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169-119
STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG DEC 2 7 ansa 1a. Well Status: Oil ❑ Gas ❑ SPLUG ❑ Other ❑ Abandoned 0 Suspended ❑ lb. ell as 25.105 20AAC 25.110 GINJ ❑ WINJ ❑ WAG 11WDSPL ❑ No. of Completions: Zero l(J'J9? ory El Service ❑ Stratigraphic Test ❑ 2. Operator Name: 6. Date Comp., Susp., or Aband.: 14. Permit to Drill Number/Sundry BP Exploration (Alaska), Inc 12/1/2019 169-119 . 319-232 3. Address: 7. Date Spudded: 15. API Number: P.O. Box 196612 Anchorage, AK 99519-6612 1/17/1970 50-029-20053-00-00 - 4a. Location of Well (Governmental Section): 8, Date TD Reached: 16. Well Name and Number: 2/20/1972 PBU 07-02 Surface: 193 FNL, 1356' FWL, Sec. 06, T10N, R15E, UM 0flew 9 Ref Elevations KB 70.00 17. Field/Pool(s): wg� Top of Productive Interval: 1242' FNL, 4021'FM, Sec. W, T10N, R15E, UM GL 40.00 BF Surface PRUDHOE BAY, PRUDHOE OIL Total Depth: 1246' FNL, 1262' FEL, Sec. 07, T10N, R15E, UM 10. Plug Back Depth(MDrTVD): 18. Property Designation: Surface / Surface ADL 028329 4b. 4b. Location of Well (State Base Plane Coordinates, NAD 27): 11. Total Depth (MDrIVD): 19. DNR Approval Number: Surface: x- 698672 ' y- 5940730 Zone - ASP 4 9930'/ 9275' 79-179 TPI: x- 696326 y- 5939619 Zone - ASP 4 Total Depth: x- 696086 y- 5939608 Zone - ASP 4 12, SSSV Depth (MD/TVD): None 20 Thickness of Permafrost MD/ND: 1900' (Approx.) 5. Directional or Inclination Survey: Yes ❑ (attached) No 0 13. Water Depth, if Offshore: 21. Re-dMill-ateral Top Window Submit electronic and printed information per 20 AAC 25.050 N/A (ft MSL) N/A MD/TVD: 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 lags 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 DIL, FDC / GR, BHC / GR, PNL, GR / CBL / CCL, Gyro 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 117' Surface 117' 20" 94# H-40 Surface 696' Surface 696' 26" 275 sx Fondu 13-3/8" 72# N-eo Surface 3004' Surface 3004' 17-1/2" 1450 sx Fondu 9-5/8" 47#/40#-awsdass /43.5# Surface 9978' Surf'292' 227' 12-1/4" 1800 ax Class'G', 912 sz Class'G' 7" 26# -ao 2286' 8876' 22Scab Liner 912 sz Class'G' 3-1/2" 9.3# L -so 904fi''84991' Scab Liner 33 Bbls Latez Acid Resistive Cement 24. Open to production or injection? Yes ❑ No 0 25. TUBING RECORD If Yes, list each interval open (MD/TVD of Top and Bottom; Perforation Size and Number; Date Perld): GRADE DEPTH SET (MD) PACKER SET (MD/TVO) 4-1/2" 12.6# 13Cr8O 8798' 8418'/ 7861' 5-1/2" 17#x4-1/2" 12.6# MN -80 8961' - 9120' 8984'/ 8395' (� 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. Was hydraulic fracturing used during completion? Per 20 AAC 25.283 (i)(2) attach electronic and printed Yes ❑ No D 2d 1 information IFF1 TIDEPfHINTERVAL(MD) AMOUNTAND KINDOFMATERIAL USED 3770'- 3775' Punch Tubing -V�� Surface 230 Bible Class'G' Surface -35 Be] AS 1 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 Test Period -.► Oil-Bbl Gas-MDF, Water -Bbl: Choke Size Gas -Oil Ratio: Flow Tubing Press Casing Press: I Calculated 24 Hour Rate -y Oil -Bbl: Gas -MCF: Water -Bbl: Oil Gravity - API (corn: Form 10-407 Revised 5/2017 CONTINUED ON PAGE 2 Submit ORIGINAL only RBDMSALJDEC 3 0 2019 ✓r_r 28. CORE DATA Conventional Corals) Yes ❑ No [ Sidewall Cores Yes ❑ No 0 , 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 laboratoryanalytical 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 m Permafrost - Base If yes, list intervals and formations tested, briefly summarizing test results. Attach Top of Productive Interval 9309' B702' separate sheets to this form, if needed, and submit detailed test information per 20 AAC 25.071. Top Sadlerochit-Zone 4 9309' 8702' CGL - Zone 3 9491' 8872' Base of COIL - Zone 2 9600' 8973' Zone 1 9850' 9202' Base Sadlerochit- Kavik 9930' 9275' Formation at total depth: Kavik 9930' 9275' 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, productionor well test results, per 20 AAC 25.070. 32. 1 hereby certify that the foregoing is true and correct to the best of my knowledge. Authorized Name: Lastufka, Joseph N Contact Name: Obrigewitch, Beau Authorized Title: SIM S ciali Contact Email: BEAU.OBRIGEWITCH@bp.com Authorized Signature: ate: Contact Phone: +1 907 564 4854 INSTRUCTIONS General: This form is designed for submitting a mmplete 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 10404 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. Weil Class Service wells: Gas Injection, Water Injection, Water-Altemating-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 given 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 orwell test results. Form 10-407 Revised 5/2017 Submit ORIGINAL Only T/I = 120/163. Temp = SI. WHPs (WIE request). No wellhouse or flowline. Dry hole tree. Temp scaffold installed. 5/16/2019 SV, MV = C. IA = OTG. 04:20 T/I = 100/120. Temp = SI. WHPs (WIE request). No wellhouse or flowline. Dryhole tree installed. Temporary scaffolding installed. The TP decreased 20 psi and the IAP decreased 43 psi since5/16/19. 5/30/2019 SV, WV = C. IA = OTG. 16:20 ***WELL S/I ON ARRIVAL*** (Plug & abandonment) MADE TWO ATTEMPTS TO PULL BK-LGLV FROM ST #3 (3,798' MD, Cracked skirts). 5/30/2019 ***JOB IN PROGRESS, CONTINUED ON 5/31/19 WSR*** ***CONTINUED FROM 5/30/19 WSR*** (Plug & abandonment) MADE TWO MORE ATTEMPTS TO PULL BK-LGLV FROM ST #3 (3,798' MD). DECIDED ON TBG PUNCH RATHER THAN OVER -SHOT (ST #3 latch fishing neck 5/31/2019 stripped). ***WELL S/I ON ARRIVAL*** (P&A) HES RELAY UNIT #46 PUNCH TUBING @ 3770'- 3775' MD w/ 2" x 5' TUBING PUNCH (4 spf, 0 deg phase) CCL TO TOP HOT= 10' CCL TO BOTTOM SHOT= 15' TIED INTO TUBING TALLY DATED 9/29/2014 6/6/2019 ***JOB COMPLETE / DSO NOTIFIED*** T/I = 20/60. Temp = SI. WHPs (WIE request). Dryhole tree installed. 6/14/2019 SV, MV = C. IA, OA = OTG. 16:30 T/I = 13/54. Temp = SI. WHPs. (WIE Request). Temporary scaffold installed. Dry hole tree. Mono bore well. TP decreased 7 psi, IAP decreased 6 psi since 6-14-19. 6/29/2019 SV, WV = C. IA = OTG. 16:30 T/1/0=0/0/0. Pre P&A. RD expired block valves. RU new block ***JOB COMPLETE***. See 7/1/2019 log for details. Final WHP's 0/0/0. Schlumberger Fullbore Pumping Crew. Job Scope: Plug and Abandon TxIA Surface Cement Plug to -3770' MD. MIRU SLB pump crew. Pumped the following down TBG taking returns up the IA to surface tanks: 5 bbls 50/50, 5 bbls FW spacer, 230 bbls 15.8 ppg Class G cement. Clean cement returns observed from IA @ -210 bbls away. DHD injected small amount of N2 across IA valve to OTTto clear any residual cement. 15.8 ppg Class G Cement in TAA TOC in TxIA = surface 7/1/2019 Est BOC in TxIA = 3770' MD/ 3752' TVD T/I = MV/20. Temp = SI. Bleed IAP (Fullbore Request). Temporary scaffolding installed. Dry hole tree. IA FL @ surface. Bled IAP from 20 psi to 0 in 30 minutes to BT.(1 bbl). Monitored for 45 minutes, IAP unchanged. Final WHPs = MV/0. 7/1/2019 SV, MV = C. IA = OTG. 05:00 T/I = Vac/Vac. Temp = SI. WHPs (WIE Req). No well house or flowline. Dry hole tree installed. Temporary scaffold installed around wellhead. 7/25/2019 SV, MV = C. IA = OTG. 15:40 T/I = Vac/Vac. Temp = SI. WHPs (WIE Req). Dry hole tree. No well house, flow line or scaffold. Temporary scaffold installed. WHPs unchanged since 07/25/19. 8/11/2019 SV, MV = C. IA = OTG. 04:15 T/I = Vac/Vac. 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. 01:45 T/I = Vac/Vac. 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 Daily Report of Well Operations PBU 01-02 Job Scope: P&A NES. Prep top of conductor for welding. Top of 30", 20" and 13-3/8" w/ -35 11/29/2019 gal 15.6 ppg AS1 cement. Cut is 5' below tundra grade. Job Scope: P&A NES - AOGCC inspection complete (M. Herrera). Weld on cap. Take final 11/30/2019 photos. Backfill can. ***In Progress*** Job Scope: P&A NES. Remove can and complete backfill. Leave mound to allow for settling. Wellhead cut 4.5' below tundra grade. Pics uploaded to U:\Wells\Interventions WellWork\Well Pictures Info\01\01-02 and submitted to AOGCC inspector M. Herrera as 12/1/2019 Irequested. Fiinal report. Awllol- Ts K ,: i ✓"�1o„u, �ti�� p p rr' � Y.;�. ' TREE= DRYHOLE WELLHEAD= CNV ACTUATOR= REMOVED OKB.ELEV= 73.0' BF. ELEV= SURFACE KOP = 3400' Max Angi, = 30'A 4100' Datum MD = 9492' Datum TVD= 8800'SS ABANDONED 30' NSUAT®-110 C%DUCTOR 20' CSG, 94 #, 696' ,D=9124B2286, TOPOH0SCA NR 9-5/8" CSG, 47#. L-80 VAM TOP, ID= 8.681' 9-5/8" BOWER CSG PATCH, D = 9.06• 2429' 2433' 13-3/8' CSG, 72#, N-80, ID = 12.347' 3004' TBG PUNCH. 4 SPF (06/06/19)377-- w 3775• TUNDRA ELEV. CEMENTED TC JRFACE & MARKER CAP WEL ON. 12/01/19 9-518' CSG, 40.5#, SOO-95, D = 8.835' 6184• XO TO 43.5#, SOO-95, D = 8.755' Minimum ID =2.992" @ 9046' 4-1/2" G LANDING SUB 4-12- TBG, 12.6#, 13CR-85 VAMTOP,8798• .0152 bpf, D = 3.958' 9-5/8' CSG, 43.5# XO TO 8801' 47#, SOO-95, D = 8.681' 7' SCAB LNR 26#, L-80 VA TOP HC, 8811' .0383 bpf, D = 6.276' 4-12' TBG, 12.69, L-80 TCL .0152bpf, D = 3.958' TOP OF }72' SCAB LNR -C 4-12' TBG -NPC, 12.8#, MN -60, 9120' .0152 bpf, D = 3.958' PEWOR4TDNSL1vWRY RE= LOG: BRCS ON 02/20!70 ANGLE AT TOP PERF 23° Q 9661' Note: Refer to Production DB for historical pert data SIZE SPF INTERVAL Opri/Sqzl SHOT I SOZ WA 4 9360-9370 S 02/27/70 03107!70 WA 4 9430-9440 S 02/27/70 03/07/70 4" 4 9455-9485 S 03109/70 10/12185 4" 4 9495- 9525 S 03/09/70 10/12/85 4" 4 9545-9575 S 03/09/70 10/12/85 4" 4 9585-9616 S 03/09/70 10/12/85 4" 4 9627-9975 S 10/18/85 05/26/87 4" 4 9660-9674 S 10118/65 05/26/87 3-318" 4 9661-9675 0 08/10/90 4" 4 9690-9708 S 06/27/87 08/06/90 3-318" 4 9691- 9709 O 08110190 3-1/2- SCAB LNR 9.3#, L-80 FL4S, I 9620- -0087 bpf, D = 2.992• 479, SOO-95, .0733 bpf, D = 8.681• 9871 01-02 MD ITVD SAFETY NOTES: -4-112" CHROME TBGI** TYPE VLV I LATCHI PORTF DATE 3 2 1 1 3796 727: 8309 BELOW -:rrllrir, KBG2 DOME BK K8G2 DOME eK KBG2 DMY BK �I�IT�'�IYI1 �y1� i 1 �� "s 06/10/19 NXW/JM TBG PUNCH (0696/19) .. ., RJH/JMD 9-5/8'NOT CUT BELOW GRADE II1 9 tlf ®.. • . \� 1,'��1 ��• - a •• 9-5/8- HES FS CEMENTER, ID 8.618' ISTI MD ITVD DEV TYPE VLV I LATCHI PORTF DATE 3 2 1 1 3796 727: 8309 3778 6821 7760 23 26 22 KBG2 DOME BK K8G2 DOME eK KBG2 DMY BK 1: 16 0 0926/15 0926/15 0499/19 06/10/19 NXW/JM TBG PUNCH (0696/19) 6397 1-19-5/8- OV COLLAR 6894'-8400' CMr TXW(04/14119)SL TAGGEDT005/4/19 J 4-12' OT6 X NP, D = 3.813' 8396' -8400'TBG PUNCH w2.4 SPF (04/09/19) 84� 7• X 4-12• HFS TNT PCR- D = 3.856• OTSX NP, D=3.813• OTS XN NP, D = 3.72`. PXN RUG (06/02/17) WLEG, D = 3.958• LTP wIBKR HMC LNR HGR, D = 620' 8822' PORT® SEAL ST81 8876' 7• X 4-12" XO 1) iSY, D = 4. D= 3.958' 8984' 1-I9-5/8• X 5-12" BKR SAB PKP, D= 4.75" W� 6-5/8' MLLOUr EXTENSION, D=_' 8996' 0420/19 S/JMD TBG PUNCH & GLVS (04/09/19) 904b• 4-12' G LANONG 8(18, D = 2.992" 9056' 4-12. OTIS XN NO-GO NP, D = 3.725• 9120' a72 wLEG,o=3.ss6 BEHIND Y4� R TiI rI m7tan LNR 7 iJy3-12• DAMS LYNCH IXi4L FLOAT SLM FZL 1.69'BPANDPECEOF5- TOOL GRAPPLE (0524/14) DATE I REV BY COMMENTS DATE I REV BY I COMMENTS 03115f70 RWN 24 INITIAL COMPLETION 0420/19 S/JMD TBG PUNCH & GLVS (04/09/19) 0321!/7 RWN 26 RWO 0420/19 A 1. MD+ TXIA CEMENT PLUG (04/14/19) 1011994 SCAB LINER 05/06/19 JMJJMD ADD BF & UPDATED SL TAGGE 1094114 D44 RWO 06/10/19 NXW/JM TBG PUNCH (0696/19) 08/16/17 RJH/JMD 9-5/8'NOT CUT BELOW GRADE 07170/19 MRD/JMDTXIH CEMENT PLUG 0791/19 0226/19 KP/JMD DRYHOLETREE 1295/19 AB/JMD ABANDONED (12/01/19) PRUDHOE BAY UNIT WELL: 0"2 PERMITNo: '1691190 AN No: 50-029-20053-00 TION, R15E, 193' FNL & 1357' FWL BP Exploration (Alaska) MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: Jim Regg ; SCIC I�17��`� DATE: 11/30/19 P. I. Supervisor j FROM: Matt Herrera SUBJECT: Surface Abandonment Petroleum Inspector PBU 01-02 BPXA PTD 1691190; Sundry 319-232 11/30/2019: 1 traveled out to PBU 01-02 and met with BPXA representative Arvell Bass and visually inspected the excavation and well casing stub. Previously noted by BPXA representative was that the well had a void in the surface casing by conductor annulus. Repairs had been made with top job cement to seal off voids prior to my arrival. Cement inside and around and outside of casing strings was solid and showed correct cement top at surface. Depth of cutoff was determined to be at a depth of 13 feet below pad and 5 feet below natural grade (3 feet below natural grade required) and marker plate information was verified. Attachments: Photos (4) 2019-1130_Surface_Abandon_PBU_01-02_mh. docx Page 1 of 3 Surface Abandonment — PBU 01-02 (PTD 1691190) Photos by AOGCC Inspector M. Herrera 11/30/2019 [Ca:sinngutoff; void in Surface ctor annulus — photo of BPXA 2019-1130—Surface_Abandon_PBU_01-02_mh.docx Page 2 of 3 THE STATE °fALASKA GOVERNOR MIKE DUNLEAVY Beau Obrigewitch Well Integrity Engineer BP Exploration (Alaska), Inc. PO Box 196612 Anchorage, AK 99519-6612 Re: Prudhoe Bay Field, Prudhoe Bay Oil Pool, PBU 01-02 Permit to Drill Number: 169-119 Sundry Number: 319-232 Dear Mr. Obrigewitch: Alaska Oil and Gas Conservation Commission 333 West Seventh Avenue Anchorage, Alaska 99501-3572 Main: 907.279.1433 Fax: 907.276.7542 v .00gcc.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, L�� Daniel T. Seamount, Jr. Commissioner DATED this % `day of May, 2019. 3BDMS 6/ MAY 15 2019 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 MAY 0 7 719 1. Type of Request: Abandon 0 r Plug Perforations ❑ Fracture Stimulate ❑ Repair Well ❑ Operations shutdown Suspend Perforate ❑ Other Stimulate ❑ Pull Tubing ❑ Change Approved Program 6 Plug for Redrill ❑ Perforate New Pool ❑ Re-enter Susp Well ❑ Alter Casing ❑ Other ❑ 2. Operator Name: SP Exploration (Alaska), Inc 4, Current Well Class: 4 Exploratory ❑ Development 5. Permit to Drill Number 169-119 3. Address: P.O. Box 196612 Anchorage, AK r 99519-6612 Stmligraphic ❑ Service ❑ 6 API Number: 50-029.20053-00-00 7. If perforating: 8. Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? Will planned perforations require a spacing exception? Yes ❑ No 0 r PBU 01-02 9. Property Designation (Lease Number): 10. Field/Pools: ADL 026329 r PRUDHOE BAY. PRUDHOE OIL ti. PRESENT WELL CONDITION SUMMARY Total Depth MD (it): Total Depth TVD(ft): Effective Depth MD: Effective Depth TVD: MPSP (psi): Plugs (MD): Junk (MD): 9930 9275 6894 6478 8773 9623 Casing Length Size MD TVD Buret Collapse Conductor 80 30" 37-117 37-117 880 Surface 659 20" 36-696 36-696 1530 520 Intermediate 2970 13-3/8" 34-3004 34-3004 5380 2670 Production 9846 9-5/8" 32-9878 32-9227 6870/8150/6820 4760/6080/3330 Scab Liner 6674 7" x 4-1/2" 2286 - 8960 2286-8372 7240 / 8430 5410/7500 Scab Liner 574 3-1/2" 9046 - 9620 8454-8991 10160 1 10530 Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): 9661 - 9709 9029-9073 12" 12.69 /5-112" 1711iW 12" 12. 13Cr80 / MN -80 1 30 - 8798 / 8961 - 9120 Packers and SSSV Type: 4-12" HES TNT Packer Packers and SSSV MD (ft) and TVD (ft): 8418/7861 5-4/2" Baker SAB Packer 8984 / 8395 12. Attachments: Proposal Summary 0 Wellbore Schematic 0 13. Well Class after proposed work: Detailed Operations Program ❑ BOP Sketch ❑ Exploratory ❑ Stretigraphic ❑ Development 0 Service ❑ 14. Estimated Date for Commencing Operations: February 15. 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. 1 hereby certify that the foregoing is true and the procedure approved herein will not Contact Name: Obrigewitch, Beau be deviated from without prior written approval. Contact Email: BEAU.OBRIGEWITCHQbp.00m Authorized Name: Obrigewitch, Beau Contact Phone: +1 907 564 4854 Authorized Title: Well Integrity Engineer Authorized Signature: Date: COMMISSION USE ONLY Conditions of approval: Nobly Commission so that a representative may witness Sundry Number: n I ^ /✓♦ 'C/— Plug Integrity ❑ BOP Test ❑ Mechanics[ Integrity Test ❑ Location Clearance (� 1 ♦ 1 ` �I Other: P% by 01-02 Full Plug and Abandon Intervention Engineer Beau Obrigewitch (907) 564-4854 Production Engineer Finn Oestgaard (907) 564-5026 Expected start date: June 15t1, 2019 History 01-02 was completed with a Gen 1 Permafrost Wellhead and three string casing design in 1969. The outer casing string is set in permafrost. GWO has determined wells of this construction are at risk for sudden wellhead movement, as demonstrated by 02-03A and 02-02A. As such, AOGCC has requested this well be plugged and abandoned to mitigate HSE consequence associated with this potential risk. In March and April 2019 reservoir plug and abandonment operations were completed per Sundry 319- 031. On May 4, 2019 AOGCC witnessed a passing CMIT-TxIA and cement tag of the reservoir plug. This was reported on subsequent 10-404. Objective Place surface abandonment cement plug in the wellbore. Excavate and cut casings 3' below original tundra level and install marker cap. This P&A program is designed to conform to BP Practice 100221: Zonal Isolation and BP Alaska's deviations captured in eMOC 10439. Job Steps 1 S Pull LGLV from STA #3 3 V Drop annulus gate valves and install integrals 4 J Surface Cement Plug IA and Tbg 5 F Assist Special Projects 6 D Bleed WHPs to 0; Monitor after 24 hrs 7 J Excavate for Full P&A; Remove Wellhead; Install Marker Plate, (AOGCC)(Permanent) Excavate & Install Shoring Box 2019 Procedural steps Slickline 1. Pull LGLV from Sta #3 at 3,798' Volume Calculations - Surface -to -Surface Cement Valve Shop 2. Drop annulus gate valves and install integral valves. Fulibore / Special Projects 3. Circulate cement down the tubing, taking returns from the IA, cementing both tubing and IA from 3,798' to surface, at 5bpm per the following pump schedule: • 5 bbis neat Meth or 60/40, at WSL discretion • 5 bbl FW spacer • 220 bbls Class G cement per design 4. Cement returns should be at surface @ -208 bbls of cement away. Continue pumping cement until clean cement returns are noted, approximately 10-15 bbls. The top of cement in the IA and tubing will be at surface. 5. At WSL discretion, inject a small amount of N2 across the wellhead in an attempt to remove some cement, increasing the chance of opening the valves and providing a monitorable space to check for pressure prior to cutting the wellhead off. Recording Requirements: Note the recording requirements in RP: Through -Tubing Abandonment, Section 5.9. Cement Desi n - Mix on the FI Cement Type / Weight Class G 15.8 ppg mixed on the fly Field blend to by equal to lab +/- 0.1 ppg Slurry Temperature 800 to 110° F Fluid Loss 40-200cc 20-100 cc / 30 min Compressive Strength 2000 psi in 48 hrs Thickening Time Minimum 5 hours Cement Thickening Time Activit Time hours Shearing time, quality control, PJSM 0 Cement displacement —220 bbls @ 5 bpm) 1 Safety 3 Minimum required thickening time: 4 DHD 6. Bleed tubing and IA pressures and monitor after a minimum of 24 hours. Special Projects 7. Excavate and Cut off all casings and wellhead 3' below original tundra level. Top job all annuli and tubulars with cement as needed. Install marker cap on outermost casing string (conductor, if present). Provide a minimum of 24 hours notice to AOGCC Inspector of the timing of welding the marker plate onto the casing stub. Photo document the condition of the tubular stub immediately after cutting the wellhead, after topping off with cement (if necessary), and after installing the marker plate. • Marker Plate to meet requirements in RP: Through -Tubing Abandoment, Section 5.8: i. Minimum Yd' Thick ii. Minimum 18" Diameter • Bead weld to the marker plate the following information: BP Exploration Alaska, Inc. PTD: 169-119 Well: PBU 01-02 API: 50-029-20053-00 Check Off Date: Engineer: Well Name: P&A Deviation Assessment 1/31/19 Beau Obrigewitch 01-02 The region will complete a verification on the individual wells to determine if they fall within the stated boundary conditions. If a well falls outside of the boundary due to particular downhole conditions, this will typically be handled by the engineer seeking email approval for a scope change to this deviation from the Zonal Isolation SETA or Area Wells Engineering Authority. In cases where the scope change results in a significant increase in risk as determined by the Zonal Isolation SETA or Area Wells Engineering Authority, the well shall have a specific deviation and eMOC performed. Reservoir Plug xxa) No evidence of sustained casing pressure on the OA or OOA from DPZ3 and/or DPZ4. b) Tag top of cement in tubing to verify placement, and pressure test where possible. Intermediate Plug X a) If DPZ2 is not present; a minimum of 200 ft MD lateral barrier between DPZ3/DPZ4 and DPZ1. b) If DPZ2 is present; a minimum of 200 ft MD lateral barrier between DPZ3/DPZ4 and DPZ2. A minimum N/A of 200 ft MD lateral barrier above DPZ2. c) Tag top of cement inside tubing, and pressure test. Negative pressure test when DPZ2 is present. X This is a "one -and -done" cement job; No cement tag or pressure testing will be performed Surface Plug a) Control line and/or chemical injection line has injectivity to place cement slurry. NA No Control line in this well. X b) Tubing, IA and OA cemented from surface a minimum of 1300 ft MD to form lateral barrier to DPZ1. c) Where possible place a lateral barrier at least 200 ft MD in length below the end of the control line and above the surface casing shoe. NA No Control line in this well. d) Where possible cement the entire OA from surface to surface casing shoe. This is typically done by X doing an OA down squeeze or punching tubing and circulating up the wellbore. Risk Level a) There are no well integrity issues that would increase the risk level determined in the Risk X Assessment and standard well abandonment protocol. Top 9-5/8" Cement (ECP) 2408' 1,-41W MC., 7711, WRn In- 12 UI [Minimum ID = 21924'@ 9046'— 4-112" G LANDING SUB 9 s ...1. 4 50 SOO a ma. file %O TOC Tbg and IA "6894' SLM Top 9-5/8" Cement (CBL) 7400' Tubing Punch - 8400' 2.60,13CW86VAMT0P, I 8798'__ =3858• 1470.S00 -95,D-8681' 4.127 CM RS 7'sCABLW284,L-80VAMTOPFC, 9911' `-EAD= CAN 01-02 Current Status NOTES:•••4-112"CNROMETBGr•' ATOR• SAKERC 4 -Ur TBG NPC, 12.89, WOO. - 9120' emE LLV= 73.0 _ .- ___.—. _> JO'99119A (8) -110 1' .. _... 30•,20',1134•C77TsFiaN 034)7//3 4- 4 9455-9485 (3ma-(1(NN114) = 3400 OOFDUCIOR 4- 4 9495-0625 Angle == 30° 9 410fJ 21Y CSO, 941, dYB' 9Ot8' 4-vr nTl4%NV O. 361r 4- Top DPZ1/BPRF-2,000' s �N Top 13-3/8" Cement 1,430' 4- J Nate. Thin l:aaorm we fmmprtv, ,., :uOmimis 0109170 10/1225 4• 2296' 2399' j „ . 1, Top 9-5/8" Cement (ECP) 2408' 1,-41W MC., 7711, WRn In- 12 UI [Minimum ID = 21924'@ 9046'— 4-112" G LANDING SUB 9 s ...1. 4 50 SOO a ma. file %O TOC Tbg and IA "6894' SLM Top 9-5/8" Cement (CBL) 7400' Tubing Punch - 8400' 2.60,13CW86VAMT0P, I 8798'__ =3858• 1470.S00 -95,D-8681' SIZE 7'sCABLW284,L-80VAMTOPFC, 9911' .0383 epf, D - 0,776* SG2 1..1 r TB6 12.61, L -6o Ta .9, 5zep1, D 3.658 H aero' of J -in= seas �rrx',–{ 9o4s. 4 -Ur TBG NPC, 12.89, WOO. - 9120' .0152 bo, D = 3,958- 4 9430-9440 PEFFORATIM SII"W REF LOG' BFICS ON 022070 ANOLEATTOP PEIV: 23' @9f181' Nob'. Refer to Roduolbn OB for hbbfcol ped dote SIZE SFF WTERVAL OpWSQz %DT SG2 WA 4 - 9380.9370 S 62n`T17o 5011`!6 WA 4 9430-9440 5 WT/7O 034)7//3 4- 4 9455-9485 S 03/09170 10/12/ffi 4- 4 9495-0625 S 03D913'0 10312185 4- 4 0646 06)6 s a O 10/12 4- 4 95M - 9618 S 0109170 10/1225 4• 4 9827-9675 S 10/18185 005187 4' 4 9860 - 9674 S 10/1885 052647 3 34' 4 8861 - 9675 O 08/10/90 4' 4 9690 - 9708 S 06/2747 08/0619D 134" 4 9691-9708 O OM10A0 SCAB LW 9 3d, L-80 FL4S, 962W W. D= 2.992 --- r o:5/5- al�, GAS LFT MAND*LS 2 � 7278I,..i 28 IKBf32IOORk OK 116 1 P218 6021 o0 11(= row SK n vM Base DPZ 1— 71044' 8396' 41IT OTB X NP. D • 3,913' 14-I1T(11RX NP.G.IIA,r i 4-12' V* FG, D - 3 9-6W X T BKR FF[ LNR IGR D = 820' { e4w64' � (-1354• x S12.13KR sAB I3Q7, D = us• I 6-5/6•071 uT ExiaiiDN. d -5l8' x 4.12' XO, D = 3.956' 9007' A/2'G UNOFIC BIB,D� 2.097 Top DPZ 3 — 9,199' IND i it io' %1' f 1 i '".i I -D'',,' p);:;,1 i -AR 1 ? !-{TOPoF(;&✓EIf (xvxvxx) . ( 9620' .-•i3117-13AVLSLYNCH(IAI.q 1AISR)F. j` 9823' SLM Ir811 I e9' Bvnw IL(;FE of s v2- I(X)( . GRAM I (Ds12411 n PRI.0F10L BAY uNi WHI 07-07 PHM!Ib.'1691190 AR No: 500292005300 SEC 3, TIOf4 R15E 193' F11$1357' FV& O,TE I RFV 0 oDM_ _---- 047E F/ BY CD M wM ----- 00/1880 f80N b/ INTtRL GOM•LlT10M I6Y9/N 7PoJ9AD MFDN SCiBA4TC PIXfB 03r21f77 RWN 26 RWO ---- &28115 J GLV(YO(ONM15) ---- 1011W94 9CABLINR 02124116 MAD TFEE00(iGIM14) 1024!14 D-14 FWO 06107/17 JGUJMD', SFT PXN PLUG (06'02117) 1d13114 CKAV FWLODLAPPROVAL 07125117 RJIi'JMD 30'.20, 133/8'89-5/6•CaiRECIDNS SP Exploration(AInko) 10127/14 J_&JK)G3-V0D(1O/1,Vl4) 8116117 ROY•BD'9-518'NOT CLIF BBCRAGE -- fi34:01RATIOM SIAWRY FEF LOG: BRCS ON 02/20100 ANGLEAT TOP PERF: 23.43 9661' Note: Refer to Production OB for historical pert data SIZE SPF IME1tVAL OpWSqz �LWAG CNV 01-02 Proposed P&A NOTrS:'•'4-112"CHROMETBG"• 1Z;IUA'IOFt= BAKER( OZ27770 03107170 XB. ELEV = 73.V 30"1V.SIIAIH)-J -110 S 1' 30•, 2(r,13318.OJT an Ow W. a[3,_ 7 4• 4 9455-9485 S ;tap- 3400 COFO C)R lax Angle = 3D• Q 4100' 20"M. 94 #, 696' 2066' hl/7 OM x NP. D • 3 813" ft mN Top 13-3/8"Cement 1,430' Top DPZ 1/BPRF-2,000' 4" 4 0646 0676 6 OapW70 Nete: This Is a correction /rom previous submitbls 4" 4 9585-9616 S 2288' i. 2389' y'.a-I;. .:I!. tJ rvl tJll i,,U tlrla' 8.518• Top 9-5/8" Cement (ECP) 2408' 2408 s-5/4 eKRrrr e- C 2 GAS LFT MANDFaS 1i-'1m'rsr;. 774. µnn n = 12347•, 8T kD 1VD DEV TYPE VLV LATCH PORT DATE 08!10190 3 1/98 3778 23 '011210014-1 BK 18 09716115 Bottom of Cement 3,798' (Sta #3) 2 7218 6821 26 , K8G7 nOVE 8K 16 09728115 I 3-318" 4 9691-9709 O uv n 10/03/14 J'4-11,9 %JLMr"4lU 9-5!' _- 184'- `6; Base DPZ 1— 7,044' XC TOC Tbg and IA 6894' 8388' 4-11r0TISXNP.D•381r] Top 9-5/8" Cement (CBL) 7400' 6418' 7•x4-12"HESTFITWR D•3.656• Tubing Punch -8400' 8469• 4.10"f MX NRIe.AA1r e77s 4-112" OTIS XN M P D = 3.725" 4112" TBG, 1260, 1SCR-86 VAM TOP, 8798' enr j 4-112• FxN PlA1G (O6*2/17) .0152 bp1,D=3.958" —" 4-58' CSG, 43.58 XO TO $801' ays' 4-trr vw L[i, D • 3956 470, 50695, D a 8 881' MV 9-578• X 7" BKRHRDE ZXFN LTPw IBKR HIM 7 SCAR I.M2, 2W, L-80 VAM T0P FIC, 8811• LN414GR. D: 62(' 0383 hpf, 1) - 6.276' 8827 PORTED SEAL STEM D 4-112" TBG, 12.60, L-80 TCI, .0152bpf, D = 3: JSW' $980' 8876' r X 4-112• XO, D- 6276' TOP OF 3-112• SCAB LNR - 8960' 51/7 BOT PBRASSY, 8960' 4-12" MdESHOF D=3 Sr 4-itr 7EaNPC, 12.60, MFI-80, 912W .0152 bp1, D = 3.958' 138984' 9 -SIB" X 5-112" 8KR 3108 PIOZ D= 4.75• fi34:01RATIOM SIAWRY FEF LOG: BRCS ON 02/20100 ANGLEAT TOP PERF: 23.43 9661' Note: Refer to Production OB for historical pert data SIZE SPF IME1tVAL OpWSqz %W SOZ WA 4 9360.9370 S OZ27770 03107170 WA 4 9430-9440 S 0212710 03107170 4• 4 9455-9485 S 030DWO 10112/85 4" 4 9496-9625 S 0.3109770 10/12/85 4" 4 0646 0676 6 OapW70 10/1286 4" 4 9585-9616 S 03AWO 10/12/65 4' 4 %27-9675 S 10/1885 MOW 4" 4 9660-9674 S 10/1865 05126197 3-18" 4 9661-9675 O 08!10190 4- 4 9690-9708 S 06!27187 08!0680 3-318" 4 9691-9709 O MIO -90 1.0087 bpf, D = 2.997- 0-516r CSG, 47#, SOO-95, .0733 bpf, D c 9878' D = 2.997 Top DPZ 3 — 91199' HNII \ I 9110'�NH 9620' -- 3177'DAVri I Y N>i[A LAI P-1,OA1 SF1tf-. !Mk SLMJ I["N 169 µP AN1(F(:r OF S 10' �1(XA (RAW U, (0517471-0) U�� 001T GATE REV !3Y ----.. OOd.R.iT M _. `LYATE PRIAHOE SAY UW WELL: 01-02 PEFWW '1691190 AFI No: 50-029-20053-00 SEC 8, TION R15E 193'FH181357fWL P£V BY COM 344 08115100 RIYN241TaT1ALCOMPLEMN vNiaei4 IRJM) MN'JRSCEtMTICED05 `09-28115 'J GLV (70 (09rMl 5) 03721/77 RWM 28 RWO 10119184 SCARUEi 02724116 DJJAD TREE00(10/14114) 10104114 D-14 RWO 06107/17JGUJIDSETPXNPU1G(08102717) 10113/14 O QJM) FTIAL ODE APPROVAL 07/25117 RHJMO 30", 20', 13-W& S -W C_OfiECnDNS BP Exploration (Alaska) 10/21114 JLSfJMD GLV CO (10114114) 08/16117 RJWJAD 9.518' NDT CUT BELOW GRADE STATE OF ALASKA RECEIVED ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations Performed MAY U 12019 Abandon ❑ Plug Perforations 0 Fracture Stimulate ❑ Pull Tubing ❑ Operations shutdoowwn ❑ ��^ Suspend 11 Perforate 11 Other Stimulate ❑ Alter Casing El Change ApIPACI63�1 IS Plug for Reddll ❑ Perforate New Pool ❑ Repair Well ❑ Re-enter Susp Well ❑ Other. Secure Reservoir v 0 2. Operator Name: BP Exploration (Alaska), Inc 4. Well Class Before Work Development 0 Exploratory ❑ 5. Permit to Dnll Number: 169-119 3. Address: P.O. Box 196612 Anchorage, AK995IM612 Stratigraphic ❑ Service❑ 1 6. API Number: 50-029-20053-00-00 7. Property Designation (Lease Number): ADL 028329 8, Wall Name and Number: PBU 01-02 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 9930 feet Plugs measured 6894, 8773 feet true vertical 9275 feet Junk measured 9623 feet Effective Depth: measured 6894 feet Packer measured 8418, 8984 feet true vertical 6478 feet Packer true vertical 7861,8395 feet Casing: Length: Size: MD: TVD: Burst: Collapse: Conductor 80 30" 37-117 37-117 880 Surface 660 20" 36-696 36-696 1530 520 Intermediate 2970 13-3/8" 34-3004 34-3004 5380 2670 Production 9846 9-5/8" 32-9878 32-9227 6870 18150 16820 4760 / 6080 13330 Scab Liner 6678 7" x 4-1/2" 2286-8960 2286-8372 7240/8430 5410 / 7500 Scab Liner 574 3-1/2" 9046-9620 8454-8991 10160 10530 Perforation Depth: Measured depth: 9661-9709 feet True vertical depth: 9029-9073 feet 4-1/2" 12.6# 13Cr80/ Tubing (size, grade, measured and true vertical depth) 5-1/2'17# x 4-1/2' 12.68 MN -80 30-8798/8961-9120 30-8218/8373-8524 Packers and SSSV (type, measured and 4-1/2' HES TNT Packer 8418 7861 true vertical depth) 5.1/2' Baker SAB Packer 8984 8395 12. Stimulation or cement squeeze summary: Intervals treated (measured): Treatment descriptions including volumes used and final pressure: 13. Representative Daily Average Production or Injection Data Oil -Bbl Gas-Mcf Water -Bbl Casing Pressure Tubing Pressure Prior to well operation: 319 33838 3286 0 1327 Subsequent to operation: Shut -In 14. Attachments: (requred r er20 AAc 25070.25.071, a 25.293) 15. Well Class after work: Daily Report of Well Operations 0 Exploratory ❑ Development 0 Service ❑ Stratigraphic ❑ 16. Well Status after work: Oil 0 Gas ❑ WDSPL ❑ Copies of Logs and Surveys Run ❑ Printed and Electronic FractureStimulation Data ❑ IGSTOR ❑ 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: 319-031 Authorized Name: Worthington, Area J Contact Name: Worthington, Ares J Authorized Title: Interventions & Integrity Engineer Contact Email: AraS.Worthinglon0bp.com Authorized Signature: Date: S/�j��/ -7 Contact Phone: +1 907 564 4102 FOM 10-4M Revised 04/2017 ' mr/I� Submit Original Only �DMS�MAY D 01019 Daily Report of Well Operations 01-02 ACTIVITYDATE SUMMARY T/1/0=300/400/0. Pre P and A. RU CIW lubricator #839 with CIW "H" TWC #296, Set 4" TWC @ 135 ". RD Upper tree, RU temp. valve #57 as Dryhole SV. Torqued to API spects 752 FT/LBS. PT'd SV 300 psi. low and 5000 psi. High for 5 min. ea. charted and retained. Pulled 4" CIW "H" TWC. PT'd tree cap to 500 psi. (PASSED). ***JOB COMPLETE***. See 2/20/2019 log for details. Final WHP's 300/400/0. T/I = 440/410. Temp = SI. WHPs (WIE request). No AL, flowline, wellhouse, or scaffold. Dryhole tree installed. 3/1/2019 JSV = C. MV = O. IA = OTG. 1545 hrs. ***WELL S/I ON ARRIVAL***(P&A) PULLED 1" DGLV FROM STA #11. 3/6/2019 ***CONT ON 3-7-19 WSR*** TWO =-5/486/NA Temp=S/I (LRS Unit 46 - Assist Slickline: Circ Out / AOGCC CMIT-TxIA) Pumped the following down the tubing, taking returns up the IA to open top tank: 3 bbls 60/40 followed by 71 bbls 140* Freshwater w/ F103 & U067 220 bbls 9.8 ppg NaCl brine 3/6/2019 **Coninued on 3/7/19 WSR** ***Continued from 03/06/19 WSR*** (LRS Unit 46 -Assist Slickline: Circ Well, AOGCC CMIT-TxIA) Continue to pump the following down the Tubing, up the IA, to surface return tanks: 190 bbls 9.8 ppg NaCl brine (410 bbls total). Sample pulled at end of circ out, clean sample 9.7 ppg brine. 5 bbls neat meth. U -Tube for 30 min between TBG & IA for freeze protect. AOGCC witnessed CMIT-TxIA to 2437/2421 psi ***PASSED*** (Brian Bixby) Target pressure=2200 psi Max applied=2500 psi. Pumped 2.6 bbls meth down TxIA to achieve test pressure of 2500/2500 psi. 15 min loss of 20/21 psi, 30 min loss of 17/18 psi, for total loss of 37/39 psi in 30 mins. Bleed TxIA to 50/50 psi Bled back —2.4 bbls See log for details. 3/7/2019 1SL on well upon departure. CVs OTG ***CONT FROM 3-6-19 WSR***(P&A) LRS CIRCULATED 410 BBLS OF 9.7# BRINE DOWN TBG & UP IA. PULLED 4-1/2" WHIDDON CATCHER SUB FROM 8773' MD.(empty) ***ST#1 @ 8309' MD POCKET LEFT OPEN*** LRS PERFORMED PASSING CMIT-TxIA TO 2200psi.(AOGCC witnessed by Brian Bixby) TAGGED PXN PLUG @ 8773' MD W/ 3.50" LIB.(good impression, AOGCC witnessed by Brian Bixby) 3/7/2019 ***WELL S/I ON DEPARTURE, DSO NOTIFIED OF WELL STATUS*** T/I/O = SI/0/NA. RD IA, RU Intergal and block valve w/ high temp gaskets. RD Companion 3/8/2019 IA, RU Intergal and block valve high temp gaskets. RDMO. ***Job Complete***. T/I = Vac/Vac. Temp = SI. WHPs (WIE Req). Dry hole tree and temporary scaffold installed. No well house or flowline. Integrals and block valves installed on IA. 3/15/2019 SV, MV = C. IA = OTG. 13:00 T/I = VACNAC. Temp = SI. WHPs (WIE Request). No wellhouse, AL or flowline. Dry hole tree. Temporary scaffolding installed. Integrals and block valves installed on IA. 4/2/2019 SV, MV = C. IA = QTG. 22:00 ***WELL S/I ON ARRIVAL*** (Plug and Abandonment) HES RELAY UNIT #46 SPOT EQUIPMENTAND BEGIN RIGGING UP. 4/8/2019 ***JOB CONTINUED ON 09 -APR -2019*** Daily Report of Well Operations 01-02 ***JOB CONTINUED FROM 08 -APR -2019*** (Plug and Abandonment) HES RELAY UNIT #46 SET 4-1/2" WHIDDON CATCHER @ 8739' SLM SET BK-DGLV @ 8309' MD. PT TBG TO 1000 PSI. PULLED 4-1/2" WHIDDON CATCHER @ 8739' SLM PUNCH TBG 8395'- 8400' MD W/ 2", 4 SPF, 60 DEG PHASE, TITAN 4C631 CHARGES (txia pressure response) ALL LOGS TIED INTO TUBING TALLY DATED 29 -SEP -2014. 4/9/2019 *** JOB COMPLETE ON 09 -APR -2019*** SLB Fullbore Pumping Crew Job Scope: Plug and Abandonment (place lateral cement plug in TBG and IA). Pumped 5 bbls 60/40 to verify flow path down the TBG taking returns from the IA OTT. Pumped 5 bbls FW spacer, 47.3 bbls 15.8 ppg Class G cement and 2 bbls FW spacer. Launched 7" foam wiper ball down TBG. Displacedwith NaCl and 10 bbls 60/40. U -tubed TxIA to FP IA. ***AWGRS continued on 04/15/19*** 15.8 ppg Class G cement in TAA Est. TOC in TBG and IA @ 7,000' MD / 6,573' TVD 4/14/2019 Est. BOC in TBG and IA @ 8,400' MD / 7,844' TVD SLB Fullbore Pumping Crew Job Scope: Plug and Abandonment (place lateral cement plug in TBG and IA). ***AWGRS Continued from 04-14-19*** 4/15/2019 Washed up choke trailer, flushed surface lines, washed up cementing van, manifested T/I = VACNAC. Temp = SI. WHPs (WIE request, post P&A). Wellhouse & scaffold removed. Dryhole tree & temporary scaffold installed. 4/17/2019 SV, MV = C. IA, OA = OTG. 17:30 T/I = VACNAC. Temp = SI. WHPs (WIE request). Wellhouse & scaffold removed. Dryhole tree & temporary scaffold installed. 5/3/2019 SV, MV = C. IA = OTG. 02:50. ****WELL S/I UPON ARRIVAL**** (Plug &Abandonment) DRIFTED W/ 2.25" CENT, S -BAILER TO TOC @ 6,894' SLM (Sample cement, 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) 5/4/2019 ****DSO NOTIFIED OF STATUS UPON DEPARTURE**** T/I/=vac/vac Temp=Sl (LRS Unit 76 -Assist Slickline: AOGCC CMIT-TxIA) AOGCC CMIT Tx IA PASSED @ 2688/2671 psi Per AOGCC Criteria (State witness by Bob Noble). Target=2500 psi Max applied 2750 psi Pumped 4.8 bbls of 25* 60/40 down TBG with 1/2 jumper to IA to get test pressures of 2712/2719 psi. 1st 15 min T/IA lost 14/26 psi. 2nd 15 min T/IA lost 10/22 psi for a total loss of 24/48 psi in 30 min. CMIT-T/IA Passed @ 2683/2666 psi (Per BP Criteria). Pressured up T/IA to 2709/2719 psi w/.05 bbls 60/40. 1 st 15 min T/IA lost 9/20 psi. 2nd 15 min T/IA lost 9/17 psi. 3rd 15 min T/IA lost 8/16 psi for a total loss of 26/53 psi in 45 min test. Bled pressures to 30/30 psi and recovered — 3 bbls. Slickline in control of well upon departure. 5/4/2019 Final Whp's=30/30 LJKY t4JLt ,D= GW MR= RINMED V= 73.0' 30' NSU A -110 444 3400' CONDUCTOR 3D' Q 4100'20' CSG94 #, = 9497 H-40, D =19.124' D= 8800'SS TOP OF 7- SCAB LNR 2286' CSG, 47#. L-80 VAM TOP, ID= 8.681' 2429' 9-5/8' BOWED CSG PATCH. D = 9.08' 2433' 13-3V CSG, 7211t, N -80,D =12.347 3004' Minimum ID = 2.992" @ 9046' 4-1/2" G LANDING SUB 9-518' CSG, 40.5#, SOO-95, D = 8.835' 6184' XO TO 43.5#. SOO-95. D = 8.755' TBG, 12.6#, 13CR-85 VAMTOP, 879W bpf, D = 3.958' KIERVAL Opn/Sgz SHOT SOZ 9-5/8' CSG, 43.5# XO TO 8801' 9360 - 9370 S 47#, SOO-95. D = 8.681' WA 0383 bpf, D = 6276' TBG, 12.69, L-80 TCI, .0152bpf, K)=3.958- 8960' TOPOF3-12•SCAB LNR 8048' 4-12' TW NPC, 12.60, W80, 9120' .0152 bpf, D = 3.958' PERFORATION SLWARY REF LOG: BHCS ON 02/20x70 ANGLE AT TOP PERF. 23-@9661- 3"@9661'Note: Refer to Production DB for historical perf data Note: SIZE SPF KIERVAL Opn/Sgz SHOT SOZ WA 4 9360 - 9370 S 02271/0 03/071/0 WA 4 9430-9440 S 02/27!70 03/07/70 4' 4 9455-9485 S 03/09(70 10/12/85 4' 4 9495-9525 S 0388770 10/12(65 4' 4 9545- 9575 S 03109770 10112185 4' 4 9585-9616 S 03109n0 10/12185 4- 4 9627 -9675 S 10/1885 05116/87 4' 4 9660 - 9674 S 10/1885 052687 3-3/8' 4 9661-9675 O 08/1080 4' 4 9690-9708 S 0627/87 08/06/90 3-3/8' 4 9691 -9709 0 08/10190 3-12' SCAB LNR 9.3#, L-80 FL4S, 1-t_ 96'10• .0087 bpf, D = 2.992' 9-5/8' CSG, 47#, SOO-95, .0733 bpf, D = 8.681' 9878' 01-02 SAFETY NOTES: •••4-1/2" CHROME TBQ •• 30', 20',13-3/8' CUT BELOWGRADE(10/04/14)Tr;6; 4-12'OTIBXNP,D= 3.813'9-5/8• X 7' BKR ZXP UP w / BKR FLEKLOCK M LNR HGR D = 6200' _ nerueunom c ST MD ND DEV TYPE I VLV I LATCH I PORT DATE 3 3798 3778 23 KBG2 DOME BK 16 0926/15 2 727e 6821 26 KBG2 DOME BK 16 0926115 1 8309 7780 22 KBG2 DMY BK 0 04/09/19 68W-8400' -I CMT TXW (04/14/19) SL TAGGED TOC 5/4/19 8386' 4-12' OTIS X NP, D= 3.813' 8386'-8400' TBG PUNCH w2'4 SPF(04/09119) 8418'7• X 4-i2' HES TNT RCR D = 3.856' $463' 4-12' OTIS X NP, D = 3.813' 8773' 4-12' OTIS XN NP. D = 3.725' 6798• jy4-12'WLUi,U=3.9S6- 8813' 9-58' X 7 BKR HRDE ZXPN LTP w /BKR HMC LNR HGR D = 6.20' 8822' PORTED SEAL STEN, D = 6.180' 8876' 7' X 4-12' X0. D = 6.276' 8960' -14-1/7 MLLESHOE, ID= 3.958' 8964' 9-5/8• X 5-12' BKRSAB PICK X 4-1/2• XO. D 9056' -14-12' OTIS XN NO-GO NP, D=3.725' 9120' 4-12• WLEG, D=3.958• BEHIND 99111 ELMD Tr LOGGED 05/14/80 LNR 1 PBTD H 9817' 0321177 1WNN 26 1 RWO 08/16/17 RIFVJMD 9-5/8' NOT CUr BELOW GRADE 10119194 SCAB LINER 0226119 KP/JMD DRY HOLETRE£ 1GIM14 D-14 IRM 0420/19 S/J TBG PUNCH & GLVS (04/09/19) 10/13(14 Cr/JMD I FNALODEAPPROVAL 0420/19 JUJIVD- TMA CEVIENT PLUG (04/14/19) II06/07(171"JJMDISEr PXN PLUG (06/02/17) 1105/06/191JNJJMDjADD BF& UPDATED SL TAGGED TOC GRAPPLE (0524/14) PRIM -DE BAY LUT WEL. 01-02 PEFW No: '1691190 APINo: 50-029-20053-00 SEC 8, Tl OR R1 5E 193' FNL & 1357' FWL BP Exploration (Alaska) MEMORANDUM TO: Jim Regg 1 �` SI (4- (9 P.I. Supervisor 6 FROM: Bob Noble Petroleum Inspector State of Alaska Alaska Oil and Gas Conservation Commission DATE: May 4, 2019 SUBJECT: Well Bore Plug & Abandonment PBU 01-02 BPXA PTD 1691190, Sundry 319-031 Section: 8 Township: 10N Range: 15E Meridian: Umiat - Drilling Rig: NA Rig Elevation: NA Total Depth: 9930 ft MD Lease No.: ADL 0028329 Operator Rep: Eric Dickerman Suspend: P&A: X Casing/Tubing Data (depths are MD): Casing Removal: Conductor: 30" O.D. Shoe@ 110 - Feet Csg Cut@ Feet Surface: 20" O.D. Shoe@ 696 - Feet Csg Cut@ Feet Intermediate: 13 3/8" O.D. Shoe@ 3004 Feet Csg Cut@ Feet Production: 9 5/8" O.D. Shoe@ 9878 Feet Csg Cut@ Feet Liner: 3 1/2" O.D. Shoe@ 9620 Feet Csg Cut@ Feet Tubing: 5 1/2" x 4 1/2" O.D. Tail@ 9120 Feet Tbg Cut@ Feet Plugging Data: Type Plug Founded on Depth Btm Depth To MW Above Verified Perforation Balanced 8400 ft MD - 6894 ft MD- 9.8 ppg Wireline tag Test Data: Initial 15 min 30 min 45 min Result Tubing 2728 2693 2671 2655 - IA 2738 2679 2638 2609 P OA Initial 15 min 30 min 45 min Result Tubing IA OA Remarks Attachments: AbK(!, rev. 11-28-18 2019-0504_Plug_Verification_PBU_01-02_bn v MEMORANDUM TO: Jim Regg�j �Zblj`j P.I. Supervisor FROM: Brian Bixby Petroleum Inspector State of Alaska Alaska Oil and Gas Conservation Commission DATE: March 7th 2019 SUBJECT: Well Bore Plug & Abandonment PBU 01-02 BP Exploration Alaska - PTD 1691190; Sundry 319-031 Section: 8 Township: 10N Range: 15E Drilling Rig: NA Rig Elevation: NA Total Depth: 9275 ft MD Operator Rep: Leighton Grey Suspend: Casing/Tubing Data (depths are MD) Conductor: 30" - O.D. Shoe@ Surface: 20" . O.D. Shoe@ Intermediate: 13 3/8" - O.D. Shoe@ Production: 9 5/8" - O.D. Shoe@ Liner: 7' x 3 1/2" -O.D. Shoe@ Tubing: 51/2"x41/2" O.D. Tail@ Plugging Data Test Data: 17 Feet 696 Feet 3004 Feet 9227 Feet 9620 Feet 9120 Feet Meridian: Umiat ' Lease No.: ADL 028329 V1- j Casing Removal: Csg Cut@ Feet Csg Cut@ Feet Csg Cut@ Feet Csg Cut@ Feet Csg Cut@ Feet Tbg Cut@ Feet TvDe Pluq Founded on Depth Btm Depth To MW Above Verified Tubing 8745 ft MID " Wireline tag inai.i 1F min in min 4S min Result Tubing 2508 2474 2454 - 2437 IA 2494 2460 2439 - 2421 P OA NA NA NA NA Initial 15 min 30 min 45 min Result Tubing IA OA Remarks: witnessed the tag if the existing slickline plug; found at 8745 ft MD (slickline measurement). I then witnessed the CMIT TAX Gas lift valve was pulled in lower station to pressure up both the tubing and IA for combination test. 2.63 bbls pumped in for test; 2.4 bbls returned. OA is cemented to surface. Attachments: none rev. 11-28-18 2019-0307_Plug_Verification_PBU_01-02_bb THE STATE °fALASKA GOVERNOR MIKE DUNLEAVY Beau Obrigewitch Well Integrity Engineer BP Exploration (Alaska), Inc. PO Box 196612 Anchorage, AK 99519-6612 Re: Prudhoe Bay Field, Prudhoe Bay Oil Pool, PBU 01-02 Permit to Drill Number: 169-119 Sundry Number: 319-031 Dear Mr. Obrigewitch: Alaska Oil and Gas Conservation Commission 333 West Seventh Avenue Anchorage, Alaska 99501-3572 Main: 907.279.1433 Fax: 907.276.7542 www.00gcc.