above steps have been completed as of 5/5/19. Wireline 1. Punch tubing —2800' MD. Fullbore 1. Remove IA gate valves and replace with integral valves at WSL discretion. 2. Pump cement job down tubing while taking returns from IA. ➢ 5Is MEOH _ _� /�N a / ➢ 2200 bbls of Class G cement per design (20 bbls excess) vb � � O e.� Cement Type/weight: Class G 15.8 ppg mixed on the fly or batch mixed. Field blend to be =lab ppg +/- 0.1 pq Slurry Temperature: between 800 and 110°F Fluid Loss: 40-200cc (20-100cc/30 min) Compressive Strength: 2000 psi in 48 hrs. Thickening Time: Minimum 5 hours DHD 1. Bleed tubing and IA pressures and monitor for 24 hours. Special Projects 1. Excavate and Cut off all casings and wellhead 3' below original tundra level.op job the 30" x 20" annulus and all other annuli and tubing with cement as needed. 2. AOGCC witness cement tops in all annuli. 3. Bead weld marker cap on outermost casing string (30" Conductor) to read as follows: BP Exploration Alaska, Inc. 01-04B PTD # 213-106 APII/# 50-029-20070-02 �J /je� �oCv ik e k (T IUAIUK= AALISUN IAL KB. ELB/ = 73' F3 W -— 730' (X1A11UL'lOR -- 4399' 13-318" CSO Angle = 11Y 6 11309' &a 3 DS 01-04 Current Status SAFETY NOTES: WELL ANGLE> 70.89376"" CHROME TBG & LNR '0* MONO80RE .conn I I wraa� ■ COMPLETION - NO OA "' Minimum ID = 3.725" @ 8561' 4-1/2" HES XN NIPPLE 518" (SG, 401 / 43 50 1 470, 80685 8T%, ^4981 = 8.835' 1 8.755'18.081. IT OFaMM 7214' ubine and IA cemented from 8440'MD to 6745'SLM ITOPOF THE 4-1/2' LN2 t -f12" TBG, 12 ft. 13CR-80 VAM TOP, 01 b2 t411, I) - 305W VAM TOP NC- -03M bnf. D = 6278" n3TORATION SUMMARY REF LOG: AMID ON 1021113 ANGLEAT TOPPERF. 87" ®10570 Able: Rafer to Production OB for hisinnod pert dela SUE SFF MSNAL OpMSw SHOT SOZ 2.88' 6 10570 -IOM O 10125/13 2.88' 6 11250-11255 C 1025113 .0152 bpf, D = 3.958' 14-12" FES X NP, D" 3.813' GAS LFT MANDRELS ST AD TVO 1 OEV I TYPE VLV LAMH PORTI DATE 6 31463146 OV20117 1 Mir13 NKS CTD(8I-048)SIJISPFMO(J20117 RC 18 1125113 5 4748 4737 16 KBO2 = OMl' BK 0 1OM13 4 5858 510211 KBG2 SO BK 20 06107117 3 6790 6720 13 KBG2 OMl' BK 0 10126113 2 7572 7475 12 1 KOO2 OW BK 0 1OW13 1 8221 81081 17 1 KBlo2 OMl' SK 0 1026113 4546' —i9-5/8" DV COLLARi MILL OUT WINDOW (01.048) 498 V - 4998' 8551' DATE j REV BY I C—OMkeJTS DATE TEV BY COM 34f5 07107170 JINITIALCOMPLETION 01113/15 TffJND SETLBP(01111115) 09101M N3S SEETRACK(01.04A) OV20117 PJWDID TRff C/O(WM17) 06131108 NKS CTD(8I-048)SIJISPFMO(J20117 GIB/JTGLVC)0(06107M7) 1029113 PKR Z72 SIOEMRCK(Ot-04B) O6Y20717 JGL/JMD SEr PXNFiUG(06/07117) 1210013 RFV PJC 1338' 120' CSG CORRECTIONS 1227113 RCT/JM) GLV 40(12/18113) 0=43V PRUDHOEBAY L"T W43.L 01-04B Raw Ab: 2131060 API No: 50-029-20070-02 TION, R15E 430' PTL & 13991 BP Exploration (Alaska) S 01-04 P&A Status SAFEIYNOTES: WELLANOLE> 70.00376"" 1g and IA cemented CHROME TBG& LM "' MONOBORE 2800'MD to surface I COMPL.ETION-NOOA"' BLA1 = ? 1P= 4339 1x AngM = 112' @ 11309' i 2(" CSG, 9", 1440 8133N, K-55 9418' CSG, 47N, L-80 TCI, D= 6.681' 1}318' 47!05. 72N, NII, D= 12.347" 8-518" X 7- BKR FLEX LOCK MR, D = 8.24' -j 40 Minimum ID = 3.725" 8551' 4-1f2' HES XN NIPPLE 9-518" CSC, 40M 143 5#14 7#, SOO, 95 BTRS , I- j 14981 D-983:1 1 8155'16681" )rilling (original) cement: 9-5/8" Casing: est. 2100' M to 4546' MD pumped through stage collar. and IA cemented from 8440'MD to 6745'SLM IMPCFTW,t-12'LNR - 8651 4-12" TBC, 12 6M, 13CR-BO VAM TOP, 14 8569' 0152 t4rl, 11 3.958" -80 VAM TOP HC, .0383 bpf, D = 8176' —f- —$5w 28N, L -8U BI(4M, .0383 qd, D= 0.21tr 8714' rErM4ATDN SUIJMARY REF LOG: MAD ON 1021113 ANGLE AT TOP PEW 87'010570' Nak- Refer b Roducbm OB for hshmcd pert data SEE I SPF I WFEWAL I Oprht- z I SHOT I SQZ 288' B 10570 -10820 O 10125/13 2.8(r 6 11250 -112551 C JIMM31 M D = 3.958' CP3.9Na V'17 =TFC ST AD TVD DEV TYPE VLV LATCH I PORTI LATE 6 3146 3146 1 LM DOSE RK 18 1125113 5 4748 4737 16 KOG2 DAM BK 0 10126/13 4 58M 5802 11 KBW SO BK 20 08107/17 3 6798 6720 13 KBG2 DAM BK 0 10/26113 2 7572 7475 12 KBG2 DMY BK 0 I IDW13 1 8221 8108 17 KBG2 DA17 BK 0 1026113 4546' I -V-315 OV CULLAI(� ROLLOUT WINDOW (01-046) 4981' - 4998' 8481' 44.12' HBBX NP, D = 3 813' 8661' 4.12' HE XN NP, D - 3.725 8561' 4.12'mmm(061071R) 8561' 7' X 5' BKR 4MYE ZXPN LTP 01113115 w 111' TEBACK, D = 4.35 DATE REI/ Y COMA34TS 11 DATE REV BY COMEMS 0707770 NnALCOMPLEnON 01113115 TTWJMJ SET CBP(01111115) 080101 WS SKEMACK(Ol."A) 061211117 RJWJND TREE CYO (04130117) 0619108 KM CTD(01-04B)SWEND6 0612W77 GIB1JND GLV 00(06107H7) 1020113 PKR272 SIDETRACK(01.048) 00120117 JCLJAV SETPXNPLUG(0607/17) 12/"73 RRl RIC 13.318'I20'CSGCOf87ECf10NS 1227113 MUM/ GLV UO(12118/13) fRUDI OE BAY LINT WH I 01-04B PEFUT W:'2131060 AR W: 50-029-20010-02 SCC 6, T10N. R15L 439 FNL 81399 FWL BP E3lptoration (Alecks) 01-04 P&A sundry Rev 2 5/9/19 Intervention Engineer Travis Montgomery (907) 564-4127 Production Engineer Finn Oestgaard (907) 564-5026 �50FQr-C'JJ L � &,J 3 History 01-04B was