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, C71 Daniel T. Seamount, Jr. Commissioner DATED this Sday 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 1. Type of Request Abandon 0 • Plug Perforations ❑ Fracture Stimulate ❑ Repair Well ❑ Operations shutdown ❑ Suspend ❑ Perforate ❑ Other Stimulate ❑ Pull Tubing ❑ Change Approved Program ❑ Plug for Redrill ❑ Perforate New Pool ❑ Re-enter Susp Well ❑ Alter Casing ❑ Other 0 2. Operator Name: BP Exploration (Alaska), Inc 4. Current Well Class: Exploratory ❑ Development 0 5. Permit to Drill Number. 169-119 ' 3, Address: P.O. Box 196612 Anchorage, AK ' 99519-6612 Stretigrephic ❑ Service ❑ 6. API Number: 50-029-20053-00-00 7. If perforating: B. Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? Wil planned perforations require a spacing exception? Yes ❑ No 0 PBU Ot-02 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): 9930 9275 8773 8195 8773 9623 Casing Length Sin MD TVD Buret Collapse Conductor 80 30" 37-117 37-117 880 Surface 659 20" 36-696 36-696 1530 520 Intermediate 2970 13-3/8" 34-3004 34-3004 5380 2670 Production 9846 9-5/8" 32-9878 32-9227 6870/8150/6820 4760/6080/3330 Scab Liner 6674 7" x 4-1/2" 2286-8960 2288-8372 7240 / 8430 5410/7500 Scab Liner 574 3-1/2" 9046-9620 1 8454-8991 1 10160 10530 Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): 9661 - 9709 9029 - 9073 -1/2" 12 BP / 5-1/2" 171x41/2" 12. 13Cr80 / MN -80 30 - 8798 / 8961 - 9120 Packers and SSSV Type: 41/2" HES TNT Packer Packets and SSSV MD (ft) and TVD (ft): 8418/7861 5-4/2" Baker SAB Packer 8984/8395 12. Attachments: Proposal Summary 0 Wellbore Schematic ® 13. Well Class after proposed work: Detailed Operations Program ❑ BOP Sketch ❑ Exploratory ❑ Stratigraphic ❑ Development 0 Service ❑ 14. Estimated Date for Commencing Operations. February 15, 2019 15, Well Status after proposed work: Oil ❑ WNJ ❑ WDSPL ❑ Suspended ❑ 16. Verbal Approval: Date: GAS ❑ WAG ❑ GSTOR ❑ SPLUG ❑ Commission Representative: GINJ ❑ OD Shutdown ❑ Abandoned 0 17. 1 hereby certify that the foregoing is true and the procedure approved herein will not Contact Name. Obngewitch, Beau be deviated from without prior written approval. Contact Email: BEAU.OBRIGEWITCHC%bp.cem Authorized Name: Obrigewitch, Beau Contact Phone: +1 907 564 4854 Authorized Title: Well Integrity gineer Authorized Signature: Date: 1/7,q Oq COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number Plug Integrity ❑ BOP Test ❑ Mechanical Integrity Test fY Location Clearance Other: �n-. -a O—$ 1 Post Initial Injection MIT Req'd? Yes ❑ No O Spacing Exception Required? Yes ❑ No ,W-! Subsequent Form Required: �� -07 APPROVED BVTHE Approved by: COMMISSIONER COMMISSION Date: �)�� ORIGINAL Re�MS01 FEB 0 5 2019 rlaR"� Submit Form and Form 10403 Revised 04/2017 Approved application is valid for 12 months from the date of approval.�hments in Duplicate o�'i��/ / 7- ie, - /H by 01-02 Full Plug and Abandon Intervention Engineer Beau Obrigewitch (907) 564-4854 Production Engineer Finn Oestgaard (907) 564-5026 Expected start date: February 1511, 2019 History 01-02 was completed with a Gen 1 Permafrost—Wsllhead and three string casing design in 1969. The outer casing -string is set inDermafrost. GWO has determined wells of this construction 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 HSE 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. Job Steps 1 S a. Pull DGLV from STA # 1 b. Tag existing plug and CMIT-TxIA; Requires AOGCC Witness Notification c. Punch Tubi 2 F Assist Slicklin . a. Surfactant Wash IA and Tbg b. Circ well to 9.8 ppg brine c. CMIT-TxIA to 2,200psi; Re uires AOGCC Witness Notificati 3 V Drop annulus gate valves and install integrals 4 J Cement IA and Tbg Surface to Surface 5 D Bleed WHPs to 0; Monitor after 24 hrs 6 J Cut off Wellhead; Install marker Plate; Requires AOGCC Witness Notification Procedural steps Slickline / Fullbore 1. Pull DGLV from Sta #1 2. Surfactant Wash IA and Tubing, Circ to 9.8 ppg Brine; Injectivity test down Tubing and up IA per the following pump schedule: • 75 bbls hot surfactant wash (180°F FW + 2 gal/mgal of F103 and 2 gal/mgal of U067) • 400 bbls 9.8 ppg brine. 9.8 ppg brine is freeze protected to -5°F. U-tube some methanol to prevent ice plugs at surface. Note: The calculated volume is 364 bbls. Pump additional as needed to confirm a good sweep. Verification of a good sweep is accomplished by one of the following two methods, at WSL discretion: • Rig up to take returns through a micro -motion to check density • Lead with an appropriately -sized pill (-10-20 bbls) of dyed brine 3. Tag existing PXN Plug at 8,773' MD 4. CMIT-TxIA to 2,200 psi Note: Both the tag and the CMIT-TxIA require minimum 24 -hr AOGCC witness notification) Hold Point: If CMIT-TxIA fails, contact Beau Obrigewitch at (907) 564-4854 (o) or (907) 952-6271 (c). 5. If CMIT-TxIA Passes: Punch 4-1/2" tubing just above packer, at - 8,400' MD, tag plug at 8,773' for deth control. se 5' tubing punch as recommended by tubing p rich supplier and verified by WSL. Volume Calculations - 9.8 Circ and Surface -to -Surface Cement 9-5/8" x 4-1/2" volume from 2,286' MD to Surface 0.0535 b f 122 bbls 7" x 4-1/2" volume from 8,400' MD to 2,286' MD 0.0186 b 114 bbls 4-1/2" volume from 8,400' MD to Surface 0.0152 b f 128 bbls Total Cased Hole Capacity See details for excess to um 364 bbls Valve Shop 6. Drop annulus gate valves and install integral valves. Fullbore / Special Projects — p.SS Lt -Cee ell C- t t--c-o ��I`P" ' �� e C 7. Circulate cement down the tubing, taking turns from the IA, cementing both tubing and IA from 8,400 to surface, at 5bpm per the following pump schedule: • 5 bbls neat Meth or 60/40, at WSL discretion • 5 bbl FW spacer • 380 bbls Class G cement per design 8. Cement returns should be at surface @ -364 bbls of cement away. Continue pumping cement until clean cement returns are noted, approximately 10-15 bbls. The top of cement in the IA and tubing will be at surface. 9. At WSL discretion, inject a small amount of N2 across the wellhead in an attempt to remove some cement, increasing the chance of opening the valves and providing a monitorable space to check for pressure prior to cutting the wellhead off. Recording Requirements: Note the recording requirements in SOP: Through -Tubing Abandonment, Section 5.9. Note, this document may become an RP by the time this job is executed. Cement Design - Mix on the FIV Cement Type / Weight Class G 15.8 ppg mixed on the fly Field blend to by equal to lab +/- 0.1 ppg Slurry Temperature 800 to 110° F Fluid Loss 40-200cc 20-100 cc/30 min Compressive Strength 2000 psi in 48 hrs Thickening Time Minimum 5 hours Cement Thickening Time Activity Time hours Shearing time, quality control, PJSM 0 Cement displacement -380 bbls @ 5 bpm) 2 Safety 3 Minimum required thickening time: 5 DHD 10. Bleed tubing and IA pressures and monitor after a minimum of 24 hours.. Special Projects � " �a JOC_ o�1 )1 4 S 11. Excavate and Cut off all casings and wellhead 3' below original tundra level. Top job all annuli and tubulars with cement as needed. Install marker cap on outermost casing string. Provide a minimum of 24 hours notice to AOGCC Inspector of the timing of the cut. Photo document the condition of the tubular stub immediately after cutting the wellhead, after topping off with cement (if necessary), and after installing the marker plate. • Marker Plate to meet requirements in SOP: Through -Tubing Abandoment, Section 5.8: i. Minimum %" Thick ii. Minimum 18" Diameter • Bead weld to the marker plate the following information: BP Exploration Alaska, Inc. PTD: 169-119 Well: PBU 01-02 API: 50-029-20053-00 9 IW [ roti UELUAFAD= CN/ 30" bSULA1R) A,,-MTOR= BAKH2C O(B. 9.EV = 73.0 BE ELEV = 7 KOP= 3400 COtDl1CfOR Kx Angle = 30• @ 4100 70" M, 94 4, H40, D = 19.124" 4tum M)_ -_ 9497 ...... TOPr 7'SCAB LNR I;. /,a /wan, n=17147- I--1 3 Lim ID = 2.992" 0 9048' G LANDING SUB 40.59.50695, D = 6.83571-4 ', SOO 95, D = 8.755' /L' IM -k IZW, 14GKIWVAM 52 bp', D= 3 958- 471, 50695, IT= 8 681" T SG18 LNK 280, L-80 VAM TOP IC, 0383 bpf, D• 8276- a VT TBG, 12.6#. L -SO TCL .0152bpf, D =3.958" 01-02 Current Status 8811' I TIOPOF 3-112^ SCAB LNR 8048' 4-12= IBGN'C, 1260. M4807 9120' 0152 bpf, D = 3.958^ iHfORATICN SUI"RY Rrr LOG: BHM C01022WO AMGLEATTCP PERF 23.09661' Nob: fetor b Roducbm DB for listmal port data SIZE SPF 941BNAL I OpnGw StDT SOZ WA 4 9300-9370 S 0=717003)07nD 1OWW711 614 RINO WA 4 9430-94W S 02/27110 0MMO 4" 4 9455-9485 S MKIWO 10112185 4• 4 9495-9525 S 0300970 10112185 4- 4 0616 %7 6 03AW70 1"2/85 4' 4 9595-9616 S 03AWO IQf12M5 4' 4 9627-9975 S 1011885 OMB87 4" 4 9660-9674 S 10/1&850526!87 3-318' 4 9601 -9675 O 01111090 4" 4 9690-9708 S 06!27187 0810690 318' 4 9691 -97091 O 0610890 31/2- SCAB LW 93 .0087 bFf, D- 2992= 9-518" CSG, 470, 50695, 0733 kP CHROMETW- 1' Xr, 20',13-L6' CUf BELOW GR40E I tOAU14) Top DPZ 1/BPRF — 21000' Base DPZ 1— 71044' 8388' H4-1/2"OTS X NP. D• 3.013'1 8418' 7•X4.11T STHipKR,D-_1- • 0463' 4-12"1TfF % HP, 6.401 t• 973' 4-1/2"OTB XM rP.D=3.725 8718' -4-112• PXN PLUG (f18AQlf7) 6790' 4-1rrwL�c,o=396e 8813• 9-WX7'BXRHRDEZXPNLTPxif3KR4K LNR LGRD=820" = 6.160' El D = 4.75 8990' M1/2"MAESWX10=3958- { 8984• H9-518^xs1rr13foxsAar4oz, D= JG-YW MLLOLT EXTENSION, D 0.3/8" X 4112' XO, D = 3 956" 9p4g� 4-112" O LANONG SLB, D = 2992" Top DPZ 3 — 9,199' GATE BEV BY OOM MEIM DOTE IV BY COMARM farlwo Maf4Df 1141fALcomm RON fWZW14 WJMD W4DRSC16A471CFM 0300 RWN29 RWO OWN15 SWUM GLV CIO(OMA1151 10119)94 SCA8L88t 024116 LTIJLD TTTffC+O(IOI14)14) 1OWW711 614 RINO 60711' "JM)SEI PAR PLUG 060J17) 10113114 OVAD FNAL ODE AFFROVAL 072511'RIW318' JLD 30", 20', 13 8 9-68" ODRHEC K 1021/14 JLSIMID GLV 6-70 (10114114) ,06161'R1WJW 9-58'NDT CUi 6B.CAH GRAtF PRIDHOE BAY UNT VVELL: 01-02 PE30L NO: '1691190 AR No: 50029-2005100 LSEC$ ,, r10µ Po 5E 193' F7181357' i1AL 6 1 BPExploration(Alaska) 4 D= CINI R= BAKERC J = 730' 91' ILII n THi ODMAMOR Top 13-3/8" Cement 2408' am SS - roPOF 7- SCAB LM z 54518' Top 9-5/8" Cement (ECP) 2408' 1411R'r.gn. 77#. NNn. in = 17 'dr– Mlnl mum 00 ;1992" @ 9046' 4-112" G LANDING SUB 9-518" CSG, 10.51, 500-95, D = 8835' NO TO 43.5#, SOO-95, D = 8.755• Top 9-5/8" Cement (CBL) 7400' Tubing Punch - 8400' 4.1/T TBG 12.6#, 13CR-86 VAM TOP, .0152 9pf, D = 3.958• 9.51 43.5# XO TO 470,8=95 , D= 8 581. ' T SCA3 LFR, i0p, L-80 VAN TOP H^_ 01-02 Proposed P&A �MNOTES: '-4-12"CHROME TT3 " ,• Sa•, za',13-3118' CUT M1oW 0383 Epf, 0- 6276' - 14 VT TBG, 12.6#. L-80 Tp, .0152opf. D = 3.956' 8160' iOPOF 312' SGB LN2 —C 4-112' TBGN'C, 12.6#, iN"W. 9126' .DI52 bp1, D = 3.956• PEff ATIONS1MIRRY REF LOG- 13HCS (IN 022070 ANGLEAT TOP FEW. 23- 0 9661' 4oh: Hafer b Roduction OB 'or Wbricalparl dab SIZE SPF NTHZVAL OpffSqz SHOT SO2 NA 4 MOD -9370 S 0227/70 03/07!70 NA 4 9430-9400 S 02127/70 03)07170 4• 4 9455-9485 S 031097/0 10/12!65 A. 4 9495-9525 S 03AWO 10/12/85 a• 4 owe; 0629 a 03ro 0 /wlm 4' 4 9585-9616 S 039WO 10/12/85 0 4 9627-9675 S 1&16185 D528f67 0 4 9660.9674 S 1011845 0526781 3-3/8• 4 %61-%75 O 0/8110190 4' 4 9690-9708 S 0627187 ORM&W 3 -VW 4 9691-9709 O 0&1Dl9O 3.97 SCAB LFR 9.30, L -W FL45, .DO87 W. D = 2.997 9 -SB' CSG,47#, S0095, .073: 'MCF' I -A Ili •r1RSXNPns161M' Top DPZ 1/BPRF - 2,000' - t' 1• r-� •r_ �� 677$–1412.OTBXN IW ID=3.125" 6775'j4-1/2'PXNPLUG(0602/lij — 6766 4-1171M -G. D = 3 9518' 6813' 9-518'X T BAR HRDE ZXFV L7P LMR HGR D=620' 9622' Hp&R SEAL STB/ D = 6.180' 8950' H5-7? B0T FBH.ASSY, D=4.75' 8980' 4-12'MJLe3HCE O=3.956' 6164' .75- 9-516' X 51/7 SKR SAB ACK D= 4.75- 1011/9 5 BLINER 2124!16 OIYJ,O TRE C10 (10114H4J 6-5/8'ML-OL1f EXTEi�&DN, D=__ 6-549- ML-OUT 6 -016'X4 -12'X0. D=3.956' 8046 4-1rT G [ANONGSL0, D=299T Top DPZ 3 - 91199' 5 PRUDME BAY UW W13L: 01-02 PERWM):'1694190 AR Ib: 50-029-2M5300 SACS, T10R R15E 193' FN. 6 135T FIAL DATE AV UY OOkSOM &ATE REV BY I CON AWS 63p18R4 f4FR424 1N77AI. COY�L[flON 142/YN 1RJ.0 MFDRSCHEl^TC69R5 03121(710902&15 24 RWO 09!20115 J GLV CJO(09128r15) 1011/9 5 BLINER 2124!16 OIYJ,O TRE C10 (10114H4J 10AIW 4 614 RWO 07117WSET PXN FUIG (0610211) 10113114 CKIJM7 R44L OOEAPPROVAL 07J2507 RIWJD30-.20'. 13918'89.518•COf51FCTKM ICY21114 JLS/JKD GLV 40110/14114) 0111116117 RIWJMIS-50- NDT OJT 8El.OW BRAOF BP Exploration IAlaskal 5 Rixse, Melvin G (DOA) From: Obrigewitch, Beau <BEAU.OBRIGEWITCH@bp.com> Sent: Tuesday, February 5, 2019 2:09 PM To: Rixse, Melvin G (DOA) Cc: Schwartz, Guy L (DOA) Subject: RE: PTD 169-119, Sundry 319-031, PBU 01-02 P&A Sundry Mel, Thank you for raising this concern. It is no problem for us to reset the DGLV in STA #1 at 8,309' prior to pumping cement, to ensure the cement will go through the tubing punches at 8,400'. Our preference would be to do this immediately after we punch the tubing. Kind regards, Beau From: Rixse, Melvin G (DOA) <melvin.rixse@alaska.gov> Sent: Tuesday, February 5, 2019 11:15 AM To: Obrigewitch, Beau <BEAU.OBRIGEWITCH@bp.com> Cc: Schwartz, Guy L (DOA) <guy.schwartz@alaska.gov> Subject: RE: PTD 169-119, Sundry 319-031, PBU 01-02 P&A Sundry Beau, If you don't reset your DMY GLV you are likely to have a very poor flow path above your packer through your perfs. That is where all the settlement of solids will have accumulated over the years since that 7" scab was run. You are already 799'MD above the Ivishak with your cement. If there was no risk of wellhead movement I would be asking you to pull the plug and cement across the Ivishak. I don't want to add another 91' distance above the reservoir for permanent isolation. Mel Rixse Senior Petroleum Engineer (PE) Alaska Oil and Gas Conservation Commission 907-793-1231 Office 907-223-3605 Cell 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 Mel Rixse at (907-793-1231) or (Melvin.Rixse(dalaska.govI. cc. Guy Schwartz From: Obrigewitch, Beau <BEAU.OBRIGEWITCH@bp.com> Sent: Tuesday, February 5, 2019 10:12 AM To: Rixse, Melvin G (DOA) <melvin.rixse@alaska.Rov> Subject: RE: PTD 169-119, Sundry 319-031, PBU 01-02 P&A Sundry L 3 A Q P�;o1 a assn /7 z�zq' 70'V,\ o.')e�I 'In �v � 13Y+ X14 -- 12'L=37o /029. c9,n(�6 TOC 7C-cO 3 Ss�z x8773 = 133.5-6615 �ez9 y va' ` 1)P�3 WI -0 - ioL ZZ8'6�m p 5-7 COL, t3 yfr� i2 -.3y7 — To 3 mac)( c aCS�Z n Po��e�0GL�1 A ' p1�9 x773',"6 IN57 RUCTIONS: This form is use{ during drilling or workove. operas: onstcstiag, coring, or pe:`oroting, too, fc: .0 tion n sme in describing work perform;d. Number all drill stem tests sequentially. Attzch description of all corer. 'i'ork per- formed by ?rodueing Section wil. be reported on "INTERIM" sheets until final Completion. Report official or roprece.:tatwve test on i'INAL" form. (1) Submit" INTERIM" sheets when filled out but not less frequently than every 30 Guys, or (2)or, `oedacs of the week in which oil string is set. Submit weekly for workovers anc io:lowing setting of oil string until completion. DAILY WELL HISTORY - Ire LRI:4 District Alaska County or Parish North Slope State Field Alaska ase or Unit T)S g]{;Zp P-� S -7- 4rei1 \o._ Date & Depth Complete Record for each Da While Drilling n at 8:00 A. M. p Y or V�orl:over In rogress 2-24-70 (0') - Standing cmtd. 9930' 2-21-70= Circ @ 9930 for logs. Ran Schl DIL, FDC -GR, BHC -GR 9930-3004'. Ran PML Sonde to 9930', tool would not completely open. POH. Survey: 9930' 24-3/40 VD9280 N86W 5868.03 W2644.99. 2-22-70= RD Schl. RIH w/12-1/4" bit to 99301, circ & mond mud 5 hrs. Had viscus mud off btm. POH. Reran Schl PML 9930-8800', normal curve, did not record, changed tools & ran PML OK. RD Schl. Instld 9-5/8" csg ra-ns. Pulled 13-3/8" bowl protector. 2-23-70= Remvd flow nipple. Retrieved 13-3/8" bowl protector. 9-5/8" csg @9877' Ran 25 its (1076') 9-5/8" 47# Soo -95 buttress incl Hail float shoe & diff clr, 63 its (2617') 43.5# Soo -95 buttress incl Halli DV cir, 140 its (6069') 40# Soo -95 Buttress-,& 2 its (87') 47# Soo -95 Buttress on Rockwell Boll Weevil hgr; Inded csg on hgr @ 25' KB, shoe @ 9877' (wt of csg on Hook 290-350,000#), Diff clr @ 9788' DV stage clr @ 6392'. Start circ @ 6:00 AM. Lost 150 bbls mud after est circ, slowed pmp down, had full returns. Circ. ,v-ZC6 2-24-70= Cmtd 9-5/8° csg @9877' in 2 stages. 1st stage w/1000 sx Class "G" premixed w/.2� D13. Slur 116#. Dry cmt -4° Slurry 5 Water 7 i mixing time 45 min. Displ w/73 bbls mud in 77 min (60 bbls w/Dowell bal w/rig pmp). Bmpd plug w/2500 psi; float held OK. CIP @ 3:00 PM --2-23-70. '` Lost 18 bbls mud after displ,400 bbls mud. Had good circ after losing -� /5 y 18 bbls. Opnd DV stage cir @ 6_3922' w/800 psi. Circ freely 3 hrs. Had wall cake but no returns. 2nd stage: Mixed 800 sx Class "G" premixed fr/7 w/107 gel 104# Slurry. Dry cmt -50, Slurry 700, Mix wtr 880. Mixing time 75 min. Displ w/485 bbls mud in 55 'min w/rig pmp. Closed DF clr �- Y w/2500 -151. CIP @ 9:35 PM 2-23-70. Instld Rockwell 9-5/8" x 13-3/8" pack- iG2� � Tstd w/5000 psi for 20 min -OK. Instld 5" rams. LDHWDP & sq stabilizers. 2-25-70 POH MW 79#, vis 4o, WL 7.5. TD 9930' Tstd CSO, DP rams & kill manifold w/5000 psi -OK. Tstd Hydril w/3000 PBD 9787' psi -OK. Measured in hole w/8-1/2" bit on 180' HWDP to 6389'. Tstd csg W/1500 psi -OK. DO DV cir @ 6392. RI CO firm cmt 9035-9787'. (Bit dropped wt @ 9750'). Will measure out. 2-26-70 Mixing Mud MW 82#, Vis 39, WL 6.9, Oil 1% TD 9930' Ran G -R CBL -CCL 9817 - 9100'. Good Cmt. Bond. 1st stage cmt top @ 7400' PBD 9817' with probable contaminated cmt @ 6392' 2nd stage cmt top @ 1550'. Mixing Invermul slug. 2-27-70 Preparing to pull Otis Plug. TD 9930' Msrd in hole w/DP. Corrected PBD 30' from 9787'_ to 9817'. Spot 50 bbl 82rf PBD 9817 -Invermul slug 9200-9500'. Perforated w/4 1/2" jet shts per ft 9360-9370' 9430-9440'._ RIH w/permeability tst asserd'o y. Set top p r rl D.cr @ 9401'. Seated Otis plug in "N" nipple at 9408'. Opnd Otis sliding sleev (s1 Q�IQ'- • • Wallace, Chris D (DOA) From: AK, D&C Well Integrity Coordinator <AKDCWellIntegrityCoordinator@bp.com> Sent: Thursday, September 10, 2015 9:05 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 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; Pettus, Whitney; Regg, James B (DOA) Subject: NOT OPERABLE: Producer 01-02 (PTD #1691190) Sustained Inner Annulus Casing Pressure over MOASP Attachments: Producer 01-02 (PTD# 1691190) TIO Plot.docx All, Producer 01-02 (PTD#1691190)was reported to have sustained inner annulus casing pressure above MOASP on September 7th, 2015.The pressures were confirmed to be TBG/IA 2510/2270 psi. A cold TIFL subsequently failed on September 8, 2015 indicating a lack of potential downhole barriers. A warm TIFL was attempted on September 10, 2015 but due to surface constraints the well had to be shut in. As the well is unavailable to be brought back online, the well has been reclassified as Not Operable until integrity can be verified or restored. Plan Forward: 1. Downhole Diagnostics: Cold TIFL- FAILED 09/08/15 2. Slickline: Change out gas lift valve, set tubing tail plug 3. Fullbore: MIT-T&CMIT-TxIA to verify integrity 4. Well Integrity Engineer:Additional diagnostics as needed A copy of the TIO plot has been included for reference. Please call with any questions or concerns. Thank you, Whitney Pettus SCANNED MAY 0 2 2016 (Alternate:Kevin Parks) BP Alaska-Well Integrity Coordinator G WIC Office: 907.659.5102 WIC Email: AKDCWellIntegrityCoordinator@BP.com 1 • • Producer 01-02(PTD#1691190) TIO Plot September 10,2015 w.,0101 - 00 t N 00A 0' - ,.. 0607,15 °MIS L00115 0614.15 099c15 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS RECEIVED NOV 0 3 2014 1. Operations Performed: ❑ Abandon ® Repair Well ❑ Plug Perforations ❑ Perforate ❑ Re -Enter Suspended Well ® Alter Casing ® Pull Tubing ❑ Stimulate - Frac ❑ Waiver ® Other ❑ Change Approved Program ❑ Operation Shutdown ❑ Stimulate - Other ❑ Time Extension Scab Liner 2. Operator Name: 4. Well Class Before Work: 5. Permit To Drill Number: BP Exploration (Alaska) Inc. ❑ Exploratory ❑ Stratigraphic ® Development ❑ Service 169-119 3. Address: 6. API Numbe P.O. Box 196612, Anchorage, Alaska 99519-6612 50-029-20053-00-00 7. Property Designation (Lease Number): 8. Well Name and Number: ADL 028329 PBU 01-02 9. Logs (list logs and submit electronic and printed data per 20AAC25.071): 10. Field / Pool(s): RBL Prudhoe Bay / Prudhoe Bay 11. Present well condition summary: Total depth: measured 9930' feet Plugs: (measured) None feet true vertical 9275' feet Junk: (measured) 9623' feet Effective depth: measured 9817' feet Packer: (measured) 8418'; 8984' feet true vertical 9172' feet Packer: (true vertical) 7861'; 8395 feet Casing Length Size MD TVD Burst Collapse Structural 110' 30" 110' 110' Conductor 696' 20" 696' 696' 1530 520 Surface 3004' 13-3/8" 3004' 3004' 4930 2670 Intermediate Production 9878' 9-5/8" 9878' 9227' Liner Scab Liner 6674' 7" x 4-1/2" 2286'- 8960' 8454'- 8991' 7240/8430 5410/7500 Scab Liner 574' 3-1/2" 9046'-9620' 8454'- 8991' 10160 10530 Perforation Depth: Measured Depth: 9661'- 9709' feet True Vertical Depth: 9029'- 9073' feet Tubing (size, grade, measured and true vertical depth):4-1/2", 12.6#; 13Cr85; 8798'; 8218'; 5-1/2", 17# x 4-1/2", 12.6# MN -80'" --"--8950'- 9120' 8363'-8524' Packers and SSSV (type, measured and true vertical depth): 7" x 4-1/2" HES TNT Packer; 8418'; 7861'; 9-5/8" x 5-1/2" Baker SAB Packer 8984' 8395' 12. Stimulation or cement squeeze summary: Intervals treated (measured): IAED JAN 6 S 2015 1 Treatment description including volumes used and final pressure: Push Fish (IBP, Piece of 5-1/2" Tool Grapple) to —9623'. Pull 5-1/2", 17#, MN -80 Tubing from 8961'. Cut and Pull 9-5/8", 40.5#, SOO-95 Casing from 2430'. Run 9-5/8", 47#, L-80 to 2433', cement w/ 165 Bbls Class 'G' (792 sx). Run 7", 26#, L-80 x 4-1/2", 12.6#, L-80 Scab Liner from 2286' to 8960', cement w/ 190 Bbls Class 'G' (912 sx). Run 4-1/2", 12.6#, 13Cr85 Tubing to 8798'. 13 Representative Daily Average Production or Injection Data Oil -Bbl Gas-Mcf Water -Bbl Casing Pressure Tubing Pressure Prior to well operation: 0 0 0 100 0 Subsequent to operation: 0 0 0 20 0 14. Attachments: ❑ Copies of Logs and Surveys run 15. Well Class after work: [IExploratory ElStratigraphic ® Development ElService ® Daily Report of Well Operations 16. Well Status after work: ® Oil El Gas ElWDSPL ® Well Schematic Diagram ❑ 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: Contact: Carolyn Kirchner, 564-4190 Email: Carolyn. Kirchner@bp.com 314-336 Printed Name: Joe Lastufka Title: Drilling Technologist Signature: ne: 564-4091 Date: 3 4 Form 10-404 Revised 10/2012 ubm' Ori incl OnI V-ry r 2/2�11� .+���/� RB is ROv - U 20 01-02, Well History (Pre -Rig Workover) Date Summary 05/25/14 RAN 1.74" LIB S/D @ 9125' SLM. IMPRESSION OF MISSING RETRIEVAL TOOL GRAPPLE. RAN 1.85" MAGNET. SKIP PAST 9125' SLM. STOP @ 9623' SLM. 06/14/14 INITIAL T/I/O = 0/0/100 PSI. RUN IN HOLE WITH TUBING PUNCHER TOOLSTRING. 06/15/14 CCL STOP DEPTH = 8883.4', CCL TO TOP SHOT = 8.6', TUBING PUNCH = 8892'- 8894'. GOOD INDICATION ON SURFACE. POOH. LRS LOAD IA AND TUBING. RIH WITH BAKER IBP. IBP DID NOT SET CORRECTLY, SHEARED OFF WHERE IT IS SUPPOSED TO AFTER PLUG SET. POOH. RIH WITH DRIFT TOOLSTRING. SET DOWN ON FOUR ATTEMPTS AT 3218', PULL 300 TO 400 LBS OVER EACH TIME, LET SET, AND FINALLY COMES FREE. UNBABLE TO GET PAST. POOH. RD. WELL SHUT IN UPON DEPARTURE. DSO NOTIFIED. 06/15/14 T/I/0= 4/6/180 OOA=O Temp= S/I Assist E -Line (RWO EXPENSE). Load and Kill. Pumped 3 bbls meth spear, 290 bbls 1% KCL, 2 bbls meth spacer, 110 bbls DSL down IA. Pumped 5 bbls meth spear, 290 bbls 1 %KCL, 3 bbls meth spacer, 60 bbls DSL down TBG. SEL in control of well upon LRS departure. FWHP= SSV/0/180/0. 06/16/14 PULLED 1.69" IBP FROM 3206' SLM.(ibp nose cone missing). 06/17/14 RAN 1.74" CENT & MAGNET TO 9,486' SLM.(no recovery). RAN 1.74" CENT & SAMPLE BAILER TO 9,642' SLM. HARD BOTTOM (no sample recovered). 06/18/14 RUN # 1 - RIH WITH POSISET PLUG. ATTEMPTED TO SET PLUG BUT NOT RESPONDING AS EXPECTED (UNABLE TO SET - FOUND COMPENSATING PISTON FOUND DUMPED. NO OIL IN TOOL. DECIDE TO TAKE TOOL BACK TO SHOP AND CHECK OUT) PLUG NOT SET. RUN# 2 - RIH WITH XFLOW TOOLSTRING - PERFORMED UP DOWN PASSES AND STOP COUNTS - SHOW NO FLUID MOVEMENT AT SETTING DEPTH. RUN# 3 - CURRENTLY RIH WITH 1-11/16" BAKER IBP. 06/19/14 RUN# 4 - RIH WITH 1-11/16" BAKER IBP - SET IBP @ 8928' MD MID ELEMENT (TOP SET @ 8923') (SPECS = 8.17' OAL / 1.188" FISH NECK / 1-11/16" MAX OD / TWO 5" ELEMENTS / ONE 1" STIFFNER RING). RUNS# 5,6 & 7 - RIH W/ 1.69" X 40' DUMP BAILER'S AND DUMPED CEMENT ON TOP OF IBP, PUTTING ESTIMATED TOP OF CEMENT @ 8913'. (TIED INTO TBG TALLY DATED 3/29/77). FINAL T/I/O = 0/0/120. WELL LEFT SI ON DEPARTURE. 06/21/14 T/1/0/00=VAC/VAC/185/0 TEMP=S1 CMIT-TxIA TO 1000 PSI *—PASS*** MIT -OA TO 2000 PSI ***PASS*** (POST CEMENT) Pumped 10 bbls of 42* Diesel down IA to load. Pumped 49 bbls of 40* Diesel down TBG to load. Made 3 attempts at CMIT-TxIA, first 2 attempts did not pass (see log) last one passed, Pumped 2.3 bbls of 40* diesel down TBG/IA to achieve CMIT-TxIA testing pressure of 1000 psi, 1 st 15 min TBG/IA lost 44/42 psi, 2nd 15 min TBG/IA lost 15/16 psi, TBG/IA lost total of 59/58 psi for 30 min test, CMIT-TxIA to 1000 psi **PASS**, bled back 2.5 bbls. Pumped 12.5 bbls of DSL down OA to achieve test pressure for MIT -OA to 2000 psi. 1 st 15 min OA lost 127 psi. 2nd 15 min OA lost 35 psi for a total loss of 162 psi in a 30 min test, **PASS**. Acquired small leak on lockdown clamp while bleeding OA, notified Pad -Op and Fullbore PE. FWHP=17/22/122/0 SV,WV,SSV=C MV=O IA,OA,OOA=OTG Tags hung on OA,IA,WV. 06/22/14 RUN#1: RIH WITH 2" TUBING PUNCH @ 3176'-3178'. RUN#2: RIH WITH 4" RCT AND CUT TUBING @ 3200. (TIED INTO LDL LOG DATED 10/5/2012). WELL LEFT SHUT-IN UPON DEPARTURE AND NOTIFIED DSO. Page 1 of 2 01-02, Well History (Pre -Rig Workover) Date Summary 07/12/14 T/1/0 SSV/0/0 Pressure tbg for BPV set. pump 1.5 bbls diesel down IA to pressure up tubing. FWHP 350/350/0 IA/OA open to guage. 07/24/14 T/I/O = SSV/120/40. Temp = SI. Eval cellar for spray in liner. Well is disconnected from system, Well House removed. Varified spray liner in cellar. SV, WV, SSV = C. MV = O. IA,OA = OTG. 16:20 hrs. 07/28/14 T/1/0 = SSV/100/50, Temp: SI, PPPOT-T (PASS) Pre RWO. PPPOT-T: Stung into test void, (450 psi) bled void to 0 psi. Functioned LDS, all moved freely. Torqued to 400 ft/lbs. Pumped through void, good returns. Pressured test vid to 5,000 psi for 30 minute test. Lost 50 psi in 15 minutes, lost 0 psi in second 15 minutes. (PASS) Bled void to 0 psi. 07/29/14 T/1/0=135/135/125. Pumped up pressure on tubing through IA to 250 psi. Set 5" FMC ISA BPV #539. Removed upper tree and installed temp valve #54. (dry hole tree). Torqued and Pt'd. (See log). Final T/1/0= BPV/250/125. 07/30/14 Bled OAP from 110 to 0 psi in 2 hours (1 bbl). OAP unchanged in 30 min. Bled IAP to bleed tank, from 100 to 0 psi in 1 hour. IAP unchanged. Job complete. FWHP's = BPV/0/0/0. SV, WV = C. SSV, MV = O. IA, OA, OOA = OTG. NOVP. 0230. 07/30/14 T/1/0/00 = BPV/100/110/0. Temp = SI. Bleed IAP & OAP to 0 psi (Pre Rig). No AL, Flowline or wellhouse. Temporary scafolding set up around well. Gravel pad built up arouond well for rig access. Bled OAP to slop tank. 07/31/14 T/1/0/00 = BPV/0/20/0. Temp = SI. WHP's (Pre Rig). No AL, flowline, WV, SSV or wellhouse. Integral flange on IA =inspection NC. Double valve on OA. Pad built up for rig. OAP increase 20 psi overnight. SV = C. MV = O. IA, OA, OOA = OTG. 1900. 08/01/14 T/1/0=0/0/30 Piggy back both IA and OA valves Temp vale # 57 on IA and Block valve on OA. verify VR Plug in OA. Page 2 of 2 ls�f•kh Am ►Ca ALA KA BP eT operation Summary�Repo ,:, F; Common Well Name: 01-02 AFE No Event Type: WORKOVER (WO) Start Date: 8/25/2014 End Date: X4 -0103J -E: (6,000,000.00) Project: Prudhoe Bay Site: PB DS 01 Rig Name/No.: DOYON 14 Spud Date/Time: 1/17/1970 12:00:OOAM Rig Release: 10/4/2014 Rig Contractor: DOYON DRILLING INC. UWI: 500292005300 Active datum: 4 : 02 1/17/1970 00:00 @73.00usft (above Mean Sea Level) Date From - To Hrs Task Code li NPT NPT Depth Phase Description of Operations (hr) -- (usft) -- - _ --- - - - - SKID RIG FLOOR. ---------- -- 8/25/2014 00:00 - 02:00 — 2.00 - MOB P PRE -PJSM. -PREPARE AND SKID RIG FLOOR TO MOVE POSITION. ;'RIG ACCEPTED FROM MAINTENANCE AT � 00: 00 H RS. 02:00 - 03:00 1.00 MOB P PRE REMOVE RIG MATT USED AS SHIM. -JACK UP RIG AND REMOVE MATT SHIMS FROM UNDER RIG. 03:00 - 07:00 4.00 MOB P PRE 111 INSTALL BOOSTERS. -INSTALL REAR BOOSTERS. INSTALL STAR WARS AND FRONT BOOSTERS. 07:00 - 09:30 2.50 MOB P PRE CREEP MODE SYSTEM TRAINING. -CREEP MODE SYSTEM TRAINING WITH RIG 09:30 - 12:00 2.50 MOB N WAIT. PRE CREW, GIVEN BY SAWYER REP. WAIT FOR ESCORT. -RIG ON STAND-BY WITH FULL CREW. -WAIT ON SECURITY TO ESCORT RIG FROM TARMAC TO DS 01-02. 12:00 - 12:30 0.50 MOB P PRE rCREEP MODE SYSTEM TRAINING. -CREEP MODE SYSTEM TRAINING WITH RIG CREW, GIVEN BY SAWYER REP. 12:30 - 15:30 3.00 MOB P PRE -MOBE RIG TO DS 01-02. -PJSM WITH SECURITY AND COMMUNICATIONS CHECK. -MOBE RIG FROM TARMAC TO DS 01 ACCESS ROAD. '24 HR BOPE TEST NOTIFICATION SUBMITTED AT 14:29-HRS.- 4:29HRS.15:30 15:30- 17:30 2.00 MOB P PRE REMOVE BOOSTERS. -REMOVE REAR BOOSTERS. -REMOVE STAR WARS AND FRONT BOOSTERS. _ 17:30 - 18:00 0.50 MOB P PRE POSITION RIG TO MOVE OVER WELL 01-02. -BACK RIG INTO POSITION TO MOVE OVER WELL 01-02. 'TUBING PRESSURE = 6 PSI, IA PRESSURE _ 6 PSI, OA PRESSURE = 45 PSI, OOA PRESSURE = 0 PSI. 'RIG ACCEPTED AT 18:00 HRS.' 18:00 - 19:00 POSITION RIG OVER WELL 01-02. 1.00 MOB P PRE -PJSM. -CONTACT DSO TO WITNESS RIG MOVING OVER WELL 01-02. 'DSO WITNESS RIG MOVING OVER WELL. -FUNCTION TEST ESD ON MOVING SYSTEM BEFORE MOVING RIG OVER WELL. TEST PASS. -POSITION AND CENTER RIG OVER WELL 01-02, USING CREEP MODE SYSTEM. -LEVELAND SHIM RIG. Printed 10/13/2014 1:19:52PM Printed 10/13/2014 1:19.52PM North America - ALASKA - BP Operation Summary Report Common Well Name: 01-02 AFE No Event Type: WORKOVER (WO) Start Date: 8/25/2014 End Date: !X4 -0103J -E: (6,000,000.00) Project: Prudhoe Bay Site: PB DS 01 ~I Rig Name/No.: DOYON 14 Spud Date/Time: 1/17/1970 12:00:OOAM Rig Release: 10/4/2014 Rig Contractor: DOYON DRILLING INC. UWI: 500292005300 Active datum: 4 : 02 1/17/1970 00:00 @73.00usft (above Mean Sea Level) Date From - To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (usft) 19:00 - 00:00 5.00 RIGU P PRE SAFE -IN CELLAR AND RIG ACCESSES. -INSTALL HANDRAILS AND STAIRS AROUND RIG. -CONSTRUCT WORKING PLATFORM IN CELLAR. -STACK RIG MATTS AND CONSTRUCT BARRICADES. - 03:30 3.50 8/26/2014 RIGU P PRE SAFE -IN CELLAR AND RIG ACCESSES. 100.00 -INSTALL HANDRAILS AND STAIRS AROUND RIG. -STACK RIG MATS AND CONSTRUCT BARRICADES. 'SIMOPS: -HARDLINE CREW, R/U HARDLINE FROM SKID MANIFOLD TO FLOWBACKTANK. -PRESSURE TEST HARDLINE FORM SKID MANIFOLD TO FLOWBACK TANK TO 250 / 4,000 PSI FOR 5 CHARTED MINS EACH. 03.30 - 04:30 1.00 RIGU P —PRE – – SKID RIG FLOOR. -PJSM. -PREPARE AND SKID RIG FLOOR INTO DRILLING POSITION. 10:00 --, 5.50 RIGU P PRE RIG UP RIG EQUIPMENT. -R/U RIG FLOOR AND SERVICE LINES. -PREPARE AND SKID OUT CONVEYOR #2. -CONNECT TOP DRIVE AND FUNCTION TEST ! SAME. TEST GOOD. -CONNECT LIGHTS OVER CHOKE MANIFOLD. i -R/U BREAK TRAILER. -R/U LINES FOR TESTING BPVAND DISPLACEMENT OF FREEZE PROTECT. 'SIMOPS: -PJSM WITH CH2 VAC -TRUCK OPER. -PREPARE MUD PITS AND TAKE ON 8.5 PPG SEAWATER. 10:00 - 10:30 ! 0.50 RIGU P PRE H2S / RIG EVACUATION DRILL. -SIMULATED H2S RELEASE, LEADING TO RIG EVACUATION, FOLLOWED BYAAR. 10:30 - 13:00 2.50 DHB P PRE PRESSURE TEST ISA BPV. -PJSM WITH PRESSURE CROSSCHECK DISCUSSION AND CONFIRMED CHALLENGE QUESTIONS WITH CORRECT RESPONSES. PRESSURE TEST ISA BPV FROM BELOW TO 1250 / 1,000 PSI FOR 5 CHARTED MINS EACH. TEST PASS. -BLEED OFF ALL PRESSURE AND BLOW _+ DOWN LINES. Printed 10/13/2014 1:19.52PM North America - ALASKA B 79 r Operation Summary ReportA» Common Well Name: 01-02 AFE No Event Type: WORKOVER (WO) Start Date: 8/25/2014 End Date: X4 -0103J -E: (6,000,000.00 ) Project: Prudhoe Bay Site: PB DS 01 Rig Name/No.: DOYON 14 Spud Date/Time: 1/17/1970 12:00:OOAM Rig Release: 10/4/2014 Rig Contractor. DOYON DRILLING INC. UW: 500292005300 Active datum: 4: 02 1/17/1970 00:00 @73.00usft (above Mean Sea Level) Date From - To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (usft) 13:00 - 18:30 5.50 WHSUR P DECOMP NIPPLE DOWN DRY HOLE TREE. -PJSM WITH CAMERON REPS. -CAMERON, BLEED ALL PRESSURE OFF HANGER VOID. -N/D DRY HOLE TREE. -CAMERON, INSPECT AND VERIFY THREADS ON TOP OF HANGER. *5-1/2" SEU HANGER THREADS IN FAIR CONDITION. -INSTALL ISA BLANKING PLUG. *M/U TURNS = 7-1/2 -M/U X -OVER TO BLANKING PLUG FOR M/U TURN COUNT. *M/U TURNS = 5-3/4 *SIMOPS: -SCAFFOLDING CREW INSTALL HANDRAILS AROUND CELLAR AND RIG ACCESSES. 18:30 - 21:00 2.50 WHSUR P DECOMP NIPPLE UP UNI CAMP ADAPTER. -CAMERON, N/U-UNI CLAMP x 13-5/8" 5M ADAPTER FLANGE. *TORQUE UNI CLAMP TO 1,800 FT/LBS -CAMERON, WORKED LDS. *LDS IN = 3-7/8" LDS OUT = 4-7/8" 21:00 - 22:30 1.50 BOPSUR P DECOMP ' "NIPPLE UP 13-5/8" 5M BOPE. -NN BOPE. 22:30 - 23:30 1.00 BOPSUR P DECOMP FIRE / RIG EVACUATION DRILL. -SIMULATED FIRE IN CELLAR THAT PROGRESSED BEYOND THE INCIPIENT STAGE, LEADING TO RIG EVACUATION, FOLLOWED BYAAR. 23:30 - 00:00 0.50 BOPSUR P DECOMP NIPPLE UP 13-5/8" 5M BOPE. -N/U BOPE. 8/27/2014 00:00 - 02:00 2.00 BOPSUR P - DECOMP NIPPLE UP 13-5/8" 5M BOPE. -PJSM. -N/U 13-5/8" BOPE DRESSED WITH 9-5/8" SOLID BODY IN UPPER PIPE RAMS AND 3-1/2" x 6" VBR IN LOWER PIPE RAMS. -R/U BELL NIPPLE, FLOW LINE, HOLE FILL LINE, BLEEDER LINES AND MOUSE HOLE. *SIMOPS: -LOAD AND TALLY 4" DP ON OFF -DRILLERS SIDE OF PIPE SHED. _ 02:00 - 03:00 1.00 BOPSUR P DECOMP RIG UP TO TEST BOPE. -RIG UP ALL FLOOR VALVES, CROSSOVERS, AND EQUIPMENT TO TEST BOPE. 03:00 - 04:30 1.50 BOPSUR P DECOMP SHELL TEST 13-5/8" 5M BOPE. -PJSM ON TESTING BOPE UTILIZING DONUT TEST JTS, WITH PRESSURE CROSSCHECK DISCUSSION AND CONFIRMED CHALLENGE QUESTIONS WITH CORRECT RESPONSES. -FILL STACKAND CHOKE MANIFOLD TO MGS. **WELL KILL DRILL.** *6 BBLS TO FILL GAS BUSTER. -SHELL TEST BOPE WITH ANNULAR PREVENTER SHUT, TO 250 / 3,500 PSI. TEST PASS. *JEFF JONES WITH AOGCC, WAIVED WITNESS ON 8/25/2014 AT 14:49 HRS. Printed 10/13/2014 1:19:52PM North America - ALASKA BPS, rl� Operation Summary Report Common Well Name: 01-02 AFE No Event Type: WORKOVER (WO) Start Date: 8/25/2014 End Date: X4 -0103J -E: (6,000,000.00 ) Project: Prudhoe Bay Site: PB DS 01 Rig Name/No.: DOYON 14 Spud Datelrime: 1/17/1970 12:00:OOAM Rig Release: 10/4/2014 Rig Contractor: DOYON DRILLING INC. UWI: 500292005300 Active datum: 4: 02 1/17/1970 00:00 @73.00usft (above Mean Sea Level) Date From - To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (usft) 04:30 - 13:00 8.50 BOPSUR P DECOMP PRESSURE TEST 13-5/8" 5M BOPE WITH DONUT TEST JTS. -TEST BOPE AS PER DDI SOP. -TEST BOPE WITH 4", 5-1/2" AND 9-5/8" TEST JTS TO 250 / 3,500 PSI FOR 5 CHARTED MINS EACH. TEST PASS. -TEST ANNULAR PREVENTER WITH 4" TEST JT TO 250 / 3,500 PSI FOR 5 CHARTED MINS EACH. TEST PASS. �'-PERFORM ACCUMULATOR DRAW DOWN TEST. TEST PASS. *FAIL / PASS ON GREY LOCK HUB LEAK. *H2S SENSOR HEAD FAILURE AT SHAKERS. (IR # 4802967): *REPLACED H2S SENSOR HEAD AND ALLOW 24 HRS ACCLAMATION PERIOD, AS PER MANUFACTURE SPECIFICATIONS. *DISCUSS REMEDIAL ACTION WITH RWO SUPT AND WTL *POSITION CALIBRATED POTABLE ATMOSPHERIC MONITOR AT H2S SENSOR LOCATION AT SHAKERS, WHICH WILL BE MONITORED BY DOYON EMPLOYEE, UNTIL NEW H2S SENSOR HEAD IS TESTED AND RETURNED TO SERVICE. -PERFORM DERRICK INSPECTION. -R/D BOPE TEST EQUIPMENT. 13:00 - 13:30 0.50 BOPSUR P DECOMP SERVICE RIG. - -LUBRICATE TOP DRIVE, DRAW -WORKS AND ST -80. 13:30 - 14:30 1.00 DHB P DECOMP RIG UP TO RETRIEVE ISA BLANKING PLUG - AND BPV. -PJSM WITH DSM CREW AND CAMERON REP. -R/U DUTCH RISER, RILDS ON DUTCH RISER AND CLOSE ANNULAR PREVENTER. -RN DSM LUBRICATOR WITH QTS. 14:30 - 15:00 0.50 DHB P DECOMP TEST DUTCH RISER AND DSM LUBRICATOR. -R/U AND TEST DUTCH RISER AND DSM LUBRICATOR TO 250 / 3,500 PSI FOR 5 MINS EACH. TEST PASS. 15:00 - 16:00 1.00 DHB P DECOMP RETRIEVE ISA BLANKING PLUG. -BREAK DSM LUBRICATOR AT QTS AND SET SAME ASIDE. -VOID BOPE OF FLUID. -R/U AND RETRIEVE ISA BLANKING PLUG. **SPILL DRILL IN CELLAR.** 16:00 - 16:30 0.50 DHB P DECOMP TEST DSM LUBRICATOR. -M/U DSM LUBRICATOR. -TEST DSM LUBRICATOR AT QTS TO 250 / 3,500 PSI FOR 5 MINS. TEST PASS. 16:30 - 18:30 2.00 DHB P DECOMP RETRIEVE ISA BPV. -RETRIEVE ISA BPV WITH TESTED LUBRICATOR. *TOOK 2- ATTEMPT TO RETRIEVE ISA BPV. -R/D DSM LUBRICATOR AND DUTCH RISER. Printed 10/13/2014 1:19:52PM North America - ALASKA - BP Pages of 79 Operation Summary Report Common Well Name: 01-02 AFE No Event Type: WORKOVER (WO) Start Date: 8/25/2014 End Date: X4 -0103J -E: (6,000,000.00 ) Project: Prudhoe Bay Site: PB DS 01 Rig Name/No.: DOYON 14 Spud Date/Time: 1/17/1970 12:00:00AM Rig Release: 10/4/2014 Rig Contractor: DOYON DRILLING INC. UWL 500292005300 Active datum: 4: 02 1/17/1970 00:00 Q73.00usft (above Mean Sea Level) Date From - To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (usft) 18:30 - 20:00 1.50 CLEAN P DECOMP CIRCULATE OUT DIESEL FREEZE PROTECT. -CLOSE BLIND / SHEAR RAMS. -PJSM WITH PRESSURE CROSSCHECK DISCUSSION AND CONFIRMED CHALLENGE QUESTIONS WITH CORRECT RESPONSES. -VERIFY LINE-UP AND CIRC OUT DIESEL FREEZE PROTECT; PUMP 260 BBLS OF 8.5 RPG SEAWATER DOWN TBG AND TAKE RETURNS THRU IA, TO FLOWBACK TANK AT 10 BPM. "ICP= 780 PSI, ,FCP= 1,040 PSI *SIMOPS: -MOBE-EQUIPMENT FOR DE -COMPLETION TO -RIG FLOOR. -R/Lt, POWER TONGS, SPOOLING UNIT AND 5-1/2" HANDLING EQUIPMENT. 20:00 - 20:30 0.50 CLEAN P DECOMP FLOW CHECK. ' -10 MIN FLOW CHECK. WELL STABLE. -VERIFY 0 PRESSURE. -OPEN BLIND / SHEAR RAMS. _ 20:30 - 23:30 3.00 PULL P DECOMP SPEAR AND PULL TUBING HANGER FREE TO RIG FLOOR. -PJSM WITH BAKER, CAMERON AND SLB REPS. -P/U AND M/U GRAPPLE SPEAR ASSEMBLY. -ENGAGE 5-1/2" COMPLETION BELOW TBG HANGER, AS PER BAKER REP. *SET 10K DOWN AND PULL 15K OVER, TO ENSURE SPEAR ENGAGEMENT. -SET 5K DOWN. -CAMERON REP, BOLDS. -PULL TBG HANGER FREE TO RIG FLOOR. *TBG HANGER PULLED FREE WITH 5K OVER PULL, AT 105K. *PUW-- 100K 23:30 00:00 0.50 PULL P DECOMP LAY DOWN TUBING HANGER ASSEMBLY. -TERMINATE DUAL 1/4" CONTROL LINE AT TBG HANGER. -DISENGAGE SPEAR FROM TBG HANGER ASSY. -UD TBG HANGER AND SPEAR ASSY. 8/28/2014 00:00 - 02:00 2.00 PULL P DECOMP CIRCULATE AND CONDITION FLUID. -CLOSE ANNULAR PREVENTER. -R/U SAFETY JT AND WELL CONTROL EQUIPMENT. -PJSM WITH PRESSURE CROSSCHECK DISCUSSION AND CONFIRMED CHALLENGE QUESTIONS WITH CORRECT RESPONSES. -CIRC 8.5 PPG SEAWATER THRU MGS AT 5 BPM WITH 40 PSI, UNTIL RETURNS CLEAN. *AT 220 BBLS; RETURNS CLEAN. 02:00 - 02:30 0.50 PULL P DECOMP FLOW CHECK. -10 MIN FLOW CHECK. WELL STABLE. -VERIFY 0 PRESSURE. -OPEN ANNULAR PREVENTER. -BLOW DOWN TOP DRIVE. Printed 10/13/2014 1:19:52PM North America - ALASKA BP , ,� .� Page 6 79 11 , Operation Summary Report f Common Well Name: 01-02 AFE No Event Type: WORKOVER (WO) Start Date: 8/25/2014 End Date: X4 -0103J -E: (6,000,000.00 ) Project: Prudhoe Bay Site: PB DS 01 Rig Name/No.: DOYON 14 Spud Datelrime: 1/17/1970 12:00:OOAM Rig Release: 10/4/2014 Rig Contractor: DOYON DRILLING INC. UWI: 500292005300 Active datum: 4: 02 1/17/1970 00:00 @73.00usft (above Mean Sea Level) Date From - To Hrs Task Code NPT 1 NPT Depth Phase Description of Operations 5 (u ) 02:30 07:00 450 PULL P DECOMP CLAY DOWN 5-1/2" 17# N-80 LT&C COMPLETION, SPOOLING DUAL 1/4" CONTROL LINE. -PJSM WITH DOYON CASING AND SLB REPS. -LINE UP ON TRIP TANK. -POOH, LAYING DOWN 5-1/2" COMPLETION, SPOOLING DUAL CONTROL LINE F/ 3,200'T/ 2,171'. `RECOVERED: 41- CLAMPS AND 40- PINS "*DUAL CONTROL LINE CLAMPS MISSING )RUBBER COVERING." 07:00 08:00 1.00 PULL P DECOMP 1 RIG DOWN SLB SPOOLING UNIT. -R/D SPOOLING UNIT AND EQUIPMENT. 08:00 - 08:30 0.50 -CLEAR RIG FLOOR OF SPOOLING UNIT. PULL P DECOMP LAY DOWN 5-1/2" 17# N-80 LT&C COMPLETION. -POOH, LAYING DOWN 5-1/2" COMPLETION F/ 2,171'. "RECOVERED: 125- JTS OF 5-1/2" 17# LT&C, 1-SSSV, 1- CUT JT OF 5-1/2" 17# LT&C, 12.35' LONG "NO FLARE ON CUT. 08:30 - 10:00 1.50 PULL P DECOMP CLEAN RIG FLOOR. -CLEAN / CLEAR RIG FLOOR OF POWER TONGS, AND 5-1/2" HANDLING EQUIPMENT. -BREAK-DOWN SAFETY JT. -MOBE BAKER 8-1/8" OVERSHOT BHA#2 TO RIG FLOOR. 10:00 - 12:00 2.00 FISH P DECOMP MAKEUP 8-1/8" S150 OVERSHOT BHA#2. -PJSM WITH BAKER REP. -P/U, M/U AND RIH WITH 8-1/8" OVERSHOT BHA TO 229'. "PUW= 70K, SOW= 70K DECOMP SERVICE RIG. 12:00 - 12:30 0.50 FISH P -LUBRICATE TOP DRIVE, DRAW -WORKS AND ST -80. DECOMP RUN IN HOLE WITH 8-1/8" 5150 OVERSHOT 12.30 17:00 4.50 FISH P BHA#2. -RIH WITH 8-1/8" OVERSHOT BHA F/ 229'T/ 3,041', P/U 4" DP FROM PIPE SHED. "PUW= 110K, SOW= 110K 17:00 - 19:00 2.00 FISH P DECOMP SLIP AND CUT DRILLING LINE. I -PJSM. -SLIP AND CUT 59' OF 1-1/4" DRILLING LINE. + "FUNCTION CROWN-O-MATIC. GOOD TEST. 19:00 19:30 0.50 FISH P DECOMP RUN IN HOLE WITH 8-1/8" 5150 OVERSHOT I- BHA #2. -RIH WITH 8-1/8" OVERSHOT BHA F/ 3,041'T/ 3,205'. -ESTABLISH PARAMETERS. "PUW= 110K, SOW= 110K, RTW-- 110K, PUMP RATE= 3 BPM WITH 60 PSI, RPMs= 50 WITH 1KTORQUE Printed 10/13/2014 1:19:52PM North America - ALASKA - BP Page 7 of 79 Operation Summary Report Common Well Name: 01-02 AFE No Event Type: WORKOVER (WO) Start Date: 8/25/2014 End Date: X4 -0103J -E: (6,000,000.00 ) Project: Prudhoe Bay Site: PB DS 01 Rig Name/No.: DOYON 14 Spud Date/Time: 1/17/1970 12:00:OOAM Rig Release: 10/4/2014 Rig Contractor: DOYON DRILLING INC. UWI: 500292005300 Active datum: 4: 02 1/17/1970 00:00 @73.00usft (above Mean Sea Level) Date From - To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (usft) 19:30 - 20:00 0.50 FISH P DECOMP CIRCULATE BOTTOMS UP DUE TO ERRATIC PRESSURE WHEN ESTABLISHING PARAMETERS. *SUSPECT DUE TO MULTIPLE DUAL CONTROL LINE CLAMP RUBBER, NOT RECOVERED. -CIRC B/U AT 10 BPM WITH 560 PSI. *RECOVERED LARGE PIECE OF RUBBER FROM DUAL CONTROL LINE CLAMP 4" WIDE x T' LONG x 1.5" THICKAND HAND FULL OF SMALL PIECES OF RUBBER. 20:00 - 22:00 2.00 FISH P DECOMP RUN IN HOLE WITH 8-1/8" S150 OVERSHOT BHA#2 AND ENGAGE 5-1/2" COMPLETION STUB. -PJSM WITH BAKER REP. -PUH F/ 3,205'T/ 3,176. -WASH DOWN F/ 3,175' AT 3 BPM WITH 50 PSI AND TAG OBSTRUCTION AT 3,216' WITH 5K - DOWN.- -TAG AND WORK THROUGH SEVERAL OBSTRUCTIONS WITH 1-3K DOWN. -PUH V TO 3,211'. -WASH AND REAM TO CLEAR DEBRIS FROM TOP OF 5-1/2" COMPLETION STUB. }10 BPM WITH 600 PSI, VARY RPMs= 5-50 WITH 1-2K TORQUE AND 5-9K DOWN -ENGAGE TOP OF 5-1/2" COMPLETION STUB WITH OVERSHOT BHA. *TOOK SEVERAL ATTEMPTS. -SHUT DOWN ROTATION AND PUMP; ENGAGE AND SET GRAPPLE. 22:00 - 00:00 2.00 FISH P DECOMP ATTEMPT TO FREE 5-1/2" COMPLETION SEALS FROM PACKER. -ATTEMPT TO JAR 5-1/2" COMPLETION SEALS FROM PACKER WITH NO SUCCESS. *FIRE JARS IN 25K INCREMENTS FROM 75-225KAND WORKING OVER -PULLS IN INCREMENTS OF 10-15K TO 240K OVER; CIRC WITH OVER -PULLS AT 9 BPM WITH 900 PSI. *DISCUSS PLAN FORWARD WITH ODE. 8/29/2014 00:00 - 01:30 1.50 FISH P DECOMP DISENGAGE OVERSHOT AND CONDUCT POST JARRING INSPECTION. -PJSM WITH BAKER REP. -DISENGAGE OVERSHOT FROM 5-1/2" STUB. -PUMP 30 BBL HI -VIS SWEEP AT 7 BPM WITH 200 PSI. *RECOVERED 1/2 CUP SMALL PIECES OF DUAL CONTROL LINE CLAMP COVER RUBBER. -CONDUCT POST JARRING DERRICK INSPECTION. -10 MIN FLOW CHECK. WELL STABLE. 01:30 - 03:30 2.00 FISH P DECOMP PULL OUT OF HOLE WITH 8-1/8" 5150 OVERSHOT BHA #2. -POOH WITH OVERSHOT BHA F/ 3,216'T/ 300'. -10 MIN FLOW CHECK FOR NOWSHEARABLES ACROSS BOPE. 03:30 - 04:30 1.00 FISH P DECOMP LAY DOWN 8-1/8" S150 OVERSHOT BHA #2. -POOH F/ 300' AND L/D OVERSHOT BHA. -MOBE 8-1/2" WASHOVER SHOE BHA#3 TO RIG FLOOR. Printed 10/13/2014 1:19:52PM North America - ALASKA - BP Page 8 of 79 Operation Summary Report Common Well Name: 01-02 AFE No Event Type: WORKOVER (WO) Start Date: 8/25/2014 End Date: X4 -0103J -E: (6,000,000.00 ) Project: Prudhoe Bay Site: PB DS 01 Rig Name/No.: DOYON 14 Spud Date/Time: 1/17/1970 12:00:OOAM Rig Release: 10/4/2014 Rig Contractor. DOYON DRILLING INC. UW:500292005300 Active datum: 4: 02 1/17/1970 00:00 @73.00usft (above Mean Sea Level) Date From - To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (usft) 04:30 - 06:00 1.50 FISH P DECOMP MAKEUP AND RIH WITH 8-1/2" WASHOVER SHOE BHA#3. -PJSM WITH BAKER REP. -RIH WITH 8-1/2" WASHOVER SHOE BHA T/ 382'. 06:00 - 08:00 2.00 FISH P DECOMP !I RIH WITH 8-1/2" WASHOVER SHOE BHA#3. -RIH WITH 8-1/2" WASHOVER SHOE BHA F/ 382'T/ 3,216'. *FILL W6RKSTRING EVERY 1,000'. 08:00 10:00 2.00 FISH P DECOMP WASHOVER 5-1/2" COMPLETION STUB. -ESTABLISH PARAMETERS. ' *PWU= 112K, SOW= 112K, RTW= 112K, RPMs= 40 WITH 1-2K TORQUE, PUMP RATE= 5 BPM WITH 120 PSI -WASHOVER 5-1/2" COMPLETION STUB F/ 3,216' T/ 3,367'. 10:00 - 11:00 1.00 FISH P DECOMP CIRCULATE 30 BBL HI -VIS SWEEP AROUND. -PUMP 30 BBL HI -VIS SWEEP AROUND AT 10 BPM 450 PSI. -10 MIN FLOW CHECK. WELL STABLE. 11:00 12:00 1.00 FISH P DECOMP PULL OUT HOLE WITH 8-1/2" WASHOVER SHOE BHA#3. -POOH WITH WITH 8-1/2" WASHOVER SHOE BHA F/ 3,367' T/ 984'. 12:00 - 13:00 1.00 FISH P DECOMP PULL OUT HOLE WITH 8-1/2" WASHOVER SHOE BHA #3. -PJSM WITH BAKER REP. POOH WITH WITH 8-1/2" WASHOVER SHOE BHA F/ 984'T/ 382'. SHOE BHA#3. 13:00 14:30 1.50 FISH P DECOMP LAY DOWN 8-1/2" WASHOVER -10 MIN FLOW CHECK FOR NON-SHEARABLES ACROSS BOPE. -POOH F/ 382', L/D 8-1/2" WASHOVER SHOE BHA. -CLEAN AND INSPECT BOOT BASKET. *RECOVERED: 1 -CUP OF PIECES OF ,RUBBER. -MOBE 8-7/16" OUTSIDE CUTTER BHA #4 TO 14:30 16:30 2.00 RIG FLOOR. RREP DECOMP SERVICE RIG. FISH N -CHECK TORQUE ON DRAW -WORKS TRACTION MOTORS "A" AND "B". CHECK GOOD. 16:30 - 18:30 2.00 FISH P DECOMP MAKE UP AND RIH WITH 8-7/16" OUTSIDE CUTTER BHA#4. -PJSM WITH BAKER REP. -P/U, M/U AND RIH WITH OUTSIDE CUTTER BHA TO 348'. 18:30 - 21:00 2.50 FISH P DECOMP RUN IN HOLE WITH 8-7/16" OUTSIDE CUTTER BHA #4. -RIH WITH OUTSIDE CUTTER BHA F/ 348'T/ 3,200'. -ESTABLISH PARAMETERS. *PUW= 112K, SOW= 112K -RIH WITH RIH WITH OUTSIDE CUTTER BHA F/ 3,200'T/ 3,342'. *NO INDICATION OF TUBING STUMP AT 3,216'. PUH AND LOCATE 5-1/2" COLLAR AT 3,328 Printed 10/13/2014 1.19:52PM Printed 10/13/2014 1:19:52PM North America - ALASKA - BP Page 9 of 79 Operation Summary Report Common Well Name: 01-02 AFE No Event Type: WORKOVER (WO) Start Date: 8/25/2014 End Date: X4 -0103J -E: (6,000,000.00 ) Project: Prudhoe Bay Site: PB DS 01 Rig Name/No.: DOYON 14 Spud Date/Time: 1/17/1970 12:00:OOAM Rig Release: 10/4/2014 Rig Contractor: DOYON DRILLING INC. UWI: 500292005300 Active datum: 4: 02 1/17/1970 00:00 @73.00usft (above Mean Sea Level) Date From - To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (usft) 21:00 - 23:30 2.50 FISH P DECOMP CUT 5-1/2" COMPLETION WITH 8-7/16" OUTSIDE CUTTER BHA #4. -PJSM WITH BAKER REP. -SLACK OFF F/ COLLAR AT 3,328', 2'T/ 3,330'. -CUT 5-1/2" COMPLETION WITH OUTSIDE CUTTER AT 3,330', AS PER BAKER REP. *PUW= 112K, SOW= 112K, RWT= 112K, RPMs= 40 WITH 1-2K TORQUE, PUMP RATE= 1 BPM WITH 50 PSI. *INDICATION 5-1/2" COMPLETION CUT AND INSIDE WASHPIPE. I *NEW PUW= 114K 123:30 - 00:00 0.50 FISH P DECOMP ! CIRCULATE. PUH F/ 3,330'T/ 3,292'. -CIRC B/U AT 1.5 BPM WITH 60 PSI. -10 MIN FLOW CHECK. WELL STABLE. 8/30/2014 00:00 - 02:30 2.50 FISH P DECOMP PULL OUT OF HOLE WITH 8-7/16" OUTSIDE CUTTER BHA #4. PJSM WITH BAKER REP. -RACK BACK 1 -STD OF 4" DP. 1 -BLOW DOWN TOP DRIVE. 1 -LINE UP ON TRIP TANK. POOH WITH OUTSIDE CUTTER BHA F/3292' T/ 443'. *SIMOPS: -CLEAN AND CLEAR BLUE GOO IN CELLAR. 02:30 03:30 1.00 FISH P DECOMP LAY DOWN 8-7/16" OUTSIDE CUTTER BHA #4. -10 MIN FLOW CHECK FOR NOWSHEARABLES ACROSS BOPE. -STAND BACK 6-1/4" DRILL COLLARS IN DERRICK. 1 *SIMOPS STAGE AND POSITION E -LINE EQUIPMENT. —1 - SAFETY 03:30 - 04:00 0.50 FISH P DECOMP MEETING. -PJSM / HAZARD WORKSHEET ON STRIPPING 5-1/2" COMPLETION FISH THRU 8-1/8" WASHPIPE. DISCUSSED WELL CONTROL CONTINGENCIES, WITH NON-SHEARABLE BHA WITH INNER STRING. Printed 10/13/2014 1:19:52PM Printed 10/13/2014 1.19:52PM North America -ALASKA - BP Page 10 of 79 Operation Summary Report Common Well Name: 01-02 AFE No Event Type: WORKOVER (WO) Start Date: 8/25/2014 End Date: X4-0103J-E: (6,000,000.00 ) Project: Prudhoe Bay Site: PB DS 01 Rig Name/No.: DOYON 14 Spud Date/Time: 1/17/1970 12:00:OOAM Rig Release: 10/4/2014 Rig Contractor: DOYON DRILLING INC. ----UW: 500292005300 Active datum: 4: 02 1/17/1970 00:00 @73.00usft (above Mean Sea Level) Date ! From - To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (usft) — - - 07:00 04:00 3.00 FISH P DECOMP LAY DOWN 8-7/16" OUTSIDE CUTTER BHA #4 WITH 5-1/2" COMPLETION INNER STRING. -UD 2- JTS OF WASHPIPE, EXPOSING 5-1/2" INNER STRING. -STRIP 1- JT OF 5-1/2" WITH CUT JT AND UD TO PIPE SHED. *OBSERVED GL STRADDLE. -SECURED GL STRADDLE WITH DOG COLLAR, HAND CUT FLOW PUP ABOVE !MANDREL AND UD SAME. -STRIP REMAINDER OF GL STRADDLE THRU 5-1/2" AND UD. -C/O WASHPIPE ELEVATORS TO 5-1/2" ELEVATORS. -STRIP 5-1/2" INNER STRING THRU WASH PIPE AND L/D TO PIPE SHED. *RECOVERED: 4 JTS OF 5-1/2" COMPLETION, 2- CUT JTS OF 5-1/2" COMPLETION (RCT CUT JT= 13.25'/ OUTSIDE CUTTER CUT JT= 2.94') *BOTH CUTS CLEAN WITH NO FLARE. -C/O 5-1/2" ELEVATORS WITH WASHPIPE ELEVATORS. =UD WASHPIPE AND OUTSIDE CUTTER. 07.00 - 08:30 ALL KNIVES ON CUTTER IN PLACE. 1.50 FISH P DECOMP CLEAN RIG FLOOR. -CLEAN / CLEAR RIG FLOOR OF OUTSIDE CUTTER BHAAND HANDLING EQUIPMENT. 08.30 - 09:00 0.50 FISH P DECOMP RIG UP DUTCH RISER SYSTEM. -R/U DUTCH RISER, RILDS ON DUTCH RISER AND CLOSE ANNULAR PREVENTER. 09:00 13:00 4.00 FISH P DECOMP RIG UP HES E-LINE EQUIPMENT. -PJSM WITH E-LINE CREW. -R/U E-LINE EQUIPMENT. **TABLE TOP WELL CONTROL DRILL WITH E-LINE IN THE HOLE.** 13:00 15:30 2.50 FISH P DECOMP MAKE UP AND RIH WITH HES RBL ON E-LINE. -ZERO E-LINE TOOLSTRING AT ROTARY. -RIH WITH CCL / CBL TO 3,328' WLM. -LOG F/ 3,328' WLM T/ SURFACE. *SENT RBL TO ODE FOR DETERMINATION OF 9-5/8" CSG CUT DEPTH. 15:30 - 18:00 2.50 FISH P DECOMP MAKE UP AND RUN IN HOLE WITH 4.49" GAUGE RING ON E-LINE. -10 MIN FLOW CHECK WHILE M/U 4.49" GAUGE RING TOOLSTRING. -RIH WITH 4.49" GAUGE RING / CCL TOOLSTRING AND TAG TOP OF 5-1/2" TBG STUB AT 3,330'. -ATTEMPT TO WORK 4.49" GAUGE RING / CCL TOOLSTRING THRU TBG STUB SEVERAL TIMES, WITH NO SUCCESS. -POOH WITH 4.49" GAUGE RING / CCL TOOLSTRING F/ 3,330'. 18:00 00:00 6.00 FISH P DECOMP MAKE UP AND RUN IN HOLE WITH 4.25" GAUGE RING / CCL ON E-LINE. -10 MIN FLOW CHECK WHILE M/U 4.25" GAUGE RING / CCL TOOLSTRING. -RIH WITH 4.25" GAUGE RING / CCL ON E-LINE AND TAG TOP OF CMT AT 9,910'. *OBSERVED TOP OF 5-1/2" STUB AT 3,330'. -POOH WITH 4.25" GAUGE RING / CCL ON E-LINE F/ 9,910'. Printed 10/13/2014 1.19:52PM North America - ALASKA - BP Page 11 of 79 Operation Summary Report Common Well Name: 01-02 AFE No Event Type: WORKOVER (WO) Start Date: 8/25/2014 End Date: X4-0103J-E: (6,000,000.00 ) Project: Prudhoe Bay Site: PB DS 01 Rig Name/No.: DOYON 14 Spud Date/Time: 1/17/1970 12:00:OOAM Rig Release: 10/4/2014 Rig Contractor: DOYON DRILLING INC. UWI: 500292005300 Active datum: 4: 02 1/17/1970 00:00 @73.00usft (above Mean Sea Level) Date From - To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (usft) 8/31/2014 00:00 - 01:00 1.00 FISH P DECOMP PULL OUT OF HOLE WITH 4.25" GAUGE RING / CCL ON E-LINE. -POOH HOLE WITH 4.25" GAUGE RING / CCL ON E-LINE F/ 3,600'T/ SURFACE. 01:00 - 07:00 6.00 FISH P DECOMP RUN IN HOLE WITH RCT ON E-LINE AND CUT 5-1/2" COMPLETION. -PJSM WITH E-LINE CREW. -M/U AND RIH WITH RCT ON E-LINE AND TAG TOP OF CMT AT 8,898' ELM. -CORRELATE RCT ON DEPTH AND SET ANCHORS. -CUT 5-1/2" COMPLETION WITH RCT AT 8,890' ELM. `INDICATION RCT FIRED. -RELEASE ANCHORS AND POOH WITH E-LINE F/ 8,890'. SPILL DRILL IN CELLAR.** 2.00 FISH P DECOMP RIG DOWN HES E-LINE TOOLAND 07:00 - 09:00 EQUIPMENT. -PJSM WITH HES E-LINE CREW. -UD RCT TOOLSTRING AND LUBRICATOR. -R/D HES E-LINE EQUIPMENT. -OPEN ANNULAR PREVENTER AND BOLDS ON DUTCH RISER SYSTEM. -UD DUTCH RISER SYSTEM TO PIPE SHED. 09:00 10:30 -BLOW DOWN CHOKE AND KILL LINES. 1.50 FISH P DECOMP MAKE UP AND RIH WITH 8-1/8" S150 OVERSHOT BHA#5. -PJSM WITH BAKER REP. -P/U, M/U AND RIH WITH 8/1/8" OVERSHOT BHA TO 229', AS PER BAKER REP. 10:30 - 11:00 0.50 FISH P DECOMP RUN IN HOLE WITH S150 8-1/8" OVERSHOT BHA #5. -RIH WITH 8-1/8" OVERSHOT BHA F/ 229'T/ 704'. 11:00 - 11:30 0.50 FISH P DECOMP WELL CONTROL DRILL. -KICK WHILE TRIPPING DRILL FOLLOWED BY AAR. *REVIEWED PROCEDURE FOR OPERATING BOPE WITH NITROGEN BACK-UP. 11:30 - 12:00 0.50 FISH P DECOMP RUN IN HOLE WITH S150 8-1/8" OVERSHOT BHA #5. -RIH WITH 8-1/8" OVERSHOT BHA F/ 704'T/ 2,034'. *PUW= 90K, SOW= 90K 12:00 - 12:30 0.50 FISH P DECOMP SERVICE RIG. -LUBRICATE TOP DRIVE, DRAW-WORKS AND ST-80. 12:30 - 13:00 0.50 FISH P DECOMP RUN IN HOLE WITH 8-1/8" S150 OVERSHOT BHA #5. -RIH WITH 8-1/8" OVERSHOT BHA F/ 2,034'T/ 3,269'. -ESTABLISH PARAMETERS. *PUW= 112K, SOW= 112K, RTW= 112K, PUMP RATE= 4 BPM WITH 80 PSI, RPMs= 50 WITH 1KTORQUE Printed 10/13/2014 1:19:62PM North America - ALASKA BP„,,, of 79 Operation Summary Report Common Well Name. 01-02 AFE No Event Type: WORKOVER (WO) Start Date: 8/25/2014 End Date: X4 -0103J -E: (6,000,000.00 ) Project: Prudhoe Bay Site: PB DS 01 Rig Name/No.: DOYON 14 Spud Daterrime: 1/17/1970 12:00:OOAM Rig Release: 10/4/2014 Rig Contractor: DOYON DRILLING INC. UWI: 500292005300 Active datum: 4: 02 1/17/1970 00:00 @73.00usft (above Mean Sea Level) Date From - To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (usft) 13:00 - 16:00 3.00 FISH P DECOMP RUN IN HOLE WITH 8-1/8” S150 OVERSHOT BHA#5 AND ENGAGE 5-1/2" COMPLETION STUB. -PJSM WITH BAKER REP. -CONDUCT PRE JARRING INSPECTION. GOOD. -RIH WITH 8-1/8" OVERSHOT BHA F/ 3,269', WASH DOWN AND ENGAGE TOP OF 5-1/2" COMPLETION STUB AT 3,330'. `-SET DOWN 5K, P/U AND SET GRAPPLE WITH IQK OVER PULL -ATTEMPT TO JAR 5-1/2" COMPLETION FREE FROM RCT CUT AT 8,890' WLM, WITH NO SUCCESS. 'FIRE JARS IN 25K INCREMENTS FROM 75-225K AND WORKING OVER -PULLS IN INCREMENTS OF 10-15K TO 275K OVER; CIRC WITH OVER -PULLS AT 5 BPM WITH 800 PSI. -CONDUCT POST JARRING INSPECTION. GOOD. 16:00 - 17:00 1.00 FISH P DECOMP DISENGAGE 8.1/8" S150 OVERSHOT BHA #5. -DISENGAGE OVERSHOT FROM 5-1/2" STUB. - -POOR WITH OVERSHOT BHA F/ 3,330' T/ 250'. 17:00 - 18:00 1.00 FISH... P DECOMP' LAY DOWN 8-1/8" S150 OVERSHOT BHA#5. -10 MIN FLOW CHECK FOR NOWSHEARABLES ACROSS BOPE. -POOH F/ 250' AND L/D OVERSHOT BHA. 18:00 - 19:30 1.50 FISH P DECOMP CLEAN RIG FLOOR. -CLEAN / CLEAR RIG FLOOR OF OVERSHOT BHA#5 AND HANDLING EQUIPMENT. 19:30 - 20:30 1.00 FISH P DECOMP RIG UP DUTCH RISER SYSTEM. -R/U DUTCH RISER, RILDS ON DUTCH RISER AND CLOSE ANNULAR PREVENTER. 20:30 - 00:00 3.50 FISH P DECOMP RIG UP SLB E -LINE EQUIPMENT. -PJSM WITH E -LINE CREW. -R/U E -LINE EQUIPMENT. "SPILL DRILL IN MUD PITS. - 9/1/2014 00:00 - 01:30 1.50 FISH P DECOMP RIG UP SLB E -LINE EQUIPMENT. -PJSM WITH E -LINE CREW. -R/U E -LINE EQUIPMENT. -DISCUSS PLAN FORWARD WITH ODE, E -LINE CREWAND INTERVENTIONS WSL. 'SIMOPS: -PREP WIND WALLS FOR PAINTING, ORGANIZE TOOL LOCKERS, PAINT DRAW -WORKS, INSTALL CENTRALIZER ON 9-5/8" CASING AND CHANGE OIL IN MUD PUMP #1. _ 01:30 - 02:00 0.50 FISH P DECOMP DRILL. -CONDUCT RIG EVACUATION DRILL INVOLVING ALL 3RD PARTY, SIMULATING H2S RELEASE AND 2- MEN DOWN FOLLOWED BY AAR. Printed 10/13/2014 1:19:52PM North America - ALASKA BP Page cuff 79 Operation Summary Report Common Well Name: 01-02 AFE No Event Type: WORKOVER (WO) Start Date: 8/25/2014 End Date: X4 -0103J -E: (6,000,000.00 ) Project: Prudhoe Bay Site: PB DS 01 Rig Name/No.: DOYON 14 Spud Date/Time: 1/17/1970 12:00:OOAM Rig Release: 10/4/2014 Rig Contractor: DOYON DRILLING INC. WI: 500292005300 Active datum: 4: 02 1/17/1970 00:00 @73.00usft (above Mean Sea Level) Date From - To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (usft) 02:00 - 06:30 4.50 FISH P DECOMP MAKE UP AND RUN IN HOLE WITH 4.25" GAUGE RING / CCL ON E -LINE. -M/U AND RIH WITH 4.25" GAUGE RING / CCL ON E -LINE AND TAG RCT CUT AT 8,890' ELM. -ATTEMPT TO WORK PAST CUT SEVERAL TIMES WITH NO SUCCESS. *OBSERVED TOP OF 5-1/2" STUB AT 3,330'. -POOH WITH 4.25" GAUGE RING / CCL ON 0630 09:30 3.00 FISH P DECOMP RUN IN HOLE WITH SLB 4.15" JET CUTTER ON E -LINE AND CUT 5-1/2" COMPLETION. -PJSM WITH SLB E -LINE CREW. -M/U AND kIH WITH JET CUTTER ON E -LINE AND TAG AT 8,890' ELM. -CORRELATE JET CUTTER ON DEPTH. -JET CUT 5-1/2" COMPLETION AT 8,889' ELM. *INDICATION JET CUTTER FIRED. -POOH WITH E -LINE F/ 8,889' ELM T/ 300' ELM. *SIMOPS -PREP WIND WALLS FOR PAINTING AND PAINT DRAW -WORKS. 09:30 - 10:30 1.00 FISH P DECOMP RIG DOWN SLB E -LINE EQUIPMENT. -PJSM WITH SLB E -LINE CREW. -CLEAR RIG FLOOR OF PERSONNEL, FOR E -LINE CREW TO VERIFYAND ENSURE JET CUTTER SPENT. -POOH WITH E -LINE F/ 300' ELM T/ SURFACE. -SLB E -LINE CREW VERIFIED JET CUTTER SPENT. -CLEAR RIG FLOOR OF SLB E -LINE TOOLS AND EQUIPMENT. -R/D SLB E -LINE EQUIPMENT. 10:30 - 11:30 1.00 FISH P DECOMP RIG DOWN DUTCH RISER SYSTEM. -PJSM. -R/D DUTCH RISER, BOLDS ON DUTCH RISER AND OPEN ANNULAR PREVENTER. -BLOW DOWN TCHOKE AND KILL LINES. 11:30 - 12:00 0.50 FISH P DECOMP MAKE UP &-1/6'S1150 OVERSHOT BHA#6. -PJSM WITH BAKER REP. -P/U, M/U AND RIH WITH 8-1/8" OVERSHOT BHA TO 28'. 12:00 - 12:30 0.50 FISH P DECOMP SERVICE RIG. -LUBRICATE TOP DRIVE, DRAW -WORKS AND ST -80. 12:30 - 13:00 0.50 FISH P DECOMP MAKE UP 8-1/8" S150 OVERSHOT BHA #15. -P/U, M/U AND RIH WITH 8-1/8" OVERSHOT BHA F/ 28'T/ 229'. 13:00 - 14:00 1.00 FISH P DECOMP RUN IN HOLE WITH 8-1/8" S150 OVERSHOT BHA #6. -RIH WITH 8-1/8" OVERSHOT BHA F/ 229'T/ 3,269'. -ESTABLISH PARAMETERS. *PUW= 112K, SOW= 112K, RTW= 112K, RPMs= 50 WITH 1 K TORQUE Printed 10/13/2014 1:19:52PM North America -ALASKA BCS'%��f r P e 14 of 79 Operation Summary Report Common Well Name: 01-02 AFE No Event Type: WORKOVER (WO) Start Date: 8/25/2014 End Date: X4-0103J-E: (6,000,000.00 ) Project: Prudhoe Bay Site: PB DS 01 Rig Name/No.: DOYON 14 Spud Date/Time: 1/17/1970 12:00:OOAM I Rig Release: 10/4/2014 Rig Contractor. DOYON DRILLING INC. UN: 500292005300 Active datum: 4: 021/17/1970 00:00 @73.00usft (above Mean Sea Level) Date From -To Hrs Task Code NPT NPT Depth Phase Description of Operations -- - 14:00 16:00 2.00 FISH P DECOMP RUN IN HOLE WITH 8-1/8" S150 OVERSHOT - I BHA #6 AND ENGAGE 5-1/2" COMPLETION STUB. -PJSM WITH BAKER REP. -RIH WITH 8-1/8" OVERSHOT BHA F/ 3,269' AND ENGAGE 5-1/2" STUB AT 3,330'. -SET DOWN 5K, P/U AND SET GRAPPLE WITH 10K OVER PULL. -P/U AND BLEED OPEN JARS WITH 60K OVER. -PULL TO 225K ON WEIGHT INDICATOR AND APPLY 500 PSI WITH PUMP. PULL TO 275K, WORK STRING F/ 125K T/ 225KAND APPLY 1,200 PSI WITH PUMP. *UNABLE TO ESTABLISH CIRC. -BLEED OFF PRESSURE TO 0 PSI AND S/O TO NEUTRAL WEIGHT. CONDUCT PRE JARRING DERRICK II I INSPECTION. GOOD. -ATTEMPT TO JAR 5-1/2" COMPLETION FREE FROM JET CUT AT 8,889' WLM, WITH NO SUCCESS. *FIRE JARS IN 25K INCREMENTS FROM 75-225KAND WORKING OVER-PULLS IN INCREMENTS OF 10-15K TO 265K OVER; WORK UNDER PRESSURE FROM 500-1500 PSI. *UNABLE TO ESTABLISH CIRC. -CONDUCT POST JARRING INSPECTION. GOOD. 16:00 - 17:30 1.50 FISH P DECOMP DISENGAGE 8-1/8" S150 OVERSHOT BHA#6. -DISENGAGE 8-1/8" OVERSHOT FROM 5-1/2" STUB AT 3,330'. -10 MIN FLOW CHECK. WELL STABLE. -POOH WITH 8-1/8" OVERSHOT BHA F/ 3,330' 'T/ 250'. 17:30 - 18:30 1.00 FISH r P DECOMP LAY DOWN 8-1/8" S150 OVERSHOT BHA #6. -10 MIN FLOW CHECK FOR NON-SHEARABLES ACROSS BOPE. -POOH F/ 250' AND L/D 8-1/8" OVERSHOT BHA. -CLEAN AND CLEAR RIG FLOOR OF OVERSHOT BHA. 18:30 21:30 3.00 FISH P DECOMP RIG UP SLB E-LINE EQUIPMENT. -PJSM WITH E-LINE CREW. R/U E-LINE EQUIPMENT. -CLEAR RIG FLOOR OF PERSONNEL WHILE E-LINE CREW SURFACE TEST E-LINE TOOLS AND ARM JET CUTTER. **TABLE TOP CAMP EVACUATION DRILL.** 21:30 - 00:00 2.50 FISH P DECOMP RUN IN HOLE WITH SLB 4.15" JET CUTTER ON E-LINE AND CUT 5-1/2" COMPLETION. -PJSM WITH SLB E-LINE CREW. -M/U AND RIH WITH JET CUTTER ON E-LINE TO 8,550' ELM. -CORRELATE JET CUTTER ON DEPTH. -JET CUT 5-1/2" COMPLETION AT 8,494' ELM. *INDICATION JET CUTTER FIRED. -POOH WITH E-LINE F/ 8,494' ELM T/ 200'. Printed 10/13/2014 1:19:52PM North America - ALASKA - BP Page 15 of 79 Operation Summary Report Common Well Name: 01-02 AFE No Event Type: WORKOVER (WO) Start Date: 8/25/2014 End Date: X4 -0103J -E: (6,000,000.00 ) Project: Prudhoe Bay Site: PB DS 01 Rig Name/No.: DOYON 14 Spud Date/Time: 1/17/1970 12:00:00AM Rig Release: 10/4/2014 Rig Contractor: DOYON DRILLING INC. _UW: 500292005300 Active datum: 4: 02 1/17/1970 00:00 @73.00usft (above Mean Sea Level) Date From - To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (usft) 9/2/2014 00:00 - 01:00 1 1.00 FISH P DECOMP RIG DOWN SLB E -LINE EQUIPMENT. -PJSM WITH SLB E -LINE CREW. -CLEAR RIG FLOOR OF PERSONNEL, FOR E -LINE CREW TO VERIFY AND ENSURE JET CUTTER SPENT. -POOH WITH E -LINE F/ 200' ELM T/ SURFACE. -SLB E -LINE CREW VERIFIED JET CUTTER SPENT. -CLEAR RIG FLOOR OF SLB E -LINE TOOLS AND EQUIPMENT. -R/D SLB E -LINE EQUIPMENT. 01:00 - 02:00 1.00 FISH P DECOMP ' RIG DOWN DUTCH RISER SYSTEM. -PJSM. -R/D DUTCH RISER, BOLDS ON DUTCH RISER -AND OPEN ANNULAR PREVENTER. -BLOW DOWN TCHOKE AND KILL LINES. 02:00 - 03:30 1.50 FISH P DECOMP MAKE UP 6-1/8" S150-DVERSHOT BHA#7. -PJSM WITH BAKER REP. -P/U, M/U AND RIH WITH 8-1/8" OVERSHOT BHA TO 232'. 03:30 - 05:00 1.50 FISH P DECOMP RUN IN HOLE WITH 8-1/8" S150 OVERSHOT BHA #7. -RIH WITH 8-1/8" OVERSHOT BHA F/ 229'T/ 3,271'. -ESTABLISH PARAMETERS. 'PUW= 112K, SOW= 112K, RTW-- 112K, RPMs-- 50 WITH 1 K TORQUE 05:00 - 07:30 2.50 FISH _ P; DECOMP RUN IN HOLE WITH 8-1/8' 5150 OVERSHOT BHA#7 AND ENGAGE 5-1/2" COMPLETION STUB. -PJSM WITH BAKER REP. -RIH WITH 8-1/8" OVERSHOT BHA F/ 3,271' AND ENGAGE 5-1/2" STUB AT 3,330'. -STACK 5K ON FISH, P/U ENGAGE OVERSHOT - PULL 15K OVER, FISH NOT FREE, SLACK OFF - PULL 70 K OVER, FIRE JARS, FISH NOT FREE, SLACK OFF - PULL 100K OVER, FIRE JARS, FISH NOT FREE, SLACK OFF - PULL 135K OVER, FIRE JARS, FISH NOT FREE, SLACK OFF - PULL 185K OVER, FIRE JARS, FISH NOT FREE, SLACK OFF - CONTINUE JARRING ON FISH, PULLING TO MAX PULL 375K, NO SUCCESS - ATTTEMPT TO CIRCULATE AT 500 PSI, STRING PRESSURED UP - HELD PRESSURE AT 375 PSI, BLEED PRESSURE OFF - CONTINUE JARRING ON FISH, PULLING TO MAX OVERPULL 375K 07:30 - 09:00 1.50 FISH P DECOMP DERRICK INSPECTION - HOLD PJSM - INSPECT DERRICK FOLLOWING JARRING ACTIVITY - NO ISSUES, DERRICK DECLARED SAFE TO CONTINUE OPERATION Printed 10/13/2014 1.19:52PM North America - ALASKA BP Operation Summary Report r wv�, Common Well Name: 01-02 AFE No Event Type: WORKOVER (WO) Start Date: 8/25/2014 End Date: X4 -0103J -E: (6,000,000.00 ) Project: Prudhoe Bay Site: PB DS 01 Rig Name/No.: DOYON 14 Spud Date/Time: 1/17/1970 12:00:00AM Rig Release: 10/4/2014 Rig Contractor: DOYON DRILLING INC. UWI: 500292005300 Active datum: 4: 02 1/17/1970 00:00 @73.00usft (above Mean Sea Level) Date From - To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) ----L (usft) - - 09:00 - 11:00 2.00 FISH P DECOMP POOH W/ 8-1/8" OVERSHOT BHA #7 - PJSM - RELEASE GRAPPLE ON FISH - POOH F/ 3330'T/ 3271', RACK STAND IN DERRICK - BLOW DOWN TOP DRIVE -CONTINUE POOH F/ 3271' T/ 326' 11:00 - 13:00 2.00 FISH P DECOMP LAY DOWN 8-1/8" OVERSHOT BHA#7 MONITOR WELL FOR 10 MINUTES, STATIC STAND BACK 2 STDS OF DC - LAY`DOWN BHA 13:00 - 14:30 1.50 FISH P DECOMP SLIP AND CUT DRILLING LINE 14:30 - 15:00 0.50 FISH P DECOMP LUBRICATE RIG R/U E -LINE 15:00 - 17:30 2.50 FISH P DECOMP - PJSM - RIG UP WIRE LINE FOR SCMT LOGGING RUN TABLE TOP WELL CONTROL DURING WIRE LINE OPERATIONS 17:30 - 23:00 5.50 FISH P DECOMP RIH W/ SCMT LOGGING TOOL - LOG F/ 8475'T/ 3300' - RUN BACK IN HOLE W/ SCMT TOOL T/ 8475' - REPEAT LOG F/ 8475' T/ 7670' - RESTRICTIONS BEHIND TUBING INDICATED ON LOG F/ 8000'T/ 7850' - CONTACT ODE, E -LINE SME, DISCUSS LOG RESULTS - AGREE TO CUT TUBING V TO 10' BELOW COLLAR AT 7677' _ 23:00 - 00:00 1.00 FISH P DECOMP L/D SCMT LOGGING TOOL 9/3/2014 00:00 - 00:30 0.50 FISH P DECOMP COMPLETE L/D SCMT LOGGING TOOL. P/U 4.15" JET CUTTER. 00:30 - 01:00 0.50 FISH P DECOMP ARM JET CUTTER. - PJSM W/ SLB. - CLEAR RIG FLOOR, BOP DECK, CELLAR. - MAKE ANNOUNCEMENT OVER INTERCOM AND HARMONY TO STAY CLEAR OF RIG. - ARM JET CUTTER. 01:00 - 02:30 1.50 FISH P DECOMP CUT 5.5" TUBING. - RIH W/ JET CUTTER T/ 7900'. - P/U T/ CUTTING DEPTH @ 7683'. - CORRELATE CCL WITH ORIGINAL SLB LDL DATED 10/05/2012, ADJUST LOG 5' HIGHER. - RIH W/ JET CUTTER T/ 7900'. - PIU T/ CUTTING DEPTH aQ 7683', VERIFY LOG IS ON DEPTH WITH ORIGINAL LDL. - FIRE JET CUTTER, GOOD INDICATION AT SURFACE OF SUCCESSFUL FIRING. 02:30 - 03:30 1 1.00 FISH P DECOMP POOH W/ JET CUTTER. - MONITOR WELL, STATIC. - POOH F/ 7683' T/ 200'. 03.30 04:30 1.00 FISH P DECOMP L/D JET CUTTER. - PJSM W/ SLB. - CLEAR RIG FLOOR, BOP DECK, CELLAR. - MAKE ANNOUNCEMENT OVER INTERCOM AND HARMONY TO STAY CLEAR OF RIG. - GOOD VERIFICATION JET CUTTER FIRED. - L/D JET CUTTER. 04:30 - 05:00 0.50 FISH P DECOMP HOLD PJSM AND RIG DOWN DUTCH RISER. Printed 10/13/2014 1:19:52PM North America - ALASKA - BP Page 17 of 79 Operation Summary Report Common Well Name: 01-02 AFE No Event Type: WORKOVER (WO) Start Date: 8/25/2014 End Date: X4 -0103)-E: (6,000,000.00 ) � - - I Project: Prudhoe Bay Site: PB DS 01 Rig Name/No.: DOYON 14 Spud Date/Time: 1/17/1970 12:00:OOAM Rig Release: 10/4/2014 Rig Contractor: DOYON DRILLING INC. UVW 500292005300 Active datum. 4:02 1/17/1970 00:00 @73.00usft (above Mean Sea Level) Date From - To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (usft) 05:00 - 05:30 0.50 FISH P DECOMP HOLD PJSM AND BLOW DOWN CHOKE AND KILL LINES. CONDUCT SPILL DRILL. 05:30 - 07:00 1.50 FISH P DECOMP P/U 8-1/8" OVERSHOT BHA#8. MOVE SLB E -LINE TRUCK CLEAR OF BEAVER SLIDE. BRING FISHING TOOLS TO RIG FLOOR. - PJSM W/ BAKER FISHING REP. - P/U 8-1/8" OVERSHOT BHA#8 F/ SURFACE T/ 231'. RIH. PJSM. 07:00 - 08:00 1.00 FISH P DECOMP RIH F/ 231'T/ 3271'. 08:00 - 09:30 1.50 FISH P DECOMP OBTAIN PARAMETERS PRIOR TO ENGAGING FISH. UP WT - 112K, DN WT - 112K. SPR MUD PUMP #1, 20 SPM - 30 PSI, 30 SPM - 60 PSI. SPR MUD PUMP #2, 20 SPM - 30 PSI, 30 SPM 60 PSI. -RIH AND TAG FISH AT 3300', STACK 1 OK ON FISH. PULL 65K OVER DRILL STRING WEIGHT AND LET JARS BLEED OPEN. -PULL 90K OVER DRILL STRING WEIGHT AND ATTEMPT TO CIRCULATE, STRING PRESSURED UP TO 500 PSI. -PULL 105K OVER DRILL STRING WEIGHT, OBSERVED PIPE MOVEMENT INDICATING FISH MOVEMENT AT 25K OVER ANTICIPATED WEIGHT. CONTINUE TO WORK STRING. -CONTINUE WORKING STRING WHILE ATTEMPTING TO CIRCULATE, PRESSURE UP TO 1000 PSI AND ESTABLISH SMALLAMOUNT OF CIRCULATION BUT COULD NOT MAINTAIN CIRCULATION. SHUTDOWN PUMP AND NO BLEED OFF OF PRESSURE OBSERVED. -DISCUSS OPTIONS WITH ODE AND AGREE ON PLAN FORWARD TO PUMP OUT OF HOLE UNTIL RETURNS ESTABLISHED. -PUMP OUT OF HOLE F/ 7683'T/ 7233'. AT 7233' RETURNS OBSERVED AND PRESSURE DECREASING. - INITIAL CIRCULATION RATE 1 BPM AT 500 TO 1000 PSI. - ESTABLISH CIRCULATION RATE OF 8 BPM AT 500 PSI OVER THE COURSE OF 40 BBLS. 09:30 - 10:00 0.50 FISH P DECOMP PUMP 30 BBL HI VIS SWEEP AT 8 BPM, 420 PSI - SMALLAMOUNT OF GAS BREAKOUT AT SURFACE WITH NO GAIN IN VOLUME. - ARCTIC PACK SLUDGE RETURNS TO SURFACE AT BOTTOMS UP STROKE FROM INTITIAL ESTABLISHMENT OF CIRCULATION CLOGGING SURFACE EQUIPMENT. - SHUT DOWN PUMPS, WELL STATIC. 10:00 - 14:00 4.00 FISH P DECOMP CLOSE BAG AND FLUSH AND CLEAN FLOW LINE, RISER AND SHAKER TROUGH. -SERVICE RIG WHILE CLEANING FLOW LINE. Printed 10/13/2014 1:19:52PM North America -ALASKA BP;;' 11 Page 18 or 79 rrr Operation Summary Report Common Well Name: 01-02 AFE No Event Type: WORKOVER (WO) Start Date: 8/25/2014 End Date: X4 -0103J -E: (6,000,000.00 ) Project: Prudhoe Bay Site: PB DS 01 Rig Name/No.: DOYON 14 Spud DateTme: 1/17/1970 12:00:OOAM Rig Release: 10/4/2014 Rig Contractor: DOYON DRILLING INC. LIN: 500292005300 Active datum: 4: 02 1/17/1970 00:00 Q73.00usft (above Mean Sea Level) Date From - To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (usft) - — 14:00 - 16:00 2.00 FISH P DECOMP CIRCULATE OUT ARCTIC PACK. - LINE UP TO FLOW BACK TANK THROUGH SKID MOUNTED CHOKE. -REVIEW PRESSURE CROSS CHECK LIST. INITIAL CIRCULATION RATE 7.5 BPM AT 800 PSI. -RETURNS FREE OF ARCTIC PACK WITH SWEEP OUT OF HOLE. - FINAL CIRCULATION RATE 7.5 BPM AT 730 PSI. SHUT DOWN PUMPS. -MONITOR RETURNS WELL STATIC. -LINE UP TO RIG CHOKE AND FLUSH CIRCULATION PATH WITH SEAWATER. -MONITOR WELL, WELL STATIC AND NO PRESSURE OBSERVED. -OPEN ANNULAR PREVENTER. -PUMP 10 BBLS WHILE RECIPROCATING PIPE TO CLEAR BOPS OF ARCTIC PACK 16:00 - 16:30 0.50 FISH P DECOMP POOH F/ 7233' T/ 7050' WITH PJSM WITH CREW. L - UP WT 180K, DN WT 160K. 16:30 - 18:00 1.50 FISH N RREP 4,600.0¢ DECOMPCODE 8 REPAIR AIR LINE ON DRAWWORKS LOW DRUMCLUTCH - - - - - - - 18:00 - 20:30 2.50 FISH P DECOMP 1 POOH F/ 7050'T/ 4353' - MONITOR WELL 10 MINUTES PRIOR TO PULLING BHA TROUGH STACK, STATIC - STAND COLLARS BACK IN DERRICK BREAKOUT OVERSHOT AND CUT JOINT 20:30 - 22:00 1.50 AND L/D IN PIPE SHED FISH P DECOMP �RI—HVA TH RTTS PJSM WITH HES REP SET RTTS TWO STANDS BELOW ROTARY TABLE ;- UNSTING FROM STORM VALVE, 22 TURNS TO THE LEFT POOH W/ RUNNING TOOL, WRAP STINGER IN ADSORB AND L/D ON RIG FLOOR - - - -- -T - - -- 22:00 23:30 1.50 FISH P - DECOMP 'RIG UP TO TEST BOPE PERFORM KICK WHILE TRIPPING DRILL PUMP THROUGH GAS BUSTER, 6 BBLS TO --- - FILL 23:30 - 00:00 0.50 FISH P DECOMP TEST BOPE - TEST WITNESS WAIVED BYAOGCC, JOHNNIE HILL PERFORM 250 PSI LOW, 3500 PSI HIGH BODY TEST - SMALL LEAK AT TEST PLUG - BLEED PRESSURE TO ZERO, LOOSEN GLAND NUTS, TIGHTEN LOCK DOWN SCREWS, TORQUE GLAND NUTS Printed 10/13/2014 1:19:52PM North America - ALASKA BP Operation Summary Report ' Common Well Name: 01-02 AFE No Event Type: WORKOVER (WO) Start Date: 8/25/2014 End Date: X4 -0103J -E: (6,000,000.00) Project: Prudhoe Bay Site: PB DS 01 Rig Name/No.: DOYON 14 Spud Date/Time: 1/17/1970 12:00:00AM Rig Release: 10/4/2014 Rig Contractor: DOYON DRILLING INC. UWI: 500292005300 Active datum: 4: 02 1/17/1970 00:00 @73.00usft (above Mean Sea Level) Date From - To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (usft) 9/4/2014 00:00 - 08:00 8.00 ----FISH P DECOMP TEST BOPE TEST WITNESS WAIVED BYAOGCC, JOHNNIE HILL. PUMP UP SENSATOR ATTEST PUMP. PEFORM BODY TEST, GOOD. RESUME BOP TEST WITH 4" TEST JOINT, 250 PSI LOW/ 3500 PSI HIGH FOR 5 MINUTES EACH. TEST ANNULAR WITH 4" TEST JOINT. TEST VBR'S WITH 4" AND 5-1/2" TEST JOINT. TEST UPPER RAMS WITH 9-5/8" TEST JOINT. 08:00 - 09:00 1.00 FISH P DECOMP RIG DOWN TEST EQUIPMENT - BACK OUT LOCK DOWNS ON TEST PLUG AND RE -TIGHTEN GLAND NUTS. SUCK OUT BOP STACK. BLOW DOWN CHOKE LINE, CHOKE MANIFOLD, AND KILL LINE. "WSL VERIFY PROPER POSITIONING AND TORQUE ON LOCK DOWNS. 09:00 10:00 1.00 FISH P DECOMP MAKE UP SAFETY JOINT AND LID IN PIPE SHED. SIMOPS, MOBILIZE 5-1/2" UHT STACK TONGS TO RIG FLOOR. 4 'RETRIEVE 10:00 - 12:00 2.00 FISH P 1 DECOMP RTTS PJSM WITH HES REP. MAKE UP RTTS RETRIEVAL TOOL WITH STINGER. - P/U TWO STANDS FROM DERRICKAND RIH, MAKE UP FOSV ON TOP OF LAST STAND AND CLOSE. MANUALLY TURN THE PIPE 22 TURNS TO THE RIGHT TO STING INTO STORM VALVE AND OPEN SAME. - VERIFY NO PRESSURE IN THE DRILL PIPE, 0 PSI. VERIFY NO PRESSURE ON BACK SIDE, M/U TOP DRIVE AND CLOSE ANNULAR, STRIP UP AND RELEASE PACKER, UP WT 145K. ANNULUS PRESSURE 0 PSI. - OPEN ANNULAR AND RIG DOWN FOSV, LET ELEMENT RELAX ON RTTS. - POOH WITH TWO STANDS F/ 4533'T/ 4353' AND BREAK OUT RTTS AND RETRIEVAL TOOL. P DECOMP LUBRICATE RIG 12:00 - 12:30 0.50 FISH 12:30 - 13:00 0.50 FISH P DECOMP RIG UP TO LAY DOWN TUBING. RIG UP STACKED TONGS TO RUN 5-1/2" TUBING. UD RTTS IN PIPE SHED AND SEND OUT DOOR WITH HES REP. 13:00 - 18:00 5.00 FISH P DECOMP POOH POOH F/ 4353'T/ SURFACE. '- UP WT 115K, DN WT 11 OK. TUBING COVERED WITH ARCTIC PACK FILM, DOUBLE UP STRIPPER RUBBERS TO HELP WIPE PIPE CLEAN. - 167 EACH FULL JTS OF 5-1/2" TUBING AND 2 EACH CUT JOINTS OF 5-1/2" TUBING RECOVERED, TOP CUT JOINT LENGTH 22.55', BOTTOM CUT JOINT LENGTH 6.95'. CONDUCT FIRE DRILL. -� Printed 10/13/2014 1.19:52PM fi Pa e 20 of 79 North America -ALASKA - BP y Operation Summary Report"' Common Well Name: 01-02 AFE No Event Type: WORKOVER (WO) Start Date: 8/25/2014 End Date: X4 -0103J -E: (6,000,000.00 ) Project: Prudhoe Bay Site: PB DS 01 Rig Name/No.: DOYON 14 Spud Date/Time: 1/17/1970 12:00:OOAM Rig Release: 10/4/2014 Rig Contractor: DOYON DRILLING INC. UN: 500292005300 Active datum: 4: 02 1/17/1970 00:00 @73.00usft (above Mean Sea Level) Date From - To Hrs I Task Code 1 NPT NPT Depth Phase Description of Operations �- (hr) - -- (--ft) 18:00 - 20:00 2.00 FISH P DECOMP CLEAN AND CLEAR FLOOR LAY DOWN TUBING TONGS. MOBILIZE 8-1/8" WASHOVER BHA COMPONENTS TO RIG FLOOR. _ 20:00 21:00 1.00 FISH P DECOMP LAY DOWN REMAINING 8-1/8" OVERSHOT BHA COMPONENTS PJSM ON BREAKING FISH OUT OF OVERSHOT. P/U OVERSHOT WITH TOP CUT JOINT FROM PIPE SHED, CLOSE BLINDS AND SET IN ROTARY TABLE. - M/U TOP DRIVE TO OVERSHOT AND BACK UP 5-1/2" TUBING WITH RIG TONGS, ROTATE TO THE RIGHT AND P/U TOP DRIVE TO BREAK OUT FISH FROM OVERSHOT. I SIMOPS FLUSH FLOWBACK TANK WITH HEATED FRESH WATER AND SUCK OUT WITH CUSCO _ VAC TRUCKS. 21:00 00:00 3.00 FISH P DECOMP PICK UP 8-1/8" WASHOVER BHA RIH F/ SURFACE T/ 682'. P/U BHA#9 WASHOVER ASSEMBLY, 15 JTS OF 8-1/8" WASHPIPE, MAKE UP WASHPIPE BY HAND AND TORQUE WITH RIG TONGS. SIMOPS FINISH EMPTYING CUTTINGS TANKAT2400 HRS. CONTINUE FLUSH FLOWBACK TANK WITH HEATED FRESH WATER AND SUCK OUT WITH CUSCO VAC TRUCKS. 9/5/2014 00:00 - 06:30 6.50 FISH P DECOMP RIH WITH 8-1/8" WASHOVER BHA - RIH F/ 682'T/ 5659'. - UP WT 175K, DN WT 135K. RUN 23 STDS OUT OF DERRICK, P/U 113 JOINTS OUT OF PIPE SHED, DRIFT ALL JOINTS OFF PIPE SKATE TO 2.40" FOR PUMP OUT SUB DART. - VERIFY PROPER HOLE FILL WITH TRIP SHEET, NO DISCREPANCIES. I SIMOPS - COMPLETE FLOWBACK TANK FLUSH AT 0400 HRS. 06:30 07:00 0.50 FISH P DECOMP CIRCULATE - OBSERVED PICK UP AND SLACK OFF WEIGHTS TRENDING APART, DETERMINED THIS TO BE CAUSED BY EMULSFIED ARCTIC 'PACK STICKING TO 8-1/8" OD WASH PIPE. M/U TOP DRIVE AND ESTABLISH CIRCULATION, BRING PUMPS UP TO 8 BPM, 900 PSI FOR 300 STKS TOTAL. - RECIPROCATE AND ROTATE PIPE WHILE PUMPING, UP WT 165K, DN WT 150K, ROT WT 160K, TQ 3K. OBSERVED HOLE CLEANING UPAS WELL AS PICK UP AND SLACK OFF WEIGHTS TRENDING BACK TO EXPECTED. SHUT DOWN PUMPS, BREAK OUT TOP - DRIVE TO CONTINUE RIH. Printed 10/13/2014 1:19:52PM North America -ALASKA BP f; , f, �r' �_« r ?�, 9 Operation Summary Report' Common Well Name: 01-02 AFE No Event Type: WORKOVER (WO) Start Date: 8/25/2014 End Date: X4 -0103J -E: (6,000,000.00 ) Project: Prudhoe Bay Site: PB DS 01 Rig Name/No.: DOYON 14 Spud Date/Time: 1/17/1970 12:00:OOAM Rig Release: 10/4/2014 Rig Contractor: DOYON DRILLING INC. UN: 500292005300 Active datum: 4: 02 1/17/1970 00:00 @73.00usft (above Mean Sea Level) Date From - To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (usft) RIH 07:00 - 08:00 1.00 FISH P DECOMP - CONTINUE RUNNING IN HOLE F/ 6471'T/ 6855' PICKING UP SINGLES OUT OF THE PIPE SHED. - DRIFTALL JOINTS OFF PIPE SKATE TO 2.40" FOR PUMP OUT SUB DART. 08:00 - 08:30 0.50 FISH P DECOMP OBTAIN FISHING PARAMETERS AND SLOW PUMP RATES PRIOR TO WASHING OVER -MUD PUMP #1 SPR, 20 SPM AT 80 PSI, 30 SPM AT 160 PSI. MUD PUMP #2 SPR, 20 SPM AT 78 PSI, 30 SPM AT 160 PSI. - BREAK CIRCULATION AND BRING PUMPS UP TO 8 BPM, 980 PSI, PUMP 400 STKS TOTAL. UP WT 165K, DN WT 150K, ROT WT 155K, 20 RPM, TQ 2-3K. SHUT DOWN PUMPS, BREAK OUT TOP DRIVE TO CONTINUE RIH. - 08:30 09:00 0.50 FISH P t DECOMP RIH -CONTINUE RUNNING IN HOLE F/ 6855'T/ 7235PICKING UP SINGLES OUT OF THE PIPE SHED. PICKUP 138 JOINTS TOTAL FROM PIPE SHED. DRIFT ALL JOINTS OFF PIPE SKATE TO 2.40" FOR PUMP OUT SUB DART. 09:00 - 13:00 4.00 FISH P DECOMP ' WASH OVER FISH WASH OVER FISH PICKING UP STANDS OUT OF THE DERRICK. WASH F/ 7235'T/ 7690' AT 7.4 BPM, 880 PSI, 20 RPM, TQ 2-3K, WOB 1-2K, UP WT 165K, DN WT 150K, ROT WT 155K. - TAG TOP OF 5-1/2" TUBING STUMP AT 7690', SET 5K ON FISH AND THEN PICKED BACK UP V AND INCREASED ROTARY TO 30 RPM. OBSERVED GUIDE SHOE SWALLOW 5-1/2" TUBING STUMP. CONTINUE TO WASH DOWN OVER FISH F/ :7690'T/ 7780 AT 7.4 BPM, 900 PSI, 20 RPM. - OBSERVED INCREASE IN WOB OF 1-2K, INCREASED TOP DRIVE RPM TO 30 RPM TO HELP CLEAN UP HOLE, TQ 3-4K, WOB 3-4K. CONTINUE WASH DOWN OVER FISH F/ 7780' T/ 8089' AT 7.4 BPM, 940 PSI, 30 RPM, TQ 2-4K, WOB 3-4K. Printed 10/13/2014 1.19:52PM North America -ALASKA BP,,„ s f%cru„ Page 22 of 79 Operation Summary Report Common Well Name: 01-02 AFE No Event Type: WORKOVER (WO) Start Date: 8/25/2014 End Date: X4 -0103J -E: (6,000,000.00 ) Project: Prudhoe Bay Site: PB DS 01 Rig Name/No.: DOYON 14 Spud Date/Time: 1/17/1970 12:00:OOAM Rig Release: 10/4/2014 Rig Contractor. DOYON DRILLING INC. UWI: 500292005300 Active datum: 4: 02 1/17/1970 00:00 @73.00usft (above Mean Sea Level) Date From - To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (usft) I _ 13:00 - 15:00 2.00 FISH P DECOMP •, WASH OVER FISH - PUMP 100 BBLS OF 120 DEGREE 8.5 PPG SEAWATER FOLLOWED BY 30 BBL HI -VIS SWEEP, 6 BPM, 940 PSI. LARGE AMOUNTS OF ARCTIC PACKAT BOTTOMS UP, LET ARCTIC PACK RUN OFF ENDS OF SHAKERS TO CUTTINGS TANK - WASH DOWN OVER FISH WITH NO ROTATION F/ 8089', TAG TOP OF FISH WITH WASH OVER BOOT BASKET AT 8140'. SET 10K ON TOP OF FISH TO VERIFY TOP OF STUMP DEPTH, OBSERVED NO WASH OFF TOP OF FISH AT 8140'. PICK UP OFF TOP OF FISH AND ROTATE AND RECIPROCATE WHILE CIRCULATING HOLE CLEAN. RECIPROCATE PIPE 30', 6 BPM, 940 PSI, 30 RPM, TO 3-4K, UP WT 200K, DN WT 150K. CONTINUE TO SEE ARCTIC PACKAT SURFACE. 15:00 - 17:00 2.00 FISH P DECOMP POOH - POOH F/ 8140'T/ 7804, OBSERVED SWABBING WITH OVERPULL OF 10-15K. M/U TOP DRIVE, PUMP OUT OF HOLE F/ '7804'T/ 6855' AT 1 BPM, OBSERVED INCREASED OVERPULL OF 25-30K AND INCREASED PUMP PRESSURE. 17:00 - 21:00 4.00 FISH P DECOMP CIRCULATE TO CLEAN UP WELL BORE - WORK THROUGH TIGHT SPOT AT 6855', PULL UP TO 175-190K, BRING PUMP ON AT 1-2 BPM WHILE CONTINUING TO WORK PIPE. CONTINUE TO WORK PIPEAND SLOWLY INCREASE PUMP RATE UP TO 7 BPM, 700 PSI. AT 7 BPM UP WT 175K AND DN WT 145K. - LARGE AMOUNTS OF ARCTIC PACK BACK TO SURFACE AT BOTTOMS UP. DECREASE PUMP RATE TO 5 BPM, 400 PSI TO PREVENT EXCESSIVE FLUID LOSS OVER SHAKERS. - MIX DEEP CLEAN SWEEP AND PUMP SURFACE TO SURFACE AT 5 BPM, 400 PSI, OBSERVED SLIGHT DECREASE IN ARCTIC PACK BACK TO SURFACE. - SHUT DOWN PUMPS AND OBTAIN UP AND DOWN WEIGHTS, UP WT 175K, DN WT 145K. 21:00 - 22:00 1.00 FISH P DECOMP POOH - MONITOR WELL FOR 10 MINUTES, STATIC. - POOH F/ 6855'T/ 5800'. - OBSERVED SWABBING AT 5800', STOPPED PULLING OUT OF HOLE. 22:00 - 22:30 0.50 FISH P DECOMP CIRCULATE TO VERIFY HOLE FULL - M/U TOP DRIVE AND CIRCUALTE 40 BBLS, SHUT PUMPS DOWN AND ATTEMPT TO PULL ON ELEVATORS, OBSERVED SWABBING. - DECREASED AMOUNTS OF ARCTIC PACK STRUNG OUT IN RETURNS WHILE PUMPING. - LINE UP TO PUMP OUT OF HOLE. 22:30 - 00:00 1.50 FISH P DECOMP PUMP OUT OF HOLE - PUMP OUT OF HOLE F/ 5800' T/ 4386', 4 BPM, 285 PSI, PULLING SPEED 40 FT/MIN. - SMALL AMOUNTS OF ARCTIC PACK IN RETURNS WHILE PUMPING. Printed 10/13/2014 1:19:52PM North America -ALASKA BPS ;» r Fes.,, ,f• -- Pagy r1 Operation Summary Report° Common Well Name: 01-02 AFE No Event Type: WORKOVER (WO) Start Date: 8/25/2014 End Date: X4 -0103J -E: (6,000,000.00 ) Project: Prudhoe Bay Site: PB DS 01 Rig Name/No.: DOYON 14 Spud Date/Time: 1/17/1970 12:00:OOAM Rig Release: 10/4/2014 Rig Contractor: DOYON DRILLING INC. UWI: 500292005300 Active datum: 4: 02 1/17/1970 00:00 @73.00usft (above Mean Sea Level) Date From - To Hrs Task Code NPT NPT Depth ! Phase Description of Operations (hr) (usft) 9/6/2014 00:00 - 00:30 0.50 FISH P DECOMP SERVICE RIG. 00:30 - 03:00 2.50 FISH P DECOMP PUMP OUT OF HOLE - PUMP OUT OF HOLE F/ 4386' T/ 2645', 4 BPM, 380 PSI, PULLING SPEED 40 FT/MIN. - UP WT 135K, ON WT 115K. - SMALL AMOUNTS OF ARCTIC PACK IN _RETURNS. 03:00 - 04:00 1.00 FISH P DECOMP PUMP OUT OF HOLE - PUMP OUT OF HOLE F/ 2645' T/ 1977',4 BPM, 360 PSI, PULLING SPEED 40 FT/MIN. - FLOW LINE STARTED PACKING OFF WITH ARCTIC PACK, STOP POOH AND JET FLOW LINE AND POSSUM BELLY. INSPECT DRIP PAN TO VERIFY DRAINING PROPERLY. 04:00 - 05:00 1.00 FISH P DECOMP PUMP OUT OF HOLE - PUMP OUT OF HOLE F/ 1977' T/ 1636',4 BPM, 340 PSI, PULLING SPEED 40 FT/MIN. FLOW LINE STARTED PACKING OFF WITH ARCTIC PACK, STOP POOH AND JET FLOW LINE AND POSSUM BELLY. INSPECT DRIP PAN TO VERIFY DRAINING PROPERLY. 05:00 - 06:30 1.50 FISH P DECOMP PUMP OUT OF HOLE PUMP OUT OF HOLE F/ 1636'T/ 1,347', 4 BPM, 320 PSI, PULLING SPEED 40 FT/MIN. - FLOW LINE AND DRIP PAN PACKING OFF WITH ARCTIC PACK. -JET FLOWLINE AND CLEAN DRIP PAN, CLEAN AND CLEAR RIG FLOOR TO AVOID TRACKING ARCTIC PACK RESIDUE THROUGHOUT THE RIG. FISH P DECOMP MAKE UP DEEP KLEEN SWEEP TO 06:30 10:00 3.50 CIRCULATE. - - MOVE FLUID IN PITS AND MIX 80 BBL DEEP KLEEN SWEEP WITH 120 DEGREE 8.5 PPG SEAWATER. - LINE UP CHOKE SKID TO TAKE RETURNS FROM IA TO FLOW BACK TANK. - PJSM, REVIEW PRESSURE CROSSCHECK CHECKLIST, VERIFY RADIO COMMUNICATION BETWEEN RIG FLOOR AND CHOKE SKID OPERATOR. - CLOSE ANNULAR. - PUMP 80 BBL DEEP KLEEN SWEEP, 5.5 BPM, 400 PSI DOWN DP, TAKE RETURNS OUT IATO FLOW BACK TANK - PUMP 30 BBLS 120 DEGREE 8.5 PPG SEAWATER, 5.5 BPM, 400 PSI DOWN DP, TAKE RETURNS OUT IA TO FLOW BACK TANK. - SHUT DOWN PUMPS AND CLOSE IA VALVE. SIMOPS - CONTINUE TO CLEAN RIG FLOOR AND SURFACE EQUIPMENT. Printed 10/13/2014 1:19:52PM Printed 10/13/2014 1:19:52PM North America -ALASKA - BP ; .ae 2d`fi►= Operation Summary Report , Common Well Name: 01-02 AFE No Event Type: WORKOVER (WO) Start Date: 8/25/2014 End Date: jX4-0103J-E: (6,000,000.00) Project: Prudhoe Bay Site PB DS 01 Rig Name/No.: DOYON 14 Spud Date/Time: 1/17/1970 12:OO:OOAM Rig Release: 10/4/2014 Rig Contractor: DOYON DRILLING INC. UWI: 500292005300 Active datum: 4: 02 1/17/1970 00:00 @73.00usft (above Mean Sea Level) Date From - To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) -- _ (usft) -LIP 10:00 13:00 3.00 FISH P 11 DECOMP RIG TLE REDP LIT(LRS) TO PUMP. - PJSM, REVIEW PRESSURE CROSSCHECK CHECKLIST, RIG UP AND TEST LRS LINES 250 i PSI LOW/ 3000 PSI HIGH FOR 5 MIN / 5 MIN. LRS PUMP 50 BBLS 120 DEGREE DIESEL DOWN DP, 2 BPM, 560 PSI. RIG PUMP 30 BBLS 8.5 PPG DEEP KLEEN SWEEP, 6 BPM, 440 PSI. LET DIESEL SOAK 1 HR. 13:00 - 14:00 1.00 FISH P DECOMP CIRCULATE DIESEL TO FLOW BACK TANK PJSM, REVIEW PRESSURE CROSSCHECK CHECKLIST. VERIFY RADIO COMMUNICATION BETWEEN RIG FLOOR, CHOKE SKID, AND FLOWBACK TANK. CIRCULATE 170 BBLS FOWN DP OUT IA TO I FLOW BACKTANK, 8 BPM, 1000 PSI. I MINUTES, -MONITOR WELL 10 WELL STATIC. - OPEN ANNULAR. - 14:00 15:00 1.00 FISH P DECOMP PULL OUT OF THE HOLE. PJSM, POOH FROM 1,347 TO 231'. - MONITOR WELL 10 MINUTES BEFORE PULLING NON SHEARABLES ACROSS STACK, !STATIC. - LAY DOWN INTENSIFIER. STAND DRILL COLLARS IN DERRICK. 