completed in 1971 with a three -string c sing design. The outer casing string is set in permafrost. GWO has determined that these well are at risk for sudden wellhead movement, as demonstrated by 02-03A and 02-02A. As such, t e AOGCC has requested this well be plugged and abandoned to mitigate HSSE consequence as ciated with this potential risk. Objective Place a lower lateral cement plug in the w (bore above the production packer. The cement top in the tubing and IA will be -7140' MD. Procedural steps Wireline/Fullbore - DONE 1. Pull the deepest accessible DGL 2. Circulate down tubing and up I with surfactant wash followed by 9.8 ppg brine. ➢ 5 bbls MEOH ➢ 50 bbls hot (160 deg reshwater + surfactant; 2 gal/mgal F103 and 2 gal/mgal U067 )> 460 bbls 9.8 ppg bri e 3. AOGCC-witnessed CMIT- AA to 1500 psi. 4. AOGCC-witnessed tag o XN plug @ 8551' MD. 5. Run GR log and caliper urvey from 2000' MD to surface for future subsidence surveillance/analysis. Wireline - DONE 1. Punch tubing -844 MD. Fullbore - DONE 1. Pump cement jo down tubing while taking returns from IA. Target TOC -7140' MD in tubing and IA. ➢ 5 bbls M OH ➢ 3 bbls FW spacer ➢ 44 bbls of Class G cement per design ➢ 2 bbls FW spacer ➢ Foam wiper ball ➢ 106 bbls of 9.8 ppg brine displacement ➢ Consider U -tubing methanol to fill TBG and IA down to 150' for freeze protection. Cement Type/weight: Class G 15.8 ppg mixed on the fly or batch mixed. Field blend to be =lab ppq +/- 0.1 ppg Slurry Temperature: I between 800 and 110°F Fluid Loss: 40-200cc(20-100cc/30 min) Compressive Strength: 2000 psi in 48 hrs. Thickening Time: Minimum 5 hours Wireline/Fullbore - DONE 1. AOGCC-witnessed CMIT-TxIA to 2500 psi. 2. AOGCC-witnessed tag of TOC. The above steps have been completed as of 5/5/19. Wireline 1. Punch tubing -1300' MD. Fullbore 1. Remove IA gate valves and replace with integral valves 2. Pump cement job down tubing while taking returns fro ➢ 5 bbls MEOH ➢ 113 bbls of Class G cement per design (20 bis of WSL discretion. IA. excess) Cement Type/weight: C194s G 15.8 ppg mixed on the fly or batch mixed. Feld blend to be =lab ppg +/- 0.1 ppg Slurry Temperature:/between 800 and 110°F Fluid Los 40-200cc (20-100cc/30 min) Compressive Stren the 2000 psi in 48 hrs. Thickening ime: Minimum 5 hours DHD 1. Bleed tubing and IA monitor for 24 hours. Special Projects 1. Excavate and Cut off all sings and wellhead 3' below original tundra level. Top job the 30" x 20" annulus and all other a uli and tubing with cement as needed. 2. AOGCC witness ceme t tops in all annuli. 3. Bead weld marker ca on outermost casing string (30" Conductor) to read as follows: BP Exploration Ala ka, Inc. 01-046 PTD # 213-106 API # 50-029-2 070-02 2 TREE= _DRY HOLE IWWELLFEAD FMC ACTLLATOR= REMOVED OKB. ELEV = 73' ELEV = 88.T BF. ELEV - 43.6T KOP= 4339' Max Angle = 112' 11309' Datum M7 = 9092' Datum ND = 8800' SS 20' CSG, 94#, H40 9-5/8' CSG, 474, L-80 T( 01-04B 13-3/8- G56, 72#, N-80, D = 12.347'2736• �/ 9-5/8' X T BKR HRD ZXR4 LTP, D = 6.19' 4077' 9-5/8' X T BKR FLEX LOCK HGP, D = 624' --®` Minimum ID = 3.725" @ 8551' 4-112" HES XN NIPPLE 9-5/8' CSG, 40# / 43.50 / 47#, SOO-95 BTRS , —4981 D=8.835'/ 8.755/8.881• EST TOP & BOT TBG & IN CMT (04119/19) 6745' 6440' SL TAGGED TOC 05/05/19 TOP OF CEMENT LNR H 8561' 412' TBG, 12.6#, 13CR-80 VAMTOP, .0152 bpf, D = 3.95W 7- LNR 26#, L-80 V AM TOP HC, .0383 bpf, D = 6276' /- LNR 269, L-80 BTC -M, .0383 bpf, D = 6.276' I -A 8714' I FERFORATION SLRTMRY REF LOG: MW1D ON 1021!13 ANGLE AT TOP PERF: 87'105 0' Note: Refer to Frodwbon DB for WbMal perf data SIZE SPF NTE VAL I OVVSgz I SHOT SOZ 2.88' 1 6 110570 - 10820 C 10/25/13 2.88-1 6 111250-11255 C 1025113 PBTD H 11314' LNR, 12.80, 13CR VAM TOP, 11400' bpf, D = 3-958- SAFETY NOTES: W ELL ANGLE > 70' Q 9375' '- CHROME TBG&LNR"'MONOBORE COMPLETION - NO OA "' 2058- -19-5/8 ES CBVNrM 2374' 4-12' HES X NP, D = GAS LFT MANDRELS ST MD I TVD I DEV I TYPE VLV LATCH PORE J DATE 6 3146 3146 1 MMG DMY ( 0 04/05/19 5 4748 4737 116 KBC BK 0 10126/13 4 5858 5802 11 KBG2 O BK 20 06/07/17 3 6798 6720 13 DMY BK 0 10126/13 2 7572 7475 12 J16W -DMY BK 0 10/26(13 1 8221 8108 17 KBG2 -DMY BK 0 03/09/19 T*STA#2 & #1 = EFIED BY CMT 4664' s -6/s FOCJL OUT WINDOW (01-048)4981'-4998' u 64+8J 8481' 112W DATE REV BY OOti?.134TS DATE REV BY COMklwTS 07107/70 INTIAL COMPLETION 03/13/19 LG(JMD GLV C/0 (03109019) 08/01101 N3S SIDETRACK (01-04A) 04/12/19 SIJ GLV C/O & TBG PUNCH (04/)5119) 0431/0111 NZS CTD (01-048) SUSPEND 51250 05002/19 JJUJMD CBA34T R -UG (04/19119) 1028113 PKR 272 51DETRACK(01-048) 05/09/19 JNJJMD UPDATED TXIA TOC PER SL TAG 01231JNl1JMD ADDED REF & BF ELE.V Ni:19 PU2/JMD DRY HOLE TREE '.G PUNCHw2'4 SPF HES X NP, D = 3.812 X 4-12' FEB TNT RCP, D = 12'F6X NP, D=3.813' 12' HES XN NP. D = 3.725' Tw /X 5= ZXPNT 11'R= 435 4-12' WLEG, 3.958' aAu TT NOT LOGO Y BKR RS PACKOFF SEAL NP, D T X 5- BKR FLEX LOCK 5- X 4-12' XO, D = 3.920' RIP JOINT w/ RATAG PRUDHOE BAY UNIT VVE 1. 