15.00 18:00 3.00 FISH P DECOMP LAY DOWN BHA. - STAND BACK 3 STANDS OF 8-1/8" WASHPIPE IN DERRICK. LAY DOWN 6 JOINTS OF WASH PIPE INTO PIPESHED. STAND BACK LAST STAND OF WASHPPIPE IN DERRICK. 18:00 19:30J 1.50 FISH P DECOMP CLEAN AND CLEAR RIG FLOOR CLEAN REMAINING ARCTIC PACK OFF RIG FLOOR. - BRING BHA COMPONENTS FOR BHA#10, CASING SCRAPER / DRESS OFF SHOE TO FLOOR. _RIG 1 19:30 20:30 1.00 FISH P DECOMP PICK UP BHA#10 CASING SCRAPER / DRESS OFF SHOE PJSM PICKUP BHA #10 F/ SURFACE T/ 228' - 120:30 00:00 3.50 FISH P _4 DECOMP RIH WITH BHA#10 CASING SCRAPER / DRESS OFF SHOE RIH F/ 228'T/ 6401' - FILL PIPE EVERY 20 JOINTS 9/7/2014 100:00 - 00:30 0.50 FISH P DECOMP RIG SERVICE. LUBRICATE AND INSPECT TOP DRIVE, BLOCKS, DRAW WORKS AND IRON ROUGHNECK. t00:30 - 02:00 1.50 FISH P DECOMP RUN IN THE HOLE WITH CASING SCRAPER AND DRESS OFF BHA#10. PJSM, RIH F/6,401' T/ 7,635'. MAKE UP SINGLE FROM PIPESHED (JT #238). - RIH T/ 7,667'. Printed 10/13/2014 1:19:52PM Printed 10/13/2014 1:19:52PM North America - ALASKA - BP Page 25 of 79 Operation Summary Report Common Well Name: 01-02 AFE No Event Type: WORKOVER (WO) Start Date: 8/25/2014 End Date: X4 -0103J -E: (6,000,000.00 ) Project: Prudhoe Bay ;Site: PB DS 01 Rig Name/No.: DOYON 14 Spud Date(Tme: 1/17/1970 12:00:OOAM Rig Release: 10/4/2014 Rig Contractor: DOYON DRILLING INC. UWI: 500292005300 Active datum: 4: 02 1/17/1970 0000 @73.00usft (above Mean Sea Level) Date From - To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (usft) - -- 02:00 - 06:15 4.25 FISH P DECOMP PUMP DIESEL AND DEEP KLEEN SWEEP -PJSM WITH RIG CREW, LITTLE RED, AND CH2MHILL. REVIEW PRESSURE CROSSCHECK CHECKLIST. DISCUSS HAZARDS WITH MOVING FLUID, OFF LOADING AND BRINGING FLUID ON VAC TRUCKS. VERIFY COMMUNICATION AT HOT OIL TRUCK, CHOKE SKID, AND FLOW BACK TANK M/U HEAD PIN AND CLOSE ANNULAR LINE UP TO PRESSURE TEST, DOUBLE CHECK VALVE LINE UP WITH TOUR PUSHER AND DRILLER. PRESSURE TEST TO 250 PSI LOW / 2500 PSI HIGH FOR 5 MIN / 5 MIN, GOOD TEST. PUMP 100 BBL DIESEL WITH LITTLE RED, 1.4 j BPM, ICP 500 PSI, FCP 1040 PSI. TAKE RETURNS THROUGH SUPER CHOKE BACK TO PITS THROUGH GAS BUSTER. -SHUT IN LITTLE RED AND SWITCH TO RIG PUMP. -PUMP 81 BBL DEEP CLEAN SWEEP AT 2 BPM. ICP 730 PSI. FCP 500 PSI. �-SHUT IN WITH DIESEL ON BACKSIDE FOR 1 -- `HOUR. 06:15 - 12:00 5.75 FISH P DECOMP PUMP 443 BBLS OF 8.5 PPG 120 DEGREE SEAWATER. - CIRCULATE 2 BPM WITH 40 PSI DOWN THE - DRILL PIPE, TAKE RETURNS TO THE PITS. DIESEL RETURN TO SURFACE AFTER 96 BBLS PUMPED. SHUT DOWN AND TAKE RETURNS TO FLOW BACK TANK. RESUME CIRCULATION AT 2 BPM WITH 60 PSI. INCREASE PUMP RATE TO 14 BPM WITH 1480 PSI PUMP PRESSURE AND 450 PSI ON THE BACKSIDE. - PUMP ADDITIONAL BOTTOMS UP OF 445 BBLS. SHUT DOWN PUMPS. FLOW CHECK FOR 10 MINUTES- WELL STATIC. - OPEN ANNULAR AND CLOSE IA VALVES. - PUMP ADDITIONAL 15 BBLS TO CLEAN OUT BOPE STACK LAY DOWN SINGLE. Printed 10/13/2014 1:19:52PM North America - ALASKA - Bof 79 Operation Summary Report'" r Common Well Name: 01-02 AFE No Event Type: WORKOVER (WO) Start Date: 8/25/2014 End Date: X4 -0103J -E: (6,000,000.00 ) Project: Prudhoe Bay Site: PB DS 01 Rig Name/No.: DOYON 14 Spud Date/Time: 1/17/1970 12:00:OOAM Rig Release: 10/4/2014 Rig Contractor: DOYON DRILLING INC. UWI: 500292005300 Active datum: 4: 02 1/17/1970 00:00 @73.00usft (above Mean Sea Level) Date From - To Hrs Task I Code I NPT NPT Depth Phase Description of Operations (hr) (usft) 12:00 - 12:30 0.50 FISH P DECOMP DRESS OFF 5 1/2" TUBING STUMP AT 7,690'. -PJSM WITH BAKER REP. P/U STAND #79 AND BREAK CIRCULATION j AT 5 BPM, 300 PSI. - UP WT 175K, DN WT 165K, ROT 170K, TQ 2K, 30 RPM. - WASH DOWN AND TAG TUBING AT 7690', SET 8K ON FISH, PICK UP 5'. - WASH BACK DOWN TO FISH AT 30 RPM, ROTARY STALLED AT 7K TORQUE. - BACK TORQUE OUT, PICK UP 5'. - INCREASE ROTARY TO 40 RPM, REAM DOWN OVER STUMP PLUS Z. PICK UP 5', SHUT DOWN ROTARY, SLIDE OVER FISH TO FULL SWALLOW AT 7697', SET 10K ON FISH. PICK UP OFF FISH, 10K OVERPULL WITH SHOE AT TOP OF FISH. PICK UP S ABOVE FISH, SLACK OFF WITHOUT ROTARY OVER FISH, 5K DRAG !WHEN SHOE SWALLOWED FISH, CONTINUE SLACKING OFF TO FULL SWALLOW AT 7697'. PICK UP T ABOVE FISH, BRING ROTARY ON AT 30 RPM, REAM DOWN OVER FISH. PICK UP ABOVE FISH, SHUT DOWN ROTARY, WASH OVER AND PICK UP OVER FISH 3X'S WITHOUT ANY OVERPULL OR DRAG. 12:30 - 13:30 1.00 ' FISH ' P DECOMP CIRCULATE P/U 10' ABOVE FISH TO 7680'. -CIRCULATE BOTTOMS UP AT 12 BPM WITH 1370 PSI. - ROTATE AND RECIPROCATE AT 20 RPM. FLOW CHECK FOR 10 MINS, STATIC. 13:30 16:30 3.00 FISH P DECOMP PULL OUT OF THE HOLE PJSM, POOH FROM 7,690' TO BHA AT 225'. - MONITOR WELL 10 MINUTES AT BHA, STATIC. - 16:30 18:00 1.50 FISH P DECOMP j LAY DOWN DRESS OFF BHA #10. PJSM. RACK BACK 2 STANDS OF 6-1/8" DRILL COLLARS IN DERRICK. BREAK DOWN DRESS OFF AND CASING SCRAPER BHA#10. MAKE ANNOUNCEMENT TO CLEAR BEAVER SLIDE AREA, AND CLEAR DRESS OFF BHA yOFF FLOOR. 18:00 - 22:30 4.50 FISH P DECOMP PICK UP 8-1/8" OVERSHOT BHA#11. - PJSM, DISCUSSED USING STABBING PEG ON SUBS, PINCH HAZARDS STABBING DRILL COLLARS IN STUMP. BRING BHA COMPONENTS TO RIG FLOOR, MAKE ANNOUNCEMENT TO AVOID BEAVER SLIDE AREA. P/U BUMPER SUB, JARS, M/U GUIDE SHOE, OVERSHOTAND RIH. P/U 2 STANDS OF DRILL COLLARS, XO, INTENSIFIER, AND XO TO DRILL PIPE AND RIH. 2230 --00-.00 1.50 FISH P -RIH ON DP FROM DERRICK F/229' T/ 7,637'. DECOMP LIP AND CUT 59' OF DRILL LINE. I 1-',PJSM, WORKING AT HEIGHTS. Printed 10/13/2014 1:19:52PM North America - ALASKA BP �,• .r., r r, 'r r Operation Summary Reports"", Common Weil Name. 01-02 AFE No Event Type: WORKOVER (WO) Start Date: 8/25/2014 End Date: X4 -0103J -E: (6,000,000.00 ) Project: Prudhoe Bay Site: PB DS 01 Rig Name/No.: DOYON 14 Spud Date/Time: 1/17/1970 12:00:OOAM Rig Release: 10/4/2014 Rig Contractor: DOYON DRILLING INC. UWI: 500292005300 Active datum: 4 : 02 1/17/1970 00:00 @73.00usft (above Mean Sea Level) Date From - To Hrs Task Code NPT NPT Depth Phase Description of Operations (ht)- (--ft) - - - -- 9/812014 00:00 00:30 0.50 FISH P DECOMP SLIPANDCUT PJSM, WORKING AT HEIGHTS, BEAVER SLIDE OPERATIONS. CUT 59' OF DRILLING LINE. MAKE ANNOUNCEMENT PRIOR TO OPERATING BEAVER SLIDE. - - ---- 00:30 01:30 1.00 FISH P DECOMP RUN IN THE HOLE ON DP W/ OVERSHOT BHA #11. -PJSM. R I H F/7,637 T/ 7,667'. 01:30 03:30 2.00 FISH P DECOMP+POOH W/ FISH OBTAIN OPERATIONAL PARAMETERS, UP WT 180K, DN WT 162K, ROT WT 172K, 10 RPM, TO 2K - RIH F/ 7,667 AND TAG NO GO AT 7,694.5', WITH 1 OK WOB. PULL 25K OVERPULLAND SLACK OFF, PULL 45K OVERPULL, SLACK OFF. FIRE JARS AT 70K OVERPULLAND THEN STRETCH TO 120K OVERPULL, REPEAT 3 TIMES. APPLY PUMP PRESSURE 500 - 700 PSI WHILE JARRING. - CONTINUE FIRING JARS WORKING UP TO 100K OVERPULLAND THEN STRETCH TO 145K OVERPULL, REPEAT 10 TIMES. APPLY PUMP PRESSURE 500 - 700 PSI WHILE JARRING. OBSERVED FISH COMING FREE AT UP WT 320K, UNABLE TO ESTABLISH CIRCULATION. PULL UP HOLE WITH FISH, CONTINUE TO APPLY PUMP PRESSURE 300 - 500 PSI. WORK STRING IN AN ATTEMPT TO BREAK DOWN DEBRI AROUND FISH AND ESTABLISH CIRCULATION, UNABLE TO WORK FISH BACK DOWN HOLE IN AN ATTEMPT TO ESTABLISH CIRCULATION. - RESUME PULLING FISH UP HOLE, UP WT DECREASED TO 215K, AT BOTTOM OF FISH DEPTH OF 8250' ESTABLISHED CIRCULATION, 2 BPM, ICP 900 PSI, FCP 240 PSI. 03:30 - 04:30 1.00 FISH P DECOMP CIRCULATE SURFACE TO SURFACE PUMP 30 BBL DEEP KLEEN SWEEP FOLLOWED BY 120 DEGREE 8.5 PPG SEAWATER SURFACE TO SURFACE. CIRCULATE 12 BPM, 610 PSI, UP WT 195K, DN WT 165K. - NO ARCTIC PACK OBSERVED AT BOTTOMS U P. 0.50 FISH P 04:30 05:00 DECOMP MONITOR WELL 10 MINUTES, STATIC. RACK BACK 1 STAND OF DP. - BLOW DOWN TOP DRIVE. LINE UP ON TRIP TANK. _ 05:00 05:30 0.50 FISH P DECOMP CONDUCT POST JARRING DERRICK INSPECTION. - PJSM, PROPERLY COMPLETE MAN RIDER PERMIT, REQUIRES WSL SIGNATURE PRIOR TO UNDERTAKING TASK. MEN WORKING AT HEIGHTS, COMPLETE TOOL LOG. -- Printed 10/13/2014 1:19:52PM North America - ALASKA - BP Page 28 of 79 Operation Summary Report Common Well Name: 01-02 AFE No Event Type: WORKOVER (WO) Start Date: 8/25/2014 End Date: I X4 -0103J -E: (6,000,000.00 ) Project. Prudhoe Bay Site: PB DS 01 Rig Name/No.: DOYON 14 Spud Date/Time: 1/17/1970 12:00:OOAM Rig Release: 10/4/2014 Rig Contractor: DOYON DRILLING INC. UWI: 500292005300 Active datum: 4: 02 1/17/1970 00:00 @73.00usft (above Mean Sea Leve Date From - To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (usft) — 3.00 FISH P DECOMP PULL OUT OF HOLE WITH OVERSHOT BHA# 05:M__- 08:30 11 - PJSM, POOH F/ 8155" T/ 1180'. MONITOR WELL 10 MINUTES PRIOR TO PULLING BHA THROUGH STACK, STATIC. 08:30 - 10:30 2.00 FISH P DECOMP L/D BHA#11 PJSM. i - L/D BHA #11 F/ 1180' T/ 856'. STAND BACK 2 STANDS OF 6-1/4" DRILL COLLARS. - BREAK OUT AND L/D BUMPER SUB, HYDRAULIC JARS AND INTENSIFIER. 10.30 - 11:30 1.00 FISH P DECOMP ! RIG UP TO LAY DOWN 5-1/2" TUBING - PJSM CONCERNING R/U OF TONGS, MAKING UP SAFETY JOINT, PAY ATTENTION TO REDUCING CONGESTION ON RIG FLOOR. MAKE UP 5-1/2" 8 ROUND XO ON FOSV. RIG UP DOUBLE STACK POWER TONGS. RIG DOWN OVERSHOT WITH CUT JOINT OF 5-1/2" TUBING. 11:30 - 12:00 0.50 FISH P DECOMP LAY DOWN 5-1/2" TUBING j- PJSM FOR OPERATING DOUBLE STACK TONGS AND LAYING DOWN TUBING. LAY DOWN TUBING F/ 856'T/ 696'. - UP WT 60K, DN WT 60K. 12:00 - 12:30 0.50 rFISH P DECOMP RIG SERVICE. - LUBRICATE RIG. 12:30 - 14:00 1.50 FISH ._. P- DECOMP LAY DOWN 5-1/2" TUBING -PJSM - - LAY DOWN TUBING F/ 696'T/ SURFACE. - RECOVERED 30 FULL JOINTS, 1 EACH TOP CUT JONT 21' LONG AND 1 EACH BOTTOM CUT JOINT 2.72' LONG. - BOTTOM CUT FLARE OD 5-7/8". _ 14:00 - 15:30 1.50 FISH P DECOMP LAY DOWN OVERSHOT BHA#11 - BREAK DOWN BAKER FISHING 8-1/8" OVERSHOT. RIG DOWN CASING TONGS AND SAFETY VALVE. - CLEAR OVERSHOT BHA#11 FROM RIG FLOOR. - MAKE ANNOUNCEMENT FOR BEAVER SLIDE OPERATIONS. 15:30 - 18:00 2.50 FISH P DECOMP PICKUP WASHOVER BHA#12. - PJSM ON MAKING UP WASH PIPE BHA. -PICKUP BHA F/ SURFACE T/ 680'. PICKUP 15 JOINTS OF WASHPIPE, HYDRAULIC JARS, BUMPER SUB, 2 STANDS OF DRILL COLLARS AND INTENSIFIER. _ 18:00 - 00:00 6.00 FISH P DECOMP RUN IN THE HOLE WITH WASHOVER BHA#12. - PJSM CONCERNING PICKING UP PIPE OFF SKATE. - PICK UP 30 JOINTS OF SINGLES FROM PIPE SHED F/ 680'T/ 1,629'. - RUN IN THE HOLE FROM DERRICK FROM 1,629' T/7,802'. - STARTED TAKING WEIGHT UP TO 10KAT 7,802', BEGIN WASHING DOWN F/ 7802'T/ 8277' AT 5 BPM, 420 PSI, NO ROTATION. Printed 10/13/2014 1:19:52PM North America - ALASKA BPS;„ Operation Summary Report` Common Well Name: 01-02 AFE No Event Type: WORKOVER (WO) Start Date: 8/25/2014 End Date: X4 -0103J -E: (6,000,000.00 ) Project: Prudhoe Bay Site: PB DS 01 Rig Name/No.: DOYON 14 Spud Date/Time: 1/17/1970 12:00:OOAM Rig Release: 10/4/2014 Rig Contractor: DOYON DRILLING INC. LIN: 500292005300 Active datum: 4: 02 1/17/1970 00:00 @73.00usft (above Mean Sea Level) Date From - To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) 1 (usft) _ 9/9/2014 00:00 - 01:30 1.50 FISH P DECOMP WASH DOWN CONTINUE WASHING DOWN F/ 8277'T/ 8500' AT 5 BPM, 480 PSI, 5-10K WOB, NO ROTATION. OBSERVED SLIGHT WEIGHT INCREASE WHEN SWALLOWING FISH. 01:30 - 07:00 5.50 FISH P DECOMP WASH DOWN GAS BREAKOUT AT SURFACE FROM ARCTIC PACK AT BOTTOMS UP STROKES, NO INCREASE IN FLOW NO INCREASE IN VOLUME, P/U OFF BOTTOM AND MONITOR WELL FOR 30 MINUTES, BUBBLES DIMINISH TO ZERO, WELL STATIC. CONTINUE WASHING DOWN OBSERVED SLIGHT INCREASE IN WEIGHT ON BIT. ACTING AS IF BHA PENETRATING MORE ARCTIC PACK. -COMMENCE ROTATING F/ 8500' T/ 8715'. - ENCOUNTER HARD SPOTAT 8705', TOP DRIVE TORQUE INCREASE FROM 5-10K, P/U AND WORK BACK DOWN TO 8705', VARY PUMP RATE FROM 5 BPM TO 7 BPM, 490 PSI TO 920 PSI, VARY WOB FROM 5-10K, TORQUE 3-10K, UP WT 205K, DN WT 175K, ROT WT 185K - SLOW PUMPS TO 3 BPM, 240 PSI ATTEMPT TO CONTINUE WASHING DOWN, NO IMPROVEMENT. SHUT PUMPS OFF AND DRY MILL, UNABLE TO GET PAST 8715'. UP WT 218K, DN WT 174K. OBSERVE INTERMITTENT SMALL AMOUNTS OF GAS BREAKOUT AT SURFACE FROM ARCTIC PACK, NO INCREASE IN FLOW, NO AGAIN IN VOLUME. 07:00 - 07:30 0.50 FISH DECOMP FLOW CHECK FOR 10 MINUTES, STATIC P LAY DOWN 1 SINGLE. BLOW DOWN TOP DRIVE. 07:30 - 08:90 0.50 FISH P DECOMP PUMP DIESEL SWEEP PJSM WITH RIG, LRS, AND CH2MHILL, REVIEW PRESSURE CROSSCHECK CHECKIST. LRS PRESSURE TEST LINES TO 250 PSI LOW AND 2500 PSI HIGH FOR 5 MIN / 5 MIN. PUMP 42 BBLS 140 DEGREE DIESEL, BYPASS VALVE ON LRS PUMP TRUCK FAILED. 08:00 - 09:00 1.00 FISH N SFAL 8,715.00 DECOMP LITTLE RED SERVICES HEATED BYPASS VALVE FAILURE. - WAIT ON PARTS TO REPAIR ON UNIT. - LRS BACK ONLINE. 09:00 - 11:00 2.00 FISH P DECOMP PUMP DIESEL SWEEP - LRS PRESSURE TEST LINES TO 250 PSI LOW AND 2500 PSI HIGH FOR 5 MIN / 5 MIN. - CONTINUE PER PUMPING SCHEDULE. - PUMP THROUGH LR AT MAX RATE OF 2 BPM WITH 1060 PSI. - PUMP 58 BBLS OF 140 DEGREE DIESEL, 2 BPM, 1060 PSI. Printed 10/13/2014 1:19:52PM North America - ALASKA - BP �. �,,, �� , r,., :', r% F 9 ;9 Operation Summary Report Common Well Name: 01-02 AFE No Event Type: WORKOVER (WO) Start Date: 8/25/2014 End Date: 'X4 -01031-E: (6,000,000.00 ) Project: Prudhoe Bay Site: PB DS 01 A Rig Name/No.: DOYON 14 Spud Date/Time: 1/17/1970 12:00:00AM Rig Release: 10/4/2014 Rig Contractor: DOYON DRILLING INC. UWI: 500292005300 Active datum: 4: 02 1/17/1970 00:00 @73.00usft (above Mean Sea Level) Date From - To Hrs Task Code NPT NPT Depth i Phase Description of Operations (h0 (usft) 11:00 - 12:00 1.00 FISH P DECOMP PUMP DEEP CLEAN SWEEP. - PJSM, LINE UP TO PUMP. - PUMP 111 BBLS DEEP KLEEN SWEEP, 2 BPM, ICP 850 PSI, FCP 410 PSI, UP WT 217K, DN WT 174K. AFTER 10 BBLS PUMPED INCREASE CHOKE PSI TO 170 PSI. - SHUT IN AT 11:57 AND LET SOAK FOR 1 HOUR. 12:00 - 13:00 1.00 FISH P DECOMP DIESEL SOAK IN ANNULAS FOR 1 HOUR. 113:00 18:00 5.00 FISH P DECOMP CIRCULATE OUT DIESEL -PJSM, CIRCULATE OUT DIESEL, VERIFY RADIO COMMUNICATION AT CHOKE SKID AND FLOW BACK TANK, DESIGNATE SPILL CHAMPION TO WATCH HOSES AND TRUCKS. - PUMP 570 BBLS HEATED SEAWATER, 2 BPM, 1 590 PSI THROUGH CHOKE.SKID. - HOLD 300 PSI ON BACK SIDE ROTATE 10 RPM AND RECIPROCATE PIPE, WHILE TAKING RETURNS TO PITS. - DIESEL RETURNS TO SURFACE AT 300 BBLS PUMPED. SHUTDOWN PUMPS AND LINEUP ON FLOWBACK TANK TAKING RETURNS - FROM IA. RESUME CIRCULATING AT 2 BPM, 590 PSI WHILE HOLDING 300 PSI ON BACK SIDE. PUMP 100 BBLS OF DIESEL, 90 BBLS OF DEEP KLEEN SWEEP TO FLOW BACK TANK. - SHUT DOWN PUMPS TO MONITOR WELL. 18:00 19:00 1.00 FISH P DECOMP CIRCULATE -OPEN CHOKE CHECK FOR PRESSURE, NO PRESSURE. - OPEN BAG AND MONITOR WELL 10 MINUTES, STATIC. - CIRCULATE BOTTOMS UP, 12 BPM, 900 PSI. 19:00 - 00:00 5.00 FISH P DECOMP POOH -MONITOR WELL 10 MINUTES, STATIC. - PJSM, REVIEW TRIPPING SOP. - B/D TOP DRIVE AND CHOKE MANIFOLD, B/D LINE TO FLOWBACK TANK. - POOH F/ 8715'T/ 2,484', UP WT 105K, DN WT 105K 9/10/2014 00:00 - 00:30 0.50 FISH P DECOMP RIG SERVICE. -INSPECT AND LUBRICATE TOP DRIVE, BLOCKS, DRAW WORKS AND IRON ROUGHNECK. 00:30 - 01:30 1.00 FISH P DECOMP POOH WITH 8-1/8" WASHOVER BHA#12 POOH F/ 2,484'T/ 775' - MONITOR WELL AT LAST STAND OF DP FOR 10 MINUTES, STATIC. Printed 10/13/2014 1:19:62PM North America - ALASKA - BP Page 31 of 79 Operation Summary Report Common Well Name: 01-02 AFE No Event Type: WORKOVER (WO) Start Date: 8/25/2014 End Date: X4 -0103J -E: (6,000,000.00 ) Project: Prudhoe Bay Site: PB DS 01 Rig Name/No.: DOYON 14 Spud Date/Time: 1/17/1970 12:00:00AM Rig Release: 10/4/2014 Rig Contractor: DOYON DRILLING INC. UWI: 500292005300 Active datum: 4: 02 1/17/1970 00:00 @73.00usft (above Mean Sea Level) Date From - To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (usft) 01:30 - 05:00 3.50 FISH P DECOMP LAY DOWN 8-1/8" WASHOVER BHA#12 PJSM, L/D INTENSIFIER. - STAND BACK 2 STANDS OF 6-1/4" DRILL COLLARS. - STAND BACK 2 STANDS OF 8-1/8" WASHPIPE IN DERRICK. - LAY DOWN 6 JTS OF 8-1/8" WASHPIPE IN PIPE SHED. - STAND BACK 1 STAND OF 8-1/8" WASHPIPE IN DERRICK. BREAK MILL SHOE OFF WASH PIPE. CLEAN AND CLEAR FLOOR. *MILL SHOE HAS MINIMUM WEAR ON BOTTOM AND INNER SIDE OF SHOE. OUTER EDGES OF SHOE ARE WORE. 05:00 - 05:30 0.50 FISH P DECOMP CLEAN AND CLEAR RIG FLOOR. PJSM ON BEAVER SLIDE OPERATIONS. REMOVE EXCESS ARCTIC PACK FROM RIG FLOOR AND EQUIPMENT. - REMOVE WASHOVER ASSEMBLY COMPONENTS FROM RIG FLOOR AND PICK UP SPEAR ASSEMBLY COMPONENTS. 05:30 - 06:30 1.00 FISH P DECOMP PECK UP AND MAKE UP 5-1/2" SPEAR (ASSEMBLY. PJSM AND REVIEW DDI SOP ON BHA ASSEMBLY. MAKE UP JARS AND BUMPER SUB TO SPEAR AND PACK -OFF ASSEMBLY. *DEVELOP PLAN FORWARD OF REPAIRING STROKE COUNTER ON CHOKE PANEL OBSERVED NOT FUNCTIONING PROPERLY 1 WHILE CIRCULATING ARCTIC PACK WITH WASHOVER ASSEMBLY IN HOLE. 06:30 - 07:00 0.50 FISH T P DECOMP LAY DOWN SPEAR ASSEMBLY TO PIPE SHED. - LAY DOWN SPEAR ASSEMBLY WITH BUMPER SUB AND JARS TO PIPE SHED. *DISCUSS PLAN FORWARD WITH OPERATIONS SUPERINTENDENT AND WTL 07:00 - 08:30 1.50 FISH P DECOMP FLUSH BOPE STACK OF RESIDUAL ARCTIC PACK FOR BOPE TEST. PJSM, MAKE UP JOINT OF 4" DRILL PIPE TO STACK WASHER AND TOP DRIVE. FUNCTION ALL RAMS AND ANNULAR PREVENTER AFTER VOIDING STACK OF ALL FLUIDS. NO METAL DEBRIS OBSERVED FROM FUNCTIONING. CIRCULATE AT 14 BPM W/ 80 PSI. WHILE ROTATING AT 110 RPM'S WHILE RECIPROCATING PIPE TO FLUSH BOPE STACK. - LAY DOWN WASH ASSEMBLY AND BLOW DOWN TOP DRIVE. *ELECTRICIAN REMOVE JUMPER LINE FROM CHOKE PANELAND REPAIR IN MOTORMAN ROOM. 4 *RE -INSTALL JUMPER LINE TO CHOKE PANEL. Printed 10/13/2014 1:19:52PM North America - ALASKA - BP Page 32 of 79 Operation Summary Report Common Well Name: 01-02 AFE No Event Type: WORKOVER (WO) Start Date: 8/25/2014 End Date: X4 -0103J -E: (6,000,000.00 ) Project: Prudhoe Bay Site: PB DS 01 Rig Name/No.: DOYON 14 Spud Date/Time: 1/17/1970 12:00:OOAM Rig Release: 10/4/2014 Rig Contractor: DOYON DRILLING INC. UN: 500292005300 Active datum: 4 : 02 1/17/1970 00:00 @73.00usft (above Mean Sea Level) Date From - To Hrs Task Code NPT NPT Depth Phase Description of Operations - 08:30 - 10:00 (hr) (usft) ----- - - 1.50 BOPSUR P DECOMP RIG UP TO TEST BOPE. - PJSM AND REVIEW DDI SOP ALONG WITH PRESSURE CROSSCHECK LIST. VOID STACK OF FLUID AND INSTALL TEST PLUG. RILDS WITH 450 FT/ LBS. OF TORQUE. FILL STACKAND TEST STROKE COUNTER ON CHOKE PANEL WITH WSL WITNESS, GOOD TEST. ASSEMBLE CROSSOVERS TO FLOOR VALVES AND TOP DRIVE FOR TESTING. - PURGE ALL SURFACE EQUIPMENT FOR BOPE TEST. `PERFORM D2 DRILLAND FILL MUD LEG AND -MGS WITH 6 BBLS. 10:00 - 16:30 6.50 BOPSUR P DECOMP TEST BOPE EQUIPMENT. --TEST TO 250 PSI LOW AND 3500 PSI HIGH FOR 5 CHARTED MINS. - TEST RAMS WITH 4" AND 5.1/2" AND 9-5/8" TEST JOINTS. TEST 2 FOSV'S, DART VALVES AND CHOKE VALVES. 16:30 - 18:00 1.50 BOPSUR P DECOMP RIG DOWN BOPE TEST EQUIPMENT. PJSM, RIG DOWN TEST EQUIPT. - PULL BOPE TEST PLUG. - BLOW DOWN CHOKE AND KILL LINES. - MAKE UP SAFETY JOINT. _ 18:00 - 18:30 0.50 FISH P_ DECOMP RIG SERVICE. - PJSM, LUBRICATE AND INSPECT DRAW WORKS, BLOCKS, TOP DRIVE AND IRON ROUGHNECK. 18:30 - 20:00 1.50 FISH P DECOMP PICK UP 5-1/2" SPEAR BHA #13. - PJSM, EMPHASIS AROUND PICKING UP DRILL COLLARS OFF SKATE. STAY TO THE SIDE AND DO NOT GET BETWEEN THE COLLAR AND THE STUMP. - PICK UP 3 JOINTS OF 6-1/4" DRILL COLLARS FROM PIPE SHED. PICK UP 2 STANDS OF 6-1/4" DRILL COLLARS FROM DERRICK. - MAKE UP INTENSIFIER AND PUMP OUT SUB. 20 00 - 23:30 3.50 1 FISH P DECOMP RIH WITH 5-1/2" SPEAR BHA#13. - RIH W 5-1/2" SPEAR F/ 327'T/ 8,399'. * KICK WHILE TRIPPING DRILL- AAR. 23:30 - 00:00 0.50 FISH P DECOMP WASH DOWN WITH 5-1/2" SPEAR BHA#13. - WASH DOWN F/ 8,399'T/ 8,503'. - ESTABLISH WORKING PARAMETERS AND SPR'S. - PICK UP SINGLE FROM PIPE SHED TO ENGAGE FISH. Printed 10/13/2014 1:19:52PM Printed 10/13/2014 1:19:52PM North America -A X00 { Operation Summary Repor ! Common Well Name: 01-02 ' AFE No Event Type: WORKOVER (WO) Start Date: 8/25/2014 End Date: X4 -0103J -E: (6,000,000.00 ) Project: Prudhoe Bay Site: PB DS 01 Rig Name/No.: DOYON 14 Spud Date/Time: 1/17/1970 12:00:OOAM Rig Release: 10/4/2014 Rig Contractor: DOYON DRILLING INC. UWI: 500292005300 Active datum: 4: 02 1/17/1970 00:00 @73.00usft (above Mean Sea Level) ate From To Hrs Task CoNPT NPT DeT Depth Description of Operations H00 P- - - --. +JARRING 9/1D1/2014 00:00 01:00 FISH Pde DECOMP OPERATIONS. PJSM, OBTAIN WORKING PARAMETERS. PUW= 205K, SOW= 172K, WITH PUMPS OFF OBTAIN PUMP PRESSURE PRIOR TO ENGAGING FISH 3 BPM, 190 PSI. - RIH AND ENGAGE GRAPPLE ON FISH AT 8,501'. - RIH WITH NO GO TO 8,502' WITH 10K WOB. PULL 15K OVERPULLAND SLACK OFF 2X'S. - PULL 20K OVERPULLAND SLACK OFF. - PULL 45K OVERPULL, FIRE JARS, PULL UP TO 250K, 2X'S. PULL 60K OVERPULL FIRE JARS, PULL UP TO 265K, 2X'S. PULL 70K OVERPULL, FIRE JARS, PULL UP TO 275K, 3X'S. PULL 95K OVERPULL, FIRE JARS, PULL UP TO 300K, 3X'S. PULL 120K OVERPULL, FIRE JARS, PULL UP TO 325K, 4X'S. - PULL 145K OVERPULL, FIRE JARS, PULL UP TO 350K, 11 XS. PULL 170K OVERPULL, FIRE JARS, PULL UP TO 375K 2X'S, FISH CAME FREE. FIRE JARS 27X'S TO FREE FISH. -WORKED FISH FREE, UP WT 210-212K, OBSERVED FLUID SWABBING WHEN WORKING PIPE WITH FISH ON, BRINGS PUMPS ON, OBSERVE PRESSURE INCREASE I 1 3 BPM, 240 PSI. - _ 01:00 - 01:30 r 0.50 FISH P DECOMP PUMP OUT OF HOLE. - LAY DOWN SINGLE IN PIPE SHED. PUMP OUT OF THE HOLE F/ 8,494 T/8,399' CIRCULATE 3 BPM WITH 230 PSI. 01:30 03:00 1.50 1 FISH P DECOMP 1 CIRCULATE. CIRCULATE BOTTOMS UP IX, 7 BPM, 830 PSI. - RECIPROCATE PIPE 90' WHILE CBU. 03:00 - 04:00 1.00 FISH P DECOMP POST JARRING DERRICK INSPECTION PJSM, WORKING AT HEIGHTS, CO. MAN SIGN MAN RIDER PERMIT DERRICK INSPECTED SAFE TO CONTINUE OPERATIONS. MOBILIZE 5-1/2" DOUBLE STACK TONGS TO RIG FLOOR. 04:00 05:30 1.50 FISH P I DECOMP POOH PJSM POOH F/ 8,399'T/ 4,339' 05:30 - 06:00 0.50 FISH P DECOMP 'KICK WHILE TRIPIING DRILL-AAR. - - OOH 06:00 08:00 1 2.00 FISH P DECOMP Pi WITH 5-1/2" SPEAR BHA#13. PJSM, POOH F/ 4,399'T/ 422'. - MONITOR WELL FOR 10 MINS, STATIC. - -- -- t- - _ - - O 08:00 09:30 1.50 FISH P DECOMP LAY DOWN SPEAR BHA#13. PJSM FOR LAYING DOWN BHA STAND BACK LAST STAND OF DRILL PIPE. LAY DOWN INTENSIFIER WITH CROSSOVERS. - STAND BACK 3 STANDS OF 6-1/4" DRILL COLLARS. Printed 10/13/2014 1:19:52PM Printed 10/13/2014 1.19.52PM North America - ALASKA - BP Page 34 of 79 Operation Summary Report Common Well Name: 01-02 AFE No Event Type: WORKOVER (WO) Start Date: 8/25/2014 End Date: X4 -0103)-E: (6,000,000.00 ) Project: Prudhoe Bay Site: PB DS 01 Rig Name/No.: DOYON 14 i Spud Date/Time: 1/17/1970 12:00:OOAM Rig Release: 10/4/2014 Rig Contractor: DOYON DRILLING INC. UVO 500292005300 Active datum: 4: 02 1/17/1970 00:00 @73.00usft (above Mean Sea Level) Date From - To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) - 1.50 - FISH P - (usft) -� DECOMP --- YLA DOWN 5-112" TUBING. -11:00 -rt-- . 09:30 PJSM FOR LAYING DOWN TUBING MAKE UP CROSSOVERS FOR FOSV. RIG UP 5-1/2" DOUBLE STACKED POWER i TONGS. RIG DOWN SPEAR ASSY. W/ 5-1/2" CUT JOINT. - LAY DOWN 7 FULL JOINTS OF 5-1/2" TBG, !(185.52') AND 1 CUT JOINT (21.05') - TOTAL FOOTAGE LAID DOWN= 206.57' FISH CAME OUT OF HOLE WITH COLLAR ON LAST JOINT, COLLAR ON FISH WAS MILLED AWAY ALLOWING TO PULL FREE FROM PIN ON FISH STILL IN HOLE. 11:00 12:30 1.50 FISH P DECOMP RIG DOWN 5-1/2" UHT POWER TONGS. PJSM, MAKE ANNOUNCEMENT FOR BEAVER SLIDE OPERATIONS LAY DOWN INTENSIFIER. MOBILIZE WASHOVER ASSY. BHA#14 TO RIG FLOOR. 12:30 - 14:00 1.50 FISH P rDECOMP 1 MAKE UP WASHOVER ASSY BHA#14. - PJSM FOR MAKING UP WASHOVER BHA, DISCUSSED USING RIG TONGS ON ! WASHPIPE. M/U 8-1/2" x 7" SHOE AND 3 STANDS OF WASHPIPE. M/U BUMPER SUB, OIL JARS, FLOAT SUB AND 3 STANDS OF 6-1/8" DRILL COLLARS. 14:00 - 18:00 4.00 FISH P DECOMP ,RUN IN THE HOLE WITH WASHOVER ASSY. BHA #14. _ 18:00 20:00 2.00 -SM, FISH - P DECOMP RIH F/ 588' T/ 8,566'. SLIP AND CUT DRILLING LINE. PJSM DISCUSS LAYING ADSORB OVER CUTTER TO PROTECT EYES, THROW GLOVES AWAY AFTER CUTTING LINE. SLIP AND CUT 59' OF DRILLING LINE. 20.00 22:30 2.50 FISH P ! DECOMP ! WASH DOWN OPERATIONS. PJSM, OBTAIN OPERATIONAL PARAMENTERS, UP WT 215K, DN WT 172K, ROT WT 190K, TQ 4K WASH DOWN TO 8,720', STRING TOOK WEIGHT, SET 5K DOWN. - PICK UP AND ROTATE 60 RPM DOWN PAST 8,720' TO 8,884' TAGGED UP. OBSERVED MINIMAL TO NO FILL IN ANNULUS BEFORE TAGGING AT 8,884', SET 5-1 OK ON FISH. ATTEMPT MULTIPLE TIMES TO WASH PAST 8,884' WITH ROTATION AND WITHOUT ROTATION. CONTINUED TO STACK WEIGHT NO SUCCESS GETTING DEEPER. 22.30 00:00 i 1.50 t FISH P DECOMP PUMP HI VIS SWEEP. PJSM, LINE UP TO PUMP. - PUMP 30 BBLS HI VIS SWEEP SURFACE TO SURFACE AT 8,882'. CIRCULATE 7 BPM WITH 690 PIS. - INCREASE PUMP RATE TO 10 BPM WITH 1350 PSI. - OBSERVED APPROXIMATELY 20% ARCTIC PACK IN RETURNS WHEN SWEEP REACHED SURFACE. RETURNS CLEANED BACK UP AFTER 40 ADDITIONAL BBLS PUMPED FOLLWING SWEEP AT SURFACE. Printed 10/13/2014 1.19.52PM North America -ALASKA BP Operation Summary Report Common Well Name: 01-02 AFE No Event Type: WORKOVER (WO) Start Date: 8/25/2014 End Date: X4 -0103J -E: (6,000,000.00 ) Project: Prudhoe Bay Site: PB DS 01 Rig Name/No.: DOYON 14 Spud Date/Time: 1/17/1970 12:00:OOAM Rig Release: 10/4/2014 Rig Contractor: DOYON DRILLING INC. UWI: 500292005300 Active datum: 4: 02 1/17/1970 00:00 @73.00usft (above Mean Sea Level) Date From - To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (usft) 9/12/2014 00:00 - 00:30 0.50 FISH P DECOMP PUMP OUT OF HOLE WITH WASHOVER ASSY. BHA #14. - MONITOR WELL FOR 10 MINUTES, STATIC. - BLOW DOWN TOP DRIVE. - POOH F/ 8,882' T/ 8,850'. - STAND BACK 1 STAND OF DP. 00:30 - 01:30 1.00 FISH P DECOMP PUMP OUT OF HOLE WITH WASHOVER ASSY. BHA #14. - ATTEMPT TO PULL OUT OF HOLE, OBSERVE SWABBING. - PUMP OUT OF HOLE, 4 BPM, 250 PSI, F/ 8,850'T/ 8,091'. MONITOR WELL, STATIC 01:30 - 05:30 4.00 FISH P DECOMP POOH WITH WASHOVER ASSY. BHA#14. - POOH F/ 8,091' T/ 6,295', INCORRECT HOLE FILL, STOP AND MONITOR WELL, STATIC. - RESUME POOH AT REDUCED PULLING SPEED. POOH F/6,295' T/ 683' LAY DOWN WASHOVER BHA#14. 05:30 - 10:00 4.50 FISH P DECOMP -FLOW CHECK FOR 10 MINUTES, STATIC. - PJSM FOR LAYING DOWN BHA F/ 583'T/ SURFACE. - - STAND BACK 3 STANDS OF 6-1/4" DRILL COLLARS, LAY DOWN JARS, AND BOOT BASKET. - REMOVE 4" ELEVATORS AND INSTALL 5" ELEVATORS., MAKE UP XO TO WASH PIPE FOR FLOOR VALVE. - STAND BACK 1 STAND OF 8-1/8" WASH PIPE. - LAY DOWN 6 JTS OF 8-1/8" WASH PIPE TO PIPE SHED. - BREAK OFF CUTLIP GUIDE SHOE. - CLEAN OUT BOOT BASKET, NO SOLIDS IN BOOT BASKET. - CLEAN AND CLEAR FLOOR, SEND BHA #14 COMPONENTS OFF FLOOR, MAKE BEAVER SLIDE OPERATIONS ANNOUNCEMENT PRIOR TO USING. DECOMP PICK UP OVERSHOT BHA #15. 10:00 11:00 1.00 FISH P - PJSM FOR PICKING UP BHA#15 F/ SURFACE T/ 306'. - P/U 8-1/8" OVERSHOT W/ 5-1/2" GRAPPLE, BUMPER SUB, HYDRAULIC JARS, 3 STANDS OF 6-1/4" DRILL COLLARS. _ 11:00 - 11:30 0.50 FISH P DECOMP RIH WITH 8-1/8" OVERSHOT BHA. - RIH F/ 306' T/ 1,256'. 11:30 - 12:00 0.50 FISH P DECOMP LUBRICATE AND SERVICE RIG. 12:00 - 14:30 2.50 FISH P DECOMP RIH WITH 8-1/8" OVERSHOT BHA. - RIH F/ 1,256' Tt 8,663'. Printed 10/13/2014 1:19:52PM North America - ALASKA Bof 79 Operation Summary Report Common Well Name: 01-02 AFE No Event Type: WORKOVER (WO) Start Date: 8/25/2014 End Date: X4 -0103J -E: (6,000,000.00 ) Project: Prudhoe Bay Site: PB DS 01 Rig Name/No.: DOYON 14 Spud Date/Time: 1/17/1970 12:00:00AM Rig Release: 10/4/2014 Rig Contractor: DOYON DRILLING INC. UW: 500292005300 Active datum: 4: 02 1/17/1970 00:00 @73.00usft (above Mean Sea Level) _ Date From - To Hrs Task Code I NPT NPT Depth Phase Description of Operations (hr) I (usft) 14:30 - 15:00 0.50 FISH P DECOMP JARRING OPERATIONS. - ESTABLISH PARAMETERS PRIOR TO ENGAGING FISH. UP WT 21 OK, SO WT 175K, ROT WT 190K - OBTAIN SLOW PUMP RATES. - WASH DOWN 4 BPM, 190 PSI TO TOP OF FISH AT 8,709' TO NO GO AT 8,714', SET DOWN 10K ON FISH, TURN PUMPS OFF. - SET GRAPPLE WITH 20K OVERPULL. - PULL SOK OVERPULL, FIRE JARS, SLACK OFF TO COCK JARS, IX. - PULL UP TO 230K AND FISH CAME FREE, WORK FISH FREE. OBSERVE ADDITIONAL 10K ON HOOK INDICATING FISH ON. STAND BACK ONE STAND OF 4" DRILL PIPE. - MONITOR WELL 10 MINUTES, STATIC. 15:00 - 18:00 3.00 FISH P DECOMP POOH WITH FISH. -PJSM FOR POOH. - POOH F/ 8,663'T/ 3,440'. DECOMP 1 LUBRICATE AND SERVICE RIG 18:00 - 18:30 0.50 FISH P 18:30 - 20:00 1.50 FISH N RREP 3,440.00 DECOMP CODE 8 CREW NOTICED UNUSUAL NOISE COMING - FROM DRAVWVORKS. - SHUT DOWN AND SECURED WELL. INSTALL FLOOR VALVE AND MONITOR WELL BORE FLUID LEVEL ON TRIP TANK. - UN -COUPLE A -MOTOR SHAFT AND CHECK MOTOR TO SHAFT ALIGNMENT, GOOD WITHIN 0.005". - RE -GREASE COUPLING AND RE -TORQUE TRACTION MOTOR MOUNTING BOLTS. - RUN DRAWWORKS, GOOD. 1.00 FISH P DECOMP POOH WITH FISH. 20:00 21:00 - PJSM FOR POOH. - POOH F/ 3,440'T/ 306'. - FLOWCHECK FOR 10 MINS BEFORE PULLING NONSHEARABLES ACROSS STACK- TACKWELL WELLSTATIC. 21:00 - 22:00 1.00 FISH P DECOMP LAY DOWN OVERSHOT BHA# 15. -PJSM, STAND BACK 3 STANDS OF 6-1/4" DRILL COLLARS IN DERRICK. 22:00 - 23:00 1.00 FISH P DECOMP RIG UP TOOLS FOR 5-1/2" FISH. - PJSM, BEAVER SLIDE OPS. - PICK UP DOUBLE STACK TONGS. - CHANGE OUT XO ON FLOOR VALVE TO 5-1/2"8 ROUND. 23:00 - 00:00 1.00 FISH P DECOMP LAY DOWN FISH - SERVICE BREAK OVERSHOT TO PREP FOR NEXT RUN. - LAY DOWN 6 JOINTS OF 5-1/2" TBG. - LAY DOWN 1 JOINT OF TUBING, ONE SLIDING SLEEVE, AND ONE RADIAL CUT JOINT. CUT JOINT 7.17' LONG. TOTAL PULLED, 7 EACH FULL JOINTS, ONE CUT JOINT, AND ONE SLIDING SLEEVE. Printed 10/13/2014 1:19:52PM North America - ALASKA - BP: Operation Summary Report Common Well Name: 01-02 AFE No Event Type: WORKOVER (WO) Start Date: 8/25/2014 End Date: IX4-0103J-E: (6,000,000.00) Project: Prudhoe Bay Site: PB DS 01 Rig Name/No.: DOYON 14 Spud Date/Time: 1/17/1970 12:00:OOAM Rig Release: 10/4/2014 Rig Contractor: DOYON DRILLING INC. LIN: 500292005300 Active datum: 4: 02 1/17/1970 00:00 @73.00usft (above Mean Sea Level) Date From - To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) 5 FISH P (usft) DECOMP BREAK DOWN OVERSHOT. 9/1312014 00:00 - 00:30 PJSM FOR ROTATING OVERSHOT OFF OF FISH. SET 5-1/2 FISH IN SLIPS AND INSTALL DOG COLLAR, CLOSE BAG ON FISH TO STABILIZE. TURN OVERSHOT TO RIGHT WITH CHAIN I TONGS WHILE SLOWLY PICKING UP WITH BLOCKS. 00:30 - 01:30 1.00 FISH P DECOMP CLEAN AND CLEAR FLOOR. 01:30 - 02:30 1.00 FISH P DECOMP PICK UP WASHOVER BHA#16. PJSM FOR PICKING UP BHA WITH DRAG TOOTH SHOE, DISCUSSED USING RIG TONGS, STAY OUT OF CAUGHT BETWEEN (HAZARDS. - P/U BHA F/ SURFACE T/ 400'. 02:30 - 07:00 4.50 FISH P DECOMP RIH WITH WASHOVER BHA #16. I - RIH F/ 400' T/ 8,855'. :00 - 09:00 2.00 FISH P DECOMP WASH DOWN. -PJSM '- OBTAIN OPERATIONAL PARAMETERS, UP WT 222K, DN WT 170K, ROT WT 193K, - OBTAIN SPR'S. WASH DOWN 13 BPM, 1690 PSI, 30 RPM, F/ 18,855'T/ 8,892'. PICKED BACK UP INCREASED ROTARY TO 60 RPM, TQ 3K, SUCCESSFULLY WASHED OVER TUBING STUB AND DOWN TO 4TOP OF PACKER AT 8,982'. 09 00 10:00 1.00 FISH P DECOMP CIRCULATE. CIRCULATE BOTTOMS UP AT 13 BPM, 1780 PSI, 60 RPM. RECIPROCATE PIPE 60' WHILE CIRCULATING. 1i 0:00 - 10:30 0.50 FISH P DECOMP [RIG SERVICE. INSPECT AND GREASE TOP DRIVE, DRAW WORKS, BLOCKS AND IRON ROUGHNECK CHANGE DIES ON ROUGHNECK. 10:30 - 15:00 --tBHA#16. 4.50 FISH P �DECOMP !, PULL OUT OF THE HOLE WITH WASHOVER PJSM, LAY DOWN 2 SINGLES TO PIPE SHED. POOH F/ 8,982'T/ 403'. MONITOR WELL PRIOR TO NONSHEARABLES ACROSS THE STACK, STATIC. 4 LAY DOWN WASHOVER BHA#16. 15:00 - 16:30 1.50 FISH P DECOMP PJSM FOR HANDLING WASHPIPE. STAND BACK 3 STANDS OF DRILL COLLARS IN DERRICK. !- LAY DOWN 3 JOINTS OF WASHPIPE TO PIPESHED. BREAK OFF DRAG TOOTH SHOE. EMPTY BOOT BASKETS, FILLED WITH ARCTIC PAC 16:30 - 17:30 1.00 FISH P _ COMP CLEAN AND CLEAR RIG FLOOR. MOBALIZE OVERSHOT BHA#17 TO RIG FLOOR. PJSM, MAKE ANNOUNCEMENT FOR BEAVER SLIDE OPERATIONS. Printed 10/13/2014 1:19:52PM Printed 10/13/2014 1:19:52PM North America - ALASKA - BP Page 38 of 79 Operation Summary Report Common Well Name: 01-02 AFE No Event Type: WORKOVER (WO) Start Date: 8/25/2014 End Date: IX4-0103J-E: (6,000,000.00) Project: Prudhoe Bay ! Site: PB DS 01 —' Rig Name/No.: DOYON 14 Spud Date/Time: 1/17/1970 12:00:OOAM Rig Release: 10/4/2014 Rig Contractor: DOYON DRILLING INC. UWI: 500292005300 Active datum: 4 : 02 1/17/1970 00:00 @73.00usft (above Mean Sea Level) Date From - To Hrs I Task Code NPT NPT Depth i Phase Description of Operations (hr)-- (usft) 1! 7:30 - 19:00 1.50 FISH P DECOMP PICK UPAND MAKE UP OVERSHOT 13HA#17. - PJSM, MAKE UP 8-1/2" OVERSHOT, OVERSHOT EXTENSION, BUMPER SUB, OIL JARS, 3 STANDS OF DRILL COLLARS, INTENSIFIER AND PUMP OUT SUB T/ 325'. 19:00 - 22:00 3.00 FISH P DECOMP RUN IN THE HOLE WITH OVERSHOT BHA#17. PJSM, RIH F/ 325' T/ 8,777'. - PU WT 21 OK, DN WT 174K. 2.00 FISH P DECOMP 22:00 - 00:00 ISLIP AND CUT DRILLING LINE. PJSM, SLIP AND CUT 59' OF DRILLING LINE. 9/14/2014 00:00 - 01:00 1.00 FISHP DECOMP SLIP AND CUT 59' OF DRILL LINE. PJSM, TIE BACK SERVICE LOOP LINE IN �- DERRICK. DECOMP PJSM 01:00 - 01:30 0.50 FISH I P - PRIOR TO ENGAGING FISH AND JARRING FREE, BROUGHT RIG CREW INTO DOGHOUSE TO DISCUSS LINE UP FOR BULLHEADING DOWN ANNULUS AND LINE UP FOR 60 BPH CONTINUOUS FILL DOWN (ANNULUS FOLLOWING BULLHEAD. BLEED OFF LINE WAS CHANGED DURING RIG MAINTENANCE SO CREW CAME UP WITH A DIFFERENT LINE UP TO PERFORM CONTINUOUS FILL. WALKED LINE WITH !TOUR PUSHER, DERRICK HAND, AND PIT WATCHER TO VERIFY LINE UP WOULD WORK. DISCUSSED JARRING OPERATIONS AND BARRICADED FLOOR PRIOR TO STARTING. TOP DRIVE / DERRICK INSPECTION REQUIRED FOLLOWING JARRING. 01:30 02:00 0.50 FISH P DECOMP JARRING OPERATIONS. OBTAIN PARAMETERS PRIOR TO ENGAGING FISH, PU WT 210K, DN WT 165K, ROT WT 190K, TQ 4K. PICK UP TWO SINGLES AND ONE STAND. TAG UP ON STUMP AT 8,897'. ROTATE OVER STUMP WITH 20 RPM, SHUT ROTARY DOWN AS SOON AS OVERSHOT SWALLOWED TOP OF FISH.SLACK OFF TO 8,903' (7' SWALLOW) AND SET 1 O ON FISH. - P/U UP TO 250K TO SET GRAPPLE. P/U TO 300K ON HOOKAND FIRE JARS, SLACK OFF TO COCK JARS, 4X -S. P/U TO 300K ON HOOK AND FIRE JARS, PULL BACK UP TO 350K, 1X. P/U TO 325K ON HOOK AND FIRE JARS, SLACK OFF TO COCK JARS, 6X -S. P/U TO 350K ON HOOK AND FIRE JARS, SLACK OFF TO COCK JARS, 1X, NOTICED SLIGHT MOVEMENT. P/U TO 350K ON HOOKAND FIRE JARS, 1X, FISH CAME FREE. TOTAL HITS ON JARS, 13 X'S. BRING STRING UP 25' TO CLEAR PBR, FLUID LOSSES NOTICED. SPACE OUT TOOL JOINTAT RIG FLOOR AND SHUT IN BAG. BULLHEAD 25 BBLS AT 5BPM WITH 30 PSI. Printed 10/13/2014 1:19:52PM North America - ALASKA - BP Page 39 of 79 Operation Summary Report Common Well Name: 01-02 AFE No Event Type: WORKOVER (WO) Start Date: 8/25/2014 End Date: X4 -0103J -E: (6,000,000.00) Project: Prudhoe Bay Site: PB DS 01 Rig Name/No.: DOYON 14 Spud Date/Time: 1/17/1970 12:00:OOAM Rig Release: 10/4/2014 Rig Contractor: DOYON DRILLING INC. UWI: 500292005300 Active datum: 4: 02 1/17/1970 00:00 @73.00usft (above Mean Sea Level) Date From - To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (usft) 02:00 - 03:00 1.00 FISH P DECOMP PUMP DOWN ANNULUS. - FILLANNULUS CONTINUOUSLY AT 60 BPH. - ATTEMPT TO PUMP DOWN DP WITH NO - SUCCESS. 03:00 - 03:30 0.50 FISH P DECOMP DROP BALLAND ROD. STAND BACK ONE STAND OF DP AND LAY DOWN TWO SINGLES TO PIPE SHED TO GET ON EVEN STANDS. - DROP BALLAND ROD AND OPEN PUMP OUT SUB. - CONDUCT POST JARRING DERRICK INSPECTION. 03:30 - 07:00 3.50 FISH P DECOMP POOH -POOH AT 45-60 FT/MIN WHILE FILLING ANNULUS AT 60 BPH.PLUS DRILL PIPE DISPLACEMENT. - POOH El_8,872' T/ 3,100'. - FILL HOLE AT 60 BPH. 07:00 - 07:30 0.50 FISH P" ''DECOMP SERVICE IRON ROUGHNECK 07:30 - 09:00 1.50 FISH P DECOMP POOH. - POOH F/ 3,100' T/ 400'. - MONITOR WELL FOR 10 MINUTES, WELL STILL TAKING FLUID AT 60 BPH. 09:00 - 11:00 2.0,0---- FISH P DECOMP L/D BHA. - PJSM FOR LAYING DOWN BHA. - L/D INTENSIFIER AND PUMP OUT SUB. - STAND BACK 3 STANDS OF DRILL COLLARS. -UD FISH, 1 CUT JOINT 1926' LONG, 1 FULL JOINT OF TUBING 23.56' LONG, 1 XN NIPPLE 1.95' LONG, 1 PUP JOINT 4.96' LONG, 1 LOCATOR SUB 0.87' LONG, 1 SEAL ASSEMBLY BODY 19.44' LONG. - - SEALS PARTED FROM BODY, LEFT INSIDE PBR. 11:00 - 12:00 1.00 FISH P DECOMP CLEAN AND CLEAR FLOOR OF BHA #17 COMPONENTS. *FLUID LOSSES FROM MIDNIGHT TO NOON= 612.5 BBLS 12:00 - 13:00 1.00 FISH P DECOMP BREAK OVERSHOT OFF FISH. - BREAK OVERSHOT EXTENSION AND ATTEMPT TO STRIP OVER CUT JOINT, UNSUCCESSFUL. - L/D CUT JOINTAND OVERSHOT EXTENSION TO PIPE SHED, SEND TO BAKER TO BE CUT OUT. 13:00 - 14:00 1.00 FISH P DECOMP CLEAN AND CLEAR FLOOR. - BRING BHA#18 CASING SCRAPER COMPONENTS TO RIG FLOOR. 14:00 - 15:00 1.00 FISH P DECOMP P/U BHA#18, 9-5/8" CASING SCRAPER. - PJSM CONCERNING HANDLING BHA COMPONENTS. -P/U BHA#18, 9-5/8" CASING SCRAPER F/ SURFACE T/ 400" 15:00 - 15:30 0.50 FISH P DECOMP LUBRICATE AND SERVICE RIG. Printed 10/13/2014 1:19.52PM North America - ALASKA - BP Page 40 of 79 Operation Summary Report Common Well Name: 01-02 AFE No Event Type: WORKOVER (WO) Start Date: 8/25/2014 End Date: X4 -0103J -E: (6,000,000.00 ) Project: Prudhoe Bay Site: PB DS 01 Rig Name/No.: DOYON 14 Spud Date/Time: 1/17/1970 12:00:OOAM Rig Release: 10/4/2014 Rig Contractor: DOYON DRILLING INC. UWI: 500292005300 Active datum: 4: 02 1/17/1970 00:00 @73.00usft (above Mean Sea Level) Date From - To Hrs Task Code NPT I NPT Depth Phase Description of Operations (hr) (usft) 15:30 - 19:00 3.50 FISH P DECOMP RUN IN HOLE WITH BHA#18, 9-5/8" CASING SCRAPER. - RIH F/ 400'T/ 2500'. -WORK SCRAPER AT 2500', RBP SETTING DEPTH. ROTATE AND RECIPROCATE UP PAST 2500' AND BACK DOWN THROUGH AT 60 RPM, 10BPM, 3X'S. NO RETURNS. - RIH F/ 2500'T/ B,B56'. 19:00 - 20:00 1.00 FISH P DECOMP SCRAPER OPERATIONS. - PICK UP 3 JOINTS FROM PIPE SHED. - TAG PBR AT 8,948'. - WORK SCRAPER F/ 8,948'T/ 8,848'. ROTATE AND RECIPROCATE, 60 RPM, 10 BPM, 5X'S. NO RETURNS. PUW= 220K, SOW= 175K, ROT WT= 190K. MONITOR WELL 10 MINS, WELL ON VACUUM. 20:00 - 00:00 4.00 FISH P DECOMP PULLOUT OF THE HOLE WITHBHA #18, 9-5/8" CASING SCRAPER. PJSM. POOH F/ 8,856'T/ 2,800'. KICK WHILE TRIPPING DRILL-AAR. POOH F/ 2,800'T/ 310'. I MONITOR WELL 10 MINUTES BEFORE PULLING NONSHEARABLES ACROSS STACK, WELL ON VACUUM. 9/15/2014 00:00 00:30 0.50 FISH P DECOMP RIG SERVICE, LUBRICATE FLOOR AND TRAVELING EQUIPMENT. 00:30 - 02:00 1.50 FISH P DECOMP LAY DOWN 9-5/8" CSG SCRAPER BHA #18. - PJSM FOR HANDLING BHA. - UD DRILL COLLARS, BUMPER SUB, 9-5/8" SCRAPER AND XO'S. - SEND BHA#18 COMPONENTS OFF RIG _ 02:00 05:30 3.50 FLOOR. DHB P DECOMP RIH WITH 9-5/8" RBP. - PJSM WITH HES FOR P/U 9-5/8" RBP. - RIH F/ SURFACE T/ 8,660'. 05:30 - 06:00 0.50 DHB P DECOMP RIH WITH 9-5/8" RBP. - PJSM FOR PICKING UP DRILL PIPE FROM PIPE SHED. - RIH F/ 8,660'T/ 8,910'. ' CONTINUE FEEDING WELL AT 60 BPH. WITH 8.5 PPG SEAWATER. 06:00 - 06:30 0.50 DHB P DECOMP SET HES 9-5/8" RBP AS PER HES REPRESENTATIVE. - MAKE UP TOP DRIVE AND OBTAIN PARAMETERS. - PUW: 202K, SOW: 165K. - RIH T/ 8,940' AND PICK UP T/ 8,928' PLACING CENTER OF ELEMENT OF RBP AT 8,922'. - ROTATE STRING WITH TOP DRIVE 3 TURNS TO THE LEFT. - CONFIRM RBP SET BY PULLING 10K OVER PUW. - SET BACK DOWN AND SET 2K ON RBP, ROTATE STRING TWO TURNS TO LEFT AND HOLD TORQUE. -PICK UP AND CONFIRM RELEASE FROM RBP AND POOH T/ 8,847'. - BREAK OUT TOP DRIVE AND STAND BACK ONE STAND OF 4" DRILL PIPE. Printed 10/13/2014 1:19:52PM North America - ALASKA - BP Page 41 of 79 Operation Summary Report Common Well Name: 01-02 AFE No Event Type: WORKOVER (WO) Start Date: 8/25/2014 End Date: X4 -0103J -E: (6,000,000.00 ) Project: Prudhoe Bay I Site: PB DS 01 Rig Name/No.: DOYON 14 Spud Date/Time: 1/17/1970 12:00:OOAM ! Rig Release: 10/4/2014 Rig Contractor: DOYON DRILLING INC. UWI: 500292005300 Active datum: 4: 02 1/17/1970 00:00 @73.00usft (above Mean Sea Level) Date From - To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (usft) 06:30 - 07:00 0.50 DHB P DECOMP FILL UP ANNULUS TO ESTABLISH STATIC FLUID LEVEL. - FILLANNULUS WITH 51 BBLS. 07:00 - 08:30 1.50 DHB P DECOMP PRESSURE TEST 9-5/8" CASING. - PJSM ON TESTING CASING WITH DRILL PIPE AND REVIEW SOP. - RIG UP TO PUMP DOWN DRILL PIPE. =CLOSE ANNULAR PREVENTER AND PUMP THROUGH DRILL PIPE OUT CHOKE TO FILL LINES. -VERIFY CREW MEMBER IN CELLAR TO MONITOR OA PRESSURE GAUGE. - PRESSURE UP TO 250 PSI WITH 0.4 BBL PUMPED AND HOLD FOR 5 MINUTES, GOOD TEST. - ATTEMPT HIGH PRESSURE TEST, PRESSURE UP TO 3650 PSI WITH 6.5 BBLS. PRESSURE BLED FROM 3650 TO 2450 IN 7 MINUTES AT A CONSTANT RATE. ATTEMPTED THREE TIMES WITH SAME RESULTS AND NO INCREASE OF PRESSURE OBSERVED ON OA -TOTAL OF 15.5 BBLS PUMPED. - BLEED OFF ALL PRESSURE AND CONFIRM NO PRESSURE ON WELLAND OPEN ANNULAR PREVENTER. - RIG DOWN ALL TEST EQUIPMENTAND BLOW DOWN SURFACE LINES. 08:30 - 11:30 3.00 DHB P DECOMP POOH WITH RBP RUNNING TOOL. - PJSM ON TRIPPING OUT OF HOLE WITH 4" DRILL PIPE. - POOH F/ 8,847' T/ SURFACE. - MONITOR HOLE FILL FROM TRIP TANK, HOLE TAKING CALCULATED DISPLACEMENT. - NOTIFIED AOGCC FOR BOPE TEST. 11:30 - 12:00 0.50 DHB P DECOMP LAY DOWN HES RBP RUNNING TOOL. - PICK UP 9-5/8" RTTS FROM PIPE SHED. ' FLUID LOSS FROM MIDNIGHT TO NOON 460 BBLS. ' BOPE TEST WITNESS WAIVED BY JEFF JONES AT 11:43 AM. 12:00 - 12:30 0.50 DHB P DECOMP LUBRICATE AND SERVICE RIG. 12:30 - 15:00 2.50 DHB P DECOMP RIH WITH RTTS. - PJSM. - RIH F/ 110' T/ 3,494'. 