01-04B PERMT No: F2131060 AR ND: 50-029-20070-02 SEC 8, TION, R15E, 430' FTL & 1399' FWL SP EKplorabon IA6aka) TM= 61 MWOY W13L1£AD=_, FUC ACIUATDR- AXELSON NfNL KB. BEY= 73' BF. flit! _ ? bYx Aro1a = 117 4b 11309' gandA cemented S 01-04 P&A Status SAFETY NOTES' ANGLE> @ S375• CHROMETBO LR••MONOBORE 1300'MD to surface COMPL OA••• •• 7N31CTOR i •1' THCUTSELOWSLAWACE I N CW 948, 14-40 8 1335, K-56 1508' 8.59' CSG 476, L-� TCl D=8.681' --2ff Y 13-38" CSO, 728, N -SO, D- 12.347• 7735' 9-5/8' X 7• BM HRD ZXFN UP, ID=6.19' — 0 10:518' X T BKR FLO( LOCK MR, D- I - 824" Minimum ID = 3.726" @ 8561' 4112' HES XN NIPPLE 9-5/8' CSG, 405143.561475. SOO SS BTFtS , —C D=8,835•! 8.755"/8.581" )rilling (original) cement: 9-5/8" Casing: est. 2 4D to 4546' MD pumped through stage collar. and IA cemented from 8440'MD to 6745 4 -OT TBG, 12.58, 13CW80 VAM TOP, 0152 bp1, D = 3.956" M 0 rEWOF81T15N SLA"RY RE' LOG: WO CN 10/21/13 ANGLEAT TOP 87' @ 10570' We: Wer b Rudarubw LB for hcbrical pert dabs SEE I SPF I INTERVAL OprVSgt OT SCIZ 8' 28 B 10570 -10820 O 1SH0r25/13 2.68' 6 11250 -11255 C 10!25113 ;1260, 13CR VALITO R D=3.956' -t HES x w GAS LFT MANORB_S SY NO TVD I TEV I TYPE VLV LATCH PORTI DATE 3146 3146 1 MA(,a DOME RC 13 5 1746 4737 16 KBG2 DMt BK 13 4 5868 5802 11 KBC2 9D BK 17 3 6798 6720 13 KBG2 DMV BK 13 2 7572 7475 12 K8G2 OM1' SK 13 1 8221 8106 17 10362 DMY SK Oil 13 4546' - -5/8" DV COLLAIq NLLOUT WINDOW (01 A46)1981' - 4998' LATE REV BV CC7 &WS DATE R1EV SY CObSr60S OTMTITO 66TIAL COMPLETION 01/13/15 TTFAJYD sEr CBP(OU11/15) 09A1101 WS SI EIRACK(O RJM0D TREEOO(04O17) 630 IQM CTO(61-04B 7 &MAU GLV 00(OMTM7) IWM13 PR7S6EIRACK(0144M WMV d7 JG AM SETPXNPI.C3G(O6A7n7) 12A4113 WPIC 13-39' / 20• CSG OOffWtDNS 1227113 FT -TAO GLV CIO (12118113) FB XN 11' TEBAC K D=495 =42Y D - 3.920" FRU HOEBAY UNT WELL 01.04B PEW No: 2131060 AR Nn 50-829-2007402 SEC 8, TION, R15E 430' Fly. 8 1399' FWL 6P BWbradm (Abska) BP EXPLORATION (ALASKA) INC., PRUDHOE BAY UNIT 01-04B (213-106) PRUDHOE BAY, PRUDHOE OIL Monthly Production Rates 10,000,000 1,000,000 L C C0 L 0 100,000 LL V O N m 10,000 m c7 O o O u+ M Im^ V LL c 1,000 v Z 3 10,000,000 W m 1,000,000 U O O 100,000 O 10,000 Q 1 Jan -2010 Jan -2012 IIIIIIIIIII'11111111111Illlllllll,lllllllllll,lllllllllll1 11111111111,111111111111 IIIIIIIII,IIIIIIIIII'Illllllll,llllllllll1 Jan -2018 lr � A Produced Gas (MCFM) I GOR Produced Water (BOPM) + Produced Oil (BOPM) 10,000,000 W m 1,000,000 U O O 100,000 O 10,000 Q 1 Jan -2010 Jan -2012 Jan -2014 Jan -2016 Jan -2018 1 Jan -2020 A Produced Gas (MCFM) I GOR Produced Water (BOPM) + Produced Oil (BOPM) SPR EADSH EET_2131060_PBU_01-04B_Prod-I nject_Cu wes_W ell_Oil_V 120_20190510.xlsx 5/10/2019 Schwartz, Guy L (DOA) From: Schwartz, Guy L (DOA) Sent: Thursday, April 4, 2019 8:39 AM To: Montgomery, Travis J; Melvin G Rixse (DOA) (melvin.rixse@alaska.gov) Cc: Daniel, Ryan; Hibbert, Michael; Worthington, Aras J Subject: RE: PTD 213-106 Sundry Modification 319-026 Well 01-04 Travis, As per our phone call you have approval to perform diagnostics as needed to determine tubing leak path. Guy Schwartz Sr. Petroleum Engineer AOGCC 907-301-4533 cell 907-793-1226 office CONFIDENTIALITY NOTICE: This e-mail message, including any attachments, contains information from the Alaska Oil and Gas Conservation Commission (AOGCC(, State of Alaska and is for the sole use of the intended recipient(s). It may contain confidential and/or privileged information. The unauthorized review, use or disclosure of such information may violate state or federal law. If you are an unintended recipient of this e-mail, please delete it, without first saving or forwarding it, and, so that the AOGCC is aware of the mistake in sending it to you, contact Guy Schwartz at (907-793-1226) or (Guv.schwartz@alaska.aov(. From: Montgomery, Travis 1 <Travis.Montgomery@bp.com> Sent: Wednesday, April 3, 2019 4:27 PM To: Schwartz, Guy L (DOA) <guy.schwartz@alaska.gov> Cc: Daniel, Ryan <Ryan.Daniel@bp.com>; Hibbert, Michael <Michael.Hibbert@BP.com>; Worthington, Aras J <Aras.Worthington@bp.com> Subject: PTD 213-106 Sundry Modification 319-026 Well 01-04 Guy, While preparing to punch the tubing on Well 01-04 as approved by Mr. Rixse in the attached email, we discovered instant communication between the IA and tubing when pressuring up on the tubing. We propose to diagnose the tubing using a D&D hole finder and change gaslift valves as needed. Once we establish tubing integrity, we will punch the tubing just above the packer as planned. Please reply with your approval to continue this proposed work. We currently have a unit rigged up on this well. Thanks, Travis Montgomery BP Alaska Interventions & Integrity Engineer Cell: 918-281-9663 by It44*0. 