15:00 - 16:30 1.50 DHB P DECOMP SET RTTS. - SET RTTS AT 3,494'. ONE TURN TO THE RIGHT, SLACK OFF 20K WHILE TAKING OUT THE TORQUE TO SHUT CIRCULATION VALVE. - INSTALL HEAD PIN AND RIG UP TEST EQUIPMENT. -TEST BELOW TO 250 PSI, GOOD. - TEST BELOW TO 3500 PSI, FAILED. - BLEED OFF AND RIG UP TO TEST FROM ABOVE. - TEST ABOVE 250 PSI, GOOD. -TEST ABOVE 3500 PSI, HIGH. - RIG DOWN TEST EQUIPMENT AND BLOW DOWN CHOKE AND KILL LINES. -MONITOR WELL FOR 10 MINUTES, STATIC. Printed 10/13/2014 1:19:52PM North America - ALASKA BPA-"M79 Operation Summary Report Common Well Name: 01-02 AFE No Event Type: WORKOVER (WO) Start Date: 8/25/2014 End Date: X4-0103J-E: (6,000,000.00 ) Project: Prudhoe Bay Site: PB DS 01 Rig Name/No.: DOYON 14 Spud Date/Time: 1/17/1970 12:00:OOAM Rig Release: 10/4/2014 Rig Contractor: DOYON DRILLING INC. UWI: 500292005300 Active datum: 4: 02 1/17/1970 00:00 @73.00usft (above Mean Sea Level) Date From - To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (--ft) 16:30 18:3 _ 020 0 DHB P DECOMP POOH W/ RTTS RUNNING TOOL. - PJSM. - POOH F/ 3,494'T/ 3,056'. - KICK WHILE TRIPPING DRILL- AAR AND REVIEW OF BOPE FAILURE CONTINGENCY PLAN 9.1 (REMOTE BOPE PANEL NOT FUNCTIONING). 18.30 - 19:30 1.00 DHB P DECOMP ,POOH W/ RTTS RUNNING TOOL. POOH F/ 3,056'T/ SURFACE - UD HES 9-5/8" RTTS. 19:30 - 22:00 2.50 DHB P DECOMP RIH WITH HES 9-5/8" RBP. - PJSM WITH HES TOOL REP. - RIH F/ SURFACE T/ 2,500'. 22:00 - 23:30 1.50 DHB P DECOMP SET HES RBP. - OBTAIN UP AND DOWN WEIGHTS PU WT 75K, DN WT 50K - SET RBP WITH 2 TURNS LEFT AND SET AT %2,495 CENTER OF ELEMENT - P/U 10K OVER TO VERIFY RBP SET. - SLACK OFF TO VERIFY SET DEPTH OF 2,500', SET 5K AND ROTATE STRING 1 TURN TO THE LEFT AND HOLD TORQUE. P/U TO VERIFY FREE OF RBP. - STAND BACK 2 STANDS. - R/U TEST EQUIPMENT. - TEST 250 PSI AND 3500 PSI FOR 5 MINS, BOTH TESTS GOOD. - 3 BBLS TO PRESSURE UP, BLED BACK 3 BBLS. - BLOW DOWN CHOKE AND KILL LINES AND TOP DRIVE. 23:30 - 00:00 0.50 DHB P DECOMP POUR SAND ON TOP OF RBP. - PJSM. -BRING SAND AND HOPPER TO RIG FLOOR. -MAKE ANNOUNCEMENT FOR USING BEAVER SLIDE PRIOR TO USING. 9/16/2014 00:00 - 03:00 3.00 DHB P DECOMP PLACE 50' OF RIVER SAND ON TOP OF 9-5/8" RBP, SET AT 2,500'. -PJSM. -RN SAND HOPPER WITH WATER LINE. -PLACE 50'/ 2,200 LBS / 44 SACKS OF RIVER SAND ON TOP OF 9-5/8" RBP. -M/U TOP DRIVE AND PUMP 25 BBLS OF SEAWATER DOWN DP TO ENSURE WORKSTRING IS FREE AND CLEAR OF RIVER SAND. -- 03:00 - 04:00 1.00 DHB P DECOMP PULL OUT OF HOLE WITH 9-5/8" RBP RUNNING TOOL. -POOH AND UD RBP RUNNING TOOL F/ 2,320'. - - WASH / FLUSH ROPE. _ 04:00 04.30 0.50 BOPSUR P DECOMP -R/U BOPE WASHER. -WASH / FLUSH BOPE CLEAN AND CLEAR OF DEBRIS. -UD BOPE WASHER. 04:30 - 05:30 1.00 BOPSUR P DECOMP RIG UP TO TEST BOPE. -R/U AND M/U ALL FLOOR VALVES, CROSSOVERS, AND EQUIPMENT TO TEST BOPE. Printed 10/13/2014 1:19:52PM North America - ALASKA - BP iso "� Page a3 of 7s Operation Summary Report Common Well Name: 01-02 AFE No Event Type: WORKOVER (WO) Start Date: 8/25/2014 End Date: X4 -0103J -E: (6,000,000.00 ) Project: Prudhoe Bay + Site: PB DS 01 Rig Name/No.: DOYON 14 Spud Date/Time: 1/17/1970 12:00:00AM Rig Release: 10/4/2014 Rig Contractor. DOYON DRILLING INC. UWI: 500292005300 Active datum: 4: 02 1/17/1970 00:00 @73.00usft (above Mean Sea Level) Date From - To Hrs Task Code NPT I NPT Depth Phase Description of Operations (hr) �— (usft)--- -- - 05:30 - 07:00 1.50 BOPSUR P DECOMP SHELL TEST 13-5/8" 5M BOPE. -PJSM ON TESTING BOPE, WITH PRESSURE CROSSCHECK DISCUSSION AND CONFIRMED CHALLENGE QUESTIONS WITH CORRECT RESPONSES. -FILL STACK AND CHOKE MANIFOLD TO MGS. "WELL KILL DRILL.— '6 BBLS TO FILL GAS BUSTER. -SHELL TEST BOPE WITH ANNULAR PREVENTER SHUT, TO 250 / 3,500 PSI. TEST PASS. *JEFF JONES WITH AOGCC, WAIVED WITNESS ON 9/15/2014 AT 11:43 HRS. 07:00 12:00 5.00 BOPSUR P DECOMP PRESSURE TEST 13-5/8" 5M BOPE. -TEST BOPE AS PER DDI SOP. -TEST BOPE WITH 4" AND 9-5/8" TEST JTS TO 250 / 3,500 PSI FOR 5 CHARTED MINS EACH. TEST PASS. -TEST ANNULAR PREVENTER WITH 4" TEST JT TO 250 / 3,500 PSI FOR 5 CHARTED MINS EACH. TEST PASS. -PERFORM ACCUMULATOR DRAW DOWN TEST. TEST PASS. _ 12:00 13:00 1.00 BOPSUR P DECOMP TRIG DOWN BOPE TEST EQUIPMENT. -R/DBOPE TEST ASSEMBLY AND EQUIPMENT. -BLOW DOWN CHOKE AND KILLS LINES. -M/U FOSV ON SAFETY JOINT. 13:00 - 13:30 0.50 CUT P DECOMP :MAKEUP B-1/4" MULTI -STRING CUTTER BHA -PJSM WITH BAKER REP. -P/U AND M/U MULTI -STRING CUTTER BHA. 13:30 - 14:00 0.50 CUT P DECOMP SERVICE RIG. -LUBRICATE TOP DRIVE, DRAW -WORKS AND ST -80. 14:00 - 19:00 5.00 CUT N RREP 11.57 DECOMP TROUBLESHOOT AND REPAIR CONTROL LINES ON DRAW -WORKS. -DISCOVERED LEAK ON PNEUMATIC CONTROL LINE AND HYDRAULIC CONTROL LINES IN POOR CONDITION. -REPLACE PNEUMATIC AND HYDRAULIC i CONTROL LINES. 19:00 - 21:00 2.00 CUT P DECOMP RUN IN THE HOLE WITH 8-1/4" MULTI -STRING CUTTER BHA#19. -RIH WITH MULTI -STRING CUTTER BHA F/ 11' AND TAG TOP OF SAND AT 2,442'. -P/U F/ 2,442'T/ 2,384'. -ESTABLISH PARAMETERS. -PUW= 90K, SOW= 90K, RTW- 90K, RPM= 60 WITH 1K FREE TORQUE, PUMP RATE= 6 BPM I WITH 560 PSI. -RIH WITH MULTI -STRING CUTTER BHA F/ 2,384' AND LOCATE COLLAR WITH KNIVES AT 2,423'. -SET KNIVES TO CUT 9-5/8" CSG AT 2,430'. *T BELOW COLLAR. Printed 10/13/2014 1:19:52PM North America - ALASKA - BP ' �F Page 44 of 79 F Operation Summary Report Common Well Name: 01-02 AFE No Event Type: WORKOVER (WO) Start Date: 8/25/2014 End Date: I X4 -0103J -E: (6,000,000.00) Project: Prudhoe Bay Site: PB DS 01 Rig Name/No.: DOYON 14 Spud Date/Time: 1/17/1970 12:00:OOAM Rig Release: 10/4/2014 Rig Contractor: DOYON DRILLING INC. UWI: 500292005300 Active datum: 4: 02 1/17/1970 00:00 @73.00usft (above Mean Sea Level) Date From - To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (usft) 21:00 - 22:00 1.00 CUT P DECOMP SAFETY MEETING. -PJSM WITH LRS CREW, MI REP, CH2 VAC -TRUCK OPER AND BAKER REP ON CUTTING 9-5/8" CASING AND ARCTIC -PACK DISPLACEMENT. -VERIFY AND WALK LINE-UP WITH PRESSURE CROSSCHECK DISCUSSION AND CONFIRMED CHALLENGE QUESTIONS WITH CORRECT RESPONSES. -POSITION AND R/U TRUCKS FOR ARCTIC -PACK DISPLACEMENT. -LRS, PRESSURE TEST LINES TO 250 / 3,500 PSI FOR 5'CHARTED MINS EACH. TEST —� -----PASS. 22:00 - 23:30 1.50 CUT P DECOMP CUT 9-5/8" CASING AT 2,430'. -CUT 9-5/8" CSG WITH 60 RPM AND 1-3K TORQUE, STAGING UP PUMP RATE F/ 3 BPM WITH 150 PSI T/ 6 BPM WITH 500 PSI. *OBSERVED PRESSURE DROP F/ 500 PSI T/ 420 PSI. "NO PRESSURE INDICATION ON OA. -SHUT DOWN PUMP AND CLOSE ANNULAR PREVENTER. 1 -ESTABLISH CIRCULATION AT 1 BPM WITH 1,550 PSI, TAKING RETURNS THRU THE OA TO THE FLOWBACK TANK, TO VERIFY 9-5/8" CSG CUT. -SHUT DOWN PUMP AND CLOSE OA. -VERIFY NO PRESSURE AND OPEN ANNULAR PREVENTER. 23:30 - 00:00 0.50 CUT P DECOMP RIG UP TO DISPLACE ARCTIC -PACK. -L/D 2 -SINGLES. -M/U FOSV, PUMP -N -SUB AND LINES TO DISPLACE ARCTIC -PACK. 9/17/2014 00:00 - 01:00 1.00 CUT P DECOMP SAFETY MEETING. -PJSM WITH LRS CREW, MI REP, CH2 VAC -TRUCK OPER AND BAKER REP ON CUTTING 9-5/8" CASING AND ARCTIC -PACK DISPLACEMENT. -VERIFY AND WALK LINE-UP WITH PRESSURE CROSSCHECK DISCUSSION AND CONFIRMED CHALLENGE QUESTIONS WITH -CORRECT RESPONSES. Printed 10/13/2014 1:19:52PM North America - ALASKA - BP f Operation Summary Report Common Well Name: 01-02 AFE No Event Type: WORKOVER (WO) Start Date: 8/25/2014 End Date: IX4-0103J-E: (6,000,000.00) Project: Prudhoe Bay Site: PB DS 01 - Rig Name/No.: DOYON 14 Spud Date/Time: 1/17/1970 12:OO:OOAM Rig Release: 10/4/2014 Rig Contractor: DOYON DRILLING INC. UWI: 500292005300 Active datum: 4: 02 1/17/1970 00:00 @73.00usft (above Mean Sea Level) Date From - To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (usft) -_ _ 101:00 - 03:30__t 2.50 CUT P DECOMP DIESEL SOAK ARCTIC-PACK -LRS, PUMP 23 BBLS OF 120° DIESEL DOWN DP AT 2 BPM WITH 540 PSI. -SHUT IN ANNULAR PREVENTER AND LINE-UP TO TAKE RETURNS THRU OA TO FLOWBACK TANK. -LRS, PUMP 104 BBLS OF 120° DIESEL DOWN DP AT 2 BPM WITH 1,431 PSI, TAKING RETURNS THRU OA TO FLOWBACK TANK *FINAL CIRC PRESSURE= 678 PSI -LINE-UP RIG PUMP. -PUMP 26 BBLS OF 120° 9.8 PPG BRINE DOWN DP AT 2 BPM WITH 110 PSI, TAKING RETURNS THRU OA TO FLOWBACK TANK 'FINAL CIRC PRESSURE= 40 PSI. SHUT DOWN PUMP. CLOSE FOSV AND OA VALVES. -ALLOW 1-HR TO DIESEL SOAK ARCTIC-PACK. 'SIMOPS: -R/D LRS LINES AND EQUIPMENT. 03:30 - 07:00 3.50 CUT P _FDECOMP DISPLACE ARCTIC-PACK FROM 13-3/8" x 9-5/8" ANNULUS. ' -LINE-UP AND DISPLACE ARCTIC-PACK WITH y'N2 BBLS OF 120° 9.8 PPG BRINE AT 2 BPM WITH 170 PSI, TAKING RETURNS THRU OA TO FLOWBACK TANK. -INCREASE PUMP RATE F/ 2 BPM T/ 5.5 BPM WITH 1,226 PSI FOR 128 BBLS. -PUMP 40 BBLS DEEP CLEAN PILLAT 4 BPM WITH 1,330 PSI. -PUMP 128 BBLS OF 120° 8.5 SEAWATER AT 4 BPM WITH 1,160 PSI. -PUMP 142 BBLS OF 120° 8.5 SEAWATER AT 8 BPM WITH 3,030 PSI. -SHUT DOWN PUMP. -VERIFY NO PRESSURE AND OPEN ANNULAR PREVENTER. -10 MIN FLOW CHECK. WELL STABLE. -PUMP 25 BBLS 120° 8.5 PPG SEAWATER AT 5 BPM WITH 30 PSI. RETURNS CLEAN. -BLOW DOWN AND R/D CIRC LINES. 07:00 09:00 2.00 CUT P DECOMP CUTAND SLIP DRILL LINE. -P/U AND M/U 2-SINGLES. -STAND BACK 1-STAND IN DERRICK -PJSM. -SLIP AND CUT 59.5' OF DRILL LINE AS PER DOYON PROCEDURES. -SERVICE TOP DRIVE AND BLOCKS. 09:00 - 10:00 1.00 CUT P DECOMP PULL OUT OF THE HOLE WITH 8-1/4" MULTI-STRING CUTTER BHA#19. -POOH MULTI-STRING CUTTER BHA F/ 2,385'. 10:00 - 10:30 0.50 CUT P DECOMP LAY DOWN 8-1/4" MULTI-STRING CUTTER BHA #19. -SERVICE BREAKAND CLEAR MULTI-STRING CUTTER BHA FROM RIG FLOOR. 10:30 - 12:00 1.50 CASING P DECOMP RIG UP 9-5/8" CASING EQUIPMENT. -PSJM WITH DOYON CASING AND BAKER REPS. -MOBE UHT POWER TONGS TO RIG FLOOR AND R/U. Printed 10/13/2014 1:19:52PM North America -ALASKA - B .r F Operation SummaryReport Common Well Name: 01-02 AFE No Event Type: WORKOVER (WO) Start Date: 8/25/2014 End Date: X4 -0103J -E: (6,000,000.00 ) Project: Prudhoe Bay Site: PB DS 01 Rig Name/No.: DOYON 14 Spud Date/Time: 1/17/1970 12:00:OOAM Rig Release: 10/4/2014 Rig Contractor: DOYON DRILLING INC. UWI: 500292005300 Active datum: 4: 02 1/17/1970 00:00 @73.00usft (above Mean Sea Level) Date From - To Hrs Task Code NPT NPDepth Phase Description of Operations eT p ( (u ) 12:00 13:00 1.00 CASING P DECOMP RETRIEVE 7" SUPPORT BUSHING. -PJSM WITH CAMERON, BAKER AND DOYON CASING REPS. -M/U 7" SUPPORT BUSHING RETRIEVAL TOOL. -ATTEMPT TO ENGAGE 7" SUPPORT BUSHING, WITH NO SUCCESS. -DISCUSS PLAN FORWARD WITH ODE. 13.00 16:00 3.00 CASING P DECOMP SPEAR 9-5/8" CASING AND PULL FREE TO RIG FLOOR. -PJSM WITH CAMERON, BAKER AND DOYON CASING REPS. -P/U AND M/U SPEAR BHA#20. ENGAGE 9-5/8" CSG BELOW MANDREL HANGER. CAMERON REP, BOLDS, -PULL 9-5/8" CSG FREE TO RIG FLOOR WITH 100K OVER PULL (250K ON WT INDICATOR). *OBSERVED ALL 4- EMERGENCY 9-5/8" CSG SLIP SEGMENTS MISSING. -POOH TO FIRST CONNECTION AND [ -- - RECOVERED 1- EMERGENCY SLIP SEGMENT. -INVESTIGATE BOPE IN SEARCH OF MISSING EMERGENCY SLIP SEGMENTS. -OBSERVED POSSIBLE MISSING CSG SLIP 1 SEGMENTS IN BLIND/SHEAR RAM CAVITY. -DISCUSS PLAN FORWARD WITH ODE. *REF. BREAKING CONTAINMENT MOC # ADW-MOC-12050 16:00 - 18:00 2.00 CASING P DECOMP I INSPECT BOPE RAM CAVITIES FOR MISSING 9-5/8" EMERGENCY CASING SLIP SEGMENTS. -PJSM WITH CAMERON AND BAKER REPS AND REVIEW HAZARD WORKSHEET ON OPENING BLIND/SHEAR RAM DOORS TO RECOVER MISSING EMERGENCY SLIP SEGMENTS. -OPEN BLIND/SHEAR RAM DOORS. *RECOVERED 1 OF 2 SLIP BOWL SEGMENTS AND 1- EMERGENCY SLIP SEGMENT. -VISUALLY INSPECT CASING HEAD THRU RAM CAVITY AND OBSERVED 2ND SLIP BOWL SEGMENT. -CLOSE AND SECURE BLIND/RAM DOORS. Printed 10/13/2014 1:19:52PM North America - ALASKA- BP Operation Summary Report j Common Well Name: 01-02 AFE No Event Type: WORKOVER (WO) Start Date: 8/25/2014 End Date: X4 -0103J -E: (6,000,000.00 ) Project: Prudhoe Bay Site: PB DS 01 Rig Name/No.: DOYON 14 Spud Date/Time: 1/17/1970 12:00:OOAM Rig Release: 10/4/2014 Rig Contractor: DOYON DRILLING INC. UWI: 500292005300 Active datum: 4 : 02 1/17/1970 00:00 @73.00usft (above Mean Sea Level) Date From - To Hrs Task Code NPT NPT Depth Phase Description of Operations -- - - 18:00 21:00 (hr)---— 3.00 rt (usft) CASING P DECOMP 'RECOVER MISSING 9-5/8" EMERGENCY CASING SLIP AND BOWL SEGMENTS. -PJSM WITH CAMERON AND BAKER REPS AND REVIEW HAZARD WORKSHEET ON N/D BOPE AT UNI CLAMP SPOOL. -CAMERON REP, RILDS TO PREVENT SLIP BOWL SEGMENT FROM MOVING DOWN HOLE. -N/D BOPE AT UNI CLAMP SPOOL. -R/D FLOW LINE AND RISER. BOPE AND RECOVERED 2ND SLIP BOWL k-P/U SEGMENT. -VISUALLY INSPECT WELLHEAD AND OBSERVED REMAINING 2- EMERGENCY SLIP SEGMENTS ON 9-5/8" CSG COLLAR. -PJSM WITH CAMERON AND BAKER REPS WITH HAZARD ASSESSMENT ON PULLING UP HOLE ON 9-5/8" CSG STRING WITH BOPE STACK SPLIT. f -CAMERON REP, BOLDS. i -P/U 9-5/8" CSG STRING SLOWLY ±20'. *RECOVERED REMAINING 2- EMERGENCY SLIP SEGMENTS FROM 9-5/8" CSG COLLAR. *ALL 9-5/8" BOWLAND SLIP SEGMENTS RECOVERED. 21:00 00:00 3.00 CASING P DECOMP NIPPLE UP BOPS. -SET DOWN BOPE. CAMERON REP, INSTALLAND TORQUE UNI CLAMP TO 1,800 FT/LBS. -INSTALL RISER AND FLOW LINE. *PUW= 155K, SOW= 145K - -- -- - - 9/18/2014 00:00 01:00 1.00 CASING P DECOMP : INSTALL FLOW LINE. -PJSM. -INSTALLAND SECURE FLOW LINE. -CENTER BOPE. 1.00 CASING P DECOMPS EH LL TEST BOPE AND BREAKS. 01:00 - 02:00 -PJSM. -R/U TEST EQUIPMENT AND LINES. -SHELL TEST BOPE AND BREAKS TO 250 / 1,000 PSI FOR 5 CHARTED MINS EACH. LEAK TIGHT TEST. -BLOW DOWN TOP DRIVE AND CHOKE MANIFOLD. -R/D TEST EQUIPMENT AND LINES. 02:00 04:00 2.00 CASING P DECOMP LAY DOWN GRAPPLE SPEAR BHA#20. -PSJM WITH BAKER REP. -LAY DOWN GRAPPLE SPEAR BHA WITH 9-5/8" CUT JT. -REMOVE 9-5/8" PACK -OFF. M/U CROSSOVERS AND R/U 9-5/8" HANDLING EQUIPMENT. 04.00 - 07:00 3.00 CASING P _ DECOMP PULL OUT OF THE HOLE LAYING DOWN 9-5/8" CASING FROM CUT AT 2,430'. -POOH, LAYING DOWN 9-5/8" CUT JOINT AND GRAPPLE SPEAR BHA F/ 2,430'T/ OVERSHOT PATCH AT 1,224'. Printed 10/13/2014 1.19:52PM North America - ALASKA - BP 79 Operation Summary Reports Common Well Name: 01-02 AFE No Event Type: WORKOVER (WO) Start Date: 8/25/2014 End Date: IX4-0103J-E: (6,000,000.00) Project: Prudhoe Bay Site: PB DS 01 Rig Name/No.: DOYON 14 Spud Date/Time: 1/17/1970 12:00:OOAM Rig Release: 10/4/2014 Rig Contractor: DOYON DRILLING INC. UN: 500292005300 Active datum: 4: 02 1/17/1970 00:00 @73.00usft (above Mean Sea Level) Date From - To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (usft) 07:00 - 11:00 4.00 CASING P DECOMP LAY DOWN 9-5/8" OVERSHOT PATCH. -PJSM WITH RIG TEAM AND BAKER REP ON HANDLING CSG PATCH. -CONTACT WELLHEAD REP FOR WACH'S CUTTER AND INSTRUCTED FISHING REP TO OBTAIN SPEAR FOR CONTINGENCY. -BREAK JT LOOSE OF 9-5/8" FROM TOP OF CSG PATCH WITH PULL TONGS. -P/U STRING AND SECURE STRING ON JT OF CSG UNDER PATCH. -LAY DOWN 1 JOINT OF 9-5/8" CSG ABOVE 'OVERSHOT. -MAKE UP 9-5/8" CROSSOVER TO STUMP AND CHANGE OUT 9-5/8" ELEVATORS TO 4-1/2". -PICK UP STRING AND TO VERIFY HEIGHT AND ABILITY TO LAY DOWN OVERSHOT WITH JT OF CASING BELOW ON PIPE SKATE. -LAY DOWN OVERSHOT. 11:00 - 13:30 2.50 CASING P DECOMP PULL OUT OF THE HOLE LAYING DOWN 9-5/8" CASING FROM CUT AT 2,430'. -M/U CROSSOVERS FOR WELL CONTROL. -POOH, LAYING DOWN 9-5/8" CSG TO PIPE SHED F/ 1,224'T/ SURFACE. t*RECOVERED: 56- JTS OF 9-5/8" CSG, 1- FO COLLAR, 1- CSG PATCH AND 2- CUT JT OF 9-5/8" CSG 7.6' LONG WITH 10-1/2" FLARE ON CUT. 13:30 - 18:00 4.50 CASING P DECOMP RIG DOWN POWER TONGS AND 9-5/8" HANDLING EQUIPMENT. -PJSM WITH DOYON CASING REP. -R/D UHT POWER TONGS AND 9-5/8" HANDLING EQUIPMENT. -CLEAN AND CLEAR RIG FLOOR OF ALL 9-5/8" EQUIPMENT. -CLEAN RIG FLOOR AND DRIP PAN OF ARCTIC PACK. -P/U SPEAR BHA WITH 9-5/8" CUT JT FROM PIPE SHED. -DISENGAGE SPEAR, SERVICE BREAK SPEAR BHA, UD 9-5/8" CUT JT AND SPEAR BHA. 18:00 20:30 2.50 CASING P DECOMP MAKE UP 12" x 9-5/8" DRESS -OFF SHOE / 13-3/8" CASING SCRAPER BHA#21. -PJSM WITH BAKER REP. -P/U, M/UAND RIH WITH DRESS -OFF BHA TO 221'. 20:30 - 22:00 1.50 CASING P DECOMP RUN IN HOLE 12" x 9-5/8" DRESS -OFF SHOE / 13-3/8" CASING SCRAPER BHA#21. -RIH WITH DRESS -OFF BHA F/ 221' T/ 2,405'. -ESTABLISH PARAMETERS AND OBTAIN SPRs. *PUW= 100K, SOW= 100K, RTW= 100K, RPM= 60 WITH 1-2K FREE TORQUE, PUMP RATE= 8 BPM WITH 300 PSI. 22:00 23:00 1.00 CASING P DECOMP DRESS -OFF 9-5/8" CASING STUB AT 2,430'. -RIH WITH DRESS -OFF BHA F/ 2,405' AND TAG TOP OF 9-5/8" STUB AT 2,430'. -DRESS-OFF 9-5/8" STUB F/ 2,430'T/ 2,431', AS PER BAKER REP. *RPM= 60 WITH 2-4K TORQUE, PUMP RATE 8 J BPM WITH 300 PSI Printed 10/13/2014 1:19:52PM North America -ALASKA - BP Operation Summary Report ; ,r Common Well Name: 01-02 AFE No Event Type: WORKOVER (WO) Start Date: 8/25/2014 End Date: X4 -0103J -E: (6,000,000.00 ) Project: Prudhoe Bay Site: PB DS 01 Rig Name/No.: DOYON 14 Spud Date/Time: 1/17/1970 12:00:OOAM Rig Release: 10/4/2014 Rig Contractor: DOYON DRILLING INC. UWI: 500292005300 Active datum: 4: 02 1/17/1970 00:00 @73.00usft (above Mean Sea Level) Date From - To Hrs Task Code NPT NPT Depth Phase Description of Operations 23:00 - 00:00 (hr) 1.00 CASING P (usft) DECOMP CIRCULATE TO CLEAN AND CLEAR WELLBORE OF ARCTIC PACK.. -CIRC, WHILE ROTATING AND RECIPROCATING 30' AT 8 BPM WITH 300 PSI. 9/19/2014 00:00 - 02:30 2.50 CASING P DECOMP CIRCULATE TO CLEAN AND CLEAR WELLBORE OF ARCTIC PACK.. -PJSM WITH BAKER REP. -CLOSE ANNULAR PREVENTER. -PUMP 100 BBLS OF 8.5 SEAWATER, TAKING RETURNS TO FLOWBACK TANK AT 6 BPM WITH 500 PSI. -RETURNS CLEANED UP. -10 MIN FLOW CHECK. WELL STABLE. -VERIFY NO PRESSURE AND OPEN ANNULAR PREVENTER. -SLACK OFF OVER 9-5/8" STUB WITH INDICATION OF STUB ON WT INDICATOR. -STANDBACK 1- STD OF DP. -PUMP 30 BBL HI -VIS SWEEP AROUND AT 12 BPM WITH 500 PSI, ROTATING 40 RPM AND RECIPROCATING 90'. 02:30 - 03:00 0.50 CASING P DECOMP PULL OUT OF HOLE WITH 12" x 9-5/8" PRESS -OFF SHOE / 13-3/8" CASING SCRAPER -POOH WITH DRESS -OFF BHA F/ 2,372'T/ 1,930'. 03:00 - 03:30 0.50' CASING P DECOMP CIRCULATE. -ESTABLISH PARAMETERS. "PUW= 90K, SOW= 90K, RTW= 90K, RPM= 40 WITH 1-2K TORQUE, PUMP RATE= 12 BPM WITH 470 PSI -CIRC B/U AT 12 BPM WITH 470 PSI WHILE ROTATING 40 RPM AND RECIPROCATING 90'. -10 MIN FLOW CHECK. WELL STABLE. 03:30 - 04:00 0.50 CASING P DECOMP PULL OUT OF HOLE WITH 12" x 9-5/8" DRESS -OFF SHOE / 13-3/8" CASING SCRAPER BHA #21. -POOH WITH DRESS -OFF BHA F/ 1,930' T/ 260'. -10 MIN FLOW CHECK BEFORE PULLING NON-SHEARABLES ACROSS BOPE. WELL STABLE. 04:00 - 06:00 2.00 CASING P DECOMP LAY DOWN 12" x 9-5/8" DRESS -OFF SHOE / 13-3/8" CASING SCRAPER BHA#21. -PJSM WITH BAKER REP. -POOH, LAYING DOWN DRESS -OFF BHA F/ 260'. DECOMP WASH / FLUSH BOPE. 06:00 - 07:00 1.00 CASING P -BREAK DOWN SAFETY JOINT. -R/U BOPE WASHER. -WASH / FLUSH AND FUNCTION BOPE TO ENSURE CLEAN AND CLEAR OF DEBRIS. -L/D_ BOPE WASHER. Printed 10/13/2014 1:19:52PM Printed 10/13/2014 1:19:52PM North America - ALASKA - BP Page 50 of 79 Operation Summary Report Common Well Name: 01-02 AFE No Event Type: WORKOVER (WO) Start Date: 8/25/2014 End Date: X4 -0103J -E: (6,000,000.00) Project: Prudhoe Bay Site: PB bs 01 Rig Name/No.: DOYON 14 Spud Date/Time: 1/17/1970 12:00:OOAM Rig Release: 10/4/2014 Rig Contractor: DOYON DRILLING INC. UWI: 500292005300 Active datum: 4: 02 1/17/1970 00:00 @73.00usft (above Mean Sea Level) Date From - To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (usft) — --- 07:00 10:30 3.50 WHSUR P i DECOMP i PREPARE AND NIPPLE DOWN BOPE. -PJSM WITH RIG CREW AND CAMERON REPS. -VOID BOPE OF FLUID. -REMOVE MOUSE HOLE AND FLOW LINE. -BLOW DOWN CHOKE, KILL AND HOLE FILL LINES. -BLEED DOWN KOOMEY. -CLEAN AND CLEAR DRIP PAN OF ARCTIC -PACK. N/D BOPE AT UNI -CLAMP SPACER SPOOL AND SECURE BOPE ON STUMP. 10:30 - 12:00 1.50 WHSUR PED COMP NIPPLE DOWN 21-1/4" x 13-5/8" UNI -WELLHEAD. -PJSM WITH RIG CREW AND CAMERON REPS. -VOID UNI -WELLHEAD OF FLUID. N/D UNI -WELLHEAD AND REMOVE FROM CELLAR. 12:00 - 13:00 1.00 WHSUR P DECOMP MAKE UP 13-3/8" MULTI -CUTTER BHA#22. -PJSM WITH RIG CREW, BAKER AND CAMERON REPS. -M/U MULTI -STRING CUTTER BHA. **TABLE TOP WELL CONTROL DRILL DISCUSSING CONTINGENCIES WITH NO BOPE ON THE WELL.** 13:00 - 15:00 2.00 WHSUR P DECOMP PREPARE TO CUT AND REMOVE 13-3/8" CASING WITH 21-1/4" UNI -WELLHEAD. -HAND CUT 3" PIPE ON VALVE IN CELLAR. i -REMOVE LOWER UNI -CLAMP BETWEEN 20" AND 13 3/8" CASING, WITH BRIDGE CRANE. 15:00 18:30 3.50 CUT P DECOMP CUT 13-3/8" CASING WITH MULTI -STRING CUTTER. -RIH AND CUT 13-5/8" CASING AT 44' BELOW ROTARYTABLE. *60 RPM WITH 3K TORQUE, STAGE PRESSURE UP F/ 300 PSI T/ 1,250 PSI. -BLED OFF PRESSURE AND POOH. -REMOVE 21-1/4" WELLHEAD WITH 13-3/8' CSG STUB FROM CELLAR. - - - 18:30 - 22:30 - 1 4.00 CUT P DECOMP PREPARE AND CUT 20" CASING WITH MULTI -STRING CUTTER BHA#23. -PJSM WITH RIG CREW, BAKER AND CAMERON REPS. -CHANGE OUT KNIVES ON MULTI -STRING I CUTTER. -RIH AND CUT 20" AT 39.5' FROM ROTARY TABLE. *60 RPM WITH 3K TORQUE, STAGE PRESSURE UP F/ 300 PSI T/ 1,250 PSI. -BLED OFF PRESSURE AND POOH. -UD MULTI -STRING CUTTER BHA#23. 22:30 00:00 1.50 CUT P DECOMP REMOVE 20" HANGER WITH CASING STUB FROM CELLAR. -R/U AND REMOVE 20" HANGER WITH CASING STUB FROM CELLAR. -VOID 20" AND 20" x 30" ANNULUS OF FLUID. Printed 10/13/2014 1:19:52PM North America - ALASKA - BP Page 51 of 79 Operation Summary Report Common Well Name: 01-02 AFE No Event Type: WORKOVER (WO) Start Date: 8/25/2014 End Date: X4 -0103J -E: (6,000,000.00 ) Project: Prudhoe Bay Site: PB DS 01 Rig Name/No.: DOYON 14 Spud Date/Time: 1/17/1970 12:00:OOAM Rig Release: 10/4/2014 Rig Contractor: DOYON DRILLING INC. UWI: 500292005300 Active datum: 4: 02 1/17/1970 00:00 @73.00usft (above Mean Sea Level) Date From - To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (usft) 9/20/2014 00:00 - 02:00 2.00 CUT P DECOMP PREPARE TO CUT AND REMOVE 30" CASING FROM CELLAR. -PJSM, REVIEWING APPROVED L2RAAND HAZARD WORK WITH RIG CREW, DOYON HSE, BP HSE, RWO SUPT, CAMERON AND BAKER REPS. -VOID 20" AND 20" x 30" ANNULUS OF FLUID IN PREPARATION FOR 30" CSG CUT. -LINE CELLAR WALLS AND GROUND LEVEL ON TOP OF GRAVEL WITH FIRE BLANKETS. -R/U WATER TRUCK AND FOAM EQUIPMENT. -ATTEMPT TO FILL 20" AND 20" x 30" ANNULUS WITH FOAM BARRIER, FOR CUTTING 30" CSG, WITH NO SUCCESS. -DISCUSS AND TROUBLESHOOT FOAM EQUIPMENT WITH ASST. FIRE CHIEF. -ATTEMPT TO OPERATE FOAM EQUIPMENT WITH NO SUCCESS, DUE TO PRESSURE LIMITATIONS OF WATER TRUCK. -DISCUSS RESULTS PLAN FORWARD WITH ASST FIRE CHIEF. 02:00 - 08:00 6.00 CUT -N SFAL DECOMP WAIT ON EQUIPMENT. -WAIT ON WATER TRUCK FROM FIRE DEPARTMENT. -FIRE TEAM AND EQUIPMENT ARRIVED ON LOCATION. -PJSM, REVIEWING APPROVED L2RAAND HAZARD WORK WITH RIG CREW AND FIRE -- FIGHTING CREW. -RN FOAM EQUIPMENT TO FIRE FIGHTING CREWS WATER TRUCK. -ATTEMPT TO FILL 20" AND 20" x 30" ANNULUS WITH FOAM BARRIER, FOR CUTTING 30" CSG, WITH NO SUCCESS. -MANUALLYAERATE FOAM CONCENTRATE AND FILL 20" AND 20" x 30" ANNULUS WITH FOAM BARRIER. —CONDUCT TABLE TOP MAN DOWN AND RIG EVACUATION DRILLS FOLLOWED BY AAR.- 08:00 - 09:00 1.00 CUT P DECOMP CUT 30" CONDUCTOR CASING. -CUT 30" CONDUCTOR 36" BELOW GROUND LEVEL AND REMOVE FROM CELLAR. 09:00 - 10:00 1.00 CUT P DECOMP CUT 20" CASING AND INSTALL LANDING RIG FOR SLIP LOCK WELLHEAD. -PJSM WITH CAMERON AND FMC REPS. -CAMERON REPS, R/U.WACH'S CUTTER AND PERFORM FINAL CUT ON 20" CSG. -FMC, PREP 20" CSG AND INSTALL LANDING RING. 'SIMOPS: -MORE VOLANT TOOL AND EQUIPMENT TO RIG FLOOR. 10:00 - 12:30 2.50 TIEBAC P OTHCMP RIG UP 9-5/8" RUNNING AND HANDLING EQUIPMENT. -PJSM WITH RIG CREW, BAKER AND DOYON CASING REPS. -INSTALL BALE EXTENSIONS. -R/U VOLANT TOOL AND 9-5/8" HANDLING EQUIPMENT. -CLEAN AND CLEAR RIG FLOOR IN PREPARATION FOR RUNNING 9-5/8" CSG PATCH. Printed 10/13/2014 1:19:52PM Common Well Name: 01-02 Event Type: WORKOVER (WO) Project: Prudhoe Bay Rig Name/No.: DOYON 14 Rig Contractor: DOYON DRILLING INC. Active datum: 4: 02 1/17/1970 00:00 @73.00usft Date From - To Hrs (hr) 12:30 - 20:30 8.00 20:30 - 22:30 1 2.00 Printed 10/13/2014 1:19:52PM North America - ALASKA - BP Operation Summary Report Start Date: 8/25/2014 End Date Site: PB DS 01 Spud Date/Time: 1/17/1970 12:00:OOAM ve Mean Sea Level) Task Code NPT NPT Depth Pha (usft) TIEBAC P OTH Page 52 of 79 1 AFE No _ - - X4 -0103J -E: (6,000,000.00 ) Rig Release: 10/4/2014 UWI: 500292005300 se Description of Operations CMP RUN 9-5/8"47# L-80 VAMTOP CASING PATCH, UTILIZING VOLANT TOOL.. -PJSM WITH RIG CREW, HES, DOYON CASING AND BAKER REPS. -P/U, M/U AND RIH WITH 9-5/8" CSG PATCH AS PER RUNNING TALLY TO 2,414'. -OBTAIN PARAMETERS. *PUWAND SOW= 155K IN 8.5 PPG SEAWATER. P/U, M/U AND RIH WITH 10.48' AND 20.33' SPACE OUT PUPS. -RIH F/ 2,414' AND TAG TOP OF 9-5/8" STUB AT 2,430'. -P/U STRING 5', ROTATE STRING AT 10 RPM AND SLACK OFF OVER 9-5/8" STUB. -SHUTDOWN ROTATION. -ENGAGE 9-5/8" BOWEN CSG PATCH, AS PER BAKER REP. *NO-GO ON 9=5/8" CSG STUB WITH 40K DOWN, PULL 100K OVER AND SET SLIPS. ALL VAMTOP CONNECTIONS TORQUE -N -TURN WITH TORQUE TO 15,900 FT/LBS. *1 -SOLID BODY, STRAIGHT VAIN CENTRALIZER INSTALLED FROM JT #1 TO JT #56. *TOTAL CENTRALIZER = 56 OTHCMP SET BAKER 9-5/8" ECP AND SHEAR HES ES CEMENTER OPEN. -PJSM WITH BAKER AND HES REPS. PRESSURE CROSSCHECK DISCUSSION AND CONFIRMED CHALLENGE QUESTIONS WITH CORRECT RESPONSES. -PRESSURE TEST 9-5/8" CSG PATCH TO 2501 1,000 PSI FOR 5 CHARTED MINS. TEST PASS. -PULL 100K OVER ON STRING FOR FINAL WTPLACEMENT OF CSG PATCH.(250K ON W INDICATOR) -INCREASE PRESSURE TO OPEN ECP INFLATION VALVE, IN 200 PSI INCREMENTS, F/ 1,000 PSI T/ 1,670 PSI, AS PER BAKER REP. *OBSERVED ECP INFLATION VALVE OPEN AT 1,670 PSI. -PRESSURE UP TO 2,000 PSI TO ENSURE ECP FULLY INFLATED. -PRESSURE TEST 9-5/8" CSG PATCH TO 2,000 PSI FOR 10 CHARTED MINS. TEST PASS. *2.1 BBLS TO PRESSURE UP TO 2,000 PSI. -BLEED PRESSURE TO 0 PSI. -PRESSURE UP TO 3,000 PSI AND OBSERVED ES CEMENTER SHEAR OPEN. *4.8 BBLS TO PRESSURE UP TO 2,000 PSI. -PUMP 10 BBLS AT 5 BPM WITH 90 PSI TO CONFIRM ES CEMENTER OPENED. North America - ALASKA - BP Page 53 of 79 Operation Summary Report Common Well Name: 01-02 AFE No Event Type: WORKOVER (WO) Start Date: 8/2512014 End Date: X4 0103)-E: (6,000,000.00 ) Project: Prudhoe Bay Site: PB DS 01 Rig Name/No.: DOYON 14 Spud Date/Time: 1/17/1970 12:00:OOAM Rig Release: 10/4/2014 Rig Contractor: DOYON DRILLING INC. UWL 500292005300 Active datum: 4: 02 1/17/1970 00:00 @73.00usft (above Mean Sea Level) Date From - To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (usft) 22:30 23:30 _ 1.00 TIEBAC P OTHCMP PRESSURE TEST CEMENT EQUIPMENT AND LINES. -PJSM WITH HES, SLB AND BAKER REPS. PRESSURE CROSSCHECK DISCUSSION AND CONFIRMED CHALLENGE QUESTIONS WITH CORRECT RESPONSES. -PUMP 5 BBLS TO PURGE CEMENT LINES. -FUNCTION TEST OVERPRESSURE PROTECTION DEVICES. 'WSL VERIFIED PUMP TRIPS FUNCTION PROPERLY ON BOTH HEADS. -PRESSURE TEST CEMENT EQUIPMENT AND LINES TO 250 / 4,000 PSI FOR 5 CHARTED MINS EACH. TEST PASS. 23:30 00:00 0.50 TIEBAC P OTHCMP CEMENT 9-5/8" CASING PATCH. -LINE UP CEMENT UNIT TO WELL. -MIX AND PUMP 165 BBLS OF 15.8 PPG CLASS G CEMENT. `YIELD = 1.17 CUFT/SK SHUTDOWN CEMENT UNIT. 9/21/2014 00:00 - 01:00 1.00 TIEBAC P OTHCMP CEMENT 9-5/8" CASING PATCH. -PJSM WITH HES, SLB AND BAKER REPS. PRESSURE CROSSCHECK DISCUSSION AND CONFIRMED CHALLENGE QUESTIONS WITH CORRECT RESPONSES. -RELEASE VOLANT TOOL. -INSTALL ES CEMENTER CLOSER PLUG. -INSERT VOLANT TOOL. -SLB CEMENTERS, KICK OUT CLOSER PLUG WITH 5 BBLS FRESH WATER. -SHUT DOWN CEMENT UNIT. -LINE UP RIG PUMPS TO DISPLACE CMT. -DISPLACE CMT WITH 8.5 PPG SEAWATER AT 7 BPM WITH 170 PSI. 'CAUGHT CLOSER PLUG AT 80 BBLS DISPLACED. -DISPLACE CMT WITH 8.5 PPG SEAWATER AT 5 BPM WITH 480 PSI. 'CMT RETURNS TO SURFACE AT 150 BBLS DISPLACED. -SLOWED PUMP TO 2 BBLS WITH 1,020 PSI, AT 165 BBLS DISPLACED. -BUMPED PLUG ON SCHEDULE AT 175 BBLS TOTAL DISPLACEMENT. `FINAL DISPLACEMENT PRESSURE = 1,020 PSI. `BUMPED PLUG AND CLOSE ES CEMENTER WITH 1,950 PSI. HELD FOR 5 MINS. -BLED OFF PRESSURE AND CHECK FLOATS. FLOATS HELD. -CEMENT IN PLACE WITH PLUG BUMPED AT 01:00 HRS ON 9/21/2014. 'UCA RESULTS: 500 PSI COMPRESSIVE STRENGTH AT 12 HRS: 05 MINS. -R/D CMT EQUIPMENT, LINES AND VOLANT TOOL. 01:00 - 02:30 1.50 TIEBAC P OTHCMP CLEAR RIG FLOOR. -CLEAN AND CLEAR RIG FLOOR OF VOLANT TOOL, 9-5/8" RUNNING AND HANDLING EQUIPMENT. -CLEAN AND CLEAR CELLAR BOX OF FLUID. Printed 10/13/2014 1:19:52PM Printed 10/13/2014 1:19:52PM North America - ALASKA - BP Page 54 of as Operation Summary Report Common Well Name. 01-02 AFE No Event Type: WORKOVER (WO) I Start Date: 8/25/2014 End Date: X4 -0103J -E: (6,000,000.00 ) Project: Prudhoe Bay Site: PB DS 01 Rig Name/No.: DOYON 14 Spud Date/Time: 1/17/1970 12:00:OOAM Rig Release: 10/4/2014 Rig Contractor: DOYON DRILLING INC. UWI: 500292005300 Active datum: 4: 02 1/17/1970 00:00 @73.00usft (above Mean Sea Level) Date From - To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (usft 02:30 - 03:00 0.50 TIEBAC _ P OTHCMP I INSTALL 9-5/8" EMERGENCY CASING SLIPS. -PJSM WITH RIG CREW, FMC AND CAMERON REPS. -VOID 13-3/8" OF FLUID TO SET EMERGENCY CASING SLIPS. -FMC, INSTALL EMERGENCY CASING SLIPS L AND ENERGIZE WITH 100K. LOCK .. 03:00 05:00 2.00 j WHSUR P OTHCMP i INSTALL 9-5/8" x 11"5M SLIP WELLHEAD. -PJSM WITH RIG CREWAND CAMERON REP. -VOID 9-5/8" CSG OF FLUID IN PREPARATION FOR WACH'S CUT. -CAMERON WACH'S CUT 9-5/8". -L/D PUP JTS AND 9-5/8" CUT JT. -INSTALL SLIP LOCK WELLHEAD. *CONFIRM ORIENTATION OF NEW HEAD WITH DSO. _ 05:00 10:30 5.50 WHSUR P OTHCMPN' IPPLE UP 9-5/8" x 11" 5M SLIP LOCK WELL HEAD AND TEST VOID AND SEALS. -PJSM WITH RIG CREWAND CAMERON REP. -TIGHTEN DOWN SLIP LOCK WELLHEAD AS DIRECTED BY CAMERON. -PRESSURE TEST SLIP LOCK VOID AND I � SEALS T/ 250 PSI. FOR 5 CHARTED MINS. AND 3,500 PSI. FOR 30 CHARTED MINS. TEST I PASS. -� 10:30 - 14:00 _ 3.50 BOPSUR P OTHCMP NIPPLE UP 11" 5M x 13-5/8" 5M ADAPTER SPOOL WITH 7'13-5/8" 5M SPACER SPOOL. -N/U ADAPTER SPOOL AND 7' SPACER SPOOL. 14:00 - 15:30 1.50 BOPSUR P 1 OTHCMP SAFE -OUT CELLAR. -CONSTRUCT WORK PLATFORM IN CELLAR. -INSTALL BARRICADE AROUND CELLAR AREA. 115:30 - 19:30 4.00 BOPSUR P OTHCMP NIPPLE UP 13-5/8" 5M BOPE. -PJSM. -N/U 13-5/8" BOPE AND CENTER WITH ROTARY. -R/U BELL NIPPLE, FLOW LINE, HOLE FILL LINE, BLEEDER LINES AND MOUSE HOLE. 19:30 - 22:00 2.50 BOPSUR P OTHCMP I SHELL TEST 13-5/8" 5M BOPE. -PJSM ON SHELL TESTING BOPE, WITH PRESSURE CROSSCHECK DISCUSSION AND CONFIRMED CHALLENGE QUESTIONS WITH CORRECT RESPONSES. -R/U BOPE TEST EQUIPMENT. -PURGE STACKAND CHOKE MANIFOLD TO MGS. ' *6 BBLS TO FILL GAS BUSTER. -SHELL TEST BOPE WITH ANNULAR PREVENTER SHUT ON 4" TEST JT, TO 250 / 13,500 PSI FOR 5 CHARTED MINS EACH. TEST PASS. -R/D BOPE TEST EQUIPMENT. -BLOW DOWN CHOKE AND KILL LINE. -INSTALL WEAR BUSHING. *I D= 9-1/16" Printed 10/13/2014 1:19:52PM North America - ALASKA - BP r�'� f Page 5s of 79 t t Operation Summary Report Common Well Name: 01-02 AFE No Event Type: WORKOVER (WO) Start Date: 8/25/2014 End Date: X4 -0103J -E: (6,000,000.00 ) Project: Prudhoe Bay Site: PB DS 01 Rig Name/No.: DOYON 14 Spud Date/Time: 1/17/1970 12:00:OOAM Rig Release: 10/4/2014 Rig Contractor: DOYON DRILLING INC. UVW 500292005300 Active datum: 4: 02 1/17/1970 00:00 @73.00usft (above Mean Sea Level) Date From - To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (usft) - 22:00 - 00:00 2.00 TIEBAC P OTHCMP MAKE UP 8-1/2" DRILL -OUT BHA#24. -PJSM WITH BAKER REP. -MOBE DRILL -OUT BHA EQUIPMENT TO RIG FLOOR. -P/U AND M/U DRILL -OUT BHA, AS PER BAKER REP. 9/22/2014 00:00 - 01:00 1.00 TIEBAC P OTHCMP MAKE UP 8-1/2" DRILL -OUT BHA #24. =PJSM WITH BAKER REP. -MOBE DRILL -OUT BHA EQUIPMENT TO RIG FLOOR. -P/U, M/U AND RIH WITH DRILL -OUT BHA TO 01:00 - 02:30 240'.- 1.50 TIEBAC P OTHCMP RUN IH HOLE WITH, 8-1/2" DRILL -OUT BHA #24. -CHANGE 5" ELEVATORS TO 4" ELEVATORS. -RIH WITH DRILL -OUT BHA F/ 240'T/2,329'. -ESTABLISH PARAMETERS AND OBTAIN SPR. *PUW= 95K, SOW --100K, RTW= 100K, RPM= I 60 WITH 1 K FREE TORQUE, PUMP RATE= 8 BPM WITH 400 PSI -- 02:30 - 04:30 2.00 TIEBAC P ! OTHCMP DRILL -OUT 9-5/8" CASING PATCH SHOE TRACK. -RIH WITH DRILL -OUT BHA F/ 2,329' AND TAG TOP OF CMT AT 2,380' WITH 5K WOB. - -DRILL CMT F/ 2,380'T/ ES CEMENTER AT 2,385'. *RPM= 60 WITH 1 K TORQUE, WOB= 3-4K -DRILL ES CEMENTER F/ 2,385'. *RPM= 70 WITH 1-2K TORQUE, WOB= 5-6K 04:30 - 05:00 0.50 TIEBAC P OTHCMP SERVICE RIG. -LUBRICATE TOP DRIVE, DRAW -WORKS AND ST -80. 05:00 - 07:00 2.00 TIEBAC P OTHCMP DRILL -OUT 9-5/8" CASING PATCH SHOE TRACK. -DRILL ES CEMENTER F/ 2,385'T/ 2,390'. -DRILL HARD CMT F/ 2,390' T/ TOP OF SAND AT 2,447'. *RPM= 70 WITH 1-2K TORQUE, WOB= 5.6K -DRY DRILL ON TOP OF SAND FOR 15 MINS. *RPM= 60 WITH 1-2K TORQUE, WOB= 5-6K *24 HR NOTICE OF INTENT TO PERFORM WEEKLY BOPE TEST, SUBMITTED ON 09/22/2014 06:03. 07:00 - 08:00 1.00 TIEBAC P OTHCMP CIRCULATE SWEEP AROUND. -STAND BACK 1 -STD OF 4" DP. -PUMP 15 BBL HI -VIS SWEEP AROUND AT 10 BPM WITH 590 PSI, RECIPROCATING STRING 60'. 08:00 - 08:30 0.50 TIEBAC P OTHCMP PULL OUT OF HOLE WITH 8-1/2" DRILL -OUT BHA #24. -10 MIN FLOW CHECK. WELL STABLE. -POOH WITH DRILL -OUT BHA F/ 2,424'T/ 360'. 08:30 - 10:00 1.50 TIEBAC P OTHCMP LAY DOWN 8-1/2" DRILL -OUT BHA#24. -10 MIN FLOW CHECK FOR NON-SHEARABLES ACROSS THE BOPE. WELL STABLE. -STAND BACK 6-1/4" DC AND UD DRILL -OUT BHA. -EMPTY BOOT BASKETS. *RECOVERED: 1/2 GAL OF METAL SHAVINGS FROM DITCH MAGNET. Printed 10/13/2014 1:19:52PM North America - ALASKA - BP f. ,, , ... ,,Y ,, i", ,r Pass s6 of 79 Operation Summary Report Common Well Name: 01-02 AFE No Event Type: WORKOVER (WO) Start Date: 8/25/2014 End Date: X4 -0103J -E: (6,000,000.00 ) Project: Prudhoe Bay Site: PB DS 01 Rig Name/No.: DOYON 14 Spud Date/Time: 1/17/1970 12:00:OOAM Rig Release: 10/4/2014 Rig Contractor: DOYON DRILLING INC. UWI: 500292005300 Active datum: 4: 02 1/17/1970 00:00 @73.00usft (above Mean Sea Level) Date From - To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (usft) 10:00 - 11:00 1.00 TIEBAC P OTHCMP MAKE UP 7-7/8" RCJB / 8-1/2" SCRAPER BHA #25. -PJSM WITH RIG CREWAND BAKER REP. -P/U, M/U AND RIH RCJB BHA T/ 84'. 11:00 - 12:00 1.00 TIEBAC P OTHCMP RUN IN HOLE WITH 7-7/8" RCJB / 8-1/2" SCRAPER BHA #25. -RIH WITH RCJB BHA F/ 84'T/ 1,196'. 12:00 - 12:30 0.50 TIEBAC P OTHCMP SERVICE RIG. -LUBRICATE TOP DRIVE, DRAW -WORKS AND ST -80. TIEBAC P OTHCMP RUN1N HOLE WITH 7-7/8" RCJB / 8-1/2" 12:30 - 13.00 0.50 SCRAPER BHA#25. -PJSM WITH RIG CREWAND BAKER REP. -RIH WITH RCJB BHA F/ 1,196' T/ 2,430'. -ESTABLISH PARAMETERS AND OBTAIN SPR. *PUW=100K, SOW --100K, ROT=90K, RPM=40 WITH 1-2KTORQ, 12 BPM WITH 1,850 PSI. **TABLE TOP KICK WHILE TRIPPING DRILL.** CLEAN AND CLEAR SAND FROM TOP OF 13:00 - 14:00 1.00 TIEBAC P OTHCMP $-5/8" RBP. -WASH F/ 2,430' AND TAG TOP OF SAND AT 2,442'. -WASH AND REAM F/ 2,442' TO TOP OF RBP - AT 2,496. *RPM=40 WITH 1-2K TORQ, WOB=1-3K, 12 BPM WITH 1,850 PSI. 14:00 - 16:00 2.00 TIEBAC P OTHCMP PULL OUT OF HOLE WITH 7-7/8" RCJB / 8-1/2" SCRAPER BHA#25. -10 MIN FLOW CHECK WELL STABLE. -POOH WITH RCJB BHA F/ 2,496' T/ 260'. _ 16:00 - 19:00 3.00 TIEBAC P OTHCMP LAY DOWN 7-7/8" RCJB/ 8-1/2" SCRAPER BHA #25. -PJSM WITH RIG CREWAND BAKER REP. -10 MINUTE FLOW CHECK BEFORE PULLING NOWSHEARABLES ACROSS STACK WELL STABLE. -POOH AND UD RCJB BHA F/ 260'. -REALIGN AND INSPECT BOPE, DUE TO BHA CATCHING FLOW LINE. -EMPTY BOOT BASKETS AND RCJB BARREL *RECOVERED 2 GALS. OF SAND AND CMT FROM THE BOOT BASKETS AND 3 PIECES OF METAL (2"x2-) FROM BARREL OF RCJB. -CLEAN AND CLEAR RIG FLOOR OF RCJB BHA. 19:00 - 21:00 2.00 TIEBAC P OTHCMP PERFORM MIT ON 9-5/8" CASING. -PJSM WITH PRESSURE CROSSCHECK DISCUSSION AND CONFIRMED CHALLENGE QUESTIONS WITH CORRECT RESPONSES. -R/U TEST EQUIPMENT. -PERFORM MIT ON 9-5/8" CSG TO 250 PSI FOR 5 CHARTED MINS AND 3,700 PSI FOR 30 CHARTED MINS. TEST PASS. -3.1 BBLS TO PRESSURE UP AND 3.0 BBLS BLED BACK. *VERIFY COMPETENCY OF MIT WITH WTL AND WAS GRANTED PERMISSION TO PROCEED WITH OPERATIONS. -R/D TEST EQUIPMENT. Printed 10/13/2014 1:19:52PM North America - ALASKA BPage 57 of 79 Operation Summary Report �,r� ON �r � r, Common Well Name: 01-02 AFE No Event Type: WORKOVER (WO) Start Date: 8/25/2014 End Date: X4 -0103J -E: (6,000,000.00 ) I Project: Prudhoe Bay Site: PB DS 01 Rig Name/No.: DOYON 14 Spud Date/Time: 1/17/1970 12:00:OOAM Rig Release: 10/4/2014 Rig Contractor: DOYON DRILLING INC. UWI: 500292005300 Active datum: 4: 02 1/17/1970 00:00 @73.00usft (above Mean Sea Leven Date From - To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (usft) 21:00 - 23:30 2.50 DHB P OTHCMP RUN IN HOLE WITH 9-5/8" RBP RETRIEVAL TOOL. -PJSM WITH RIG CREWAND HES REP. -P/U, M/U AND RIH WITH RBP RETRIEVAL TOOL TO 2,484'. -ESTABLISH PARAMETERS. 'PUW= 87K, SOW= 87K, RATE= 17 BPM WITH 1,030 PSI. -RIH F/ 2,484' AND ENGAGE RBP AT 2,506', AS PER HES REP. -SET 10K DOWN, PULL 25K OVER TO CONFIRM LATCH. SET 10K DOWN. -CLOSE ANNULAR PREVENTER. MAKE 1/4 RIGHT HAND TURN TO OPEN BY-PASS. -RELEASE RBP WITH 120K. -CIRC B/U THRU MGS AT 6 BPM WITH 230 PSI. *NO OBSERVATION OF HYDROCARBONS AT BOTTOMS UP. -10 MIN FLOW CHECK. WELL STABLE. -VERIFY ZERO PRESSURE. -OPEN ANNULAR PREVENTER. 23:30 - 00:00 0.50 DHB P OTHCMP PULL OUT OF HOLE WITH 9-5/8" RBP. -10 MIN FLOW CHECK. WELL STABLE. -POOH WITH 9-5/8" RBP F/ 2,506' T/ 2,294'. 9/23/2014 00:00 - 00:30 0.50 DFIB P OTHCMP SERVICE RIG. -LUBRICATE TOP DRIVE, DRAW -WORKS AND ST -80. 00:30 - 02:00 1.50 DHB' P OTHCMP PULL OUT OF HOLE WITH 9-5/8" RBP. -PJSM WITH RIG CREWAND HES REP. -POOH WITH 9-5/8" RBP F/ 2,294'T/ SURFACE. -UD 9-5/8" RBP. 02:00 - 05:00 3.00 DHB P OTHCMP RUN IN HOLE WITH 9-5/8" RBP RETRIEVAL TOOL. -RIH WITH RBP RETRIEVAL TOOL TO 8,846'. Printed 10/13/2014 1:19:52PM North America - ALASKA - BP Page 58 of 79 Operation Summary Report Common Well Name: 01-02 AFE No Event Type: WORKOVER (WO) Start Date: 8/25/2014 End Date: X4-0103J-E: (6,000,000.00 ) Project: Prudhoe Bay Site: PB DS 01 Rig Name/No.: DOYON 14 Spud Date/Time: 1/17/1970 12:00:OOAM Rig Release: 10/4/2014 Rig Contractor: DOYON DRILLING INC. UWI: 500292005300 Active datum: 4: 02 1/17/1970 00:00 @73.00usft (above Mean Sea Level) Date From - To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (usft) 05:00 - 06:00 1.00 DHB P OTHCMP RETRIEVE 9-5/8" RBP AT 8,922'. -ESTABLISH PARAMETERS AND OBTAIN SPR. *PUW= 195K, SOW= 160K -PJSM WITH RIG CREWAND HES REP, DISCUSSING POSSIBLE PACKER GAS MIGRATION BELOW 9-5/8" RBP, WITH PRESSURE CROSSCHECK DISCUSSION AND CONFIRMED CHALLENGE QUESTIONS WITH CORRECT RESPONSES. -RIH F/ 8;846' AND ENGAGE RBP AT 8,920', AS PER HES REP. -SET 25K DOWN, PULL 25K OVER TO CONFIRM LATCH. -SET 25K DOWN, MAKE 1/2 RIGHT HAND TURN AND PULL 1 OK OVER PULL (205K) TO OPEN BY-PASS. -ALLOW 10 MINS FOR___ELEMENTS TO RELAX. *WELL ON VACUUM. -OVERPULL IN 1 OK INCREMENTS F/ 205K AND RBP RELEASED WITH 55K OVER PULL (250K ON WT INDICATOR). -CLOSE ANNULAR PREVENTER. -BULLHEAD 13.5 BBLS OF 8.5 PPG SEAWATER AT 7 BPM WITH 130 PSI. - -10 MIN FLOW CHECK. WELL ON VACUUM. -ESTABLISH LOSS RATE AT 60+ BPH. -LINE UP AND CONTINUOUSLY MONITOR WELL AND FILL AT 60 BPH THROUGH IA. - -VERIFY ZERO PRESSURE. -OPEN ANNULAR PREVENTER. 106:00 - 10:00 4.00 DHB P OTHCMP PULL OUT OF HOLE WITH 9-5/8" RBP. -POOH WITH 9-5/8" RBP F/ 8,920'T/ SURFACE. 10:00 - 10:30 0.50 DHB P OTHCMP LAY DOWN 9-5/8" RBP AND RETRIEVAL TOOL. -PJSM WITH RIG CREWAND HES REP. -UD RBP AND RETRIEVAL TOOL. -CLEAN AND CLEAR RIG FLOOR. 10:30 - 11:00 0.50 DHB P OTHCMP CIRCULATE -LINE UP AND PUMP 100 BBLS OF 8.5 PPG SEAWATER AWAY AT 6.5 BPM WITH 30 PSI. 11:00 - 11:30 0.50 DHB P OTHCMP INSTALL TEST PLUG. -PJSM WITH RIG CREWAND CAMERON REP. -R/U AND RETRIEVE WEAR BUSHING. -R/U AND INSTALL 11" TEST PLUG. -CAMERON, RILDS ON TEST PLUG. *LDSRI= 5-1/4" LDSBO= 6-1/2" 11:30 - 12:00 0.50 DHB P OTHCMP PRESSURE TEST 11" TEST PLUG FROM ABOVE. -PJSM WITH RIG CREWAND CAMERON REP WITH PRESSURE CROSSCHECK DISCUSSION AND CONFIRMED CHALLENGE QUESTIONS WITH CORRECT RESPONSES. -CLOSE BLIND/SHEAR RAMS. -R/U TEST EQUIPMENT. -PT BETWEEN BLINDISHEAR RAMS AND TEST PLUG TO 250 / 3,500 PSI FOR 5 CHARTED MINS EACH. TEST PASS. *CONTINUOUSLY MONITOR WELLAND FILL AT 60 BPH THROUGH IA. 'FLUID LOSSES AT 12:00 HRS= 446 BBLS Printed 10/13/2014 1.19:52PM /. � %✓F ".". f%` / .%�// ,%H ���-'//''/,�"f / ,,,� /,/F .., ,:,y-; . ,,,,;; p f/� f`/y//�J'. f`l`JJ f/f lFr+,. f/ / fir% �y;� t /,;.:"/�''",%"�1�. '' ��/j ',iii%r//jf .�,, y'/yr ��i�; '� i r .•r y,. �,,/ %.fr����fJif''y� �%!'•''��!'� `'�J'f� 9% //:///'/r .! /�/.!;-//� f�r'///��/ .f/f/,%'l '.// /r✓/'f/>� r � � - ,f"//.•'' ,'� r�,'.f� �'.?vfil/+✓ �1.,f ,'; "F� � /// � fff l � .f ,.`%'.•''. / ,/ % /�,s�r'�.`F/,f�i'f.� j �f�f f/, /✓� f � /. / r �. � �� f��r;J�,`'` f/,/,,'_;',,;/� r,: `"��ryf'ff%i ,,, •.`�:�.:r%./r,.c ,,, J/ ,/i, /,://, r;�'F//y',c .�',/•r/%,,�'.,��!,.,fJ„' . r,r�;"�i,�'.',���. F/f,f �,.✓,� fl r,�%' / JJfi'�� /f...f /,rJf,yf ,: J./ / / //`' ,�`�, 'a �f �,/�fF` r'-:F',Jf'�� ,r J//,f�f �/%% �f/� /f/NST �IlA���l��� �r� J�� �. �� ':'r r,'='.f f/'� //G/,'"`y f �`'`'.',:r �//,' y ,;;f/l�fy�rf . fl`� /jj 9 ',9/ / /1 /% !' < r.•�+' ,f F/i', f`r � s f �'y /'/J �f/,^'J'�� � •��J'`ff`'//yr1h,:�%f��1A'``;•1��J.%,�`;1/f y1���� mss'%L,c �,.