4 • 'r"V?k 01-04 P&A Rev 1 Intervention Engineer Travis Montgomery (907) 5644127 Production Engineer Finn Oestgaard (907) 564-5026 s(.aw) H istory 01-04B was completed in 1971 with a three -string casing design. The outer casing string is set in permafrost. GWO has determined that these wells are at risk for sudden wellhead movement, as demonstrated by 02-03A and 02-02A. As such, the AOGCC has requested this well be plugged and abandoned to mitigate HSSE consequence associated with this potential risk. Objective Place a lower lateral cement plug in the wellbore above the production packer. The cement top in the tubing and IA will be 7140' MD. Procedural steps Wireline/Fullbore — DONE 1. Pull the deepest accessible DGLV. 2. Circulate down tubing and up IA with surfactant wash followed by 9.8 ppg brine. ➢ 5 bbls MEOH ➢ 50 bbls hot (160 deg) freshwater + surfactant; 2 gal/mgal F103 and 2 gal/mgal UO67 ➢ 460 bbls 9.8 ppg brine 3. AOGCC-witnessed CMIT-TxlAto 1500 psi. �?o �l LTJ 4. AOGCC-witnessed tag of XN plug @ 8551' MD. p V 5. Run GR log and caliper survey from 2000' MD to surface for future subsidence surveillance/analysis. Wireline 1. Punch tubing 8440' MD. Fullbore 1. Pump cement job down tubing while taking returns from IA. ➢ 5 bbls MEOH ➢ 3 bbls FW spacer ➢ 44 bbls of Class G cement per design ➢ Foam wiper ball ➢ 2 bbls FW spacer ➢ 106 bbls of 9.8 ppg brine displacement Target TOC 7140' MD in tubing and IA. ➢ Consider U -tubing methanol to fill TBG and IA down to 150' for freeze protection. Cement Type/weight: Class G 15.8 ppg mixed on the fly or batch mixed. Field blend to be =lab ppg +/- 0.1 ppg Slurry Temperature: I between 80° and 110°F Fluid Loss: 40-200cc (20-100cc/30 min) Compressive Strength: 2000 psi in 48 hrs. Thickening Time: Minimum 5 hours Wireline/Fullbore 1. AOGCC-witnessed CMIT-TxlA to 2500 psi. 2. AOGCC-witnessed tag of TOC. Remainder of P&A to be resubmitted after AOGCC final ruling on Docket OTH-18-064. TTS = 6' MCEVOY DS 01-04 Current Status AL KB. 61EV =.. 73' F . = 930• (x1NKICHat 1= 4339 13-318• CSG 1449' AnOk =_ 117,W -I1309' PATCH Im MD = _ 9097 an TVD = 8800 SS 20 -CSG, 9M, M408 Iiia,K-55 9-518' CSG. 470, L-80 TCI, D= 8.681' —C 113 -YO -CSG. 720, DF80. D - 12.347• 273W 19-518-X7-BKRHRDZXPNLTP,D=6.19- �-1 4077 8 5/8' X 7• BKR FLD( UX:K HCS D - 6.2�-" 4093' Minimum ID = 3.725" @ 8551' 4112' HES XN NIPPLE 9-516• CSG, 40N 143.5# 147#. S0O,95 BTFtS , 1 '�=oB1 D = 8.835.1 8,155"13.061, 9Lr: SY;a1se S :4i IT0POFTIE4-12•LN2 Ml - 4 -W- TBC. 12 BN, 13MBO VAM TDP, 85$9' 01526pl,U- 3956• LATCH I V AM TOP HC, .0383 EPf. 9) GATE 6 3146 • r_xn wrr_u nixes nor •r= a�]x- �»L' f EWOHU1TKIN S( K"nY RET LOG: AM0 ON 1021/13 ANGLEAT TOP P6iF: 87" Q 1OSAY Nole: Hafer to Ro&cBon DB for hsbricW ped date SIZE I SPF I 9n13NAL I OpNSgz I SHOT I SOZ 2.68• 6 10570 - IOM O 1025113 2.86• 6 1125D- 1255 C 10125M 3 LIR 12.60, 13CR VAMTOP, *f, D = 3.958' SAFETY NOTES: WELL ANGLE> 70•@9375- CHROME TBG& LNR "' MONOBORE COMPLETION - NO OA •'• 206$'9-518 655 C -m -w -r i 4 2374' -412-FESXNP,D=TS13- GAS LFT MANDRELS ST MD TVD DEV TY FE VLV LATCH F09TI GATE 6 3146 3146 1 M.L. DOW W 16 1125113 5 4748 4737 16 KBG2 ORM BK 0 10116113 4 5658 5802 11 KBG2 SO BK 20 06107117 3 6798 6720 13 KBC2 DMI' BK 0 1026113 2 7572 7475 12 KBGJ Dfr17 BK 0 1026113 1 8108 17 KBC2 DW BK .0 10126113 4546' -{9-518" DV COLLAR kMLLOUT WINDOW (01.048) 4981' - 4998' 841-14-12- HES X N', U- 3.813- P" u4- !1- BHYo ' 8446• - 7- X 4 117 H- TNT WR U 3,656- $4$T --I4-12- FES X NP. D= 3 813• REV BY I C0KWENTS I DAIS 86161'-4-1/2•T[3XN N', D-3-125'1 8551' 4-117 PA PLLr.(06107/17) $$$� ]'XS'BKR Fr�EZXFN LT? w/ i t' TACK, D = 4.35' 8681' -1 S' BKR RS pAtl(OFF SFAL PIP, D = RMT J 7- X 5- SKR FLEX LOCK PER D = 4 $693• 5' X 4111' XO, D = 3920" ® RIP JONiw/RATAG 10309 RRJONIw/RATAG 1 11206• 41YIV1PO(3F1P(01/11115) DATE REV BY I C0KWENTS I DAIS REV BY ODAf+B4TS 0770720 $9AAL COMPLETION 01/1115 TMJND SETCBP(01/11/15) 09MUM N3S SIOETRACK(01-04A) 06/20117 RIFYJND TAE£ CIO (04130117) 05131108 KM CTD(01-UR SU&PB0 062W77 GJFVJR0GLV00(06107/17) 1W29713 PKR272 SMETRACK(01-048) O6rM17 JGU,MJD SET PXNPLLIG(WI07/17) 12104113 RR PJC 13-3/8'1 20• CSG COFfZF{:TKMB 1227/13 RCOJMD GLV 00(1211&113) PRLCIDEBAY ENT W13_L 01-04B PBRW NO: '2131060 AFINo 50.029-2007002 SBC B, T10N. R15E 430' FTL & 1399 FWL EP B(ploratlm (Alaska) ALI VAIVM= AX1dw. NRAL KB. ELEV = RFRW= Mac Angle= 112'@ 11309' Ekvtum M)- 9092 Dottan TVD = 8800' Ss DS 01-04 P&A Status {-1449• -1 ( 20. 6C, 940, K40 A 1330. K-55 1508' -SIB' CSG. 477. L-80 TC{ D= 8.681" 2073' 13318• CSG. 720, 1480, D- 12.347' 2736• IWD/5 X/-BKHMNDZXPNLTP,D=8.79• j-1 4077' 9 5/8• X 7• BKR FLIT( LOCK HGK U T 624' -- 4093' Minimum ID = 3.725" @ 8551' 4112' HES XN NIPPLE 9-sar CSC, 4lM 143 SR I47N, 51:10-95 BTRS , =4981 Al 8836 ! 8.75618681- ---- Drilling (original) cement: 9-5/8" Casing: est. 2100' MD to 4546' MD pumped through stage collar. TOPOFCBUfr ubing and IA cemented from 8440' MD to 7140' TOP OF ITE 4.12' LNR 412• TBG, 17 60, 13MSO VAM TOP, 0:571y1, I7 397.8- L-80 VAM TOP HC, .039.1 bP/, D = 8.278' LN{, MO. L-00 b IG -K 0383 bpf. U=6.Z78- I 8714' rQY01'7ATION S(A"RY Rff LOG: A1710 ON 1021113 ANGLEAT TOP . 