�� ..y �:. Jl .,,, ,`� "r` .c�+rr'+3k��:�J'. ., „ .,;. �,, �, ,..:•r/�/�/� F" / ✓✓ Common Well Name: 01-02 AFE No Event Type: WORKOVER (WO) Start Date: 8/25/2014 End Date: X4 -0103J -E: (6,000,000.00 ) Project: Prudhoe Bay Site: PB DS 01 Rig Name/No.: DOYON 14 Spud Date/Time: 1/17/1970 12:OO:OOAM Rig Release: 10/4/2014 Rig Contractor: DOYON DRILLING INC. UWI: 500292005300 Active datum: 4: 02 1/17/1970 00:00 @73.00usft (above Mean Sea Level) Date From - To Hrs Task Code NPT NPT Depth Phase Description of Operations - hr — -- -- 1112:00 usft- - -- -_ - - -- PRESSURE TEST 11" TEST PLUG FROM 14:30 2.50 DHB P OTHCMP BELOW. PJSM WITH RIG CREW AND CAMERON REP WITH PRESSURE CROSSCHECK DISCUSSION AND CONFIRMED CHALLENGE QUESTIONS WITH CORRECT RESPONSES. -R/U AND PERFORM ROLLING ON TEST PLUG FROM BELOW TO 500 PSI AT 6 BPM. *50 BBLS PUMP. LEAK TIGHT TEST. 14:30 - 19:00 t 4.50 BOPSUR t P OTHCMP CHANGE UPPER PIPE RAMS. -PJSM WITH RIG CREW. -VOID BOPE OF FLUID, DOWN TO CLOSED BLIND/SHEAR RAMS. -CHANGE UPPER PIPE RAMS F/ 9-5/8" FIXED RAMS T/ 7" FIXED RAMS. *BARRIERS: CLOSED AND TESTED BLIND/SHEAR RAMS, TESTED TEST PLUG, CONTINUOUSLY MONITOR WELLAND FILLAT 60 BPH THROUGH IA WITH 8.5 PPG SEAWATER KWF. f *SIMOPS: -PERFORM DERRICK INSPECTION, WHILE CHANGING UPPER PIPE RAMS. 19:00 19:30 l 0.50 BOPSUR P OTHCMP RIG UP TO TEST BOPE. -VERIFY NO PRESSURE. -OPEN BLIND/SHEAR RAMS. -R/U AND M/U ALL FLOOR VALVES, CROSSOVERS, TEST EQUIPMENT AND 4' TEST ASSEMBLY TO TEST BOPE. - 19:30 - 20:00 0.50 BOPSUR P OTHCMP SHELL TEST 13-5/8" 5M BOPE. -PJSM ON TESTING BOPE, WITH PRESSURE CROSSCHECK DISCUSSION AND CONFIRMED CHALLENGE QUESTIONS WITH CORRECT RESPONSES. -FILL STACK AND CHOKE MANIFOLD TO MGS. **KICK DRILL.** *6 BBLS TO FILL GAS BUSTER. SHELL TEST BOPE WITH ANNULAR PREVENTER CLOSED ON 4" TEST JT, TO 250 / 3,500 PSI. TEST PASS. 20:00 00:00 4.00 BOPSUR + P - + OTHCMP PRESSURE TEST 13-5/8" 5M BOPE DRESSED WITH 7" SOLID BODY IN UPPER PIPE RAMS AND 3-1/2" x 6" VBR IN LOWER PIPE RAMS. !-PRESSURE TEST BOPE, AS PER DDI SOP. -TEST LOWER 3-1/2" x 6" VERs WITH 4" TEST JT TO 250 / 3,500 PSI FOR 5 CHARTED MINS 'EACH. TEST PASS. -TEST ANNULAR PREVENTER WITH 4" TEST JT TO 250 / 3,500 PSI FOR 5 CHARTED MINS :EACH. TEST PASS. -PERFORM ACCUMULATOR DRAW DOWN TEST. TEST PASS. *JOHNNIE HILL WITH AOGCC, WITNESS BOPE TESTING AND GAS ALARM FUNCTION TESTING. *CONTINUOUSLY MONITOR WELLAND FILLAT 60 BPH THROUGH IA. *FLUID LOSSES AT 23:59 HRS= 741 BBLS Printed 10/13/2014 1:19:52PM North America - ALASKA BP fr r� �r%r F' f- Page 60 of 79 Operation Summary Report% rw Common Well Name: 01-02 AFE No Event Type: WORKOVER (WO) Start Date: 8/25/2014 End Date: X4 -0103J -E: (6,000,000.00) Project: Prudhoe Bay +Site: PB DS 01 Rig Name/No.: DOYON 14 Spud Date/Time: 1/17/1970 12:00:OOAM Rig Release: 10/4/2014 Rig Contractor: DOYON DRILLING INC. UWI: 500292005300 Active datum: 4: 02 1/17/1970 00:00 @73.00usft (above Mean Sea Level) Date From - To Hrs Task Code NPT NPT Depth Phase Description of Operations 02:00 (hr) 2.00 (usft) 9/24/2014 100:00 BOPSUR P - OTHCMP PRESSURE TEST 13-5/8" 5M BOPE DRESSED WITH 7" SOLID BODY IN UPPER PIPE RAMS AND 3-1/2" x 6" VBR IN LOWER PIPE RAMS. -PJSM ON TESTING BOPE, WITH PRESSURE CROSSCHECK DISCUSSION AND CONFIRMED CHALLENGE QUESTIONS WITH CORRECT ,RESPONSES. -PRESSURE TEST BOPE, AS PER DDI SOP I! WITH 4", 4-1/2" AND 7" TEST JTS TO 250 / 3,500 PSI FOR 5 CHARTED MINS EACH. TEST PASS. *MADE 2 -ATTEMPTS TO TEST HCR CHOKE, NO SUCCESS. -PERFORM REMAINING BOPE TEST, WHILE PREPARING TO REPAIR HCR CHOKE. *JOHNNIE HILL WITH AOGCC, WITNESS BOPE TESTING AND GAS ALARM FUNCTION I, TESTING. *CONTINUOUSLY MONITOR WELLAND FILLAT 60 BPH THROUGH IA. 02:00 02:30 0.50 BOPSUR P OTHCMP SERVICE RIG. -LUBRICATE TOP DRIVE, DRAW -WORKS AND ST -80. 02:30 - 05:00 2.50 BOPSUR N RREP OTHCMP REBUILD HCR CHOKE. '-PJSM WITH RIG CREWAND MECHANIC. -RIG MECHANIC, REBUILD HCR CHOKE. '-FUNCTION AND PRESSURE TEST HCR CHOKE TO 250 / 3,500 PSI. TEST PASS. *1-FAIL/PASS ON HCR CHOKE, DURING BOPE TESTING. *2014 -IR -4824251 05:00 - 08:00 3.00 BOPSUR K MISC OTHCMP RIG SERVICE. -PJSM WITH REVIEW OF HAZARD WORKSHEET ON PERFORMING DDI MP2 OF TESTING HIGH PRESSURE LINES. -PRESSURE CROSSCHECK DISCUSSION AND CONFIRMED CHALLENGE QUESTIONS WITH CORRECT RESPONSES. -PRESSURE TEST HIGH PRESSURE PUMP LINES TO 250 / 4,000 PSI FOR 5 CHARTED MINS EACH, TEST PASS. 08:00 - 09:00 1.00 BOPSUR P OTHCMP RIG DOWN BOPE TEST EQUIPMENT. -R/D BOPE TEST ASSEMBLY AND EQUIPMENT. BLOW DOWN CHOKE AND KILLS LINES. -INSTALL WEAR BUSHING. *I D= 9-1/16" M_ /U FOSV ON SAFETY JOINT. 09:00 09:30 0.50 t TIEBAC P OTHCMP RIG UP TO RUN LOWER 7" 26# L-80 VAMTOP HC SCAB LINER. -PJSM WITH RIG CREW AND BAKER REP. -R/U POWER TONGS AND 7" HANDLING EQUIPMENT. - — - 09:30 - 10:30 1.00 1 TIEBAC P OTHCMP MAKE UP LOWER 7" 26# L-80 VAMTOP HC SCAB LINER. -PIU AND M/U 4-1/2" HALF -MULE SHOE x 7" X -OVER, 7" 26# L-80 TC -II PUP JT AND 7" 26# L-80 TC -II PIN x VAMTOP HC X -OVER JT. Printed 10/13/2014 1:19:52PM North America - ALASKA - BP Page 61 of 79 Operation Summary Report Common Well Name: 01-02 AFE No Event Type: WORKOVER (WO) Start Date: 8/25/2014 End Date: X4 -0103J -E: (6,000,000.00 ) Project: Prudhoe Bay Site: PB DS 01 - — - Rig Name/No.: DOYON 14 Spud DateTme: 1/17/1970 12:00:00AM Rig Release: 10/4/2014 Rig Contractor: DOYON DRILLING INC. UWI: 500292005300 Active datum: 4: 02 1/17/1970 00:00 @73.00usft (above Mean Sea Level) Date From - To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (usft) 10:30 - 11:30 1.00 TIEBAC P OTHCMP SET 7" BAKER WLSRBP IN LOWER 7" SCAB LINER. -PJSM WITH RIG CREWAND BAKER REP. -P/U, M/U AND RUN 7" WLSRBP IN LOWER 7" SCAB LINER ASSEMBLY, 49' FROM ROTARY. -R/U TO SET 7" WLSRBP. -PRESSURE UP TO 3,120 PSI AND OBSERVED 7" WLSRBP SET. -L/D WLSRBP SETTING TOOL. 11:30 12:00 0.50 TIEBAC P OTHCMP ;RIG UP TO PRESSURE TEST 7" BAKER WLSRBP IN LOWER 7" SCAB LINER. -R/U TEST EQUIPMENT TO PRESSURE TEST 7" WLSRBP. "CONTINUOUSLY MONITOR WELLAND FILLAT 60 BPH THROUGH IA. `FLUID LOSSES AT 12:00 HRS= 680 BBLS OTHCMP PRESSURE TEST 7" BAKER WLSRBP IN 112:00 13:00 1.00 TIEBAC P LOWER 7" SCAB LINER. -PJSM WITH RIG CREWAND BAKER REP. I -PRESSURE TEST 7" WLSRBP TO 250 /4,000 PSI FOR 5 CHARTED MINS EACH. TEST PASS. OTHCMP , PLACE 50' OF 20/40 RIVER SAND ON TOP OF 13:00 - 14:00 1.00 _ TIEBAC- P 7" WLSRBP. -RN SAND HOPER. -PLACE 50'/ 1,250 LBS / 25 SKS OF RIVER SAND ON TOP OF 7" WLSRBP. 14:00 - 15:00 1.00 TIEBAC P OTHCMP MAKE UP 9-5/8" x 7" BAKER HMC LINER HANGER / "2RH" HD ZXP LINER TOP PACKER ASSEMBLY. -P/U AND WU LINER HANGER / PACKER ASSEMBLY. •WSL AND BAKER REP VERIFY SHEAR SCREWS. 15:00 - 00:00 9.00 TIEBAC P OTHCMP RUN LOWER 7" 26# L-80 VAMTOP HC SCAB LINER. -RIH WITH LOWER 7" SCAB LINER ON 4" DP F/ 83' T/ 8,700' AT 2 MINS PER STD, FILLING DP EVERY 10 STDS. -ESTABLISH PARAMETERS. `PUW= 207K, SOW= 165K -RIH WITH LOWER 7" SCAB LINER ON 4" OP F/ 8,700' AND TAG TOP OF PBR AT 8,948'. "SPILL DRILL IN PUMP ROOM." *CONTINUOUSLY MONITOR WELLAND FILLAT 60 BPH THROUGH IA. 'FLUID LOSSES AT 23:59 HRS= 758 BBLS 9/25/2014 00:00 - 00:30 0.50 TIEBAC P OTHCMP SERVICE RIG. -LUBRICATE TOP DRIVE, DRAW -WORKS AND ST -80. 'CONTINUOUSLY MONITOR WELLAND FILLAT 60 BPH THROUGH IA. Printed 10/13/2014 1.19:52PM ,� � i„**ww North America -ALASKA - BP ,� ��,.� F. -��,� � � Operation Summary Report Common Well Name: 01-02 AFE No Event Type: WORKOVER (WO) Start Date: 8/25/2014 End Date: X4-0103J-E: (6,000,000.00 ) Project: Prudhoe Bay Site: PB DS 01 Rig Name/No.: DOYON 14 Spud Date/Time: 1/17/1970 12:00:OOAM Rig Release: 10/4/2014 Rig Contractor: DOYON DRILLING INC. UWI: 500292005300 Active datum: 4: 02 1/17/1970 00:00 @73.00usft (above Mean Sea Level) Date From - To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (usft) 00:30 - 01:30 1.00 TIEBAC P OTHCMP RUN LOWER 7” 26# L-80 VAMTOP HC SCAB LINER. -PJSM WITH RIG CREWAND BAKER REPS. -MADE SEVERAL ATTEMPTS TO WORK LOWER 7" SCAB LINER PAST PBR AT 8,948', WITH NO SUCCESS. -DISCUSS PLAN FORWARD WITH ODE. 01:30 - 02:00 0.50 TIEBAC N DPRB OTHCMP PULL OUT OF HOLE WITH LOWER 7" 26# L-80 VAMTOP HC SCAB LINER. -PJSM WITH RIG CREWAND BAKER REPS. -POOH, WET WITH LOWER SCAB LINER F/ , 02:00 04:30 8,948'T/ 8,479'. _ OTHCMP CUT AND SLIP DRILL LINE. 2.50 TIEBAC P -SLIP AND CUT 59.5' OF DRILL LINE AS PER DOYON PROCEDURES. -SERVICE TOP DRIVE AND BLOCKS. *RESET AND FUNCTION CROWN-O-MATIC. GOOD TEST. 04:30 - 08:30 4.00 TIEBAC N DPRBOTHCMP PULL OUT OF HOLE WITH LOWER 7" 26# L-80 VAMTOP HC SCAB LINER. -POOH, WET WITH LOWER SCAB LINER F/ 8,479'T/ 150'. *CONTINUOUSLY MONITOR WELLAND FILLAT 60 BPH PLUS DISPLACEMENT, THROUGH IA. 08:30 - 09:00 0.50 TIEBAC' N DPRB OTHCMP RIG UP POWER TONGS AND 7" HANDING EQUIPMENT. -10 MIN FLOW CHECK FOR NOWSHEARABLES ACROSS THE BOPE. -R/U TONGS AND T' HANDLING EQUIPMENT. 09:00 - 10:00 1.00 TIEBAC N DPRB OTHCMP PREPARE TO STAND BACK LOWER 7" SCAB LINER ASSEMBLY. -PJSM WITH RIG CREWAND BAKER REP. -STAND BACK 1-STD OF V' DP. -CHANGE 4" ELEVATORS TO 4-1/2" ELEVATORS. -POOH WITH LOWER SCAB LINER ASSEMBLY AND SET SLIPS ON 4-1/2" HALF-MULE SHOE. -R/U TO HEAT BAKER LOWED CONNECTION WITH STEAM. 10:00 - 12:00 2.00 TIEBAC N DPRB OTHCMP BREAK OUT 4-1/2" HALF-MULE SHOE TO STAND BACK LOWER 7" SCAB LINER ASSEMBLY. -HEAT 7" x 4-1/2" X-OVER, BAKER LOK'ED CONNECTION WITH STEAM. -ATTEMPT TO BREAK OUT X-OVER SEVERAL TIMES WITH POWER TONGS. NO SUCCESS. -HEAT 4-1/2" HALF-MULE SHOE, BAKER LOWED CONNECTION BELOW X-OVER WITH STEAM. -BREAKOUT AND LID 4-1/2" HALF-MULE SHOE. -STAND BACK LOWER 7" SCAB LINER ASSEMBLY IN DERRICK AND SECURE SAME. *CONTINUOUSLY MONITOR WELLAND FILLAT 60 BPH THROUGH IA. *FLUID LOSSESAT 12:00 HRS= 613 BBLS TIEBAC N DPRB OTHCMP 12:00 12:30 0.50 SERVICE RIG. -LUBRICATE TOP DRIVE, DRAW-WORKS AND ST-80. Printed 10/13/2014 1:19:52PM North America - ALASKA - BP Page 63 of 79 Operation Summary Report Common Well Name. 01-02 AFE No Event Type: WORKOVER (WO) Start Date: 8/25/2014 End Date: X4 -0103J -E: (6,000,000.00 ) Project: Prudhoe Bay Site: PB DS 01 Rig Name/No.: DOYON 14 Spud Date/Time: 1/17/1970 12:00:00AM Rig Release: 10/4/2014 Rig Contractor: DOYON DRILLING INC. UN: 500292005300 Active datum: 4: 02 1/17/1970 00:00 @73.00usft (above Mean Sea Level) Date From - To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) i (usft) 12:30 - 15:00 2.50 TIEBAC N DPRB OTHCMP MAKE UP 4-3/4" DRESS -OFF / CLEAN-OUT BHA #26. PJSM WITH RIG CREWAND BAKER REP. /U, M/U AND RIH WITH DRESS -OFF / CLEAN-OUT BHA T/ 316. 15:00 - 17:30 2.50 TIEBAC N DPRB OTHCMP RUN IN HOLE WITH 4-3/4" DRESS -OFF / CLEAN-OUT BHA#26. -RIH WITH DRESS -OFF / CLEAN-OUT BHA F/ 316' T/ 8,863'. 3.**7-FIRE DRILL AT CAT #3.'- 117:30 30 - 20:00 2.50 TIEBAC N DPRB OTHCMP DRESS -OFF / CLEAN OUT PBR AND SEAL (STEM. ESTABLISH PARAMETERS. *PUW= 213K, SOW= 165K, RTW= 188K, RPM= 40 WITH 5K TORQUE. -RIH WITH DRESS -OFF /CLEAN-OUT BHA F/ 8,863' AND TAG TOP OF PBR AT 8,948' WITH 5K DOWN. *MADE SEVERAL ATTEMPTS WITH NO PUMP OR ROTATION, WITH NO SUCCESS. -PICK UP 10', ROTATE AT 5 RPM, SLACKED OFF AND WENT THROUGH WITH NO INCREASE IN TORQUE OR WEIGHT F/ 8,948' T/ 8,961'. -WASH REAM AND RECIPROCATE F/ 8,961'T/ 8,948' SEVERAL TIMES. *40 RPM WITH 5K TORQUE, 8 BPM WITH 1,100 PSI. *CIRC ESTABLISH WITH FULL RETURNS. -PICK UP T/ 8,938'. SHUTDOWN ROTATION AND PUMP. -MADE SEVERALATTEMPTS TO GET THRU PRB, SETTING DOWN 5K WITH NO SUCCESS. -WITH 5K DOWN ON PRB AT 8,948', TURN STRING 1 -TURN TO THE RIGHT AND i ENTERED PBR. -WASH AND REAM THRU PBR SEVERAL TIMES. 1 -SHUT DOWN ROTATION AND PUMP. -MADE SEVERALATTEMPTTO GET THROUGH PRB, SETTING DOWN 5K WITH NO SUCCESS. -WITH 5K DOWN ON PRB AT 8,948', TURN STRING 1 -TURN TO THE RIGHT AND ENTERED PBR. -DISCUSS PLAN FORWARD WITH ODE. -SET DOWN 15K ON TOP OF PBR WITH NO PUMP OR ROTATION. 20:00 - 00:00 4.00 TIEBAC 'I DPRB OTHCMP PULL OUT OF HOLE WITH 4-3/4" DRESS -OFF ! CLEAN-OUT BHA #26. -10 MIN FLOW CHECK. WELL ON VACUUM AT 160+ BPH. -POOH WITH DRESS -OFF / CLEAN-OUT BHA F/ 8,948' T/ 450'. *CONTINUOUSLY MONITOR WELLAND FILLAT 60 BPH PLUS DISPLACEMENT, THROUGH IA. *FLUID LOSSES AT 23:59 HRS-- 818 BBLS Printed 10/13/2014 1:19:52PM North America - ALASKA - BP Operation Summary Report Common Well Name: 01-02 AFE No Event Type: WORKOVER (WO) Start Date: 8/25/2014 End Date: X4 -0103J -E: (6,000,000.00) Project: Prudhoe Bay Site: PB DS 01 Rig Name/No.: DOYON 14 Spud Daterrime: 1/17/1970 12:00:OOAM Rig Release: 10/4/2014 Rig Contractor: DOYON DRILLING INC. UWI: 500292005300 Active datum: 4: 02 1/17/1970 00:00 @73.00usft (above Mean Sea Level) _ Date iFrom - To Hrs Task Code NPT NPT Depth Phase Description of Operations 9/26/2014 00:00 - 01:00 (hr) 1.00 TIEBAC N DPRB (usft) - - OTHCMP PULL OUT OF HOLE AND L/D 4-3/4" DRESS -OFF / CLEAN-OUT BHA #26. -10 MIN FLOW CHECK FOR NON-SHEARABLES ACROSS THE STACK WELL ON VACUUM AT 60+ BPH. -POOH AND L/D DRESS -OFF / CLEAN-OUT BHA F/ 450'. 'CONTINUOUSLY MONITOR WELLAND FILLAT 60 BPH PLUS DISPLACEMENT, THROUGH IA. 01:00 - 01:30 0.50 TIEBAC N DPRB OTHCMP CLEAR RIG FLOOR. -CLEAN AND CLEAR RIG FLOOR OF DRESS -OFF / CLEAN-OUT BHA AND 1 HANDLING EQUIPMENT. 01.30 04:30 3.00 TIEBAC N DPRB OTHCMP BREAK OUT 9-5/8" x 7" BAKER HMC LINER HANGER / "2RH" HD ZXP LINER TOP PACKER ASSEMBLY. -PJSM WITH REVIEW OF HAZARD WORK SHEET ON HEATING BAKER LOK'ED CONNECTION WITH STEAM. -R/U AND STEAM LINER HANGER / PACKER ASSEMBLY CONNECTION. -R/U RIG TONGS ON OFF-DRILLER'S SIDE AND R/U 8-1/2" POWER TONGS. -BREAK OUT AND L/D LINER HANGER / PACKER ASSEMBLY. 04:30 - 07:00 2.50 TIEBAC N DPRB OTHCMP RIG UP TO RUN LOWER 7" 26# L-80 VAMTOP HC SCAB LINER. -PJSM WITH RIG CREW, DOYON CASING AND BAKER REP. -R/U POWER TONGS AND 7" HANDLING EQUIPMENT. -M/U X -OVER ON SAFETY JT FOR RUNNING 7" SCAB LINER. 07:00 - 10:00 3.00 TIEBAC N DPRB OTHCMP MAKE UP LOWER 7" SCAB LINER ASSEMBLY. -P/U AND M/U 1- JT OF 4-1/2" 12.6# L-80 AND HALF -MULE SHOE TO 7" x 4-1/2" X -OVER. -P/U, M/U AND RIH WITH 9-5/8" x 7" BAKER HMC LINER HANGER W/ "HRDE" ZXPN LINER TOP PACKER TO 146'.- 10:00 - 12:00 2.00 TIEBAC N DPRB OTHCMP RUN LOWER 7" SCAB LINER ASSEMBLY ON 4" DP. -RIH WITH LOWER 7" SCAB LINER ASSEMBLY, AT 2 MINS PER STD F/ 146' T/ 2,724'. 'FILL 4" DP EVERY 10-STDS. 'CONTINUOUSLY MONITOR WELLAND FILLAT 60 BPH THROUGH IA. 'FLUID LOSSES AT 12:00 HRS= 596 BBLS Printed 10/13/2014 1:19:52PM North America - ALASKA - BP Operation Summary Report Common Well Name: 01-02 AFE No Event Type: WORKOVER (WO) Start Date: 8/25/2014 End Date: X4 -0103J -E: (6,000,000.00 ) Project: Prudhoe Bay Site: PB DS 01 Rig Name/No.: DOYON 14 Spud Date/Time: 1/17/1970 12:00:OOAM Rig Release: 10/4/2014 Rig Contractor: DOYON DRILLING INC. UWI: 500292005300 Active datum: 02 1/17/1970 00:00 @73.00usft (above Mean Sea Level) -4: Date From - To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr)- (usft) —I — -- - 12:00 - 17:30 5.50 TIEBAC N DPRB OTHCMP RUN LOWER 7" SCAB LINER ASSEMBLY ON 4" DP. PJSM WITH RIG CREW, DOYON CASING AND BAKER REP. -RIH WITH LOWER 7" SCAB LINER ASSEMBLY, AT 2 MINS PER STD F/ 2,724'T/ 8,897'. *FILL 4" DP EVERY 10-STDS. !-ESTABLISH PARAMETERS. *PUW= 207K, SOW= 167K, RTW= 180K, RPM= 5 WITH 5 K TORQUE. -RIH WITH LOWER 7" SCAB LINER ASSEMBLY F/ 8,897' AND TAG TOP OF PBR AT 8,948' WITH 3K DOWN. -WITH 3K DOWN, TURN STRING 1- RH TURN AND ATTEMPT TO PASS THRU PBR WITH NO SUCCESS. -PICK UP HOLE TO 8,940'. -ROTATE STRING AT 5 RPM AND RIH INTO PRB TO 8,950'. STOP ROTATION. i -RIH WITH LOWER 7" SCAB LINER ASSEMBLY 1 — — F/ 8,950' AND TAG AT 8,961' WITH 5K DOWN. 17:30 - 18:30 1.00 TIEBAC N DPRB OTHCMP SET 9-5/8" x 7" BAKER HMC LINER HANGER W/ "HRDE" ZXPN LINER TOP PACKER. PJSM WITH RIG CREWAND BAKER REP. -P/U 1' TO 8,960'. -SET LINER HANGER AND PACKER, AS PER BAKER REP. -PRESSURE UP ON DP TO 1,500 PSI AND SET DOWN 65K TO SET LINER HANGER. PRESSURE UP F/ 1,500 T/ 2,500 PSI AND OBSERVED PUSHER TOOL NEUTRALIZE. -PRESSURE UP F/ 2,500 PSI T/ 4,000 PSI AND HELD FOR 5 MINS. -BLEED PRESSURE TO 0 PSI. -P/U TO AND RELEASE RUNNING TOOL. *P/U 4' AND OBSERVED DOG OUT AFTER P/U 4' AT 195K PUW. -SET 65K DOWN ON LINER TOP PACKER TO ENSURE SET. -P/U 5, ROTATE AT 15 RPM WITH 4 K TORQUE AND TAG LINER TOP PACKER 3 -TIMES WITH 65K DOWN. *TOP OF 9-5/8" x 7" ZXPN LINER TOP PACKER SET AT 8,813'. I *BOTTOM OF 4-1/2" HALF -MULE SHOE SET AT 8,960'. *7" WLSRBP SET AT 8,885'. *TOP OF SAND AT 8,838'. 18.30 20:30 2.00 TIEBAC P OTHCMP SERVICE RIG. -STAND BACK 1 -STD OF 4" DP T/ 8,813'. -10 MIN FLOW CHECK. WELL STATIC. -VOID BOPE OF FLUID. -BLOW DOWN TOP DRIVE. -LUBRICATE TOP DRIVE, DRAW -WORKS AND ST -80. Printed 10/13/2014 1:19.52PM North America - ALASKA - BP ,ffi Operation Summary Report41,,% Common Well Name: 01-02 AFE No Event Type: WORKOVER (WO) Start Date: 8/25/2014 End Date: X4 -0103J -E: (6,000,000.00 ) Project: Prudhoe Bay Site: PB DS 01 Rig Name/No.: DOYON 14 Spud Daterrime: 1/17/1970 12:00:OOAM Rig Release: 10/4/2014 Rig Contractor: DOYON DRILLING INC. UWL 500292005300 Active datum: 4: 02 1/17/1970 00:00 @73.00usft (above Mean Sea Level) Date From - To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (usft) 20:30 - 00:00 3.50 TIEBAC P OTHCMP PULL OUT OF HOLE WITH LOWER SCAB LINER RUNNING TOOL. -PJSM WITH RIG CREWAND BAKER REP. -POOH WITH SCAB LINER RUNNING TOOL F/ 8,813'T/ 1,204'. 'FLUID LOSSES AT 23:59 HRS= 700 BBLS 9/27/2014 00:00 01:00 1.00 TIEBAC P OTHCMP PULL OUT OF HOLE WITH LOWER SCAB LINER RUNNING TOOL. POOH WITH SCAB LINER RUNNING TOOL F/ 11,204'T/ SURFACE. -L/D LOWER 7" LINER RUNNING TOOL. 01:00 03:00 2.00 TIEBAC P OTHCMP I PRESSURE TEST LOWER 7" SCAB LINER AND 9-5/8" CASING. -PJSM WITH PRESSURE CROSSCHECK DISCUSSION AND CONFIRMED CHALLENGE QUESTIONS WITH CORRECT RESPONSES. -CLOSE BLIND/SHEAR RAMS. '-PRESSURE TEST 9-5/8" CSG AND 7" LINER TO 250 PSI FOR 5 CHARTED MINS. TEST PASS. *0.7 BBLS TO PRESSURE UP. -PRESSURE UP TO 3,600 PSI FOR 15 MINS AND PRESSURE BLED DOWN TO 2,200 PSI. *9.4 BBLS TO PRESSURE UP. *93 PSI/ MIN PRESSURE LOSS. -PRESSURE UP F/ 2,200 PSI T/ 3,600 PSI AND PRESSURE BLED T/ 2,500 PSI IN 10 MINS. NO TEST. -BLEED PRESSURE TO 0 PSI. *6 BBLS BACK. -VERIFY NO PRESSURE AND OPEN BLIND/SHEAR RAMS. -VOID BOPE OF FLUIDAND BLOW DOWN CHOKE / KILL LINES. *SIMOPS: -REPLACE SWIVEL PACKING ON TOP DRIVE. 03:00 - 06:30 3.50 TIEBAC P OTHCMP RIG UP TO RUN 7" 26# L-80 VAMTOP HC UPPER SCAB LINER ASSEMBLY. -PJSM WITH RIG CREWAND DOYON CASING REPS. -CLEAN AND CLEAR RIG FLOOR. -MOBE CENTRALIZER'S, BALE EXTENSIONS, VOLANT TOOL, TORQUE -TURN AND HANDLING EQUIPMENT TO RIG FLOOR. -R/U VOLANT TOOL, TORQUE TURN, BALE EXTENSIONS AND 7" HANDLING EQUIPMENT. Printed 10/13/2014 1:19.52PM North America - ALASKA BP Page 67 of 79 "r �f Operation Summary Reports Common Well Name: 01-02 AFE No Event Type: WORKOVER (WO) Start Date: 8/25/2014 End Date: X4 -0103J -E: (6,000,000.00 ) Project: Prudhoe Bay Site: PB DS 01 Rig Name/No.: DOYON 14 Spud Date/Time: 1/17/1970 12:00:OOAM Rig Release: 10/4/2074 Rig Contractor: DOYON DRILLING INC. UWI: 500292005300 Active datum: 4: 02 1/17/1970 00:00 @73.00usft (above Mean Sea Level) Date From - To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (usft) 06:30 - 12:00 5.50 TIEBAC P OTHCMP MAKE UP -P' 26# L-80 VAMTOP HC UPPER SCAB LINER ASSEMBLY. -PJSM WITH RIG CREW, DOYON CASING AND BAKER REPS. -M/U 7-1/2" PORTED SEAL STEM, 7" 26# L-80 PORTED FLOAT COLLAR JT, 7" X -OVER JT AND 7" 26# L-80 JT W/ INSERT LANDING COLLAR. -P/U, M/U AND RIH WITH UPPER 7" SCAB LINER ASSEMBLY, UTILIZING VOLANT TOOL T/ 561'. *PUW= 85K, SOW= 85K *BAKER LOK ALL ASSEMBLIES. 'ALL VAMTOP''HC CONNECTIONS TORQUE TURN TO 11,950 FT/LBS *7 LINER AND ASSEMBLIES DRIFTED TO 6.51" *1- FREE FLOATING, SOLID BODY, STRAIGHT VAIN CENTRALIZER INSTALLED PER JT. 12:00 - 12:30 0.50 TIEBAC P OTHCMP SERVICE RIG. -LUBRICATE TOP DRIVE, DRAW -WORKS AND ST -80. 12:30 - 00:00 11.50 TIEBAC P OTHCMP' ,RUN 7" 26# L-80 VAMTOP HC UPPER SCAB LINER ASSEMBLY. -PJSM WITH RIG CREW, DOYON CASING AND BAKER REPS. -P/U, M/U AND RIH WITH UPPER 7" SCAB LINER ASSEMBLY, UTILIZING VOLANT TOOL F/ 561'T/ 5,520'. *PUW= 185K, SOW= 175K 9/28/2014 00:00 - 00:30 0.50 TIEBAC P OTHCMP SERVICE RIG. -LUBRICATE TOP DRIVE, DRAW -WORKS AND ST -80. 00:30 - 03:00 2.50 TIEBAC P OTHCMP RUN 7" 26# L-80 VAMTOP HC UPPER SCAB LINER ASSEMBLY. -PJSM WITH RIG CREW, DOYON CASING AND BAKER REPS. -P/U, M/U AND RIH WITH UPPER 7" SCAB LINER ASSEMBLY, UTILIZING VOLANT TOOL F/ 5,520'T/ 6,501'. *PUW= 215K, SOW= 190K *ALL VAMTOP HC CONNECTIONS TORQUE TURN TO 11,950 FT/LBS *7" LINER AND ASSEMBLIES DRIFTED TO 6.51" *1- FREE FLOATING, SOLID BODY, STRAIGHT VAIN CENTRALIZER INSTALLED PER JT. TOTAL CENTRALIZER'S= 158 03:00 - 04:00 1.00 TIEBAC P OTHCMP RIG DOWN VOLANT TOOL, 7" RUNNING AND HANDLING EQUIPMENT. -PJSM WITH RIG CREWAND DOYON CASING REPS. -R/D BALE EXTENSIONS AND VOLANT TOOL. TORQUE -TURN AND HANDLING EQUIPMENT. -BLOW DOWN TOP DRIVE. -CLEAN AND CLEAR RIG FLOOR. Printed 10/13/2014 1:19:52PM North America - ALASKA BP ��` ��t ��� �; Page ss of 79 Operation Summary Report f'Y° Common Well Name: 01-02 AFE No Event Type: WORKOVER (WO) Start Date: 8/25/2014 End Date: X4 -0103J -E: (6,000,000.00 ) Project: Prudhoe Bay Site: PB DS 01 Rig Name/No.: DOYON 14 Spud Date/Time: 1/17/1970 12:00:OOAM Rig Release: 10/4/2014 Rig Contractor: DOYON DRILLING INC. UN: 500292005300 Active datum: 4: 02 1/17/1970 00:00 @73.00usft (above Mean Sea Level) Date From - To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (usft) 04:00 - 09:30 5.50 TIEBAC P OTHCMP RUN 7" 26# L-80 VAMTOP HC UPPER SCAB LINER ASSEMBLY, ON 4" HWDP / 4" DP. -PJSM WITH RIG CREW, DOYON CASING AND BAKER REPS. -P/U AND M/U BAKER 9-5/8" x 7" FLEXLOCK IV LINER HANGER / ZXP LINER TOP PACKER ASSEMBLY. -R/D 7" HANDLING EQUIPMENT AND R/U 4" HANDLING EQUIPMENT. -RIH WITH UPPER SCAB LINER ASSEMBLY, PAJ 10- JTS OF 4" HWDP F/ 6,501'T/ 6,841'. -RIH WITH UPPER SCAB LINER ASSEMBLY ON 4" DP F/ 6,841' T/ 8,791'. *DRIFT DP FROM DERRICK WITH 2.45" DRIFT. *FILL STRING EVERY 10 -STANDS. 09:30 - 10:00 0.50 TIEBAC P OTHCMP RIG UP ROTATING CEMENT HEAD. -RAJ 1- JT OF DP F/ PIPE SHED AND PLACE MOUSE HOLE. -P)U AND R/U ROTATING CEMENT HEAD AND CEMENT LINES. - -M/U ROTATING CEMENT HEAD TO JT OF DP IN THE MOUSE HOLE. -M/U ROTATING CEMENT HEAD ASSEMBLY AND TOP DRIVE. 10:00 10:30 0.50 TIEBAC P OTHCMP ENGAGE SEAL STEM INTO TIE -BACK RECEPTACLE. -PJSM WITH BAKER REPS ON R/U AND SPACE OUT OF ROTATING CMT HEAD AND ENGAGING SEAL STEM INTO TIE -BACK RECEPTACLE. -ESTABLISH PARAMETERS. *PUW-- 258K, SOW-- 215K -RIH WITH UPPER SCAB LINER F/ 8,791' T/ 8,822' AND OBSERVED SEAL STEM ENGAGE TIE -BACK RECEPTACLE AND NO-GO WITH 10K DOWN. *NO-GO WITH END OF SEAL STEM AT 8,822'. -PRESSURE UP ON DP TO 600 PSI. -PUH AND OBSERVE PRESSURE DROP F/ 600 PSI T/ 0 PSI AT 8,812', INDICATING CIRC PORT EXPOSED. *MARK DP AT NO-GO AND AT CIRC PORT. 10:30 - 11:30 1.00 TIEBAC P OTHCMP CIRCULATE. -CIRC B/U AT 6 BPM WITH 330 PSI. *SIMOPS: -POSITION AND R/U SLB CEMENT EQUIPMENT. -POSITION AND R/U TRUCKS FOR CMT JOB. Printed 10/13/2014 1:19:52PM North America - ALASKA - BPr, r„f"Page 69 of 79 Operation Summary Report Common Well Name: 01-02 AFE No Event Type: WORKOVER (WO) Start Date: 8/25/2014 End Date: iX4-0103J-E: (6,000,000.00 ) Project: Prudhoe Bay Site: PB DS 01 Rig Name/No.: DOYON 14 Spud Date/Time: 1/17/1970 12:00:OOAM Rig Release: 10/4/2014 Rig Contractor: DOYON DRILLING INC. UWI: 500292005300 Active datum: 4: 02 1/17/1970 00:00 @73.00usft (above Mean Sea Level) Date From - To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (usft) 11:30 - 13:00 1.50 TIEBAC P OTHCMP PRESSURE TEST CEMENT EQUIPMENT AND LINES. -PJSM WITH RIG CREW, CH2, SLB CREW, MI SWACO AND BAKER REPS. PRESSURE CROSSCHECK DISCUSSION AND CONFIRMED CHALLENGE QUESTIONS WITH CORRECT RESPONSES. -PUMP 5 BBLS TO PURGE CEMENT LINES FROM CEMENT UNIT TO CEMENT HEAD. -FUNCTION TEST OVERPRESSURE PROTECTION DEVICES. *WSL VERIFIED PUMP TRIPS FUNCTION PROPERLY ON BOTH HEADS. -PRESSURE TEST CEMENT EQUIPMENT AND _ LINES TO 250 / 4,500 PSI FOR 5 CHARTED MINS EACH. TEST PASS. 13:00 - 15:30 2.50 TIEBAC P OTHCMP CEMENT 7” 26# UPPER SCAB LINER ASSEMBLY. -LINE UP CEMENT UNIT TO WELL. -SLB, MIX AND PUMP 190 BBLS OF 15.8 PPG CLASS "G' CEMENT WITH GASBLOK AND ADDITIVES AT 5 BPM WITH 120 PSI. *ICP AND FCP = 120 PSI *YIELD = 1.17 CUFT/SK -SHUT DOWN CEMENT UNIT. -LAUNCH DART. -SLB, KICK OUT DART WITH 5 BBLS FRESH WATER. -SHUT DOWN CEMENT UNIT. -LINE UP RIG PUMPS TO DISPLACE CEMENT. -CLOSE ANNULAR PREVENTER AND LINE UP TO TAKE RETURN THRU THE IA, TO THE - FLOWBACK TANK. -DISPLACE CEMENT WITH 9.8 PPG BRINE AT 5 BPM WITH 90 PSI. *CEMENT AROUND THE CORNER AT 79 BBLS DISPLACED. *CAUGHT DART / WIPER AT 157 BBLS DISPLACED. -DISPLACE CEMENT AT 5 BPM WITH 620 PSI. -SLOWED PUMP TO 2 BBLS WITH 1,900 PSI, AT 256 BBLS DISPLACED. -SLOWED PUMP TO 1 BBLS WITH 1,800 PSI, AT 260 BBLS DISPLACED. -BUMPED PLUG 5 BBLS EARLY AT 261 BBLS TOTAL DISPLACEMENT. *FINAL DISPLACEMENT PRESSURE = 1,800 PSI. *BUMPED PLUG WITH 2,400 PSI. -CHECK FLOATS. FLOATS HELD. -CEMENT IN PLACE WITH PLUG BUMPED AT 15:30 HRS ON 7/28/2014. *UCA RESULTS: 500 PSI COMPRESSIVE STRENGTH AT 14 HRS: 40 MINS. .. **TABLE TOP SPILL DRILL.— Printed 10/13/2014 1:19:52PM !f/�.�'"//rff����. �6/filJ����J✓f .'Yi �.FN',i`/r" .'r//l%/;l /., f e� / / /. !.%":1F G� /`��if� f �' J, J NNE //�/' /�,Fk`,^J' fj �,�: 1/! � %/l, r�r'FJ ✓,f+f. x �Y ,'v' ''/�,+/"�'r t ,• % . • J ; �([ / :,y�y F,.l j �/, ,!���f��.r F'F Common Well Name: 01-02 AFE No Event Type: WORKOVER (WO) Start Date: 8/25/2014 End Date: !X4 -0103J -E: (6,000,000.00) Project: Prudhoe Bay Site: PB DS 01 Rig Name/No.: DOYON 14 Spud Date/Time: 1/17/1970 12:00:OOAM Rig Release: 10/4/2014 Rig Contractor: DOYON DRILLING INC. UN: 500292005300 Active datum: 4: 02 1/17/1970 00:00 @73.00usft (above Mean Sea Level) Date From - To Hrs 1 Task Code NPT NPT Depth Phase Description of Operations (hr)— - - (usft) L 15:30 16:00 0.50 TIEBAC P OTHCMP SET BAKER FLEX LOCK LINER HANGER AND ZXP LINER TOP PACKER, AS PER BAKER REP. -OPEN ANNULAR PREVENTER AND LINE UP 1 TO TAKE RETURNS TO CUTTINGS BOX. -PRESSURE UP ON DP TO 4,200 PSI TO SET FLEX LOCK LINER HANGER. 1 *TOOK4 BBLS TO PRESSURE UP. -SET 40K DOWN AND BLED OFF PRESSURE. -PIU TO NEUTRAL WEIGHT AND ROTATE 20 RIGHT HAND TURNS. -ROLL PUMP AND P/U 5TO EXPOSE DOG SUB AND SET DOWN 50K. *OBSERVE DOGS SHEAR. -P/U 5' AND CIRC AT 10 BPM WITH 500 PSI, FOR 30 BBLS TO CLEAR LINER TOP PACKER OF CEMENT. -SET 60K DOWN TO ENSURE ZXP PACKER � SET. 16:00 - 17:00 1.00 TIEBAC P OTHCMP *TOP OF LINER SET AT 2,286'. , CIRCULATE OUT EXCESS CEMENT. -PICK UP HOLE 35'. -CIRC OUT EXCESS CEMENT AT 10 BPM WITH 580 PSI, RECIPROCATING STRING 20'. *CMT RETURNS TO SURFACE AT 121 BBLS. *RETURNS CLEAN AT 201 BBLS. -- 117:00 - 18:00 1.00 TIEBAC P OTHCMP RIG DOWN CEMENT HEAD, LINES AND EQUIPMENT. - -PJSM. -10 MIN FLOW CHECK. WELL STABLE. R/D AND L/D ROTATING CEMENT HEAD ASSEMBLY. -POOH WITH RUNNING TOOL, LAYING DOWN 4" DP TO PIPE SHED F/ 4,511' T/ 1,240'. *SIMOPS: -TOP OFF 20" x 30" ANNULUS WITH 35 GALS OF 15.8 PPG CLASS "G" CEMENT. 1 -SLB, WASH DOWN, R/D CEMENT EQUIPMENT 18:00 - 19:30 1.50 TIEBAC P OTHCMP AND LINES. PULL OUT OF HOLE WITH UPPER 7" SCAB 1 LINER RUNNING TOOL. -PJSM. -POOH WITH RUNNING TOOL F/ 2,286'T/ 307'. 19:30 - 20:00 0.50 TIEBAC P OTHCMP LAY DOWN 4" HWDP AND UPPER 7" SCAB LINER RUNNING TOOL ASSEMBLY. -10 MIN FLOW CHECK BEFORE PULLING NON-SHEARABLES THRU BOPE. WELL STABLE. -L/D 10 JTS OF 4" HWDP AND SCAB LINER RUNNING TOOL. Printed 10/13/2014 1:19:52PM North America - ALASKA - BP Page 71 of 79 F Operation Summary Report r` f Common Well Name. 01-02 AFE No Event Type: WORKOVER (WO) Start Date: 8/25/2014 End Date: X4 -0103J -E: (6,000,000.00 ) Project: Prudhoe Bay Site: PB DS 01 Rig Name/No.: DOYON 14 Spud Date/Time: 1/17/1970 12:00:OOAM Rig Release: 10/4/2014 Rig Contractor: DOYON DRILLING INC. UN: 500292005300 Active datum: 4: 02 1/17/1970 00:00 @73.00usft (above Mean Sea Leven Date From - To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (..ft) 20:00 - 22:00 2.00 TIEBAC P OTHCMP CLEAR RIG FLOOR AND FLUSH / WASH BOPE. -CLEAN AND CLEAR RIG FLOOR OF UPPER 7" SCAB LINER RUNNING TOOLS AND EQUIPMENT. -BREAK DOWN SAFETY JT. -R/U AND RETRIEVE WEAR BUSHING. -FLUSH / WASH BOPE AS PER DDI SOP. -MVU STACK WASHER AND FLUSH / WASH BOPE AND SURFACE LINES WITH BLACK WATER. -FUNCTION BOPE TO ENSURE CLEAR OF ANY DEBRIS. -R/D STACK WASHER. -R/U AND INSTALL WEAR BUSHING. *ID= 9-1 /16" `SIMOPS: INSTALL NEW SPOOL OF DRILLING LINE. 22:00 - 00:00 2.00 TIEBAC P OHCMP CUT AND SLIP DRILL LINE. -SLIP AND CUT 59.5' OF DRILL LINE AS PER DOYON PROCEDURES. -SERVICE TOP DRIVE AND BLOCKS. *RESET AND FUNCTION CROWN-O-MATIC. 00:00 - 00:30 GOOD TEST. OTHCMP SERVICE RIG. 9/29/2014 0.50 TIE$AC P -LUBRICATE TOP DRIVE, DRAW -WORKS AND ST -80. 00:30 - 03:30 3.00 TIEBAC" P' OTHCMP MAKE UP 6-1/8" DRILL -OUT BHA#27. -PJSM WITH RIG CREWAND BAKER REP. - -MOBE DRILL -OUT BHA COMPONENTS TO RIG FLOOR. -P/U, M/U AND RIH WITH 6-1/8" DRILL -OUT BHA TO 316'. 03:30 - 08:00 4.50 TIEBAC P OTHCMP RUN IN HOLE WITH 6-1/8" DRILL -OUT BHA #27. -RIH WITH 6-1/8" DRILL -OUT BHA F/ 316'T/ 8,483'. *NO ISSUES PASSING THRU 7" SCAB LINER TOP AT 2,286'. -ESTABLISH PARAMETERS. *PUW= 198K, SOW= 155K -RIH WITH 6-1/8" DRILL -OUT BHA F/ 8,483' AND TAG TOC AT 6,547' WITH 1 OK WOB. -PUH 10' AND ESTABLISH CIRC AT 2 BPM WITH 80 PSI. **FIRE DRILL.** 08:00 - 11:30 3.50 TIEBAC P OTHCMP DISPLACE 9.8 PPG BRING WITH 8.5 PPG SEAWATER. -PJSM WITH RIG CREW AND BAKER REP WITH PRESSURE CROSSCHECK DISCUSSION AND CONFIRMED CHALLENGE QUESTIONS WITH CORRECT RESPONSES. -LINE UP TO TAKE RETURNS TO CUTTINGS BOX. -DISPLACE 9.8 BRINE WITH 8.5 SEAWATER AT 6 BPM WITH 1,150 PSI. Printed 10/13/2014 119.52PM North America - ALASKA - BP, Page 72 of 79 Operation Summary Report Common Well Name: 01-02 AFE No Event Type: WORKOVER (WO) Start Date: 8/25/2014 End Date: X4-0103J-E: (6,000,000.00 ) Project: Prudhoe Bay Site: PB DS 01 Rig Name/No.: DOYON 14 Spud DatelTime: 1/17/1970 12:00:OOAM Rig Release: 10/4/2014 Rig Contractor: DOYON DRILLING INC. UWI: 500292005300 Active datum: 4: 02 1/17/1970 00:00 @73.00usft (above Mean Sea Level) Date From - To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (usft) _ 11:30 - 12:00 0.50 TIEBAC P OTHCMP RIG UP TO PERFORM MIT ON 9-5/8" x 7" SCAB LINER. -PJSM WITH RIG CREW AND BAKER REP WITH PRESSURE CROSSCHECK DISCUSSION AND CONFIRMED CHALLENGE QUESTIONS WITH CORRECT RESPONSES. -R/U TEST EQUIPMENT AND PURGE LINES. -CLOSE ANNULAR PREVENTER. 12:00 - 13:30 1.50 TIEBAC P OTHCMP PERFORM MIT ON 9-5/8" x 7" SCAB LINER. -P,JSM WITH RIG CREW AND BAKER REP WITH PRESSURE CROSSCHECK DISCUSSION AND CONFIRMED CHALLENGE QUESTIONS WITH CORRECT RESPONSES. -PERFORM MIT ON 9-5/8" x 7" SCAB LINER TO 250 PSI FOR 5 CHARTED MINS AND 3,770 PSI FOR 30 CHARTED MINS. TEST PASS. -5.5 BBLS TO PRESSURE UP AND 5.5 BBLS BLED BACK. *VERIFY COMPETENCY OF MIT WITH WTL AND WAS GRANTED PERMISSION TO PROCEED WITH OPERATIONS. -R/D TEST EQUIPMENT. -VERIFY NO PRESSURE. OPEN ANNULAR PREVENTER. 13:30 00.00 10.;00 TIEBAC P OTHCMP DRILL 7" SCAB LINER SHOE TRACK -ESTABLISH PARAMETERS AND OBTAIN SPR. *PUW= 200K, SOW--112K, RTW--175K, RPM= 90 WITH SK FREE TORQUE, PUMP - RATE= 8 BPM WITH 1,350 PSI. -RIH AND TAG TOC AT 8,547'. -DRILL OUT HARD CMT F/ 8,547'T/ 8,663'. -DRILL DART / WIPER PLUG AND HARD CMT F/ 8,663' T/ 8,750' -DRILL LANDING COLLAR AND HARD CMT F/ 8,750'T/ 8,794'. -DRILL FLOAT COLLAR AND HARD CMT F/ 8,794'T/ 8,796'. -DRILL HARD CMT F/ 8,796'T/ 8,820'. *WOB= 3-5K **TABLE TOP H2S DRILL." 9/30/2014 00:00 - 00:30 0.50 TIEBAC P OTHCMP DRILL 7" SCAB LINER SHOE TRACK -ESTABLISH PARAMETERS AND OBTAIN SPR. *PUW= 205K, SOW= 162K, RTW-- 182K, RPM= 80 WITH 5K FREE TORQUE, PUMP RATE= 8 BPM WITH 1,360 PSI. -DRILL OUT HARD CMT F/ 8,820' T/ TOP TO SAND AT 8,839'. _ 00:30 - 01:00 0.50 TIEBAC P OTHCMP CIRCULATE HI-VIS SWEEP AROUND. -PUH 15'T/ 8,824'. -PUMP 20 BBL HIAAS SWEEP AROUND AT 12 BPM WITH 2,330 PSI. 01:00 - 01:30 0.50 TIEBAC P OTHCMP DRY DRILL ON TOP OF SAND. -SHUTDOWN PUMPS AND ROTATION. -RIH AND TAG TOP OF SAND AT 8,839'. -DRY DRILL ON TOP OF SAND FOR 20 MINS. *80 RPM WITH 5-7K TORQUE AND 5-8K WOB -PUH 30' AND BREAK CIRC TO ENSURE BIT IS CLEAR OF SAND OR DEBRIS. BIT CLEAR. Printed 10/13/2014 1:19:52PM North America - ALASKA - BP Page 73 of 79 Operation Summary Report Common Well Name: 01-02 AFE No Event Type: WORKOVER (WO) Start Date: 8/25/2014 End Date: X4 -0103J -E: (6,000,000.00 ) Project: Prudhoe Bay Site: PB DS 01 Rig Name/No.: DOYON 14 Spud Date/Time: 1/17/1970 12:00:OOAM Rig Release: 10/4/2014 Rig Contractor: DOYON DRILLING INC. UWI: 500292005300 Active datum: 4: 02 1/17/1970 00:00 @73.00usft (above Mean Sea Level) Date From - To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (usft) 01:30 - 05:00 3.50 TIEBAC P OTHCMP PULL OUT OF HOLE WITH 6-1/8" DRILL -OUT BHA#27. -10 MIN FLOW CHECK. WELL STABLE. -BLOW DOWN TOP DRIVE. -POOH WITH 6-1/8" DRILL -OUT BHA F/ 8,839' T/ 411'. 05:00 - 06:30 1.50 TIEBAC P OTHCMP LAY DOWN 6-1/8" DRILL -OUT BHA#27. -PJSM WITH RIG CREWAND BAKER REP. -POOH, L/D 6-1/8" DRILL -OUT BHA. STAND BACK 3 STDS OF 4-3/4" DRILL COLLARS. CLEAN BOOT BASKETS 06:30 - 07:30 1.00 TIEBAC P OTHCMP - PJSM FOR HANDLING BOOT BASKETS. - USE LIFTING EYE AND STABBING PEG TO INVERT BOOT BASKETS. RECOVER APPROXIMATELY 15 LBS OF CEMENT WITH SMALL AMOUNT OF ALUMINUM. - UD BOOT BASKETS. -BRING RCJB TO RIG FLOOR. 07:30 - 09:30 2.00 TIEBAC P `OTHCMP MAKE UP RCJB CLEANOUT BHA#28 PJSM FOR MAKING UP RCJB BHA. - M/U RCJB, BOOT BASKETS, BUMPER SUB, _. FISHING JARS. - RUN 3 STANDS OF DRILL COLLARS FROM DERRICK. 09:30 - 12:00 2.50 TIEBAC P OTHICMP RIH W/ RCJB CLEANOUT BHA #28 - RIH F/ 327' T/ 5,075' 12:00 - 12:30 0.50 TIEBAC P OTHCMP SERVICE RIG 12:30 - 14:00 1.50 TIEBAC P OTHCMP RIH W/ RCJB CLEANOUT BHA #28 - RIH F/ 5,075' T/ 8,800' 14:00 - 15:30 1.50 TIEBAC P OTHCMP CLEAN OUT SAND ON TOP OF BRIDGE PLUG - TAG TOP OF SAND AT 8,842. - PU TO 8,810', BREAK CIRCULATION, ICP 4 BPM, 450 PSI, FCP 8BPM, 1520 PSI, 50 RPM, ROT WT 182K. - DROP 7/8 BALL, PUMP ON SEAT AT 4 BPM, 450 PSI, ON SEAT ICP 4 BPM 550 PSI, FCP 8.5 BPM 2100 PSI. - WASH AND REAM, 8.5 BPM, 2100 PSI, 50 RPM, TORQUE 7-8K, TAG AT 8,842'. - TORQUE UP TO 10K AT TOP OF SAND. - PICK UP AND SLACK OFF 2X AND ATTEMPT TO WASH DOWN, UNSUCCESSFUL. - INCREASE RPM TO 80, SLACK OFF TO 8,843',1-2K WOB, TORQUE ON 6-7K, TORQUE AND WEIGHT FELL OFF. - CONTINUE TO ROTATE AT 80 RPM, CIRCULATE 8.5 BPM, 2300 PSI. - WASH DOWN TO 8,875' WITH MINIMAL TORQUE ON AND MINIMAL WOB. - SLOW ROTARY DOWN TO 15 RPM, TAG RBP AT 8,880', PICK UP TO 8,875', SHUT DOWN ROTARY, SLACK OFF AND TAG PLUG 2X AT 8,880'. 15:30 - 16:30 1.00 TIEBAC P OTHCMP CIRCULATE HIGH VIS SWEEP - ROTATE AND RECIPROCATE PIPE WHILE CIRCULATING. - 8 BPM, 1900 PSI, 10 RPM, 5K TORQUE. - PUMP HIGH VIS SWEEP SURFACE TO SURFACE. Printed 10/13/2014 1:19:52PM North America - ALASKA - BP Page 74 of 79 Operation Summary Report Common Well Name. 01-02 AFE No Event Type: WORKOVER (WO) Start Date: 8/25/2014 End Date: X4 -0103J -E: (6,000,000.00 ) Project: Prudhoe Bay Site: PB DS 01 Rig Name/No.: DOYON 14 Spud Date/Time: 1/17/1970 12:00:OOAM Rig Release: 10/4/2014 Rig Contractor: DOYON DRILLING INC. UN: 500292005300 Active datum: 4: 02 1/17/1970 00:00 @73.00usft (above Mean Sea Level) Date From - To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (usft) 16:30 - 21:30 5.00 TIEBAC P OTHCMP POOH WITH RCJB CLEANOUT BHA#28 - F/ 8,880', T/ 350'. - UP WT 207K, DN WT 162K. 21:30 - 23:00 1.50 TIEBAC P OTHCMP LAY DOWN RCJB CLEANOUT BHA #28 - MONITOR WELL FOR 10 MIN, STATIC. - PJSM FOR LAYING DOWN BHA. - LAY DOWN D/C. CLEAN OUT BOOT BASKETS AND RCJB. RECOVERED 3 LBS OF UNDER 1/4" ALUMINUM PIECES FROM BOOT BASKETS, RCJB CLEAR OF DEBRIS.. 23:00 - 00:00 1.00 TIEBAC P OTHCMP R/U TO TEST BOPE - PICK UP SINGLE AND WEAR RING PULLER. - REMOVE WEAR RING. TEST BOPE 10/1/2014 00:00 - 01:00 1.00 TIEBAC P OTHCMP - PJSM CONCERNING TESTING BOPE. - RIG UP BOPE FOR TESTING. - CAMERON REP. AND RIG CREW VERIFY TEST PLUG LANDED PROPERLY IN TUBING SPOOL. - CAMERON REP RILDS, TORQUE TO 450 LBS, GLAND NUTS TORQUED TO 500 LBS. - - MAKE UP FOSVS WITH DART VALVE. 01:00 - 11:00 10.00,---- TIEBAC P OTHCMP TEST BOPE - CONDUCT KICK WHILE DRILLING DRILL. NOTE VOLUME TO FILL GAS BUSTER AND U -TUBE, 6 BBLS. _. - TEST BOPE 250 / 3500 PSI FOR 5 MIN / 5 MIN. - TEST WITH 4", 4-1/2", AND 7" TEST JOINTS. HCR KILL SIDE FAILED -GREASED, FUNCTIONED AND RETEST GOOD. - AOGCC, BOB NOBLE WAIVED WITNESS OF BOPE TEST. 11:00 - 12:00 1.00 TIEBAC P OTHCMP TEST BOPE - RIG DOWN BOPE TEST EQUIPMENT. - BACK OUT LOCK DOWN SCREWS ON TEST PLUG, DRAIN BOP STACK. - BLOW DOWN CHOKE AND KILL LINES. - INSTALL WEAR RING, ID 9-1/16". 12:00 - 12:30 0.50 TIEBAC P OTHCMP LUBRICATE RIG. 12:30 - 14:00 1.50 TIEBAC P OTHCMP RIH WITH RBP RETRIEVABLE TOOL. - P/U AND M/U RETRIEVAL TOOL PER BAKER REP. - RIH F/ SURFACE T/ TOL AT 2,286', UP WT 85K, DN WT 85K. - TAG TOL, PICK UP AND ROTATE THROUGH SUCCESSFULLY AT 10 RPM, TORQUE OK. 14:00 16:00 2.00 TIEBAC P OTHCMP RIH WITH RBP RETRIEVABLE TOOL. - RIH F/ 2,286' T/ 8,841'. 16:00 - 16:30 0.50 TIEBAC P OTHCMP RETRIEVE RBP - OBTAIN PARAMETERS PRIOR TO LATCHING RBP. - UP WT 200K, DN WT 155K, 8 BPM, 970 PSI. - WASH DOWN TO TOP OF RBP AT 8,880', LATCH ON TO RBP - OBSERVE PRESSURE INCREASE TO 1100 PSI, SHUT DOWN PUMPS. - RELEASE RBP AS PER BAKER REP. Printed 10/13/2014 1:19:52PM North America -ALASKA - BP f `'' fi ' f`i'r" ''" ` Page 75 of 79 Operation Summary Report Common Well Name: 01-02 AFE No Event Type: WORKOVER (WO) Start Date: 8/25/2014 End Date: X4-0103J-E: (6,000,000.00 ) Project: Prudhoe Bay Site: PB DS 01 Rig Name/No.: DOYON 14 Spud Date/Time: 1/17/1970 12:00:OOAM Rig Release: 10/4/2014 Rig Contractor: DOYON DRILLING INC. UWL 500292005300 Active datum: 4: 02 1/17/1970 00:00 @73.00usft (above Mean Sea Level Date From - To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (usft) 16:30 - 17:00 0.50 TIEBAC P OTHCMP BULLHEAD 40 BBLS -OBSERVED WELL TAKING LOSSES UPON RELEASE OF RBP. -SHUT ANNULAR, OPEN KILL LINE AND BULLHEAD 40 BBLS AT 5 BPM, 20 PSI. -MONITOR WELL FOR 10 MINUTES, 0 PSI. - OPEN ANNULAR AND CHECK FOR FLOW, WELL STILL ON VACCUM. BEGIN FILLING HOLE AT 60 BPH. 17:00 - 00:00 7.00 TIEBAC P OTHCMP POOH WITH RBP - POOH LAYING DOWN DRILL PIPE F/ 8,880, T/ SURFACE. UP WT 205K, DN WT 160K @ 8,880'. CONTINUE FILLING HOLE, 60 BPH. TOTAL LOSSES FOR TOUR 513 BBLS. 10/2/2014 00:00 - 02:00 2.00 RUNCOM P RUNCMP RIG UP TO RUN 4-1/2" COMPLETION CLEAN AND CLEAR FLOOR. LOAD PIPE SHED WITH COMPLETION JEWELRY. -VERIFY RUNNING ORDER WITH HES, DRILLER, TOU_R_PUSHER, AND WSL. 02:00 - 03:00 1.00 RUNCOM P RUNCMP DUMMY RUN HANGER - M/U LANDING JOINT AND 5 FOOT HANGER - - NTO TUBING SPOOL, GOOD. LAY DOWN HANGER AND LANDING JOINT. - M/U 4-1/2 VAMTOP XO TO FOSV. 03:00 - 10:30 7.50 RUNCOM P RUNCMP RIH WITH 4-1/2"COMPLETION - PJSM, DISCUSS POWER TONG SAFETY, KEEP HANDS AWAY FROM OPEN DOOR ON TONGS, USE ROPES TO PULL TONGS ONTO PIPE. - VERIFY SKATE OPERATOR, DRILLER, HES HAVE CORRECT RUNNING ORDER. - RIH WITH 4-1/2" COMPLETION F/ SURFACE T/ 3,318'. - BAKER-LOK ALL CONNECTIONS BELOW PACKER. - TORQUE TURN ALL CONNECTIONS, OPTIMUM TORQUE 4,440 FT-LBS. - KICK WHILE TRIPPING DRILL (D1). 10:30 - 11:00 0.50 RUNCOM P RUNCMP SERVICE RIG - NOTICE HYDRAULIC OIL LEAK ON TOP DRIVE. 11:00 - 12:00 1.00 RUNCOM N RREP 3,318.00 RUNCMP CODE 8 - REPLACE HYDRAULIC PUMP ON TOP DRIVE. 12:00 - 12:30 0.50 RUNCOM P RUNCMP SERVICE RIG - CONTINUE WORKING ON TOP DRIVE HYDRAULIC PUMP. 12:30 - 00:00 11.50 RUNCOM N RREP 3,318.00 RUNCMP CODE 8 - CONTINUE WORKING ON TOP DRIVE HYDRAULIC PUMP. - 10/3/2014 00:00 - 08:30 8.50 RUNCOM P RUNCMP RIH WITH 4-1/2"COMPLETION - RIH WITH 4-1/2" COMPLETION F/ 3,318 T/ 8,758'. - LAY DOWN JOINT #101 BAD PIN, REPLACE WITH JOINT #216. - TORQUE TURN ALL CONNECTIONS, OPTIMUM TORQUE 4,440 FT-LBS. Printed 10/13/2014 1:19.52PM North America - ALASKA - BP Page 76 of 79 Operation Summary Report Common Well Name: 01-02 AFE No Event Type: WORKOVER (WO) Start Date: 8/25/2014 End Date: X4 -0103J -E: (6,000,000.00 ) Project: Prudhoe Bay Site: PB DS 01 Rig Name/No.: DOYON 14 Spud Date/Time: 1/17/1970 12:00:OOAM Rig Release: 10/4/2014 Rig Contractor: DOYON DRILLING INC. I UWI: 500292005300 Active datum: 4: 02 1/17/1970 00:00 @73.00usft (above Mean Sea Level) Date From - To Hrs Task Code j NPT NPT Depth Phase Description of Operations (hr) (usft) 08:30 - 10:00 1.50 RUNCOM P RUNCMP MAKE UP LANDING JOINT AND LAND HANGER. - PJSM WITH CAMERON REPS AND DDI PERSONNEL ON LANDING JOINTAND RILDS. - RIH AND LAND. - FINAL PUW=160K, SOW=135K. -CAMERON REP RILDS AND TORQUED TO 500 FT/LBS. 10:00 - 12:00 2.00 RUNCOM P RUNCMP DROP BALL AND ROD PJSM PUMP 30 BBLS OF 9.8 PPG BRINE DOWN TBG, 3.5 BPM, 30 PSI. - DROP BALLAND ROD WITH CHARGE PUMP ON FOR AN ADDITIONAL 7 BBLS OF 9.8 PPG BRINE AND WAIT 15 MINS. - PUMP DOWN TBG TO VERIFY BALLAND ROD SEATED PER HES REP, TOTAL PUMPED 3 BELS, FINAL PRESSURE 120 PSI. 681 BBLS LOSS FROM MIDNIGHT TO NOON_. 12:00 - 16:00 4.00 RUNCOM P -RUNCMP SET COMPLETION PACKER, TEST TUBING AND IA -PJSM, CONCERNING MOVING FLUID AND VALVE ALIGNMENT. - PUMP DOWN IA WITH 245 BBLS, 9.8 PPG BRINE WITH CORROSION INHIBITOR. - PUMP 9.8 PPG BRINE DOWN TBG, TOTAL PUMPED 3.7 BBLS, PRESSURE TO 3600 PSI AND SET PACKER. - HOLD PRESSURE AT 3600 PSI AND TEST TBG FOR 30 MINS, TEST GOOD. - BLEED TBG PRESSURE TO 1500 PSI. - FILL BACKSIDE, PUMP DOWN IA FOR A TOTAL OF 27.5 BBLS, NO PRESSURE INCREASE NOTED, SHUT DOWN PUMPS AND BLEED AIR FROM IA. -PUMP ADDITIONAL 16 BBLS, PRESSURE INCREASE OF 500 PSI OBSERVED, SHUT DOWN PUMPS AND BLED AIR FROM IA. - PUMP AN ADDITIONAL 4.5 BBLS TO TEST PSI AT 3500. HOLD FOR 30 MINUTES, TEST GOOD. - WSL DISCUSS TEST RESULTS WITH WTL, RECEIVE APPROVAL TO PROCEED WITH SHEARING OUT. - BLEED TBG PRESSURE OFF TO SHEAR DCK VALVE, OBSERVE SHEAR AT 2100 PSI ON BACKSIDE. 