87' ®10570' Nole: Refer to Producton DB for Mstoncal pert data SEE I SPF I INTERVAL I OpNSgz I SHOT SOZ 288• I B 10570 - 10820 O 1025/13 2.88' , 6 11250 -11255 C 10/25113 PBTU 11314' D = 3.958' SAFETY NOTES: WELL ANGLE> 70' !28375'•'• CHROME TBG 8 LNR ••• MONOBORE COMPLETION - NO OA •'• �� WI Bf30W SLRFA(3= • 2068' 8-518 ES C81ENT62 GAS LIFT VANUILS STI ►D TVD I DEVI TYPE I VLV LATCH PORTI OATS 6 3146 3146 1 A11f DOME HK NZEB CTO(01-04B)SL1SPEW52510(08/10017 5 4748 4737 16 KBG2 CA71' BK 4 58.58 5802 11 KBG2 SO BK LIVi-I&I13 3 6796 6720 13 KBG2 DMY BK 2 '1572 7475 18108 12 KBG2` DW BK 1 8221 17 KBG2 DMT BK MIL LOUT WINDOW (01.048) 4981'-4998' HFS X W. U = 3 813* &"W !-I/- X 4 10- FES nM WR F) 8481' -,4-V7- HFS X NP D = 3 813- � 8661'-4-ill•HES XN K•. U-3.125 X 5'6KRI ZXPWL 111' TACK, D = 4-35 10• %M FG. 3 958' SEAL NP, D = 425- �ZQ n--ea•- 10309' RJP JONI all RA TAG DATE I REV BY I COLOJENTS DATE REV BY COMM34rS 07A7070WTIAL COMPLETION 01/13075 T718JND SET CBP(O1/11/15) 09101101 WE SIOETI7ACK(01-04A) J.. OG/20017 RJWJMD TRff(YO(OWNV17) 05131A8 NZEB CTO(01-04B)SL1SPEW52510(08/10017 GJBUAOGLVCJO(06007117) 1020113 PKR272 SIDErMCK(01414B) '0620/17 JGUw SETPXNFLIJG(06/07117) 12A4/13 (BY PJC 13-308.120• CSG CORRECTIONS 1227/13 RCT/JMDGLVCJO(12/18113) PRLCHOEBAY IMT WELL 01-04B PEI AETN0:'1131060 AR N0: 50-029-20070-02 ZION, R15E 430' FtL 81399' FWL BP 6cploratbn (Alaska( MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: Jim Regg 2e�K 3/z,F, DATE: March 9, 2019 P.I. Supervisor \ I l� SUBJECT: Well Bore Plug & Abandonment PBU 01-04B FROM: Adam Earl BPXA Petroleum Inspector PTD 2131060; Sundry 319-026 Section: 8 Township: Drilling Rig: NA Rig Elevation: Operator Rep: Jeremy Grimes Casing/Tubing Data (depths are MD): Conductor: 30" 0. D. Shoe@ Surface: 20" O.D. Shoe@ Intermediate: 13 3/8" 0. D. Shoe@ Production: 9 5/8" 0. D. Shoe@ Liner: 7"x41/2" -O. D. Shoe@ Tubing: 41/2" 0. D. Tail@ Plugging Data: Test Data: 10N Range: R15E NA Total Depth: 11402 ft MD Suspend: 130 ' Feet 1524 Feet 2751 Feet 4981 Feet 11400 Feet 8569 Feet Meridian: Umiat Lease No.: ADL 028329 P&A: X - Type ug ounded on Depth Btm Depth To MW Above Verified Tubing 8551 ft MD Wireline tag Initial 15 min 30 min 45 min Result Tubing 2210 2178 2160 ' Casing Removal: Csg Cut@ na Feet Csg Cut@ na Feet Csg Cut@ na Feet Csg Cut@ na Feet Csg Cut@ na Feet Tbg Cut@ na Feet Type ug ounded on Depth Btm Depth To MW Above Verified Tubing 8551 ft MD Wireline tag Initial 15 min 30 min 45 min Result Tubing 2210 2178 2160 ' IA 2215 2183 2165 P OA Initial 15 min 30 min 45 min Result Tubing IA OA Remarks: I traveled out to PBU 01-04B for verification of the reservior abandonment plug by slickline tag and combo tubing- IA pressure test. Jeremy Grimes was the BP rep on location. I witnessed the slickline depth veification tag that showed the plug was indeed set in the tubing nipple @ 8,551 ft MD. Little Red conducted the pressure test combo Tubing and IA. Attachments: rev. 11-28-18 2019-0309_Plug_Verification_PBU_01-04B_ae THE STATE °fALASKA GOVERNOR MIKE DUNLEAVY Travis Montgomery Interventions and Integrity Engineer BP Exploration (Alaska), Inc. PO Box 196612 Anchorage, AK 99519-6612 Re: Prudhoe Bay Field, Prudhoe Bay Oil Pool, PBU 01-04B Permit to Drill Number: 213-106 Sundry Number: 319-026 Dear Mr. Montgomery: Alaska Oil and Gas Conservation Commission 333 West Seventh Avenue Anchorage, Alaska 99501-3572 Main: 907.279.1433 Fax: 907.276.7542 WW 'aogcc.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 DATED this 'r day of February, 2019. SCANNED FEB 0 6 2019 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 t'i E I V E D 1AN ? 3 2019 1. Type of Request: Abandon El Plug Perforations ❑ Fracture Stimulate ❑ Repair Well ❑ Operations shutdbwrvl� Suspend ❑ Perforate ❑ Other Stimulate ❑ Pull Tubing ❑ Change Approved Program ❑ Plug for Redrill ❑ Perforate New Pool ❑ Re-enter Susp Well ❑ Alter Casing ❑ Other ❑ 2. Operator Name: BP Exploration (Alaska), Inc 4. Current Well Class: Exploratory ❑ Development m 5. Permit to Drill Number. 213-106 3. Address: P.O. Box 196612 Anchorage, AK 99519-6612 Stretigraphic ❑ Service ❑ e_ API Number 50-028-20070-02-00 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 0 PBU 01-04B 9. Property Designation (Lease Number): 10. FielNPools: 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): 11402 8899 8551 8417 8551.11205 None Casing Length Size MD TVD Burst Collapse Conductor 80 30" 50-130 50-130 880 Surface 1475 20" 49-1524 49-1524 2320 / 1530 1500/520 Intermediate 2704 13-3/8" 47-2751 47-2751 5380 2670 Intermediate 4936 9-5/8" 45-4981 41-42 58 6870 / 6820 4760 / 3330 Liner 4367 7" 4077 - 8714 4077 - 8569 7240 5410 Liner 2839 4-1/2" 8561- 11400 8427-8900 8430 1 7500 Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): 10570- 11255 1 - 8953 4-1/2" 12.6# 13Cr80 42-8569 Packers and SSSV Type: 4.112- RES TNT Perm Pecker Packers and SSSV MD (ft) and TVD (ft): 8446/8320 No SSSV Installed No SSSV Installed 12. Attachments: Proposal Summary m Wellbore Schematic m 13. Well Class after proposed work: Detailed Operations Program ❑ BOP Sketch ❑ Exploratory ❑ Stratigraphic ❑ Development 0 Service ❑ 14. Estimated Date for Commencing Operations: February 7, 2019 15. Well Status after proposed work: Oil ❑ WINJ ❑ WDSPL ❑ Suspended ❑ 16. Verbal Approval: Date: GAS ❑ WAG ❑ GSTOR ❑ SPLUG ❑ Commission Representative: GINJ ❑ Op Shutdown ❑ Abandoned IZ 17. 1 hereby certify that the foregoing is true and the procedure approved herein will not Contact Name: Montgomery, Travis J be deviated from without prior written approval. Contact Email: Travis.MontgomeryDbp.com Authorized Name: Montgomery, Travis J Contact Phone: +1 907 564 4127 Authorized Title: Interventions &lIlntegrity Engineer ) Authorized Signature: %,_ .. ;. lye 1. Date:// xf COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number: 361-00 Plug Integrity 1 L❑ BOP Test ❑J Mechamcl�/Integrity Test (� Location Clearence Other: 1' h0-\a[V.O C 0 VL4, eA&, Cg.S tri!X1�.m.�� Post Initial Injection MIT Req'd? Yes ❑ No ❑ Spacing Exception Required? Yes ❑ No it Subsequent Form Required 0-q07 01 APPROVED Approved by: COMMISSIONER COMMISSIONYTHE Date. r Form 10-403 Revised 04/2017 ORIGINAL MMS-- rEB052019 Submit Form and kf Approved application is valid for 12 months from the date of approval. Attachments in Duplicate by 04"gr 1y*j 01-04 P&A Intervention Engineer Travis Montgomery (907) 564-4127 Production Engineer Finn Oestgaard (907) 564-5026 Expected start date: February 711, 2019 History 01-04B was completed in 1971 with a The outer casino strino is set etrmatr . GWO has determined that these wells are at risk for sudden wellhead movement, as demonstrated by 02-03A and 02-02A. As such, the AOGCC has requested this well be plugged and abandoned to mitigate HSSE consequence associated with this potential risk. Objective Place cement plugs in the wellbore. Excavate and cut casings 3' below original tundra level and install marker cap. Procedural steps Wireline/Fullbore 1. Pull the deepest accessible DGLV. 2. Circulate down tubing and up IA with surfactant wash followed by 9.8 ppg brine. ➢ 5 bbls MEOH ➢ 50 bbls hot (160 deg) freshwater + surfactant; 2 gal/mgal F103 and 2 gal/mgal U067 ➢ 460 bbls 9.8 ppg brine's Z2CO 3. AOGCC-witnessed CMIT-TxIA to 15bKpsi. 4. -AOGC-witnessed tag of XN pluq (a)8551'MD. Flaq wire for 5. survey control. subsidence surveillance/analysis. 6. Punch tubing -8440' MD. Fullbore G e�-cc1 I-4-�-e �, 4 clP�-•- 1. Remove IA gate valves and replace with integral valves at WSL discretion. 2. Pump cement job down tubing while taking returns from IA. ➢ 5 bbls MEOH ➢ 460 bbls of Class G cement per desiqn (20 bbls excess) Cement Type/weight: Class G 15.8 ppg mixed on the fly. Field blend to be =lab +/- 0.1 ppg Slurry Temperature: between 800 and 110°F Fluid Loss: 40-200cc (20-100cc/30 min) Compressive Strength: 2000 psi in 48 hrs. Thickening Time: Minimum 5 hours DHD 1. Bleed tubing and IA pressures and monitor for 24 hours. Special Projects 1. Excavate and Cut off all casings and wellhead 3' below original tundra level. Top job the 30" x 20" annulus and all other annuli and tubing with cement as needed. 2. AOGCC witness cement tops in all annuli. 3. Bead weld marker cap on outermost casing string (30" Conductor) to read as follows: BP Exploration Alaska, Inc. 01-04B PTD # 213-106 API # 50-029-20070-02 TREE= 6' MCCVOY WELLHEAD= ACTUATOR= FMC AXI3SON MTAL KB. R = 73' BF ALV = 7 KOP= 4339' NkX AnBb = 112.6 11309' Orion MD= 9097 Datum TVD = 8Bw SS DS 01-04 Current StatusI{ SAFETY NOTES: L WELL MNGLE> 70 @ 8375' cHRom1 ,. r COMPLETION -1100A "' 120 CSG, 84#, 1+40 8 133#. K-55 1508' 9-578' CSG, 474, L-80 TC1. D=8.681' 2073' 13-3/8' CSG, 129, WOO, D= 12.347' 2735' 8-5/8' X 7' 6KR NRD ZXPN LTP, D = 6.19' -C 9-5l8' % 1' BKR FLEX LOCK FIGR —IU- 0.21" -C Minimum ID = 3.725" @ 8551' 41/2' HES XN NIPPLE 3518'CSG,408/43.50/47M,SCO-95BTRS, 4 D = BAW / 8.755^ 18.081' ITOPOFTW4-112'LNR I--8581' 412' TBG, U M. 13CR-80 VAM TOP, 8569' .0152 bpl, D = 3 958' LATCHIFORTI 3 VAM TOPFIC, .0383 bPf, D = 8278' DATE U= 6.2/d- -( 8714 furoftATDN SLBRAAny FULOG: MMOCN1021/13 ANGLE AT TOP PHiF: 87' ®10570 Note : Peter to Producbon OB for historical pert data SIZE I SPF I NIHNAL I OprJS/R I SHOT I SOZ 2.88' 8 10570 -10820 O 1025!13 -- 2.88' 6 11250 -11255 C 110125!13 0=19W CNS -1I.0 _'SV k�-�I ST MD TVD OW TYPE VLV LATCHIFORTI DATE 6 3146 3146 1M4G DOME RK 16 11/25113 5 4748 4737 16 KBG2 OM4Y BK 0 10/26113 4 5&58 5802 11 KBG2 SO BK 20 06107117 3 6798 6720 13 KB62 OMY SK 0 1026113 2 7572 7475 12 KBG2 DW BK 0 IWM13 1 8221 8108 17 KBG2 DMY SK 0 10M13 4546' -{4-5/8" DV COLLAR MILLOUT WINDOW (01.046) 4981' - 4998- 841W -{4-1/2'FIESXNP,D=3.813' RAIAW -4 7- X 4 112- FES TNT PKR D = 3-850- 8481' -{41/2- FES X W. D - 3 813- 8661' 