16:00 - 16:30 0.50 RUNCOM P RUNCMP PUMP BOTH WAYS TO CONFIRM SHEAR - PUMP 5 BBLS DOWN TBG AT 2 BPM, 600 PSI. - PUMP 5 BBLS DOWN IA AT 2 BPM, 380 PSI. Printed 10/13/2014 1:19:52PM North America - ALASKA - BP Page 77 of 79 Operation Summary Report Common Well Name: 01-02 AFE No Event Type: WORKOVER (WO) Start Date: 8/25/2014 End Date: X4 -0103J -E: (6,000,000.00 ) Project: Prudhoe Bay Site: PB DS 01 Rig Name/No.: DOYON 14 Spud Date/Time: 1/17/1970 12:00:00AM Rig Release: 10/4/2014 Rig Contractor. DOYON DRILLING INC. UWI: 500292005300 Active datum: 4: 02 1/17/1970 00:00 @73.00usft (above Mean Sea Level) Date From - To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (usft) 16.30 20:00 3.50 RUNCOM P RUNCMP . PUMP DIESEL FREEZE PROTECT WITH LRS PJSM WITH LRS REPS AND DDI PERSONNEL. USE PRESSURE CROSSCHECK CHECKLIST PRIOR TO PUMPING. RIG UP LRS LINE TO IA, TEST TO 3500 PSI FOR 5 MINUTES PER TEST CRITERIA D, TEST I GOOD. r PUMP 5 BBLS DIESEL DOWN IA AT i BPM, 40 PSI. - SHUT IN WELLAND ALLOW TO U -TUBE FOR 30 MINUTES, DID NOT OBSERVE FLUID MOVING. OBSERVE AIR BURPING FROM TBG AND IA, NO DIESEL OBSERVED BURPING FROM IA. WSL CONSULT WITH ENGINEER AND DRL I ! SUPT., DECIDE ON PLAN FORWARD. - P 20:00 00:00 i 4.00 i RUNCOM RUNCMP FLUID PACK WELLAND PUMP DIESEL FREEZE PROTECT WITH LRS - PJSM WITH LRS REPS AND AND DDI PERSONNEL, DISCUSS NEW PLAN FORWARD AND ASSIGN TASKS TO CREW MEMBERS. - USE PRESSURE CROSSCHECK CHECKLIST PRIOR TO PUMPING. PUMP 1/2 BPM, 60 PSI. DOWN TBG TAKING RETURNS TO FLOW BACK TANK 3.5 BBLS PUMPED BEFORE SEEING DIESEL RETURNS AT FLOW BACK TANK, PUMP ADDITIONAL 1.5 BBL FOR TOTAL PUMPED OF 5 BBL. - SHUT DOWN PUMP AND LINE UP LRS TO PUMP FREEZE PROTECT. PUMP 10 BBLS DOWN IAAT 1 BPM, 100 PSI. f I SHUT IN WELLAND ALLOW TO U -TUBE FOR 30 MINUTES, DID NOT OBSERVE FLUID MOVING. IA NOW PACKED WITH DIESEL ON TOP BUT STILL OBSERVED AIR AND SOME FLUID BURPING FROM TBG WITH NO DIESEL PRESENT IN TBG. WEIGHED FLUID BURPING FROM TBG AT 8.5 !PPG. WSL CONSULT WITH ENGINEER AND DRLG SUPT., DISCUSS 8.5 PPG SEAWATER OBSERVED IN TBG, DECIDE ON PLAN _ + FORWARD. 10/4/2014 100:00 _:30 . 01 150 I i RUNCOM P RUNCMP PUMP DIESEL FREEZE PROTECT WITH LRS - LOAD ADDITIONAL 40 BBLS DIESEL ON LRS PUMPTRUCK PJSM WITH LRS REPS AND AND DDI PERSONNEL, DISCUSS NEW PLAN FORWARD AND ASSIGN TASKS TO CREW MEMBERS. USE PRESSURE CROSSCHECK CHECKLIST PRIOR TO PUMPING. I- PUMP 35 BBLS DOWN IAAT 1 BPM, ICP 150 I PSI, FCP 300 PSI. FLUID RETURNS FROM TBG INITIALLY WEIGHED 8.5 PPG AND STEADILY INCREASED TO 9.8 PPG FOR FINAL 15 BBLS PUMPED. Printed 10/13/2014 1:19:52PM North America - ALASKA - BP Operation Summary Report Common Well Name: 01-02 AFE No Event Type: WORKOVER (WO) Start Date: 8/25/2014 End Date: X4 -0103J -E: (6,000,000.00 ) Project: Prudhoe Bay Site: PB DS 01 Rig Name/No.: DOYON 14 Spud Date/Time: 1/17/1970 12:00:OOAM Rig Release: 10/4/2014 Rig Contractor: DOYON DRILLING INC. UWI: 500292005300 Active datum: 4: 02 1/17/1970 00:00 @73.00usft (above Mean Sea Leve Date From - To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (usft) " 01:30 - 02:30 1.00 RUNCOM P RUNCMP U -TUBE - SHUT DOWN PUMPS AND LINE UP TO U -TUBE. - OBSERVE FLUID MOVING WHEN OPENING VALVES TO U -TUBE. -ALLOW WELL TO U -TUBE FOR ONE HOUR. - CHECK SAMPLE VALVE ON TBG SIDE, GOOD INDICATION OF DIESEL IN TBG. - CHECK SAMPLE VALVE ON IA SIDE, GOOD INDICATION OF DIESEL IN IA. MONITOR WELL FOR 10 MINUTES, STATIC. 02:30 - 03:30 1.00 RUNCOM P T RUNCMP ' BLOW DOWN RIG DOWN FREEZE PROTECT LINES AND BLOW DOWN SAME.: 0330 05:00 1.50 WHSUR P RUNCMP INSTALLTWC SUCK OUT BOP STACK. - M/U T -BAR AND DRY ROD. - CAMERON REP DRY ROD TWC, TWC IN PLACE AT 04:45 HRS. PRESSURE TEST TWO WAY CHECK FROM 05:00 06:00 1.00 WHSUR P RUNCMP BELOW. PJSMWITH ALL CREWS AND LITTLE RED SERVICES. - REVIEW PRESSURE CROSSCHECK CHECKLIST PRIOR TO PUMPING. - LINE UP LITTLE RED TO PUMP DOWN IA. - LITTLE RED PRESSURE UP TO 250 PSI AT 0.4 BBLS PUMPED FOR 5 CHARTED MINUTES, TEST GOOD. - LITTLE RED PRESSURE UP TO 3500 PSI AT 3.5 BBLS PUMPED FOR 5 CHARTED MINUTES, TEST GOOD. - BLEED OFF TEST PRESSURE, 4 BBLS BLED BACK, CLOSE IA VALVE. - RIG DOWN LITTLE RED SERVICES. -- - IA PRESSURE, 0 PSI. _. - -- 06:00 07:00 1.00 BOPSUR P RUNCMP NIPPLE DOWN BOPE. - NIPPLE DOWN BOPE RISER AND FLOW LINE. - BLOW DOWN LINES AND RIG DOWN LINES TO CELLAR PUMP. " SIM OPS- TUNE UP TOP DRIVE CONTROLS. - FIRE DRILL AND AAR. RUNCMP CHANGE OUT LOWER PIPE RAMS. 0700 10,00 3.00 BOPSUR P - C/O RAMS FROM 3-1/2" X 6" VBR'S TO 2-7/8" X 5" VBR'S. 10:00 - 15:00 5.00 BOPSUR P RUNCMP NIPPLE DOWN BOPE AND STAND BACK ON STUMP IN CELLAR. 15:00 - 20:00 5.00 WHSUR P RUNCMP NIPPLE UP ADAPTER. - PJSM WITH CAMERON REPS AND DDI PERSONNEL. - NIU ADAPTOR AND TEST HANGER VOID AND SEALS TO 5000 PSI FOR 30 MINUTES, TEST GOOD. - INSTALL TREE 20:00 - 21:00 1.00 WHSUR P RUNCMP RIG UP AND TEST TREE. - TEST TO 250 PSI AND 5000 PSI FOR 5 MINS EACH- TESTS GOOD. - R/D TEST EQUIPMENT. 21:00 _ 21:30 0.50 WHSUR P RUNCMP SECURE TREE AND CLEAN CELLAR. Printed 10/13/2014 1:19:52PM Printed 10/13/2014 1:19:52PM North America -ALASKA - BP Page 79 ©f 79 Operation Summary Reportf Common Well Name: 01-02 AFE No Event Type: WORKOVER (WO) Start Date: 8/25/2014 End Date: X4 -0103J -E: (6,000,000.00 ) Project: Prudhoe Bay Site: PB DS 01 Rig Name/No.: DOYON 14 Spud Date/Time: 1/17/1970 12:00:OOAM Rig Release: 10/4/2014 Rig Contractor. DOYON DRILLING INC. UWL 500292005300 Active datum: 4: 02 1/17/1970 00:00 @73.00usft (above Mean Sea Level) Date From - To Hrs Task Code NPT ! NPT Depth Phase Description of Operations (hr) 121:30 (usft) - 22:30 1.00 RIGID P RUNCMP RIG DOWN RIG FLOOR AND PREPARE FLOOR TO SKID. 22:30 - 00:00 1.50 RIGID P RUNCMP SKID RIG FLOOR INTO MOVING POSTION. - PJSM, REVIEW FLOOR SKIDDING SOP * RIG RELEASED FROM DS 01-02 AT 23:59 10-04-2014 Printed 10/13/2014 1:19:52PM Printed 10/28/2014 3:35:14PM Page 1 of 2 ,North America -ALASKA - BP Cementing Report Common Well Name: 01-02 / OH Report no.: 1 Report date: 9/21/2014 Project: Prudhoe Bay Site: PB DS 01 'Spud Date/Time: 1/17/1970 Event Type: WORKOVER (WO) Start Date: 8/25/2014 End Date: AFE No.: Contractor: DOYON DRILLING INC. Rig Name/No.: DOYON 14 Rig Release: 10/4/2014 X4 -0103J -E: (6,000,000.00) UWI: 500292005300 Active datum: 4 : 02 1/17/1970 00:00 @73.00usft (above Mean Sea Level) General Information`a Job type: Primary Cement job start date/time: 9/20/2014 11:30PM Job end date/time: 9/21/2014 1:OOAM Cement Company: SLB -CEMENTING Cementer: J.WALLACE Cemented String: CASING PATCH String Size: 9.625 (in) String Set TMD: 2,433.00 (usft) Hole Size: 12.250 (in) Pipe Movement Pipe Movement: NO MOVEMENT Rotating Time (Start -End): RPM: Rotating Torque (init/avg/max): (ft-lbf) Reciprocating Time (Start -End): Recip Drag Up/Down: - (kip) SPM: Stroke Length: Fluid Name: SEA WATER Fluids (1 of 1) Slurry Type: CEMENT Purpose: PRIMARY Class: G -CLASS Description: TAIL SLURRY Density: 15.80 (ppg) Yield: 1.1700 (ft'/sk) Mix Water Ratio: 3.385 (gal/sk94) Excess: Mix Method: BATCH Sacks Used: 792.00 (941b sacks) Water Volume: 63.8 (bbl) Excess Slurry Volume: Density Measured by: DENSOMETER Other Volume: Total Vol in Well: 165.0 (bbl) Slurry Volume: 165.0 (bbl) Excess Measured From: EST. GAUGE HOLE Mud Type: WATER/BRINE Density: 8.50 (ppg) PV: YP: Viscosity: Gels 10 Sec: Gels 10 Min: Additives Name Type Amount Units Concentration Unit D047 ANTIFOAM AGENT 0.200 GAL/SX D-65 DISPERSANT 0.300 % BWOC D600 G GAS -BLOCK 1.500 GAL/SX D-186 ACCELERATOR 0.120 GAL/SX Printed 10/28/2014 3:35:14PM Printed 10/28/2014 3:35:14PM Pa North America -ALASKA - E� 41-, re'r C em i ng Report ent' .,., Common Well Name: 01-02 / OH Report no.: 1 Report date: 9/21/2014 Project: Prudhoe Bay Site: PB DS 01 Spud Date/Time: 1/17/1970 Event Type: WORKOVER (WO) Start Date: 8/25/2014 End Date: AFE No.: Contractor: DOYON DRILLING INC. Rig Name/No.: DOYON 14 Rig Release: 10/4/2014 X4 -0103J -E: (6,000,000.00) UWI: 500292005300 Active datum: 4 : 02 1/17/1970 00:00 @73.00usft (above Mean Sea Level) Stages Stage Stage Type Est. Top Est. Bottom Mud Circ. Mud Circ. Top Bottom plug Pressure Float Pressure Returns Cmt Vol to Total Annular no. (usft) (usft) Rate Press. Plug Plug I Bumped Bumped Held Held ]Circulate Prior Surface Mud Lost Flow (gpm) (psi) (hr) (bbl) (bbl) After (psi) min) 1 PRIMARY CEMENT 37.91 2,433.00 Y Y Y 1,950.001 1 5.00 Pumping Schedule Fluid pumped Volume Avg. Max Disp. Slurry Top Slurry Base Start Mix Cmt Start Slurry Pumping end Start Disp Foam Gas Type Gas Vol BH circ. Bh static Pumped Disp. Rate TMD TMD Prep date/time job Used temp. temp. (bbl) Rate (bbl/min) (usft) (usft) (scf) (bbl/min) SEAWATER -TAIL SLURRY 165.0 5.00 6.00 37.91 2,433.00 N Tests Casing Test Shoe Test Liner Top Test Test Pressure: (psi) FIT/LOT: (ppg) Liner Overlap: (usft) Time: (min) Tool: N Positive Test: (ppg) Positive Test Tool: N Cement Found between Shoe and Collar: N Open Hole Length: (usft) Negative Test: (ppg) Negative Test Tool: N Hours Before Start: (hr) Time before test: (hr) Cmt Found on Tool: N Log/Survey Evaluation Interpretation Summary CBL Run: N Cement Top: (usft) Under Pressure: (psi) How Determined: Bond Quality: TOC Sufficient: N CET Run: N Job Rating: Bond Quality: If Unsuccessful, Detection Indicator: Temp Survey: N Remedial Cement Required: N Hrs Prior to Log: (hr) How Determined: Printed 10/28/2014 3:35:14PM Printed 10/29/2014 7:59:11AM North America -ALASKA - BP Page 1 of 2 Cementing Report Common Well Name: 01-02 / OH Report no.: 2 Report date: 9/28/2014 Project: Prudhoe Bay Site: PB DS 01 Spud Date/Time: 1/17/1970 Event Type: WORKOVER (WO) Start Date: 8/25/2014 End Date: AFE No.: Contractor: DOYON DRILLING INC. Rig Name/No.: DOYON 14 IRig Release: 10/4/2014 X4-0103J-E: (6,000,000.00) UWI: 500292005300 Active datum: 4 : 02 1/17/1970 00:00 @73.00usft (above Mean Sea Level) .,formation Job type: Primary Cement job start date/time: 9/28/2014 1:OOPM Job end date/time: 9/28/2014 3:30PM Cement Company: SLB-CEMENTING Cementer: LANCE KALIVAS Cemented String: UPPER SCAB LINER String Size: 7.000 (in) String Set TMD: 8,821.91 (usft) Hole Size: 8.500 (in) Pipe Movement Pipe Movement: NO MOVEMENT Rotating Time (Start-End): RPM: Rotating Torque (init/avg/max): (ft-lbf) Reciprocating Time (Start-End): Recip Drag Up/Down: - (kip) SPM: Stroke Length: Fluid Name: BRINE Fluids (1 of 1) Slurry Type: CEMENT Purpose: PRIMARY Class: G-CLASS Description: TAIL SLURRY Density: 15.80 (ppg) Yield: 1.1700 (ft'/sk) Mix Water Ratio: 2.933 (gal/sk94) Excess: Mix Method: BATCH Sacks Used: 912.00 (9411b sacks) Water Volume: 63.7 (bbl) Excess Slurry Volume: 0.0 (bbl) Density Measured by: DENSOMETER Other Volume: Total Vol in Well: 190.0 (bbl) Slurry Volume: 190.0 (bbl) Excess Measured From: Mud Type: WATER/BRINE Density: 9.80 (ppg) PV: YP: Viscosity: Gels 10 Sec: Gels 10 Min: Additives Name Type Amount Units Concentration Unit D047 ANTIFOAMAGENT 0.200 GAL/SX D-65 DISPERSANT 0.300 % BWOC D600 G GAS-BLOCK 1.500 GAL/SX D-186 ACCELERATOR 0.120 GAL/SX Printed 10/29/2014 7:59:11AM Printed 10/29/2014 7:59:11AM North America - ALASKA - BP Page 2 of 2 Cementing Report Common Well Name: 01-02 / OH Report no.: 2 Report date: 9/28/2014 Project: Prudhoe Bay Site: PB DS 01 Spud Date/Time: 1/17/1970 Event Type: WORKOVER (WO) Start Date: 8/25/2014 End Date: AFE No.: Contractor: DOYON DRILLING INC. Rig Name/No.: DOYON 14 Rig Release: 10/4/2014 X4-0103J-E: (61000,000.00 ) UWI: 500292005300 Active datum: 4 : 02 1/17/1970 00:00 @73.O0usft (above Mean Sea Level) Stage Stage Type Est. Top Est. Bottom Mud Circ. Mud Circ. Top Bottom Plug Pressure Float Pressure Returns Circulate Cmt Vol to Total Annular no. (usft) (usft) Rate Press. Plug Plug Bumped Bumped Held Held Prior Surface Mud Lost Flow (gpm) (psi) (psi) (min) (hr) (bbl) (bbl) After 1 PRIMARY CEMENT 2,286.00 8,812.00 Y Y Y 1 2,400.00 Pumping Schedule Fluid pumped Volume Avg. Max Disp. Slurry Top Slurry Base Start Mix Cmt Start Slurry Pumping end Start Disp Foam Gas Type Gas Vol BH circ. Bh static Pumped Disp. Rate TMD TMD Pmp date/time job Used temp. temp. (bbl) Rate (bbl/min) (usft) (usft) (scfi (bbl/min) BRINE - TAIL SLURRY 190.0 5.00 5.40 2,286.00 8,812.00 N Tests Casing Test Shoe Test Liner Top Test Test Pressure: (psi) FIT/LOT: (ppg) Liner Overlap: (usft) Time: (min) Tool: N Positive Test: (ppg) Positive Test Tool: N Cement Found between Shoe and Collar: N Open Hole Length: (usft) Negative Test: (ppg) Negative Test Tool: N Hours Before Start: (hr) Time before test: (hr) Cmt Found on Tool: N Log/Survey Evaluation Interpretation Summary CBL Run: N Cement Top: (usft) Under Pressure: (psi) How Determined: Bond Quality: TOC Sufficient: N CET Run: N Job Rating: Bond Quality: If Unsuccessful, Detection Indicator: Temp Survey: N Remedial Cement Required: N Hrs Prior to Log: (hr) How Determined: Printed 10/29/2014 7:59:11AM FL a A- 30- WAAATED J-110 CONDUCTOR 20' CSG, 91.5 #, 1"O' 1) -19.114" 19. 12e TOPOF7- SCAB LNR I -F —2'2.qW =,47#.L-80VAM'T0P.V=8.681* 2429* 9-518" BOWEN CSG PATCH, 1) MW 13-3/8' CSG, T2ik, N-80, ID = 12.347"�3004M Minim1a 10 = 2.992" @ 9046' 4-112" G LANDING SUB I 9 -5/8 - CSG, 40A!'#,SO(>.95,1)=8'835- -Erjl& <0 TO 43.57#, SOO-95, ID = 8155' 4-112* TBG12.61# , 13CP,86 VAM TOR .0152bpf, K)=3.958' 9[ -5" -5/8- CSG, 43.5# XO TO 974, SOO-95, 11= 8,681' 'r SCAB LNR, 26#, L-80 VAM TOP M .0383 bpf, ID = 6.276' 172- TBG, 12.6#, L-80 TC4,,0152bpf, K1- 3 -958 - FT -9P OF 3-1a- SCAB LNR [4- V2* TBG -NPC, 12. �0152 bpf, ID = 3.958* PERFORATION SUMMARY REF LOG. BHCS ON 02J20170 ANG -4-E AT TOP PB;F: 23' a 9661' �i512M 01 2 bpf, Note: Refer to Production DB for historical pei -Sff SPF -R�AL OprdSqz SHOT WA 4 9360-9370 S 071'27170 NIA 4 9430-9440 S 02127170 4 4 W5 - 9485 S 031CM9/70 4' 4 9495-9525 S 03119/70 4* 4 9545-9575 S 03/09/70 4*' 4 9585-9616 S 03/09170 4" 4 9627-9675 S 10/18185 4" 4 9660-9674 S 10118/85 3-3/8* 4 9WI - 9675 0 OWIWO 4!* 4 %90-9708 S 06127187 3-318' 4 9691-9709 0 08110190, 3 -Ur SCAB LW 9�3#, L-80 FL4S, L -OW bpf, K) = _2-992" 9-5/8- CSG, 47#, SOO-95_0733 bpf, 11) = &681 SAFETY NOTES, ***4-112" CHROM E TBG*** 2066' LeTiRl Fq—T MD TVD TVD V.V OW Ty PE V LATCH PORT DATE V!Sfl.� ---------- ;%&8 D '98r 3778 23 KBG2 DOME SK 16 10114/14 �1 !3M 7278 6821 26 KBG2 SO I BK 20 10114114 8309 7760 22 La e-*-' rA"V t Bl< 0 10103/14 877T J-14 1212'11S NIT? 1Ci = 3.725 112 - W -W S-198' 4,0-3.958" r VIII PRUDHLOE BAY LUT VVEL01-02 PERMITNo: *1691190 AF! No: %029,-20053-0D SEC 8� T I OR RISE, 1W FW & 135r M 12 1ITME01011"Hi"INK Z. V!Sfl.� ---------- 877T J-14 1212'11S NIT? 1Ci = 3.725 112 - W -W S-198' 4,0-3.958" r VIII PRUDHLOE BAY LUT VVEL01-02 PERMITNo: *1691190 AF! No: %029,-20053-0D SEC 8� T I OR RISE, 1W FW & 135r M 12 1ITME01011"Hi"INK Z. Ell . ..... XHVZE Image~ject Well History File Cover P This page identifies those items that were not scanned during the initial production scanning phase. They are available in the original file, may be scanned during a special rescan activity or are viewable by direct inspection of the file. _L ~ ~ - I ~ ~ Well History File Identifier RESCAN DIGITAL DATA OVERSIZED (Scannable) [] Color items: D Diskettes, No. [] Grayscale items: [] Other, No/Type D Poor Quality Originals: [] Other: NOTES: BY: BEVERLY ROBIN VINCENT SHERYL MARl IN DATE: [] Maps: Other items scannable by large scanner OVERSIZED (Non-Scannable) [] Logs of various kinds [] Other ScanningPreparatio. '~2 x 30 = '[~)0 + c~Cj = TOTALPAGES -~~ BY: BEVERLY ROBIN VINCENT SHERYL MARIA.~ Production Scanning / Stage I PAGE COUNT FROM SCANNED FILE: ~ (~) ,~ / PAGE COUNT MATCHES NUMBER IN SCANNING PREPARATION: Stage 2 BY: (SCANNING IS COMPLETE AT THIS POINT UNLESS SPECIAL ATTENTION IS REQUIREO ON AN INDIVIDUAL PAGE BASIS DUE TO QUALITY. GRAYSCALE OR COLOR IMAGES) NO IF NO IN STAGE 1, PAGE(S) DISCREPANCIES WERE FOUND: YES NO RESCANNEDBY; BEVERLY ROBIN VINCENT SHERYL MARIA WINDY DATE: General Notes or Comments about this file: IS/ Quality Checked 12110/02Rev3NOTScanned.wpd Wallace, Chris D (DOA) From: AK, D&C Well Integrity Coordinator <AKDCWellIntegrityCoordinator@bp.com> Sent: Monday, November 03, 2014 1:04 PM To: AK, OPS FS1 OSM; AK, OPS FS1 Facility OTL; AK, OPS FS1 DS Ops Lead; AK, OPS PCC EOC TL; AK, D&C Well Services Operations Team Lead; AK, D&C Wireline Operations Team Lead; Cismoski, Doug A; Daniel, Ryan; AK, RES GPB East Wells Opt Engr; AK, RES GPB West Wells Opt Engr; G GPB FS1 DS; AK, OPS FS1 DS1 Operator; Oestgaard, Finn; Wallace, Chris D (DOA) Cc: AK, D&C DHD Well Integrity Engineer; AK, D&C Projects Well Integrity Engineer; AK, OPS FF Well Ops Comp Rep; AK, D&C Well Integrity Coordinator; Regg, James B (DOA) Subject: OPERABLE: Producer 01-02 (PTD #1691190 ) Rig Workover Complete - MIT -IA Passed Attachments: image001.png; Producer 01-02 (PTD #1691190) Wellbore Schematic.pdf All, Producer 01-02 (PTD #1691190) underwent a rig workover to repair production casing and tubing leaks. A subsequent MIT -IA passed on 10/03/2014. The passing test confirms two competent barriers in the wellbore. The well is reclassified as Operable. Well status is Operable Annuli are fluid packed, AFE sign and tags are in place and have been confirmed • A SSSV is not required A copy of the wellbore schematic is included for reference. Thank you, Jack Disbrow BP Alaska - Well Intemy Coordinator �� N 0 s 2�j4 GWGlobal Wells Organization Office: 907.659.5102 WIC Email: AKDCWeIIIntegrityCoordinator@bp.com From: Reynolds, Charles (Alaska) Sent: Saturday, March 03, 2012 1:30 PM To: 'Regg, James B (DOA)'; 'Schwartz, Guy L (DOA)'; AK, D&C Well Integrity Coordinator; AK, OPS FS1 OSM; AK, OPS FS1 Facility OTL; AK, OPS FS1 DS Ops Lead; AK, OPS FS1 DS5 Operator; AK, OPS PCC EOC TL; AK, D&C Well Services Operations Team Lead; AK, D&C Wireline Operations Team Lead; Cismoski, Doug A; Daniel, Ryan; AK, RES GPB West Wells Opt Engr; AK, RES GPB East Wells Opt Engr; G GPB FS1 DS; Youngmun, Alex Cc: Walker, Greg (D&C); Clingingsmith, Mike J; Olson, Andrew; Vo, Nick (Hoang) Subject: NOT OPERABLE: Producer 01-02 (PTD #1691190 ) Sustained Casing Pressure Producer 01-02 (PTD #1691190) has been found to have sustained casing pressure on the IA. Wellhead pressures were SSV/2300/230 on 3/1/12. The well will remain classified as Not Operable until tubing integrity can be restored. Plan forward: 1. F: L&K 2. D: Monitor with periodic L&Ks to keep IAP below 2000 psi until patch is pulled 3. CT: Remove patch in well 4. S: Pull IBP. Set WRP below packer 5. F: CMIT-TxIA A TIO plot and wellbore schematic have been included for reference Please call if you have questions or concerns. Thank you, Charles Reynolds Filling in for... Mehreen Vazir Well Integrity Coordinator BP Alaska Drilling & Wells Well Integrity Office: 907.659.5102 Email: AKDCWellintegrityCoordinator@BP.com From: AK, D&C Well Integrity Coordinator Sent: Saturday, February 18, 2012 10:56 AM To: AK, OPS FS1 OSM; AK, OPS FS1 Facility OTL; AK, OPS FS1 DS Ops Lead; AK, OPS FS1 DS5 Operator; AK, OPS PCC EOC TL; AK, D&C Well Services Operations Team Lead; AK, D&C Wireline Operations Team Lead; Cismoski, Doug A; Daniel, Ryan; AK, RES GPB West Wells Opt Engr; AK, RES GPB East Wells Opt Engr; G GPB FS1 DS; Youngmun, Alex Cc: AK, D&C Well Integrity Coordinator; Wills, Shane M; King, Whitney Subject: NOT OPERABLE: Producer 01-02 (PTD #1691190 ) Secured With Kill Weight Fluid /0, Producer 01-02 (PTD #1691190) has been secured with kill weight fluid on 02/17/2012. The well is reclassified as Not Operable. Plan forward: 1. CT: Remove patch in well 2. S: Pull IBP. Set WRP below packer 3. F: CMIT-TxIA Please call if you have questions or concerns. Thank you, Gerald Murphy (alt. Mehreen Vazir) Well Integrity Coordinator Office (907) 659-5102 Cell (907) 752-0755 Pager (907) 659-5100 Ext. 1154 From: AK, D&C Well Integrity Coordinator Sent: Thursday, December 01, 20117:45 PM To: AK, OPS FS1 OSM; AK, OPS FS1 Facility OTL; AK, OPS FS1 DS Ops Lead; AK, OPS FS1 DS5 Operator; AK, OPS PCC EOC TL; AK, D&C Well Services Operations Team Lead; AK, D&C Wireline Operations Team Lead; Cismoski, Doug A; Daniel, Ryan; AK, RES GPB West Wells Opt Engr; AK, RES GPB East Wells Opt Engr; G GPB FS1 DS; Youngmun, Alex Cc: King, Whitney; Olson, Andrew Subject: UNDER EVALUATION: Producer 01-02 (PTD #1691190 ) Failed TIFL All, Producer 01-02 (PTD # 1691190 ) failed a TIFL on 11/28/2011 indicating a lack of two competent barriers. The well is reclassified as Under Evaluation and can remain online while further diagnostics are conducted. The plan forward is: 1. Slickline: Set DGLV in gas lift straddle patch 2. Fullbore: MIT -IA Thank you, Mehreen Vazir Alli f"!?L7tE; -,t f"a 141 Mii1"l?/)1'% Well Integrity Coordinator BP Alaska Drilling & Wells Well Integrity Office: 907.659.5102 Email: AKDCWelllntegrityCoordinator@BP.com I.. L WELLHEAD = ROCKWELL ACTUATOR = SPF OKB. ELEV = 73.0' BF. ELEV = ? KOP= 34W Max Angle= 30" @ 4100' Datum MD = 9497 Datum TVD = 88W SS 30" NSULATt31 ^-110 CONDUCTOR 20" CSG, 94 #, H-40, D = 19.124" TOP OF 7" SCAB L -12516- 9-5/8" CSG, 47#. L-80 VAM TOP, D = 8.681" 2429' 9-5/8" BOWEN CSG PATCH, D = 9.06" 2433' 13-3/8" CSG, 72#, N-80, D =12.347" 3004' Minimum ID = 2.992" @ 9046' 4-1/2" G LANDING SUB 9-5/8" CSG, 40.5#, SOO-95, D = 8.835" 6184' XO TO 43.5#, SOO-95, D = 8.755" 4-1/2" TBG, 12.6#, 13CR-86 VAM TOP, .0152 bpf, D = 3.958" 9-5/8" CSG, 43.5# XO TO - 47#, SOO.95, D = 8.681 " r SCAB LLQ 26#, L-80 VAM TOP HC, .0383 bpf, D = 6.276" 4-112" TBG, 12.6#, L-80 TC K, .0152bpf, D = 3.958" ITOPOF 3-1/2" SCAB LNR 4-1/2" TBG -NPC, 12.6#, MNI-80, .0152 bpf, D = 3.958' 8798- 8811' 798 r 8801'. 8811' 8960' 9120' PERFORATION SUMMARY REF LOG: BHCS ON 02/20/70 ANGLE AT TOP PERF: 23" @ 9661' N D19: Refer to Production DB for hisloriral perf data SIZE I SPF WTERVAL Opn/Sgz SHOT SQZ WA 4 9360-9370 S 02/27/70 03107/70 WA 4 9430-9440 S 02/27/70 03/07/70 4" 4 9455- 9485 S 03/09(70 10/12/85 4" 4 9495-9525 S 03/09/70 10/12/85 4" 4 9545-9575 S 03/09((0 10112185 4" 4 9585-9616 S 03/09(70 10/12/85 4" 4 9627 -9675 S 10/18185 0526/87 4" 4 9660- 9674 S 10118185 05126/87 3-318" 4 9661-9675 O 08110/90 4" 4 9690-9708 S 06/27/87 08/06/90 3-3/8" 4 9691-9709 O 08/10190 31/2" SCAB LNR, 9.3#. L-80 FL4S, .0087 bpf, D = 2.992" 9-5/8" CSG, 47#, SOO-95, .0733 bpf, [)=8.681* 9878' 01-02 SAFETY NOTES: "'4-112" CHROME TBG"" 2066' j4-112" OTfS X RSP, D = 3.813" 2286' 9518" X 7" BKR ZXP LTP w /BKR FLEXLOCK N LNR HCR, D = 6.200" 2386' 9-518" HFS ES LT-7u1B+tfi32, D = 8.618" 240$` 9-518" BKR rlAS 1 FT MANORE1_S ST MD TVD DEV TYPE VLV LATCH PORT DATE 3 3798 3778 23 KBG2 DOME BK 16 10114/14 2 7278 6821 26 KBG2 SO SK 20 10/14/14 1 8309 7760 22 KBG2 DMY BK 0 10/03/14 6392' 9-5/8" TN OOL 83$6' 4-1/2" OTIS X W? D = 3.813" 8418' 7• X 4-112" FIS TNT PKR, U-- 3.856" 8453' H 4-112" OTIS X Nig, D = 3.813" 8773' H 4-1/2' OTIS XN NP, D = 3.725" 8798' 4-1/2" W.EG. D =3.958" 8813' 9 518" X 7" BKR HRDE ZXPN LTP w /BKR HMC ? TOP OF CBVENT (XX/XX/XX) 962W DAVIS LYNCH DUAL FLOAT SHOE ^9623' SLM 11 FISH - 1.69" BP AND PIECE OF 5 -1/2 - TOOL GRAPPLE (0524/14) mm H 981 r DATE REV BY COMMENTS I LNR HGR, D = 6.20" -1 8822' PORTLY SFAL STEM, D ---6 8-0• 8876' r X d -f t2" XO, D = fi.27fi• $950' 5-112" BOT PBR ASSY, D = 4.75" 8960' 4-112" MUI SHOE, D = 3.958" 8984' 9-518" X 5-1/2" BKRSAB PIR, V = 4.75" 8� 6-518" MLLOUT EXTENSION, D = " $�6-5/8" X 4-12" XO, D = 3.958" 9046' 4 1/2" G LANDNG SUB, D = 2.992" 9056' 4-112" OTIS XN NO-GO N6? U= 3.725- 912W 4-1/2" VtLl9G, D = 3.958" BEHIND 9110' ELM) TT O LOG05/14/80 LNR ? TOP OF CBVENT (XX/XX/XX) 962W DAVIS LYNCH DUAL FLOAT SHOE ^9623' SLM 11 FISH - 1.69" BP AND PIECE OF 5 -1/2 - TOOL GRAPPLE (0524/14) mm H 981 r DATE REV BY COMMENTS DATE REV BY COLOM34 S 03116170 RINN 24 IN71AL COMPLETION 1029h4 TR/JM) MNOR SCHEMATIC ®ITS 03/21177 OWN 26 RWO 10/19/94 SCAB UNH( 10(04(14 014 RWO 110113/141 CKJJMO I FML DOE APPROVAL 1101211141 JLSIJMDGLV CJO (10/14/14) PRUDHOE BAY UNIT WELL: 01-02 PEF WIf No: '1691100 AH No: 50.029-2005300 SEC 8, TION, /2151;, 193' FNL & 135T FWL BP Exploration (Alaska) Originated: Schlumberger PTS - PRINT CENTER 2525 GAMBELL STREET, STE. 400 ANCHORAGE, AK 99503 (907) 273-1700 main OGGG Delivered to: ,%IMakanaK Bender Natural Resources Technician II Alaska Oil & Gas Conservation Commission 333 W_ Th Ave, Suite 100 Anchorage, AK 99501 i9M7) 793-1225 inak;tra i 1F r._a Mask ,g v_ j 25 -Sep -14 25Sep14-C801 DATA LOGGED 'I 1& a201 -k M.K.BENDER WELL NAME 01-02 SERVICE ORDER # C2JC-00173 FIELD NAME SERVICE PRUDHOE BAY DESCRIPTION WL DELIVERABLE DESCRIPTION SCMT/JETCUT DATA TYPE FINAL FIELD DATELOGGED 3 -Sep -14 • •• PRINTS 1 ACDS 1 04-17 CBOO-00084 PRUDHOE BAY WL RST FINAL FIELD 12 -Sep -14 1 1 MPB-05A CFGK-00085 MILNE POINT MEMORY IPROF FINAL FIELD 5 -Sep -14 1 1 MPC -42 CFGK-00083 MILNE POINT MEMORY IPROF FINAL FIELD 2 -Sep -14 1 1 MPE-23 CFGK-00084 MILNE POINT MEMORY IPROF FINAL FIELD 3 -Sep -14 1 1 MPF -81 CY89-00027 MILNE POINT MEMORY LDL FINAL FIELD 15 -Sep -14 1 1 L1-21 CYCD-00026 LISBURNE WL PPROF FINAL FIELD 16 -Sep -14 1 1 1-2-33 C1SD-00130 LISBURNE MEMORY LDL FINAL FIELD 17 -Sep -14 1 1 MPH -191-1 C1SD-00131 MILNE POINT MEMORY PPROF FINAL FIELD 18 -Sep -14 1 1 MPJ -15 CY89-00028 MILNE POINT MEMORY [PROF FINAL FIELD 18 -Sep -14 1 1 17-06 CFMH-00084 PRUDHOE BAY WL [PROF FINAL FIELD 10 -Aug -14 1 1 09-04A CFMH-00083 PRUDHOE BAY WL LDL FINAL FIELD 8 -Aug -14 1 1 1-5-28A CYCD-00021 LISBURNE WL PPROF FINAL FIELD 17 -Aug -14 1 1 G -29B C1SD-00125 PRUDHOE BAY MEMORY PPROF FINAL FIELD 11 -Aug -14 1 1 G -08A CV6H-00035 PRUDHOE BAY MEMORY PPROF FINAL FIELD 2 -Aug -14 1 1 18-11B CY89-00023 PRUDHOE BAY MEMORY LDL FINAL FIELD 2 -Sep -14 1 1 132-53 C2JC-00149 PRUDHOE BAY WL PPROF FINAL FIELD 11 -Jun -14 1 1 F-36 CYCD-00014 PRUDHOE BAY WL USIT FINAL FIELD 23 -Jul -14 1 1 S-13 CYCD-00023 PRUDHOE BAY WL USIT-MSIP FINAL FIELD 8 -Sep -14 1 1 18-07A CFMH-00081 PRUDHOE BAY WL LDL FINAL FIELD 16 -Jul -14 1 1 MPL-08 CY89-00020 MILNE POINT MEMORY IPROF FINAL FIELD 10 -Aug -14 1 1 15-01B ClSD-00128 PRUDHOE BAY MEMORY PPROF FINAL FIELD 19 -Aug -14 1 1 02-21B C1SD-00127 PRUDHOE BAY MEMORY LDL FINAL FIELD 17 -Aug -14 1 1 1-5-16A C2JC-00166 LISBURNE WL PPROF FINAL FIELD 6 -Aug -14 1 1 Transmittal Receipt D^j A Transmittal Receipt signature confirms that a package (box, Q Y✓ envelope, etc.) has been received and the contents of the package X V have been verified to match the media noted above. The specific Print Name Signature Date p 1-2-9j 11content of the CDs and/or hardcopy prints may or may not have been il verified for correctness or quality level at this point. Please return via courier or sign/scan and email a copy to BP. BP PDC LR2-1, 900 E Benson Blvd, Anchorage, AK 99508 WELL LOG TRANSMITTAL To: Alaska Oil and Gas Conservation Comm. Attn.: Makana Bender 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 RE: Radial Cement Bond Log: 01-02 Run Date: 8/30/2014 �Gq - kkcl 2AItGz DATA LOGGED O� nzwoiq M. K. BENDS September 10, 2014 RECEIVED SEP 2 2 2014 AOGCC The technical data listed below is being submitted herewith. Please address any problems or concerns to the attention of: Fanny Sari, Halliburton Wireline & Perforating, 6900 Arctic Blvd., Anchorage, AK 99518 01-02 Digital Log Image files 50-029-20053-00 Cement Bond Log 50-029-20053-00 5xAMAK) 1 CD Rom 1 Color Log PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Halliburton Wireline & Perforating Attn: Fanny Sari 6900 Arctic Blvd. Anchorage, Alaska 99518 Office: 907-273-3572 Fax: 907-273-3535 FRS—ANC@halliburton.com Date: Signed: �✓a� Ferguson, Victoria L (DOA) From: Kirchner, Carolyn J <Carolyn.Kirchner@bp.com> Sent: Wednesday, September 17, 2014 5:57 PM To: Ferguson, Victoria L (DOA) Subject: RE: 01-02 permit to drill #1691190 Attachments: 01-02 scab liner.pdf Follow Up Flag: Follow up Flag Status: Flagged Hi Victoria, Thank you for the approval. My oversight for failing to attach the WBS. Please see the enclosed. Carolyn From: Ferguson, Victoria L (DOA) [ nailto:victoria.ferguson( alaska.gov] Sent: Wednesday, September 17, 2014 3:40 PM To: Kirchner, Carolyn J Subject: RE: 01-02 permit to drill #1691190 Carolyn, Please provide a wellbore schematic with changes. Changes to procedure are approved as written. Thanx, Victoria Victoria Ferguson Senior Petroleum Engineer State of Alaska Oil & Gas Conservation Commission 333 W. 7th Ave, Ste 100 Anchorage, AK 99501 Work: (907)793-1247 victoria.ferguson(c-)alaska.gov P7-0 1 tq- 1 1 q SCAt4f4p OCT 2 8 ZDA 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 Victoria Ferguson at (907)793-1247 or Victoria. Ferguson@alaska.gov From: Kirchner, Carolyn J [ �iltoCarolyn.Kirchner@bp.com] Sent: Wednesday, September 17, 2014 11:36 AM To: Ferguson, Victoria L (DOA) Cc: Lastufka, Joseph N Subject: 01-02 permit to drill #1691190 Ferguson, Victoria L (DOA) From: Ferguson, Victoria L (DOA) Sent: Wednesday, September 17, 2014 3:40 PM To: 'Kirchner, Carolyn Y Subject: RE: 01-02 permit to drill #1691190 Follow Up Flag: Follow up Flag Status: Flagged Carolyn, Please provide a wellbore schematic with changes. Changes to procedure are approved as written. Thanx, Victoria Victoria Ferguson Senior Petroleum Engineer State of Alaska Oil & Gas Conservation Commission 333 W. 7th Ave, Ste 100 Anchorage, AK 99501 Work: (907)793-1247 victoria.ferguson(cDalaska.00v CONFIDEN17ALITY 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 Victoria Ferguson at (907)793-1247 or Victoria. Fercauson@alaska.gov From: Kirchner, Carolyn J mailto:Carolyn. Kirchner@bp.com] Sent: Wednesday, September 17, 2014 11:36 AM To: Ferguson, Victoria L (DOA) Cc: Lastufka, Joseph N Subject: 01-02 permit to drill #1691190 During RWO operations a 9-5/8" casing leak was discovered on 01-02. To remediate this problem. A 7" scab liner is planned. Please see the proposed operational plan below: • Install 7' upper rams and test BOPE with four preventers configured top down (annular, 7" fixed, blind shears, mud cross and , 3-1/2" x 6" VBR's). Test the VBR's and the annular to 3,500 -psi. • Run fully cemented 7" scab liner to 2300 ft. • Drill out shoe track and pressure test to 3500 psi • Pull RBP. • Run Completion. Thank you for your consideration. Please let me know if you have any question. Carolyn Carolyn Kirchner RWO Engineer, Alaska Office: 907-564-4190 Cell: 907-227-6169 carolyn.kirchnercift com TREE _ FMC WELLHEAD= ROCKWELL ACTUATOR= BAKER OKB. ELEV = 73.0' BF. ELEV = SQZ KOP = 3400' kbx Angle = _" @ ' Datum MD = _' Datum TVD = 8800' SS PROPOSED 30" INSULATED 11W CONDUCTOR 20" CSG, 91.5 #, 695' H-40, ID =19.124" 9-5/8' CSG, _#, _, 9-5/8' BOWEN CSG PATCH, ID = -{ 13-3/8" CSG, 72#, N-80, D = 12.347" 3004• Minimum ID = " @ ' 9-5/8" CSG, 40.5#, SOO-95, D = 8.835" 6184' XO TO 43.5#, SOO-95, D = 8.755" 19-5/8* CSG, 43.5# XO TO 8801' 47#, SOO-95, D = 8.681" PERFORATION SL*RMRY REF LOG: BHCS ON 02/20/70 ANGLE AT TOP PERF: 21'(g 9360' Note: Refer to Production DB for historical pert data 4-1/2" TBG, 12.6#, _ —_ INTERVAL _0152 bpf, D = 3.958" SHOT SQZ 7" SCAB LNR, 4 9360-9370 bpf, D = " 02/27!70 7' LNR, _#, _, D -� 4 4-1/2" TBG, 12.6#, S 02127!70 .0152 bpf, D = 3.958" 4" TOP OF 3-1/2" LNR, D = 2.992" 9046' 4-1/2" TBG -NPC, 12.6#, W+80,.0152 bpf, D = 3-9-58--l-4-912W 03109[70 10/12/85 4" PERFORATION SL*RMRY REF LOG: BHCS ON 02/20/70 ANGLE AT TOP PERF: 21'(g 9360' Note: Refer to Production DB for historical pert data SIZE SPF INTERVAL Opn/Sgz SHOT SQZ WA 4 9360-9370 S 02/27!70 03/07/70 WA 4 9430-9440 S 02127!70 03/07170 4" 4 9455 - 9485 S 03109[70 10/12/85 4" 4 9495-9525 S 03/09/70 10/12/85 4" 4 9545-9575 S 03/09/70 10/12/85 4" 4 9585-9616 S 03/09/70 10/12/85 4" 4 9627-9675 S 10/18/85 05/26/87 4" 4 9660 -9674 S 10/18/85 05/26/87 3-318" 4 9661 -9675 O 08/10/90 4" 4 9690-9708 S 06/27/87 08/06/90 3-31W 4 9691-9709 O 08/10/90 3-1/2" SCAB LNR, 9.3#, L-80 FL4S, .0087 bpf, D = 2.992" 9-5/8- CSG, 47#, SOO-95, .0733 bpf, D = &681- 1 9620' 1 1 9930' 1 01-02 SAFETY NOTES: ST JH9-5/8" HES ES CEMENTER 2000' 4-1/2" OTIS X LANDING NP, D = 3.813' I TYPE 7" X 4-1/2' LTPw/-- LATCH LNR HGR, D = _" 9-5/8" BKR ECP 5 GAS LIFT AMNDRELS ST MD TVD DEV I TYPE I VLV LATCH I PORT DATF 5 05/30/14 RS/JMD I FISH (05/24/14) LNR HGR, D = _" 106/25/141 PJC I PERF/LNR/ TBG CORRE�CTIONS 7" X 4-1/2" XO, D = _- 8950' 5-1/2" BOT PBRASSY, D=4.75" 4-1 /2" AALXESHOE, D = 3.958- .958" 4 9-5/8" X 5-1/2" BKR SAB WJ;%' D = 4.75" 8996' 6-5/8" MILLOUT EXTENSION, ID = " 8996' 6-5/8" X 4-1/2" XO, D = 3.958- 9046- 4-1 /2" G LANDING SUB, 9056' 3 9120' 4-1/2" TUBING TAIL, D = 1958- BEHIND LNR 9110' EMD TT LOGGED 05/14/80 2 1 T(jP GF c >,nNNr (xxtxx/x)() 9620' 1-i3-1/2"DAVIS LYNCH DUAL FLOATSHDE --9623' SLM" FISH -1.69" BP AND PIECE OF 5-1/2" (TOOL GRAPPLE (05/24/14) PBTD 9817' DATE REV BY COWAENTS 4-1/2" OTtS X NP, D = 3.813' 03115/70 RWN24 INITIAL COMPLETION 7" X 4-1/2" HES TNT PKR, D = _" 03/21177 RINN 26 RWO 4-1/2" OTIS X NP, D = 3.813- .813"4-1/2" 10/19/94 SCAB LINER 4-1/2-OTIS XN NP, D = 3.725" 05127114 JMD BUILT PROPOSED 7" X 4-1/2" LTPw/ 05/30/14 RS/JMD I FISH (05/24/14) LNR HGR, D = _" 106/25/141 PJC I PERF/LNR/ TBG CORRE�CTIONS 7" X 4-1/2" XO, D = _- 8950' 5-1/2" BOT PBRASSY, D=4.75" 4-1 /2" AALXESHOE, D = 3.958- .958" -d 9-5/8" X 5-1/2" BKR SAB WJ;%' D = 4.75" 8996' 6-5/8" MILLOUT EXTENSION, ID = " 8996' 6-5/8" X 4-1/2" XO, D = 3.958- 9046- 4-1 /2" G LANDING SUB, 9056' 4-1 /2" OTIS XN NO-GO NP, D = 3.725" 9120' 4-1/2" TUBING TAIL, D = 1958- BEHIND LNR 9110' EMD TT LOGGED 05/14/80 T(jP GF c >,nNNr (xxtxx/x)() 9620' 1-i3-1/2"DAVIS LYNCH DUAL FLOATSHDE --9623' SLM" FISH -1.69" BP AND PIECE OF 5-1/2" (TOOL GRAPPLE (05/24/14) PBTD 9817' DATE REV BY COWAENTS DATE REV BY COKWENTS 03115/70 RWN24 INITIAL COMPLETION 09/16/14 CK/JKU RECONFIGURED LNR/TBG 03/21177 RINN 26 RWO 10/19/94 SCAB LINER 05127114 JMD BUILT PROPOSED 05/30/14 RS/JMD I FISH (05/24/14) 106/25/141 PJC I PERF/LNR/ TBG CORRE�CTIONS PRUDHOE BAY UNIT WELL 01-02 PERMT No: '1691190 API No: 50-029-20053-00 SEC 8, T101, R15E, 193' FNL 8 1357' FWL BP Exploration (Ataska) I:, 2— VOLHEAD=ROCKWELL SQE ACTUATOR= BAKER KB. ELEV = 73.0' BF. ELEV = ? KOP = 3400' Max Angle = 30' @ 5000' Datum MD = 9492' Datum TVD= 88W SS 30" INSULATED 0 l -0 2 SAFETY NOTES: "'" OTIS SSV NIP DAMAGJ— ED CONDUCTOR 9-5/8' CSG, 47#, D = 8.681" XO TO 40.5#, S00-95, ID = 8.835' 20" CSG, 94#, 696' IH -40,0=19.124- 13-3/8" CSG, 72#, N-80, D =12.347" 1 3004' r 5-1/2" TBG CUT (06122/14) 3200' Minimum ID =1.992" @ 3226' 6-1/2" X 2-3/8" GL STRADDLE 9-5/8" CSG, 40.5# XO TO 6184' 43.5#, SOO-95, D = 8.755" 9-5/8" CSG, 43.5# XO TO 8801' 47#, SOO-95, D = 8.681" 5-1/2" TBG PUNCH (06/15114) 8892' - 8894' 5-1/2" TBG -NPC, 17#, Mit-80, 8996' 0232 bpf, D = 4.892' TOP OF 3-1/2" LW D = 2.992' H 9046' 4-1/2"TBG-NPC, 12.6#, MN -80, I- j 9120' .0152 bpf, D = 3.958" PERFORATION SL*"RY REF LOG: BHCS ON 02/20/70 ANGLE AT TOP PERF: 21 ° (Qa 936V NDte: Refer to Production DB for historical pert data SQE SPF INTERVAL Opn/Sqz SHOT SOZ WA 4 9360-9370 S 02/27/70 03107/70 WA 4 9430-9440 S 02/27/70 03/07/70 4" 4 9455-9485 S 03/09/70 10/12/85 4" 4 9495-9525 S 03/09/70 10/12/85 4" 4 9545-9575 S 03/09/70 10/12/85 4" 4 9585-9616 S 03/09/70 10/12/85 4" 4 9627-9675 S 10/18/85 05/26/87 4" 4 9660-9674 S 10/18/85 05/26/87 3-3/8" 4 9661-9675 O 08/10/90 4" 4 9690-9708 S 06/27/87 08/06/90 3-318" 4 9691-9709 O 08/10/90 3-1/2" SCAB LNR, 9.3#, L-80, ( 9620' .0087 bDf. D = 2.992' FBTD —j 9817' 9-5/8" CSG, 47#, SOO 95, D = 8.681 --I 2171'—{5-1/2" OTIS FRO SSSV NIP DAMAGED CAN PASS ThRU w /4.635' 3176'- 3178' ELM 5-trr TBG PUNCH (06/22r1a) 3225' - 3256' 5-1/2' X 2-3/8' WFD GL STRADDLE (05/24/07), D = 1.992" GAS LIFT MANDRELS iT I MD I N D DEV TY PE V LV LATCH PORT I DATE - 1 1 3225 13224 7 CAM OMY BK 0 12/20/11 4L STRADDLE SET 05124/07 3243'-3245' ELM, , 5 112" TBG PUNCH (05/2a/ol) 88$5' 5-1/2" OTIS XA SLD SLV , D = 4.562- 8913'—{CEM�T Dl1NP (06!19114) EST TOC 8923'—{1-tit16" BP(O6/79/14) —8939' 5-1/2' OTIS XN LANDING NP, D = 4.455' -8950' 5-1/2' BOT PBR ASSY, D = 4.75" —8984' 9-51r X 5-1/2' BKR SAB PKR, D = 4.75- 5-1/2' X 4-112' XO, D = 3.958' 9056'4-1/2" OTIS XN NO-GO LANDING NP 1 D = 3:725" (BBiND CT) 9128' 4-12" REM TAIL (B€ *DCT) 9110' ELIuD TT LOGGED 05/14/80 1 ^9623' S LM�� FISH - 1.69" BP A ND PECE OF 5-1/2' TOOL GRAPPLE (05/24/14) DATE REV BY COMuBTTS DATE REV BY OOMM3JTS 03/15!70 RWN 24 INITIAL COMPLETION 06/16/14 JG/ PJC FISH LEFT DH (NOSE CON 19 0321177 RWN 26 RWO 06/18/14 PJC PERFORATION CORRECTIONS 10/19/94 SCAB LINER 06/19/14 JCMPJC TBG PUNCH (06/15/14) 01/08/12 TTP/PJC SET BP(01/07/11) 06/20/14 JCMPJC SET 13RDUMP CMT (06/19/14) 102125/121 PJC I FISH (02/08/12) 06122/14 CJS/ PJC TBG PUNCW TBG CUT (6/22/14) 05/30/14 RS/JMD I FISH (05/25114) PRUDHOE BAY L14T WELL: 01-02 PNMT Nb: 1691190 API ND: 50-029-20053-00 SEC 8, TION, R15E, 193' FNL 8 1357' FIIWL. BP Exploration (Alaska) THE STATE f GOVERNOR SEAN PARNELL Dave Bjork Engineering Team Leader BP Exploration (Alaska), Inc. P.O. Box 196612 Anchorage, AK 99519-6612 Re: Prudhoe Bay Field, Prudhoe Bay Oil Pool, PBU 0 1 -02 Sundry Number: 314-336 Dear Mr. Bjork: AWka il and Gas P3 West Seventh Avenue Anchorage, Alaska 99501-3572 Main: 907.279.1433 Fax: 907.276.7542 Enclosed is the approved application for sundry approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the AOGCC grants for good cause shown, a person affected by it may file with the AOGCC an application for reconsideration. A request for reconsideration is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. DATED this day of June, 2014. Encl. Sincerely, Cathy P oerster Chair STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVAL 20 AAC 25.280 RECEIVED � �1 i 1. Type of Request: ❑ Abandon ❑ Plug for Redrill ❑ Perforate New Pool ® Repair Well ❑ Change Approved Program ❑ Suspend ❑ Plug Perforations ❑ Perforate ® Pull Tubing ❑ Time Extension ❑ Operations Shutdown ❑ Re -Enter Suspended Well ❑ Stimulate ® Alter Casing ❑ Other 2. Operator Name 4. Current Well Class 5. Permit To Drill Number BP Exploration (Alaska) Inc. ❑ Exploratory ❑ Stratigraphic ®Development El Service 169-119' 3. Address:6. API Number: P.O. Box 196612, Anchorage, Alaska 99519-6612 9 50.029-20053-00-00 ' 7. If perforating: 8. Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? PBU 01-02 Will planned perforations require a Spacing Exception? [:]Yes No 9. Property Designatior 10. Field / Pool(s): ADL 028329 Prudhoe Bay / Prudhoe Bay 11. PRESENT WELL CONDITION SUMMARY Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD (ft) Effective Depth TVD (ft): Plugs (measured): Junk (measured). 9930' 9275' • 9817' 9172' 8945' Unknown Casing Length Size MD TVD Burst Collapse Structural 110' 30" 110' 110' Conductor 696' 20" 696' 696' 1530 520 Surface 3004' 13-3/8" 3004' 3004' 4930 2670 Intermediate Production 9878' 9-5/8" 9878' 9227' Liner Scab Liner 574' 3-1/2" 9046'- 9620' 8454'- 8991' 10160 10530 Perforation Depth MD (ft):Perforation Depth TVD (ft): Tubinq Size: Tubing Grade: Tubing MD (ft): 9661'- 9709' 9029'- 9073' 5-1/2", 17# x 4-1/2", 12.6# MN -80 9120' Packers and SSSV Type: 9-5/8" x 5-1/2" Baker SAB Packer Packers and SSSV 8984'/ 8395' MD (ft) and TVD (ft): 12. Attachments: 13. Well Class after proposed work: ® Description Summary of Proposal ® BOP Sketch ❑Exploratory ❑Stratigraphic ®Development ❑Service E] Detailed Operations Program 14. Estimated Date for 15. Well Status after proposed work: Commencing Operation August 10, 2014 ® Oil ❑ WINJ ❑ WDSPL ❑ Plugged ❑ Gas ❑ GINJ ❑ GSTOR ❑ Abandoned 16. Verbal Approval: Date ❑ WAG ❑ SPLUG ❑ Suspended Commission Representative: 17. 