4-12' F6 XN NP. D. 3.725 8551' 4i/7 PM PLUG(o6/07117) 8561• 7^ X 5' BKR F�EZXPN LTP TTFV MD SETCBP(Ot/11115) w! 11' TEHACK, D=4.35- N3S SDETRACK(01-04A) CATE REV BY COM AR4TS40111IE3115 PF/ BY CAM.rS4fS 07107770 NTIALCOMPLETION TTFV MD SETCBP(Ot/11115) 09101/01 N3S SDETRACK(01-04A) RIWJMD TR EU0(04/30/17) 05731106 7FS CTD(01-048) SlF,P9D GJBIJMO GLV GO (06/07117) 10729/13 PKR272 SDETRACK(01-048) JGUJND SET PXN R-UG(06107117) 12X14113 RPo PJC 11318' 120' CSG OORRECT73NS 1227113 RCTIJMD GLV GO(vi18113) 5' BMR RS PACKOFF SEAL NP, D = 425' 7' % 5' BKR FLEX LOCK 5' % 4-112' %O, D = 3.920 TAG FRUDHX BAY UNIT WELL 01-04B PERT No: 2131060 AR No: 50-02320070-02 rIOR R15F 430' F1l B 1399' FWL BP Ekptmfion (Alaska) TREE= 61 MMVOY WELLHEAD= FMC ACRYITO_R= AX_ELSON N014L KB. 0" = 73° BF. ELEV = .._ ? KOP= 4399' Mex Angle = 117 0 11309' ptlun MD = 9097 Dahxn TVD = 8804 SS 20' CSG. 94 9 -SB' CSG. 47#. DS 01-04 P&A StatusSAFETY NOTES: WELL ANGLE >700@0375'•• 1CHROME TBGR LNR'0' MONOBORE 1 COMPLETION -NO GA'•• 13318' CSG j-( 1449' 13318- CSG, 720, 1480. D = 12.347- H 2735' r 9-51W X 7' 13M HRD ZXP4 L7P,D=6.19" 407T &5/8' X 7- BKR FLEX LOCK FGK D = 8.24" Minimum ID = 3.725" @ 8551' 4112' HES XN NIPPLE 9-58' CSG, 40# / 43.5# 147#, 500.95 BTRS , —4981 D = 8.935" / 8.75:1 18.881" )rilling (original) cement: 9-5/8" Casing: est. 2100' 4D to 4546' MD pumped through stage collar. and IA cemented from 8440' MD to 4-12' TBG, 12.8#, 13CR-80 VAM TOP, .0152 SOf. D = 3➢58' I- LW 2W, L-80 B IUM, $569' rUVDRATDN SLRWRY REF LOG: MAD ON 1021113 ANGLE AT TOP PEW: 87' a 10570 Note: Refer b Production OB for Fsmrical perf date SIZE SPF I INTERVAL Opn/Sqz SHOT SOZ 2w B 10570 -10620 O 1025/13 2.68' 6 11250 -11255 C 1025/1 I 4-12' LNR, 12.6#, 13CR VAM TOP, .0152 hof. D = 3.958' 14-112'FE5XFP,D=3.813' GAS LFT KIAMF13-S ST M) TVD DEV TYPE VLV LATCH POR! 647E 6 3146 3146 1 MIM DOME RK 16 112513 5 4745 4737 16 KBG2 DW BK 0 1026113 4 5858 5802 11 KBG2 SO BK 20 06107117 3 6798 6720 13 KBG2 OW BK 0 16'26113 2 7572 7475 12 KBG2 OM1' BK 0 16126113 1 8221 8108 17 KBG2 DMV SK 0 1026113 4546' —{9-5/8" DV COLLAR MILLOUT WINDOW (01A4B)4981'-4998' 8418' —14 -W -HES XNP, D=3,813- F-8z—W-74 .813'I 8z—W J 7' X 4 112- FES TW PKR D I 8481' ,44-112" HFS X NP, D = 3 813" 8661' 4-1/2'VESXNNP,D-3.725' 8551' 4-117 Pi04 R.Lia (O6A7117) 8961' 7' X 5' BKR FIDE ZXFN UP GATE REV BY COMMB4f5 w/ 11' TEBACK, D=4.35 MD TT NOT LOGGM BKR RS PACKOFF SEAL NP, D = X 5- SKR FLET( LOCK HGP D = 4 X 4-12- X0_ n= 3 920" 10309' PP JOM w 1 RA TAG 11205' 4-12' WFD CBP(0111 Ill 6) PRIAHOE BAY UNIT WELL: 01-04B PEFUT ND' 02131060 AR N3: 50-029-20070.02 SEC8,T10N,RI5E430rM6I399'FWL DATE I REV BY I COWlENrS I GATE REV BY COMMB4f5 07107/70 JWTIALCOMPLETION 01113115 TTWJND SETCBP(0IlIV15) DMIXII N3S SDEFRACK(01-04A) _ 06120/17 RIWJf4D TWE CIO(04130117) 0531108 WES CTD (81-048) SIWFWD 0620117 GJWJ&U GLV CIO (08107117) 10120173 PKR272 SDETRACK(01.0481 0612(M17 JGLJJND SEr PXNPLLIO(O6A7117) 12A4113 Wtl PJC 13-318' / 20' CSG TKM -- BP Expk/ration(AWaka) 1227113 RCTIAU GLV 00(12J18/13) __-I STATE OF ALASKA Al ;A OIL AND GAS CONSERVATION COMM, )N REPORT OF SUNDRY WELL OPERATIONS 1 Operations Abandon❑ Repair Well ❑ Plug Perforations ❑ Perforate❑ Other r17 G/B P Performed Alter Casing❑ Pull Tubing ❑ Stimulate-Frac ❑ Waiver Time Extension❑ Change Approved Program❑ Operat Shutdown❑ Stimulate-Other ❑ Re-enter Suspended WE 2 Operator 4.Well Class Before Work. 5 Permit to Drill Number. BP Exploration(Alaska),Inc Name Development 0 Exploratory❑ 213-106-0 3.Address P O Box 196612 Stratigraphic ❑ Service❑ 6.API Number Anchorage,AK 99519-6612 50-029-20070-02-00 7 Property Designation(Lease Number) 8.Well Name and Number: ADL0028329 PBU 01-04B 9 Logs(List logs and submit electronic and printed data per 20AAC25.071) 10.Field/Pool(s): PRUDHOE BAY,PRUDHOE OIL 11.Present Well Condition Summary RECEIVED Total Depth measured 11402 feet Plugs measured 11205 feet JAN 2 7 Z015 true vertical 8898 97 feet Junk measured None feet Effective Depth measured 11205 feet Packer measured See Attachment feet LA()GCC true vertical 8971 4 feet true vertical See Attachment feet Casing Length Size MD ND Burst Collapse Structural None None None None None None Conductor 1428 62 20"94#H-40 96 9-1525 52 96 89-1525 47 1530 520 Surface 733 77 13-3/8"72#N-80 2016 93-2750 7 2016 84-2750 43 4930 2670 Intermediate None None None None None None Production See Attachment See Attachment See Attachment See Attachment See Attachment See Attachment Liner See Attachment See Attachment See Attachment See Attachment See Attachment See Attachment Perforation depth Measured depth 10570-10820 feet 11250-11255 _feet SCp►NNEC1 i H 1. 9 ,,0 .i True Vertical depth 9063.38-9063 25 feet 8954 86-8953 03 feet Tubing(size,grade,measured and true vertical depth) 4-1/2"12 6#13Cr80 42 65-8569 61 42.65-8434 5 Packers and SSSV(type,measured and true vertical depth) See Attachment See Attachment See Attachment Packer None None None SSSV 12 Stimulation or cement squeeze summary. Intervals treated(measured)- Treatment measured)Treatment descriptions including volumes used and final pressure 13 Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation 1001 54084 493 2034 979 Subsequent to operation 1028 50314 662 1568 989 14 Attachments 15 Well Class after work Copies of Logs and Surveys Run Exploratory ❑ Development [] Service ❑ Stratigraphic ❑ Daily Report of Well Operations X 16 Well Status after work Oil E Gas ❑ WDSPL ❑ GSTOR ❑ WINJ ❑ WAG ❑ GINJ❑ SUSP ❑ SPLUG ❑ 17 I hereby certify that the foregoing is true and correct to the best of my knowledge Sundry Number or N/A if C 0 Exempt N/A Contact Garry Catron Email Garry.Catron@BP.Com Printed Name Garry Catron Title PDC PE Signature A(A41, a - Phone 564-4424 Date 1/26/2015 a VEL. /R-/J c /l 44/— Form 10-404 Revised 10/2012 Submit OrigggIOnly RBDMS(Y" JAN 3 0 2015 Packers and SSV's Attachment ADL0028329 SW Name Type MD TVD Depscription 01-04B PACKER 4088.85 4088.47 7" Baker ZXP Top Packer 01-04B PACKER 8446.98 8320.72 4-1/2" HES TNT Perm Packer 01-04B PACKER 8573.06 8437.7 5" Baker ZXP Top Packer co O Cfl a.00000 00 N O M Cp M CO co co N N- V L 0 0 0 0 0 0 MVMf— NOM0 M co• - N- 000 CO CO co 00 CO CD 1- M M T 0 M Ln L0 CA CA O 0 O (713 N CO 0) 0) In (NIUC) co La co O O N co • ,0 CO N Tr N co Tr N N O co CO LO CO(O CD N- N O ON) N 0) 0 to co O Tr Tr co N N co ENr- • co O O N N CO III LO CD N 2 a Cal CO 0)) OD - M NI- CaCO C4 CASCO CV C C O Q N O 00 0) "0 0 02 a O Uwp 1- NtmMJO0z = yU) 03 0,1 4tCO . o 4* N. co •N N 0N - - N C - N ' Eo N- Eo — U NCS) 4 O co t N M co OTr co O N � oco - NNN0 � 000 Z Z CO0 00 < .0 1- 1— Dui as » UQO 001:CCLOOOti ? O Z Z ix D D = 12 . % = 2 / f g / , NOO / / f � af 15 5 $ _ . = co c +2, -0 m 7 Q / / \ 7B 0O o 10 £ \ moo = / / aE � 3 \ 0 cu / /\ 7 �\ 3 ± I L.. CO22/ / c \k « asIEf as / c . ..� 0 f ¥ cob 0 CJ C & £ \ / p k 7 0 ( /© 2 7 F- 0 g =RI / o2 ± \ kC " C ® a (13\ % 2R2 Ca OO) ecno6c a) op CNI : : c y a_' G = E -8 co I 2 owe $ # 50 i . 00 / 0 rod % � � /f , b_ / % � - , w o « ;2 / g & a c 8 © _ CD « m up/ G ■ % 8 c . maces / � / 2k E n w - 0 2 \ 0 6 0 E CIS ± c j 2 / / »/ Q f \R � $ tcmc � R - 0 a % \ f / 0 / / 2 / kk / k/ k / / f � \ k/ / / 0 LL ca ± 0 00 $ SF- k k k1 2 0 f = _ ± _o £ -9 2 ..o— O o I U k & [t ƒ $ k i 0 / a f E i w R r r / 5 c) R 2 2 U « MCEVOY WELLHEAD 6"MCEVOY 01 -04B ` Sl. t NOTES: WELL ANGLE>70°@ 9375'*** ACTUATOR= AXELSON CHROME TBG& LNR***MONO BORE J tNIT1AL KB.ELEV= 73° 'I V ,v• COMPLETION-NO OA*** BF.ELEV= ? 30"CONDUCTOR — ? 11� KOf'_ 4339' 1'1 —1' —I CUT BELOW SURFACE PATCH CSG -i 1449' •0 • 2058'►'i ' hh3xAngle= 112"@11309' (• —19-5/8 E5 CEMENTER ADatum MD= 9092' Datum ND= 8800'SS I I 2374' —4-1/2"FRES X NP,D=3.813" 20"CSG,94#,H-40&133#,K-55 --1 1508' ii 9-5/8"CSG,47#,L-80 TCI,D=8.681" —I 2073' GAS LFT MANDRELS 13-3/8°CSG,72#,N-80,D=12-347" —I 2735' ST MD TVD DEV TY FE VLV LATCH PORT DATE 6 3146 3146 1 MMG DOME RK 16 11/25/13 5 4748 4737 16 KBG2 DMY BK 0 10/26/13 9-5/8"X 7"BKR HRD ZXPN LTP,ID=6.19' --{ 4077' Li 4 5858 5802 11 KBG2 SO BK 20 12/18/13 9-5/8°X 7"BKR FLEX LOCK HGR,ID=6.24" —{ 4093' 1_ 3 6798 6720 13 KBG2 DMY BK 0 10/26/13 2 7572 7475 12 KBG2 DMY BK 0 10/26/13 Minimum ID = 3.725" @ 8551' 1 8221 8108 17 KBG2_ DMY BK 0 10/26/13 4-1/2" HES XN NIPPLE 4584' H9-8/5"FOC 9-5/8"CSG,40#!43.5#/47#,SOO-95 BTRS, H —4981 MILLOUT WINDOW(01-04B)4981'-4998' D=8.835"! 8.755"!8.681" TOP OF CEMENT —I 7214' ;; 4 ' ' 8418' —4-1/2"FES XNP,D=3.813" .4 ti -' 8448' H 7"X 4-112"I- S TNT PKR,D=3.856" .4 ' ' 8481' H4-1/2"FPS X NP,D=3.813" k 4 .4 855V --14-1/2"HES XN NP,D=3.725" .4 TOP OF THE 4-1/2"LNR —{ 8561' 8561' —{7"X 5"BKR FRO E ZXPV LTP 4-1/2"TBG, 12.6#,13CR-80 VAM TOP, — 8569' .0152 bpf,D=3.958" w!11'TlB+4CK,D=4.35' 20 9' —4-112"WLCG,3.958' 7"LNR 26#,L-80 VAM TOP HC..0383 bpf,D= 6.276" H 8590' 1 'E, H E LKO TT NOT LOGGED 8581' H5"BKR RS PACKOFF SEAL NP,D=4.25" 7"LNR 26#,L-80 BTC-M,-0383 bpf,D= 6.276" H 8714' t 8583' —17'X 5"BKR FLEX LOCK HGR,D=4.31' 8593' —15"X 4-1/2"XO,D=3.920" PERFORATION SUMMARY REF LOG: MM)ON 10/21/13 I 9429' HPUP JOINT w/RA TAG ANGLE AT TOP FERE:87°©10570' Note:Refer to Production DB for historical perf data II 10509' --I Pl1P JOINT w/RA TAG SIZE SPF INTERVAL Opn/Sqz SHOT SOZ 2.88" 6 10570-10820 0 10/25/13 4 2 11205' —4-1/2"WFD CIBP(01/11/15) .88" 6 11250-11255 C 10/25/13 FBTD --I 11314' • 1�1�1t1 4-1/2"LNR,12.6#,13CR VAM TOP, 11400'm 111 .0152 bpf,,ID=3.958" DATE REV BY COME TTS DATE REV BY COMMENTS PRUDHOE BAY UHT 07/07/70 INITIAL COMPLETION 12/04/13 RR/PJC 13-3/8"/20'CSG CORRECTIONS WELL: 01-04B 09/01/01 N3S SIDETRACK(01-04A) 12/27/13 RCT/JM3 GLV C/O(12/18/13) PERMIT No: 2131060 05/31/06 N2ES CTD(01-04B)SUSPEND 5/25/01 01/13/15 TTR/JMD SET CEP(01/11/15) API No: 50-029-20070-02 10/29/13 PKR 272 SIDETRACK(01-04B) SEC 8,T1ON,R15E,430'FNL&1399'PM.. 11/11/13 FM PJC FINAL ODE APPROVAL 11/25/13 CJN PJC GLV C/O BP Exploration(Alaska)