1 hereby certify that the foregoing is true and correct to the best of my knowledge. Contact: Carolyn Kirchner, 564-4190 Printed Name: Dave Bjork Title: Engineering Team Leader Email: Carolyn. Kirchner@bp.com Signature: „ � Phone: 564-5683 Date: v5l y Commission Use Only Conditions of approval: Notify Commission so that a representative may witness �` SundryNumber: BOP ❑ Plug Integrity tj Test ❑ Mechanical Integrity Test ❑ Location Clearance Other: Spacing Exception Required? ❑ Yes u No Subsequent Form Required: IQ 4 Q /L (/ APPROVED BY Approved By:2�1" P. COMMISSIONER THE COMMISSION Date: W �� Form 10-403 Revised /2012 Approve a+fiofj a o 2 Fnths from the date of approval Submit In Duplicate y-3`' ' /p/. Sundry Request for casing repair Well: 01-02 Date: 5/23/14 Engineer: Carolyn Kirchner MASP: 2387 psi Well Type: Producer Estimated Start date: August 10, 2014 History: 01-02 is a gravity drainage producer with a leaking 5-1/2" straddle patch. Non -rig attempts to fish the patch have been exhausted and the remaining option is to work the well over and run new tubing. The well does not pass a CMIT so the rig will have to test the casing unless there is success at setting and testing the IBP to secure the well. If the casing fails, a scab liner will be run to below the 13-3/8" shoe. 01- 02 has an oversized wellhead as it is an early generation well. The plan is to cut and pull the 9-5/8" casing so that the wellhead can be replaced. Scope of Work: Pull 5-1/2" MN -80 completion. Cut and pull 9-5/8". Replace wellhead. Run 4-1/2"x9-5/8" 13Cr completion. Pre Rig Prep Work: S 1 Drift tubing for IBP fish, last tagged at 9507' 10/4/12. Attempt to pull (max 1 day). If unable to fish, push to bottom. F 2 Kill well with 1% KCL and FP with diesel to 2500' MD. E 3 Set 1.69" IBP at 8918' MD. F 4 A/EL: Circ well again with 1% KCI and FP with diesel to 2500' MD. CMIT-TxIA to 1000 psi with diesel to confirm IBP is holding. MIT -OA to 2000 psi. Bleed T/I/O to 0 psi. E 5 Using 1-11/16" OD bailer, dump 9 gals of cement on IBP (-V9 ft, or 3 bailer runs). Bailer holds —3 gals cement per run. F 6 Re -test IBP once cement has set. CMIT-TxIA to 2500 psi. E 7 RCT cut 5-1/2" tubing at 3200' MD, mid -joint in first full joint above 5-1/2"x2-3/8" WFD GL Straddle at 3225'. There is a significant 3.9 bpm leak below the RCT cut, so a tbg punch is not necessary. However, punch tubing at 1-2 ft below the sliding sleeve at 8885 ft MD to allow tubing to drain when retrieving with rig. W 8 Check the tubing hanger lock down screws for free movement. Completely back out and check each lock down screw for breakage check one at a time). PPPOT-T & IC. V 9 Set TWC in the tubing hanger if CMIT passes, otherwise set BPV. O 10 Remove the wellhouse & flow line. Level the pad as needed for the rig. Proposed RWO Procedure: • MIRU Doyon 14. ND tree. NU and test BOPE with four preventers configured top down (annular, 9-5/8" fixed, blind shears, mud cross and , 3-1/2" x 6" VBR's). Test the VBR's and the annular to 3,500 -psi. • Pull 5-'/2" MN -80 tubing to cut at -V3225' MD. • Run outside cutter over Weatherford straddle patch and retrieve pipe section. • Attempt to pull remaining pipe from PBR. • If unsuccessful, RU EL and run USIT log to locate 9-5/8" TOC and make deep tubing cut at 8900 ft. • RIH with overshot and pull tubing from deep cut. • RIH with overshot and pull remaining tubing out of Baker polished bore assembly. • RIH with test seals and a RTTS packer Test the 9-5/8" casing from 8900' to surface. • Set a deep 9-5/8" RBP at 8900' and test casing to 3500 psi. Set a second 9-5/8" RBP 100 ft below TOC and dump 50 ft of sand on top. Test RBP to 3500 psi. • Mechanically cut 9-5/8" casing in 1 st full joint above the TOC. Pull 9-5/8" casing through the stack. • Scrape 13-3/8" and dress off 9-5/8" casing stub. • Cut 13-3/8", 20" and 30" pipe near surface and remove wellhead. • Run 9-5/8" tie -back fully cemented to surface with 195 bbls of 15.8 ppg class G cement. • Install 9-5/8" sliplock wellhead. • Drill out the 9-5/8" shoetrack and test casing to 3500 psi. • Perform RCJB runs, and retrieve both 9-5/8" RBPs. • Run 4-'/z" 12.6# 13Cr VamTop tubing with HES TNT packer, set the packer at 8,850' MD. • Set TWC. ND BOPE. NU and test tree. RDMO. Post rig Work V 1 Pull TWC S 2 Pull B&R, pull RHC seat, run generic GILD C 3 Drill out cement and retrieve IBP WELLHEAD = ROCI ACTUATOR = SPF KB. ELEV = 73.0' BF. ELEV = ? KOP = 3400' Max Angle = 30' @ 5000' Datum MD = 9492' Datum TVD = 8800' SS a He 110,-1 0 l -02 SAFETY NOTES: *** OTIS SSV NIP DAMAGED 9-5/8" CSG, 47#, XO 115' TO 40.5#, S00-95, D = 8.681" 20" CSG, 94#, 696' --1 H-40, D = 19.124" 13 3/8" CSG, 72#, N-80, D = 12.347" 3004'^ J� Minimum ID = 1.992" @ 3225' 5-1/2" X 2-3/8" GL STRADDLE 9-5/8" CSG, 40 :5#727 XO TO 6184' 43.5#, SOO-95, D = 8.755" 9-5/8" CSG, 43.5# XO TO 8801' 17#, SOO-95, D = 8.681' 11.69"BP 10� 8945' 5-1/2" TBG -NPC, 17#, MN -80, 8996' 0232 bpf, D = 4.892" TOP OF 3-1 /2" LNZ D = 2.992" 9046' 4-1/2" TBG -NPC, 12.6#, W8O, 9120' .0152 bpf, D = 3.958" PERFORATION SLMMRY REF LOG: BRCS ON 02/20/70 A NGLE AT TOP PERF: 21 * @ 9360' Note: Refer to Production DB for historical pert data SIZE SPF INTERVAL Opn/Sgz SHOT SCZ WA 4 9360-9370 S 10/18/94 I DMY WA 4 9430-9440 S 10/18/94 PJC FISH (02/08/12) 4" 4 9455-9485 S 10/18/94 4" 4 9495-9525 S 10/18/94 4" 4 9545-9575 S 10/18/94 4" 4 9585-9616 S 10/18194 3-3/8" 4 9627-9661 S 08/06/90 3-3/8' 4 9661-9675 O 08/10/90 3-3/8' 4 9690-9691 S 08106/90 3-3/8" 4 9691-9709 O 08/10/90 3-1/2" SCAB LNRZ 9.3#, L-80, 9620' .0087 bpf, ID = 2.992" P13TD 9817' 9-518" CSG, 47#, SOO-95, D = 8.681' 9878' 0 2171' 5-1/2' 0115 HRO SSSV NP DAMAGED CAN PASS THRU w /4.635" 3225' - 3256' 5-1/2" X 2-3/8" VVFD GL STRADDLE (05/24/07), D= 1.992" GAS LIFT MANDRELS ST MD -fVD I DEV I TY PEI VLV I LATCH I PORT I DATE 10/02/09 PJC DRAWING CORRIrTiONS 03/2177 RWN 26 RWO 12/29/11 CJWJMD GLV GO (12/20/11) 1" 3225 3224 1 7 1 CAM I DMY I BK 1 0 12/20/11 "GL STRADDLE SET 05/24/07 3243'-3245' ELM 4-112" TBG, I t xNIQJ1(o5/24/07) ? FISH - PE -CE OF 5,1/2' RER#_VAL TOOL GRAPFLE (02/08/12) —[F)71/2' OTIS XA SLD SLV, D = 4.562" 8939' 5-1/2" OTIS XN LANDING 1, 1D= 4.455" 8950' S 1/2" BOT FBR ASSY, D = 4.75" 8984' 9-5/8" X 5-1/2" BKR SAB PKR, D = 4.75" 8996' 5-1/2" X 4-1/2" XO, D= 3.958" RPCJSV GLV GO (09/20109) 02225/12 PJC FISH (02/08/12) BP Exploration (Alaska) 10/01/09 ROCJPJC SSSV NP DAMAGED (8/30/0911 9056' —{4-1/2" OTIS XN NO-GO LANDING NP D = 3.725" (BEHIND CT) 9120' 4-1/2" TUBING TAL ( BBA D CT) 9110' EMD TT LOGG®05114/80 9620' 1—I3-1/2" DAVIS LYNCH DUAL FLOAT SHOE PRUDHOE BAY LUT WELL 01-02 PERMIT No '1691190 API No: 50-029-20053-00 SEC 8, T1 OR R1 5E, 193' FNL 8 135T FWL DATE REV BY COMMENTS DATE REV BY COMN6ITS 03/15(70 RWN 24 INITIAL COMPLETION 10/02/09 PJC DRAWING CORRIrTiONS 03/2177 RWN 26 RWO 12/29/11 CJWJMD GLV GO (12/20/11) 10/19f94 SCAB LINER 12/29/11 CJWJMD SSSV/ STRADDLE CORRECT (12/2 09/30109 MVGSV TREE CIO (09/03/09) 01/08/12 TTR/ PJC SET BP(01/07/11) 09/30/09 RPCJSV GLV GO (09/20109) 02225/12 PJC FISH (02/08/12) BP Exploration (Alaska) 10/01/09 ROCJPJC SSSV NP DAMAGED (8/30/0911 TFC = ' FWC .WELLHEA'D = ROCKWELL ACTUATOR= BAKER OKB. ELEV = 73.0' BF. a.EV = DATE KOP = 3400' kbx Angle = @ Datum MD = Datum TVD = 8800' SS PROPOSED 30" INSULATED 10' CONDUCTOR 20" CSG, 91.5 #, 695' H-40, D = 19.124" 9-5/8"B WENCSG PATCH, D = 8.681' 13-3/8" CSG, 72#, N-80, ID = 12.347" 3004' Minimum ID = " 9-5/8" CSG, 40 5#277 XO TO 6184' 43.5#, SOO-95, D = 8.755" 9-5/8" CSG, 43.5# XO TO 8801' 47#, SOO-95, D = 8.681" 4-1/2" TBG, 12 6#, , .0152 bpf, D = 3 958" 51/2" TBG -NPC, 17#, MN -80, 8996' 0232 bpf, D = 4.892" TOP OF 3-1/2" LW D= 2.992" 9046' 4-1/2" TBG - NPC, 12.6#, MN -80, 9120' .0152 bpf, D = 3.958" EST TOC (_/_/_) — PEWORATION St1MA4%RY FEF LOG BHCS ON 02/20/70 ANGLE AT TOP PER-: 21 ° @ 9360' Note: Refer to Production DB for historical pert data SIZE I SPF I NTERVAL Opn/Sqz SHOT SQZ "SEE PERFORATION SUMMARY ON PAGE 2" 1 1 1 1 1 3-1/2" SCAB LNR, 9.3#, L-80, 1 9620' 0087 bpf, ID = 2.992" PBTD 9817' 9-5/8" CSG, 47#, SOO-95, D = 8.681" 9930' 01-02 SAFETY NOTES: 1-49-5/8* HES LS CMF-NTFT 2000' H4-1/2" OTIS X LANDING NIP, D = 3.813" �� 9-5/8" BKR ECP GAS LIFT MANDRELS ST MD TVD DEV TYPE VLV LATCH PORT DATE 5 05/27114 JMD BULT PROPOS® 4 3 2 1- . _. 4-1 /2" OTIS X LANDING NP, ID 8820' 9-5/8" X 4-1/2" HES TNT PKR, ID = S 885' 4-1 /2" OTIS X LANDING NP, ID - 3.813" 892r -14-1/2" OTIS XN LANDING NP, D = 3.725" 8950' 5-1/2" BOT PBR ASSY, D = 4.75" 4- i /2" MULESHOE, D = 3.958" 8984' 9-5/8" X 5-1/2" BKR SAB WR D = 4-75- 8996' —�5-1/2" X 4-1/2" XO, D = 3.958" 9056' 4-1/2" OTIS XN NO-GO LANDING NP U=3.725- (BE IND CT) 9120' 4-1/2" TUBING TAE (BEH1 D CT) 9110' —{FEND TT LOGGED 05/14/80 1 9620' 3-1/2" DAMS LYNCH DUAL FLOAT SHOE DATE REV BY COMMBJTS DATE REV BY COMMENTS 03/15/70 RWN24 INITIAL COMPLETION 03/21177 RWN26 RIND 10/19/94 SCAB LINER 05/27114 JMD BULT PROPOS® PRUDHDE BAY UNIT WELL: 01-02 PET2MT No ............. . API No. 50-029-20053-00 SEC 8, T1 ON, R1 5E, 193' FTL 8 1357' FWL BP Exploration (Alaska) TREE = • FMC ,WELLHEAD= ROCKWELL ACTUATOR= BAKER OKB. ELEV = 73.0' BF E_EV = SOZ KOP = 3400' Max Angle S Datum MD = _ Datum ND = 8800' SS PROPOSED 01-02 PERFORATION SLUMRY REF LOG. BRCS ON 02/20/10 ANGLE AT TOP PEW: 21'@ 9360' Note: Refer to Production DB for historical pert data SIZE SPF NTER1/AL Opn/Sgz SHOT SOZ WA 4 9360-9370 S 10/18/94 10/19194 WA 4 9430-9440 S 10/18/94 BULT PROPOSED 4" 4 9455-9485 S 10/18/94 4" 4 9495-9525 S 10/18/94 4" 4 9545-9575 S 10/18/94 4" 4 9585-9616 S 10/18/94 3-3/8" 4 9627-9661 S 08/06/90 3-3/8" 4 9661 -9675 O 08/10/90 33/8" 4 9690-9691 S 08/06/90 3-3/8" 4 9691-9709 O 08/10/90 DATE REV BY COWANTS DATE REV BY COMMENTS 03115/70 RWN24 IN_TIALCOMPLETION 03/21(77 RWN 26 RWO 10/19194 SCAB UN3t 05127/14 JMD BULT PROPOSED PRLUHOE BAY UNT WELL 01-02 PEW No AR No 50-029-20053-00 SEC 8, T1 OR R15F-193' FN- 8 1357' FWL BP Exploration (Alaska) CAMERON BPXA WOA Well H-16 Wellhead Description Old Equipment Completely Removed and Replaced with SlipLock Wellhead System free Assembly t-1/16 API 5000 PSI with 4-1/16 Ning 3N 2012448-06 cubing Head Adapter 11" 5K Btm. X 4-1/16" API 5K Top w/ two ;ontinuous control line preps. �N 2247222-05-01 SlipLock Casing Head 4ssembly Type S-3 9-5/8 Blip Lock BTM x 11" API 5K FLG Top With (2) 2-1/16 API 5K HWO Valves. Canh Metal Seal for 9-5/8 Casing. PN 2263050-10-21 0 0 O� l0 0 Tubing Hanger 11" Bowl, 4-1/2" 12.6 lb. TC -II Top & Btm. w/4" Type "H" BPV w/ two CCL Preps PN 2031940-15-01 ° 00 ° l EOA Well DS 01-02 Replacement Wellhead Equipment Slip Lock Casing Head Assembly Type S-3 9-5/8 Slip Lock BTM x 11" API 5K FLG Top With (1) 2-1/16 API 5K Manual Gate Valve, Companion Flanges and Bull Plugs Min Bore 8.88 PN 2263050-10-21 BP CAT ID 362336 Tubing Hanger Assembly "SA -SRL" 11" Bowl, 4-1/2" 12.6 Ib. TC -II Top & Btm. w/3.980 (4" Nom.) Type "H" BPV w/ two 1/4" NPT continuous control Line Preps and 5-7/8" Nom SRL Seal Neck PN 2031940-15-01 BP CAT ID 362877 Tubing Head Adapter 11" 5K Btm. X 4-1/16" API 5K Top Std'd with 5-7/8" nom. SRL seal pocket and T Seal for 7" nom. Hanger Neck Btm w/ two continuous control line preps. Clad above Metal Seal Area and Flange Face Inlaid with 625 PN 2247222-05-01 BP CAT ID 362879 Tree: 4-1/8 5000 Carbon Tree PN 2012448-06 CAT ID 69517 1 RIG FLOOR 33.7 ' AGL 13 5/8', 5000 PSI. KYDRIL ANNULAR BOP. STUDDED TOP/FlANOED BOTTOM BOP STACK ELEVATION 150 PSI HPDR. RATED KNIFE GATE VALVE 7G'D VENT UNE SURFACE DIVERTER CONFIGURATION SINGLE 13 5/8•, 5000 PSI, 10' MPL OPERATORS, HYDRBL PPE RAM STUDDED BOTTOM/FANGED TOP BX 180 -21 1/4', 2000 PSI, MSP HYORIL BOP/%yTER STUOOED lOP/FUNGED BOTiDIA -RANGE/FLANGE RX 73 ACCUMULATOR: NL SHAFFER, 180 GAL, 6 STATION TRIPLEX PUMP: 575 VAC, 30 HP AIR PUMP: 1, NL SHAFFER ACCUMULATOR MANIFOLD 18 BOTTLES, 10 GALLONS EACH � i:IiIEi �:TS�L't91:Z L t � �j VALVE LEGEND 1 BYPASS 2 KILL 3 CHOKE 4 BOTTOM RAMS 5 BLIND RAMS 6 TOP PIPE RAMS 7ANNULAR 000 BY PASS • • • • lsoo 3000 D lil • • q�[ill�I:1�14�I7EAIe1:[�II�y� - FLANGED TOP 13 5/8', SODO PSI, 10' MPL OPERATORS, HYDRBL PIPE RAM 3 1/8' 5000 PSI SIDE OUTLET 13 13 5/8'. SOOD PSI, 14• MPL OPERATORS, 3' CHOW LINE BUND SHEAR RAM STUDDED BOTTOM BX 180 3 1/8' 5000 PSI HCR VALVE 2- KILL LINE 3 1/8' 5000 PSI NCR VALVE) I 3 1/8' 5000 PSI GATE VALVE 3 1/8' 5000 PSI GATE VALVE) BOP STACK ELEVATION 150 PSI HPDR. RATED KNIFE GATE VALVE 7G'D VENT UNE SURFACE DIVERTER CONFIGURATION SINGLE 13 5/8•, 5000 PSI, 10' MPL OPERATORS, HYDRBL PPE RAM STUDDED BOTTOM/FANGED TOP BX 180 -21 1/4', 2000 PSI, MSP HYORIL BOP/%yTER STUOOED lOP/FUNGED BOTiDIA -RANGE/FLANGE RX 73 ACCUMULATOR: NL SHAFFER, 180 GAL, 6 STATION TRIPLEX PUMP: 575 VAC, 30 HP AIR PUMP: 1, NL SHAFFER ACCUMULATOR MANIFOLD 18 BOTTLES, 10 GALLONS EACH � i:IiIEi �:TS�L't91:Z L t � �j VALVE LEGEND 1 BYPASS 2 KILL 3 CHOKE 4 BOTTOM RAMS 5 BLIND RAMS 6 TOP PIPE RAMS 7ANNULAR 000 BY PASS • • • • lsoo 3000 D lil • • q�[ill�I:1�14�I7EAIe1:[�II�y� • • bp BP Exploration (Alaska) Inc. 0 Attn: Well Integrity Coordinator, PRB -20 Post Office Box 196612 Anchorage, Alaska 99519 -6612 / 17C May 11 2012 —it?' Mr. Jim Regg Alaska Oil and Gas Conservation Commission 333 West 7 Avenue Anchorage, Alaska 99501 Subject: Corrosion Inhibitor Treatments of GPB DS -01 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, Mehreen Vazir BPXA, Well Integrity Coordinator • 0 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 qal 01 - 01C 2070920 50029210070200 0.8 NA 0.8 NA 8.5 10/22/2011 .,ri7 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 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 -198 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 • fstt 01_6. z_ p7-6 )6q ii Diu Regg, James B (DOA) Sent: . Saturday, March 03, A 2012 1:30 PM s.Reynolds @bp.com) der ! z-- To: Regg, James B (DOA); Schwartz, Guy L (DOA); AK, D &C Well Integrity Coordinator; AK, OPS FS1 OSM; AK, OPS FS1 Facility OTL; AK, OPS FS1 DS Ops Lead; AK, OPS FS1 DS5 Operator; AK, OPS PCC EOC TL; AK, D &C Well Services Operations Team Lead; AK, D &C Wireline Operations Team Lead; Cismoski, Doug A; Daniel, Ryan; AK, RES GPB West Wells Opt Engr; AK, RES GPB East Wells Opt Engr; G GPB FS1 DS; Youngmun, Alex Cc: Walker, Greg (D &C); Clingingsmith, Mike J; Olson, Andrew; Vo, Nick (Hoang) Subject: NOT OPERABLE: Producer 01 -02 (PTD #1691190 ) Sustained Casing Pressure Attachments: 01- 02.pdf; 01 -02 (PTD 1691190) TIO Plot.doc All, Producer 01 -02 (PTD #1691190) has been found to have sustained casing pressure on the IA. Wellhead pressures were SSV/2300/230 on 3/1/12. The well will remain classified as Not Operable until tubing integrity can be restored. Plan forward: 1. F: L &K 2. D: Monitor with periodic L &Ks to keep IAP below 2000 psi until patch is pulled 3. CT: Remove patch in well 4. S: Pull IBP. Set WRP below packer 5. F: CMIT -TxIA A TIO plot and wellbore schematic have been included for reference Please call if you have questions or concerns. Ir 75Ztips Thank you, % LZ Charles Reynolds Filling in for... MAR 7 CtY1`Z yt0]`c2 6 �- Mehreen Vazir Otto Cel ai 1 ,1 - fui j h ) Well Integrity Coordinator BP Alaska Drilling & Wells Well Integrity Office: 907.659.5102 Email: AKDCWelllntegritvCoordinator @BP.com From: AK, D &C Well Integrity Coordinator Sent: Saturday, February 18, 2012 10 :56 AM To: AK, OPS FS1 OSM; AK, OPS FS1 Facility OTL; AK, OPS FS1 DS Ops Lead' : , OPS FS1 DS5 Operator; AK, OPS PCC EOC TL; AK, D &C Well Services Operations Team Lead; AK, D &C Wireli - •perations Team Lead; Cismoski, Doug A; Daniel, Ryan; AK, RES GPB West Wells Opt Engr; AK, RES GPB Eas fells Opt Engr; G GPB FS1 DS; Youngmun, Alex Cc: AK, D &C Well Integrity Coordinator; Wills, Shane M; King, itney Subject: NOT OPERABLE: Producer 01-02 (PTD #1691191 Secured With Kill Weight Fluid All, Producer 01 -02 (PTD #1691190) has bee ecured with kill weight fluid on 02/17/2012. The well is reclassified as Not Operable. Plan forward: 1. CT: Remove patch in well,� 2. S: Pull IBP. Set WRP *ow packer 1 PBU 01 -02 PTD #1691190 3/3/2012 TIO Pressures Plot Well. 01 -02 4,000 • 3,000 - -4,- Tby f IA 2000 - • - OA OOA - 4-- 000A O 1,030 -- - - - - -- - ASV 12/03/11 12/10/11 12/17/11 12/24/11 12/31/11 01/07/12 01/14/12 01/21712 01/28/12 02/04/12 02/11/12 02/18712 02/25/12 03/03/12 • TREE = FMC • WELLHEAD = ROCKWELL 01-0 2 SAFETY NOTES:*** OTIS SSV NIP DAMAGED*" ACTUATOR= BAKER KB. ELEV = 73.0' "BF, ELEV = ? 9 -5/8" CSG, 47 #. XO --{ 115' I KOP = 3400' TO 40.5#, 500 -95, Max Angle = 30° C• 5000' ID = 8.681" 2171' — 5 -1/2" OTIS HRQ SSSV NIP Datum MD = 9492' 20" CONDUCTOR —1 695' Y DAMAGED CAN PASS THRU w /4.635" Datum TVD = 6500' SS H-40 ID = 19.124" 3225' - 3256'i 5 -1 X 2 -3/8" WFD GL STRADDLE (05124/07), ID = 1.992' 113 -3/8" CSG, 72 #, N-80, ID = 12.347" —I 3004' 0 GAS LIFT MANDRELS _ 01111 MD TVD DEV TYPE LATCH PORT DATE Minimum ID = 1992" @ 3225' L'' Ma 3225 3224 © CAM DMY BK 0 1220/11 5 -112 X 2-3/8" GL STRADDLE 0 0 -*GL STRADDLE SET 05/24107 3243'4245' ELM 1 4 -12' TBG PUNCH (05/24/07) .ZDP' 9-5/8" CSG, 40.5# X0 TO —1 6184' ? — FISH - PIECE OF 5-1/2" RETRIEVAL A 4 � "�' 43.5 #, SOO.95, ID = 8.681" 1 TOOL GRAPPLE (02/08/12) 9-5/8" CSG, 40.5# XO TO —1 8801' I I 8885' 1-1-1/2" OTIS XA SLD SLV, ID = 4.587' 47 #, 500.95, ID = 8.681" 8939' I-15 -112" OTIS XN LANDING NIP, ID = 4.455" 11.69 IBP (01!07/12) —{ 8945' 8950' H5 -1/7' BOT FOR ASSY, ID = 4.75" =, kJ _ 8984' — 9 - 5/8" X 5-1/7' BKR SAB PKR ID = 4.75" I 5 TBG -NPC, 17 #, MN-80, — 8996' I 8896' H5 -12" X 4-12" XO, ID = 3.958" 0232 bpf, ID = 4.897' TOP OF 3.12" L.NR ID = 2.992" H 9046' , 1 1 i 9056' I — 412" OTIS XN NO-GO LANDING NIP 4-1/7' TBG -NPC, 12.6 #, MN 80, 9120' ID = 3.725" ( BEHIND CT) .0152 bpf, ID = 3.958" •••• i• 9120' I -4-12' TUBING TAIL (BEHIND CT) 1 ••��� I4 ••4 V 9110' I--I ELMD TT LOGGED 05/14/80 PERFORATION SUMMARY M it. • REF LOG: BHCS ON 02/20/70 • 44 I � ANGLE AT TOP FERF' 21° t0 9360' •"V'' ' $ ' 4 ' 4 Note: Refer to Production DB for historical perf data 4•• I,,• SIZE SPF INTERVAL Opn/Sqz DATE 4 1� N/A 4 - 9360 - 9370 S 10/18/94 1 4 •'' NIA 4 9430 -9440 S 10/18/94 • 1'1� 1 � 0 11 � 1 � J 4" 4 9455 - 9485 S 10/18/94 I� 4 ' , �� ' � I 4" 4 9495 - 9525 S 10/18/94 • � + � � 0 I� 4" 4 9545.9575 S 10/18/94 4 • 04 4" 4 9585 - 9616 S 10/18/94 4 1'A' * ' ' 3-3/8" 4 9627 - 9661 5 08/06/90 4 * 3-3/8" 4 9661 -9635 0 08/10/90 '' •I r � i • I 3-3/8" 4 9690 -9691 S 08106/90 4 4 ���4 3-3/8" 4 9691 - 9709 O 08/10/90 ♦, i G' • iii * �� +�� e 9620' I--I3 -112' DAVIS LYNCH DUAL FLOAT SHOE ( -- 4A.e VA � . 3-12' SCAB LNR, 9 3#, L -80, --{ 9620' I .0087 bpf, ID = 2.992" - I PBTD 9817' 9-5/8" CSG, 47 #. SOO -95, ID = 8.681" —1 9930' • + • " • A . £ � • 4 • # ' - DATE REV BY COMMENTS ' DATE REV BY COMMENTS PRUDHOE BAY UNIT 03/15/70 ORIGINAL COMPLETION 10/02/09 PJC DRAWING CORRECTIONS WELL: 01 -02 03121177 't• AN2: LAST WORKOVER ' 1229/11 CJN/JMD GLV C/0 (12/20/11) PERMIT No: "1691190 10/19/94 SCAB LINER 12/29/11 CJWJMO SSSV/ STRADDLE CORRECT (1212 API No: 50- 029 - 20053 -00 09/30/09 RMC/SV TREE C/O (09/03/09) 01/08/12 TTR/ PJC SET IBP (01/07/11) SEC 8, T1 ON, R15E, 193' FNL & 1357' FWL 09/30/09 RPC/SV GLV C/0 (09/20/09) 02/25/12 PJC FISH (02/08/12) 10/01/09 ROC/PJC SSSV NIP DAMAGED (8/30 /09) BP Exploration (Alaska) 12/10/10 Schlumkerger NO. 5658 Alaska Data & Consulting Services Company: State of Alaska 2525 Gambell Street, Suite 400 Alaska Oil & Gas Cons Comm Anchorage, AK 99503 -2838 Attn: Christine Shartzer ATTN: Beth 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Well Job # Log Description Date BL Color CD MPF -13 BDAD -00024 USIT / 9,T r (") 09/29/10 1 1 p$ / NK -65A BCRD -00064 INJ PROFILE/RSTMIFL S - h(o3 10/21/10 , 1 1 , . I Go ` S-41A BCRD -00058 USIT I0 ^- /! 09/24/10 1 1 / 1- 15/P -25 B3SO -00096 SCMT J 43 — Q5 10/31/10 1 1 O �r W -219 BGZ7 -00012 USIT „a /�5 — /05 1 1 ' IS, // � 09-09 BCRO -00062 RST / `}G 10/14/10 1 1 /' 01 -02 BCRD -00066 RST / (O .- II _ 10/26/10 1 1 05-338 BAUJ -00042 MCNL /O— ('ilri 08128/10 _ 1 - 1 414 05-31B 10AKA0071 OH MWD /LWD EDIT a {t) -mod vs- 08130/10 2 1 • PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING ONE COPY EACH TO: BP Exploration (Alaska) Inc. Alaska Data & Consulting Services Petrotechnical Data Center LR2 -1 2525 Gambetl Street, Suite 400 900 E. Benson Blvd. Anchorage, AK 99503 -2838 • ' AR 1 4 2 -'; 040 „ 7. c,,,,,,,,,01:‘,40 11/30/10 Schinkerger NO. 5652 Alaska Data 8, Consulting Services Company: State of Alaska 2525 Gamhell Street, Suite 400 Alaska Oil & Gas Cons Comm Anchorage, AK 99503 -2838 - Attn: Christine Shartzer ATTN: Beth 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Well Job # Log Description Date BL Color CD Z -01 B BD86 -00070 MEM PROD PROFILE 00 - 6n `lf 10/31/10 1 1),S7` 1 04 -25 BJOH -00005 ,INJECTION PROFILE (2 ") V TG Jiro [st(9 11/08/10 1 Y± ' 1 04 -25 BJOH -00005 INJECTION PROFILE (r) U , 4, -r$.Ll 11/08/10 1 _ . - 'PI. — 1 V -07 BAUJ -00052 MEM PROD PROFILE ....., Y - .. 11/12/10 1 (, 1 - 06 -24A _ BCRD -00068 PRODUCTION PROFILE ^ 11/11/10 1 l5 '' 1 F -19A AWJI -00121 MEM PROD PROFILE a (' Y •- 1 11/09/10 1 ' ('j, 1 X -25 8088.00068 MEMORY GLS 7 10/30/10 1 r')A 1 P -08A BCUE -00090 MEMORY GLS --t7 , - 10/22/10 1 'r y 1 04 -30 B088 -00063 MEM PROD PROFILE - - -_--+ 691'5- -tfS j 10/26/10 1 1 01 -06A BCRD -00063 PRODUCTION PROFILE j S_ 8 t _ 10/23/10 1 qk 1 • D -33 BD88 -00061 MEM PROD PROFILE 9 , 10/20 /10 1 Z Z-26/4 1 B088.00061 MEM PROD PROFILE Q 10/28/10 1 1 Z -13A 8088 -00062 MEM PROD PROFILE p(. /- "./45 10/22/10 1 1 ( 1 01 -02 BCRD -00066 INJ PROFILEIWFL 9 10125110 1 1 p(.O S . $ V -219 AZ2F -00069 MEM INJECTION PROFILE 0 -1 Q. a 10/31/10 1 - , / 1 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING ONE COPY EACH TO: BP Exploration (Alaska) Inc. Alaska Data & Consulting Services 90 E. B hnisol enson Blvd Data Center LR2 -1 7 I) ( I Anchorage, AK 99503 - 2838 400 900 E. Benson Bl. t i II 0 §' il ‘ b_, ki.,..- e" P‘ fr- ,..,.„ ,,,,,--...,,,,F li�,,,,,� r ^„ 43)1:57frOAri ALASKA OIL AND GAS CONSERVATION COMPHSSION TONY KNOWLE$, GOVERNOR 3001 PORCUPINE DRIVE ANCHORAGE, ALASKA 99501-3192 PHONE: (907)279-1433 FAX: (907) 276-7542 Janua.,'y 28, !996 Sherrie GeoQuest Schlumberger 500 W International Airport Road Anchorage AK 99518-1199 Re: PBU D~lC0'J'&'I~S 7-06 PTI~~ 78-014 Dear Ms Sherrie Enclosed please find the digital data that we are unable to read. At your eadiest convenience, please provide the Commission with a replacement for the enclosed digital data. Should you have any questions regarding this request, feel free to contact me or Howard Oakland, at 279-1433. Sincerely, MEO II cc: we!! file Prudhoe Bay APl # 50-029-20294-00 ARCO ALASKA INC. 3 Pass Cased Hole CNL Logged 22-Jan-1995 9554' - 889O' GeoQuest Reference #95048 IBM TAPE IMAGE FORMAT · t~6-^ON-~Z; pessaooJcl ~6-JdV-6 ~ pa66o-I QIN3 alOH pase3 ssecl ~ GeoQuest 500 w. International Airport Road Anchorage, AK 99518-1199 ATTN: Sherrie NO. 9139 Company: Alaska Oil & Gas Cons Corem Attn: Larry Grant 3001 Porcupine Drive Anchorage, AK 99501 12/30/94 D~. 1-9A Ca I ! .~ ~ ~ DUAL BURST TDT-P (8-7-94) ~S. 1-9A I -I - ~ ~ DUAL BURST TDT-P (9-25-94) D~. 1-12 ~ 7- ~ ~ DUAL BURST TDT-P (2-7-93) o.s. ~-~ ~ 7 ff CNTH (2-2~-9~) CS. 1-23 ~- l ~ O DUAL BURST TDT-P (11-15-93) ~. 1-30 ~ -I11 CNTD (8-6-94) ~S. 1-31 ~'1~ ~ CNTH (3-1-93) ~. 1-32 ~ ~'1 ~7 DUAL BURST TDT-P (3-6-93) ~~-33 ~- I~ DUAL BURST TDT-P (3-28-94) ~.~-a4 F~- 1/~ CNTH (~-=.-.a) ~. 2-2 7~~ d3~'DUAL BURST TDT-P (2-26-93) ~s. =-4 ~ ~- ol 7 CNTD (S-~-.4) D.S~-5 ~ O- O ~ O CNTD (5-7-94) ~s. 2-12 7 ~-~ 71 CNTH (2-23-93) Field: Prudhoe Bay Floppy Well Log Description BL RR Sepia RF Sepia Mylar Disk SIGNED: JA~ O ~ ~$95 Please sign and return one copy of this transmittal to Sherrie at the above address. Alaska Oil'& Gas Cons. DATE: ' Ahchorage Thank you. Page 1 STATE OF ALASKA ALAS~- OIL AND GAS CONSERVATION [" "MMISSION REPOR'i OF SUNDRY WELL OPERATIONS 1. Operations performed: Operation shutdown Stimulate Plugging Pull tubing Alter casing Repair well Perforate Other X 2. Name of Operator ARCO Alaska, Inc. 3. Address P.O. Box 100360, Anchorage, AK 99510-0360 4. Location of well at surface 193' S & 1356' E from NW cr, Sec. 8, T10N, R15E, UM 5. Type of Well Development Exploratory Stratigraphic Service 6. Datum of elevation(DF or KB) 73 RKB 7. Unit or Property Prudhoe Bay Unit 8. Well number 1-2 At top of productive interval 1214' S & 1002' N from NE cr, Sec. 7, T10N, R15E, UM At effective depth At total depth 1208' S & 1239' Wfrom NE cr, Sec. 7, T10N, R15E, UM RECEIVED DEC 1 2 lgg,l Alaska 0~ & 8ae Cons. feet 9. Permit number/approval number 69-119 10. APl number 50 - 029-20053 11. Field/Pool I1Prudhoe Bay Oil Pool 12. Present well condition summary Total depth: measured 9930 feet true vertical 9285 feet Effective depth: measured 9708 feet true vertical 9072 feet Casing Length Size Conductor 696' 20" Sudace 2931' 13-3/8" Production 9804' 9-5/8" Scab Liner 574' 3-1/2" Plugs(measured) PBTB @ 9708' MD (10/22/94) Junk(measured) ORIGINAL Cemented Measured depth True Vertical depth 275 sx Fondu 696' 696' 1450 sx Fondu Flyash 3004' 3004' 1800 sx GL G 9877' 9226' 31.5 bbls LARC 9046'-9620' 8454'-8991' Perfoiation depth: measured 9660'-9674'; 9690'-9708' true vertical 9028'-9041'; 9055'-9072' Tubing (size, grade, and measured depth) 5-1/2", 17#, MN-80, NPCT @ 8996' MD; 4-1/2", 12.6#, MN-80, NPCT @ 9120' MD Packers and SSSV (type and measured depth) SAD packer @ 8984' MD; 5-1/2", Otis RQ SSSV @ 2171' MD 13. Stimulation ~)r cement squeeze summary Intervals treated(measured) See Attached Treatment deScription including volumes used and final pressure 14. Prior to well operation Subsequent to operation Representative Daily Average Produ~ionorlniection Data OiI-Bbl Gas-Md Water-Bbl Casing Pressure 1285 '24220 15 - / / 2954 t 3041 202 - Tubing Pressure 220'8 257 15. Attachments Copies of Logs and Surveys run Daily Report of Well Operations 16. Status of well classification as: Oil X Gas Suspended Service 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed Title Engineering Supervisor Form 10-4194'Rev 06/15/88 AJB cc: KZ, JWP Date /~'/~?/~ ~"~ SUBMIT IN DUPLICATE~ 1-2 DESCRIPTION OF WORK COMPLETED COIL TUBING SCAB LINER INSTALLATION FOR GAS SHUTOFF 1013194: RIH & tagged bottom fill at 9706' MD. 10114/94: MIRU CTU & PT equipment. Loaded the wellbore w/Seawater & RIH w/CT to tag bottom, then PU & pumped gelled sand slurry containing a total of 4750 lbs of 20/40 mesh sand, to place an isolation sand plug over the open perforation intervals located at: 9660 - 9674' MD (Z2) 9690 - 9708' MD (Z2) Ref Log: BHCS 2/20/70. Tagged sand plug top at 9609' MD, then jetted & reversed excess sand to dress plug to 9625' MD. POOH w/CT displacing the wellbore w/Seawater. Rigged down. 10/17/94: A 3.5" Coil Tubing Liner Installation was performed for Gas Shutoff as follows: RIH w/CT conveyed Scab Liner assembly, consisting of Shoe & Collar w/check valves, followed by 18 joints of 3.5" OD, L-80, FL4S Uner & 3.5" Pup joint (574' total liner length). Hung the liner assembly by a 'G' landing sub at 9046' MD, putting the shoe at 9620' MD. Disconnected from liner top & POOH w/CT. 10/18/94: RIH w/CT mounted stinger & stung into liner top. Pumped 33 bbls of Latex Acid Resistive Cement down the CT & through the check valves, to cement the Liner in position while isolating leaking squeezed perforation intervals located at: 9360 - 9370' MD (Z4: Sqzd) 9430 - 9440' MD (Z4: Sqzd) 9455 - 9485' MD (Z4: Sqzd) 9495 - 9525' MD (Z4: Sqzd/Leaking) 9545 - 9575' MD (Z3: Sqzd) 9585 - 9615' MD (Z3/2: Sqzd) Ref Log: BHCS 2/20/70. Attained 1500 psi max squeeze pressure & placed 31.5 bbls of cement in the 3-1/2" x 9-5/8" annulus. Unstung from liner top & POOH w/CT leaving 1.5 bbls of cement in the CT liner. RD. 10/22/94: MIRU CTU & PT equipment. PT Scab Liner to 2000 psi, then RIH w/CT mounted diamond mill & milled through liner cement to the CaCO3/sand plug. POOH w/mill. RIH w/jetting nozzle and jetted out the sand plug to 9708' MD, to uncover the open perforations (above). POOH w/CT. RD. Returned the well to production w/N2 lift & obtained a valid welltest. Drill Site: 1 Well: 2 _ ~,~ _..~ Thu Nov 10 09:12:10 1994 DOME SET PRESSURE: 285 PSIG @ 60 DEC F FTP @ CLOSE (PSIG): 250 PSIG K-VALVE CLASS (A,B,C): A COMMENTS: Well will likely have to be choked back during normal operations, however only 30 to 50 psi. This k-valve was redesigned due to a scab liner sqz. CC: '~~FBI~.F!LE /-C~'~O~INA~R PRB 24 (WITH ATTACHMENTS) J.C. SMART / M.~. SHOEMAKE PRB 20 (WITHOUT ATTACHMENTS) FS 1 DS Supervisors PRB 15 (COVER ONLY) DS I Eng ATO 15 (WITHOUT ATTACHMENTS) STATEOF~S~i~"(COVER ONLY) DESIGNED BY: MMM~.4~~ Drill Site: 1 Well: 2 CK LGR FTP OIL %WTR 87 87 63 56 50 51 71 88 8O 41 79 79 WELL TEST DATA Thu Nov 10 09:12:19 1994 GOR GLR LIQ PWF PI SEPARATOR DATE SEL TEMP PRES 0 258 2818 6.5 800 747 3017 1631 1.50 119 228 11/09/94 Y 0 255 3108 6.2 1195 1120 3315 1176 0.00 119 214 11/02/94 0 355 2886 5.6 1412 1332 3059 0 0.00 113 220 10/31/94 0 548 2601 5.5 2463. 2326 2754 0 992 1935 5.8 3660 3'445 2056 0 2208 1285 1.1 18848 18631 1300 0 1684 3216 2.3 12548 12259 3292 0 1175 3492 4.5 14271 13620 3659 0 1091 3559 4.4 11717 11195 3725 0 2394 570 0.0 21809 21809 570 0 1246 3059 4.7 12250 11674 3210 0 1011 3185 5.6 6655 6278 3376 0 0.00 107 234 10/31/94 0 0.00 90 229 10/28/94 . 0 0.00 89 797 10/04/94 0 0.00 102 843 09/06/94 0 0.00 112 808 07/21/94 0 0.00 115 807 07/18/94 0 0.00 72 797 07/17/94 0 0..00 113 824 07/08/94 0 0.00 121 800 07/06/94 EeC=EXIT; Fi=HELP; F3=DESIGN; F4=DISTRIBUTION LIST; F5=SENSITIVITY TABLE; ~6=CHECKLIST; F10=ACCEPT; SFS=RESTORE WELL TEST; CFg=CYCLE DATA; SSSV DEPTH (MEAS): 2171 FTP @ CLOSE (PSIG): 250 PRESS ADJUSTMENT: !1 TEMP CORRELATION: LINEAR NOTE: LINEAR CORR USES SEP TEMP, PI PROF USES BH TEMP AND WELL PI WPS C= ..79354e-3 N= 1.000000 NEW C= ..89528e-3 ENTERED N= 1.000000 ARCO Alaska, Inc. Date: Subject: From/Location: Telephone: To/Location: May 10, 1994 Transmittal #: 94037 ARCO Cased Hole Finals C E' t,'V E D John E. DeGrey/ATO- 1529 (907) 263-4310 Distribution i Number OWDW- Nw C~- ~.'~q SE ~- ~q--------~ 1-2 ~0-~-~ ---------~; 1-4 qg-~-~ 1-17 ~&-13% -~ 1-24A ~- 2~ - ~~ 2-18 ~t- tS~ 2-19 ~?'~ ~ 2-25 ~t-t~ ~.~ 2-34 3-17 ~ 93'tt~- ~ 3-21 8q-~ 3-29 ~ ~%~% ~ 4-29 ~-- ~~ 4-33 ~q~3q ~J ~ 4-45 q~'_?~ '~ 4-45 4-46 5-10 ~ 5-15A, 5-15A t 5-35 6-6 6-14, 6-14A 07-23 ~ 07-23 ,. i 7-24 i 7-24 9-1 9-9 9-19 Log Date (M-D-Y) 04-30-94 04-30-94 04-19-94 04-20-94 O4-O7-94 O4-O8-94 04-16-94 04-17-94 04-18-94 04-19-94 04-12-94 04-27-94 04-19-94 04-20-94 04-14-94 Tool Type ' Pump-in Temp ump-in Temp f CNL i f TDT-P /' TDT-P -' Perf Record Run, Scale 1 5ll 1, 5" 1 5ll ! 5II 1,5" 1, 5" ,~ Perf Record i 1, 5" Prod Profile ! 1, 5" .-' Bridge Plug .-- Prod Log -" Prod Profile '/Injection Profile Perf Record Perf Record Leak Detect 04-29-94 l/Injection Profile 04-12-94 t / USIT 04-14-94 04-14-94 04-24-94 04-24-94 04-22-94 ]/'- TDT-P t/ CNTG I ~' CNTG f TDT-P fPerf Record 04-13-94 1~ Leak Detect 04-25-94 f CTU Prod 04-26-94 f TDT-P 04-16-94 I ~' Leak Detect 04-17-94 t-'" Completion 04-08-94 1" TDT-P t---~ Completion ~Perf Record ----Patch Record /'Leak Detect t -'~ TDT-P 1,5" 1,5" ! 1,5" 1,5" 1, 5" 1, 2"&5" 1,5" 1 5" 1,5" 1, 5" Contractor Sch Sch Sch · Sch Sch Sch°: Sch Sch Sch Sch Sch Sch Sch Sch Sch Sch Sch Sch Sch Sch Sch Sch Sch Sch Sch Sch Sch Sch i 1, 5" I Sch ~ 1, 5"t Sch 04-19-94 Sch t Sch Sch Sch Sch Sch Sch 04-27-94 04-13-94 04-16-94 12-09-93 04-20-94 04-18-94 i -'" Inj Profile i 1, 5" 04-12-94 i~' Patch i 1, 5" 04-23-94 t --'Patch Record i 1, 5" i ~-Inject Profile I 1, 5" ARCO AlasY~ inc. is a Su~slcllary of AtlantlcRIchfleldCompany RECEIVED Drillsite-Well~ PRUDHOE BAY FIELD K-VALVE DOME SETTING PRESSURE DATA SHEET 1-02 , I APR 2 8 1994 Alaska 0il & Gas Cons. Commission Anchorage Date:i 3/1/~'4 '" ..... C°mmentsi!l GOR and FTP are rising following MARCIT sqz breakdown. Will need to operate choked back to enable testing. . New design should be good as GOR rises to -12,000 scf/stb. ,, Previous Settings: Date Dome Pres. (PSIG) Closure FTP (PSIG) 300 300 8/27/93 710 850 2/11/93 500 600 1/25/92 Production Data: ROR = 3408 BOPD @ 90 Deg choke CFR = BOPD @ Deg choke Swing Well (very high or Iow GOR): No , Choke Priority Well: No Design Parameters: Basis (one only): X Rates {if needed): Oil Rate 2900 BOPD Watercut 6,7 % Formation GOR 10098 SCF/STB Gas Lift Gas Rate 0 MSCF/D Total GLR 9413 SCF/STB Flowing Tbg. Pressure 590 PSIG Flow. Wellhead Temp. 97+ Deg F · Choke Setting 8 9 Deg Actual well test and date. Flowing-pressure survey and 'date. Rates used With hyd,raulics program (one only): , IPH2 R:iLDHYD Conditions at Valve: Temp. @ SSSV 147 Deg F Pres. @ SSSV 806 PS~ Pres.'Adjustment @ SSSV -94 PSIG Notice: This adjustment is at the valve, not surface. Calc. Dome Set Pres, 600.0 PSIG @ 60 Deg F Actual Dome Set Pres. 6 0 0 PSIG @ 60 De~l F 7 0 0 PSIG @ Surface FTP at K-valve Closure K-valve Type A (A~ B, or C). cc: Cooper/Lance Kennedy / Lash (2 copies) State of Alaska cc: D,S. Eng: Steve Lauver D.S. Supv: Prep. by: J~ ATO- 1566 PRB-13 PRB-24 ARCO Alaska, Inc. Date: Subject: From/Location: Telephone: To/Location: P.O. Box 100360, /~" orage, AK Mar 15, 1994 Transmittal #: 94029 AR~leFinals ~(~:~ (~{~/~'~~~ John E. DeGrey/ATO- 1529 (907) 263-4310 Distribution 99510,~ ~. Well i Log Date Tool Type Run, Contractor NurrberI (M-D-Y) Scale foci- IR i 01-02 2-26-94 Prod/Spin/Templ~> 1, 5" ' Schlumber,. c~Z.~o-~[i 'fo--[~' I 01-03 2-19-94 ProdS, BS/Temp~.~') 1, 5" Schlumber 10(~5o-l~bz.o 7(,; i 01'-09 3-01-94 Tubing Cutter ~' 1, 5" Schlumber OrOr.- c~--+ 01 ~11 2-27-94 Prod Prof/Spin 1, 5~' Schlumber -r'~ ~'E~- Z-ct 01-18 I 2-23-94 Leak Detection 1, l"& 5" Schlumb.er" ~7..- ?.D'5 01-25 I 3-06-94 CNL 1, 5" Schlumber ~%-- uf~ ,~O3;20A I 2-17-94 Perf ' 1, 5" Schlumber ~03~20A ~ 3-03-94 DtJal Burst '~:i~' !., 5" '.. SChi,u.mb.'.er ','. ~c~_ ~D~ 03-32 2-26-94 Leak/press/Temp 1, 2" Schlumb.er ... ti?..-- [~ I 03-34A 2-24-94 Prod/Press/Temp 1, 2"&5" Schlumber' ~3.. 04-01 2-19-94 Prod 1, 5" Schlumber ~%* 04-24 2-22-94 Prod 1, 5,' Schlumber ct',-! [~ 04-40 t 2-22-94 perf 1, 5" Schlumber cFS_ ~a,~ 04-46 2,16-94 Rope Perf .... 1, 5" Schlumber °lq-t2% ~/04-47' 2-18-94 v perf 1, 5" .Schlumb.er ! ;k 04-47 12-15-94 ./CBT-GR 1, 5" Schlumber %,04-47. 2-15-94 v CET-GR 1, 5" Schlumber ':b~- ~0 05-06 2-11-94 Perf 1, 5" Schlumber ct' E~ 05'14A 7-11-93 USIT/Cem&Corr ( ~,r~l, 5" Schlumber cl~- 05-15A 05-15A ~ GND/GR-Lv,~,' bt., 1, 5" Schlumber ~p~.- 11"5 05-26 3-02-94 Dual Burst 'T~ f 1, 5~ ..... Schlumber 150- ~,?-- /'06-15 . 2-21-94 Prod 1, 5" .. Schlumb,.,er ~' 06-15 2-22-94 ComP Neutron 1, 5" Schlumber ~-~- 06-22A 3-01-94 Perf 1, 5" Schlumber Iio 07-08 '3-02-94 Prod ~~l~e% 1, 5" Schlumber ,~ 07-23 ..3-07-94 Leak/Spin/Tem~,~ 1, 5" Schlumber t~- 09-34 2-21.94 Tubing] Cutter t~c. 1, 5" Schlumber et- I~ 11-02 2-10-94 Inj Pmf/:E~~H, 5" SchlUmber '~0- ~ /11-04 2-20-94 'l:~bi~'cj Cutter ~'. 1, 5" Schlumber !~..11~04 2-17-94 Tubing ~)~t~c~( ~v_.l, 5" SChlumber 15 [- t-'Jr--4r 11-7ST 3-06-94 Inj Pmf/Spin ~E-~I/'~._ 1, 5" Schlumber 11- 2-25-94 Leak/Press/Temp 1, 1"&5" Schlumber ~(~- ~ 16ST /Spin//~Cfib ~---[t L0l~ ~X~111- 3-08-94 Comp/l~l~table 1, 5" Schlumber 6ST I Zo~-.I'z~.~ o ~(o-- ~ /411-17 .2-20-94 Leak 1, 5" Schlumber ~,..11-17 3-08-94 Prod 1, 5" Schlumber ~b-i it% 11-23 8-09-91 TMD ' ' 1, 5" Halliburton ct~- 7.Dur /11-24A 3-05-94 Perf/GR/CCL 1, 5" Schlumber ~! 1-24A f 2-22-94 Comp/Perf 1, 5" Schlumber %000-~5qo ARCO Alaska, Inc. I$ a ~ul~Mdlary of AIllcRl~lCo~pmly We~ 4'24 the co~ect AP~ ~ is 50-029-2~ 506-00 Number ot Re~orcis: h~ E. ~eG~e¥ O~str~but~°n: Oe~t'~'a~ ~eS chevron ph~Ps ANO-8 Geology Exxon STATE OF ALASKA ALASKA ~'~' .A, ND GAS CONSERVATION C~ IISSION REPORT SUNDRY WELL OPEHATION . Operation shutdown Stimulate Plugging Perforate Or ~,,~j~--~ Pull tubing ~ Alter casing ---.. Repair well the X OY~ _ 1. Operations performed: 2. Name of Operator ARCO Alaska, Inc. 3. Address P.O. Box 100360, Anchorage, AK 99510-0360 4. Location of well at surface 193' S & 1356' E from NW cr, Sec. 8, T10N, R15E, UM At top of productive interval 1214' S & 1002' N from NE cr, Sec. 7, T10N, R15E, UM At effective depth At total depth 1208' S & 1239' W from NE cr, Sec. 7, T1 ON, R15E, UM 5. Type of Well Development Exploratory StralJgraphic Service 6. Datum of elevation(D"l~c~,j~ 73 RKB '~/f~ ~feet 7. Unit or Property Prudhoe Bay Unit 8. Well number 1-2 9. Permit number/approval' n"umber 69-119 10. APl number 50 - 029-20053 ,=,,,, 11. Field/Pool Prudhoe Bay Oil Pool 12. Present well condition summary Total depth: measured true vertical 9930 feet 9285 feet Plugs(measured) PBTD @ 9802' MD (8/20/93) Effective depth: measured 9802 feet true vertical 9158 feet Junk(measured) Casing Length Size Conductor 696' 20" Sudace 2931' 13-3/8" Production 9804' 9-5/8" Cemented 275 sx Fondu 1450 sx Fondu Flyash 1800 sxCl G Measured depth 696' 30O4' 9877' RECEIVED True ve~icaldepth 696' 3004' 9226' Perforation depth: measured 9660-9674'; 9690-9708' true vertical 9028-9041'; 9055-9072' S E P - 8 199 Alaska Oil & Gas Cons. Commission Anchorage Tubing (size, grade, and measured depth) 5-1/2", 17#, MN-80, NPCT @ 8996' MD; 4-1/2", 12.6#, MN-80, NPCT@ 9120' MD Packers and SSSV (type and measured depth) SAB packer @ 8984' MD; 5-1/2", Otis RQ SSSV @ 2171' MD 13. Stimulation or cement squeeze summary Intervals treated(measured) See attached. Treatment description including volumes used and final pressure Representative Daily Averaae Production or Iniection Data OiI-Bbl Gas-Md Water-Bbl Casing Pressure Prior to well operation 989 13943 0 -- Tubing Pressure 2398 Subsequent to operation 3664 4530 264 421 15. Attachments 16. Status of well classification as: Copies of Logs and Surveys run _ Daily Report of Well Operations Oil x.,. Gas ..._ Suspended .__ Service '17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed ~'" Z" ~'~~' Title Engineering Supervisor Form 10-404 Rev 06/15/88 1041/5 GSS cc: SW, JWP SUBMIT IN DUPLICATE DESCRIPTION OF WORK COMPLETED MARASEAL GEL SQUEEZE FOR GAS SHUTOFF 7128/93: RIH & tagged PBTD at 9779' MD. 7130193: MIRU CTU & PT equipment. Loaded wellbore w/1% KCI Water & Crude. RIH w/CT to tag bottom, then pumped 48 bbls of gelled sand slurry, containing 1700 lbs 30/60 & 6550 lbs 20/40 mesh sand, to place a sand plug to 9585' MD, over the open perforation intervals at: 9660 - 9674' MD (Z2) 9690 - 9708' MD (Z2) Ref. Log: BHCS 2/20/70. POOH w/CT. Rigged down. 811193: RIH & tagged top of sand plug at 9602' MD. 8/6/93: Performed a CTU Gel Squeeze of leaking cement squeezed perforations, as follows: MIRU CTU & PT equipment. Fluid packed the wellbore w/cold 1% KCl Water, then RIH w/CT to resqueeze leaking cement squeezed perforation intervals located above the sand plug at: 9360 - 9370' MD (Z4) 9430 - 9440' MD (Z4) 9455 - 9485' MD (Z4) Ref. Log: BHCS 2/20/70. Pumped 156 bbls of Maraseal Gel & placed 135 bbls of Gel behind pipe @ 3000 psi maximum squeeze pressure. Displaced Gel w/32 bbls of 1% KCI Water, followed by shutdown. Left a Gel plug in the wellbore with an estimated final top at 9275' MD. POOH w/CT. Rigged down. 8/8/93: Performed a CT Maraseal Gel & Sand Plug fill cleanout to 9610' MD. Couldn't jet below 9610' MD due to hard bottom. POOH w/CT & RIH w/CT mounted milling assembly to drill out hard fill down to 9630' MD, where hydraulic disconnect parted. POOH w/CT leaving the bottom 19' of milling assembly in hole. Rigged down. 8119/93: Fished the CT motor/milling assembly from the wellbore. 8/20/93: Performed a CT Gel/Sand Plug fill cleanout from 9600' to 9802' MD, to uncover the open perforation intervals (listed above). POOH w/CT. Rigged down. Returned the well to production .w/nitrogen lift & obtained a valid welltest. RECEIVED S E P - 8 199~ Alaska 0ii & Gas Cons. Commissio~ Anchorage Drill Site: 1 Well: 2 K-VALVE DESICN Fri Aug 27 10:26:15 1993 DOME SET PRESSURE: 300 PSIG @ 60 DEG F FTP @ CLOSE (PSIG): 300 PSIG K-VALVE CLASS (A,B,C): A COMMENTS: K-VALVE RE-DESIGNED FOLLOWING SQUEEZE. CC: ENGINEERING FILE /. COORDINATOR PRB 24 (WITH ATTACHMENTS ) J.C. SMART / M.G. SHOEMAKE PRB 20 (WITHOUT ATTACHMENTS ) J.M. RALP. H / T.J. BRASSFIELD PRB 15 (COVER ONLY) K.L. HUDSON ATO 1566 (WITHOUT ATTACHMENTS) STATE OF ALASKA (COVER ONLY) DESIGNED BY: JMS ~{~ ARCO Alaska, Inc. P.O.Box 100360 Anchorage, Alaska 99510 DATE: 04--22-93 REFERENCE: 3-13-93 Produ~n Log 3-15-93 Production Log 3-14-93 Spin/Temp/Gradlo/Press 3-14-93 CBT 3-1493 USIT (Cement & Corrosion) 3-14-93 ~,h~ng Cut Record 3-1293 Peri Record 3-18-93 Peri Record 3-18-93 Peri Record 3-13-93 (~ 3-14-93 Tubh~ Cut Record 3-12-93 Production Log 3-15-93 Leak Detect 3-1~93 Production Log 3-17-93 Tie-In GR/CCL 3-17-93 Inj Prof/Spin/Temp/Press 3-17-93 Production Log 3-2O-93 PITS 3-16-93 Production Log 3-1 1-93 Peri Record 3-12-93 Press/Temp Color Color Please sign end return the attached copy u receipt of data. RECEIVED BY_~_~~Z~_ .~~ Have A Nice Day! SonFa Wallace ATO-1529 APPROVED__~ Trans# 93048 # CENTRAL FILES # CHEVRON # LUCILLE JOHNSTON # EXXON # MOBIL # PHILLIPS PB WELL FILF~ # BPX # STATE OF ~KA * The correct APl# for 1-5ST is 50-029-20076-00. Drill Site: 1 Well: K-VALVE DESIGN Mon Feb 01 14:59:30 1993 DOME SET PRESSURE: 710 PSIG @ 60 DEG F FTP @ CLOSE (PSIG): 850 PSIG K-VALVE CLASS (A,B,C): A COMMENTS: K-Valve redesigned following state testing. Last design was done in January, 1992. This design will work in HP or LP system; however, a CFR may be needed while in LP. K-Valve class is A in LP and B in HP. CC: ENGINEERING FILE / COORDINATOR PRB 24 (WITH ATTACHMENTS) J.C. SMART / M.G. SHOEMAKE PRB 20 (WITHOUT ATTACHMENTS) E.E. VAUGHN / E.A. CAMPBELL PRB 15 (COVER ONLY) HUDSON-SEITZ ATO 1566-1556 (WITHOUT ATTACHMENTS ) STATE OF ALASKA ( COVER ONLY) DESIGNED BY: JMS Drill SiR: I~ W~ll: 2 K-VAf.,VE DESI~ Thu Jan 23 11:52:34 1992 II ~OM~ S~T~UU~SSU~: 500 Ps~ @ 60DE~ F Il I ~ e c~os~ (~s~): 600 ~s~ II Dump valve by moving well from H.P. line to L.P. line J.C. SMART ! M.~. SHOEMAKE PRB 20 J. M. Ralph/ T. J. Brassfield PRB 15 P.A. DR~UC, HON ATO 1562 DESI~KED BY: W. H. Smalstig RECEIVED FEB 05 1992 Al~sk2 Oil & G~$ Gons. Commission Anchorage Drill Site: I Well: 2 K-VALVE DESIGN Mon Jan 21 08:46:21 1991 DOME SET PRESSURE: 245 PSIG ~ 60 DEG F : : FTP ~ CLOSE (PSIG): 192 PSIG : : K-VALVE CLASS (A,B.C): B : ~ COMMENTS: Valve design chanbed since ROR is now 90 degrees. Also reduce pressure adjustment at the valve . Well may now dump while in hole during State K-valve test. CC: C.P. FARMER /~f F'RB 24 K.M. KENNEDY / W.S. WILDER PRB 20 C.B. HURST / D.B. MONTGOMERY PRB 15 ENGINEERING WELL FILE P A DRAUGHON mFQ 1558 STATE OF ALASKA DESIGNED BY: D. L. Lagerlef Print. ir, g contents of current screen - wait for message to ,.-"lear --' i ii ,1 i i il ........... ARCO Alaska, Inc. Prudhoe Bay Operations Engineering K-Valve Design Checklist Well' i '1 Reason for k-valve redesign (recent wellwork 13erforme~l_?): ~L~-] !/$ IQ ~Sq' ~nl well test ~t~ is ~rate and sh~ut data ~nfi~s watercut? Subje~ well is producin~ into the hiflh or Iow pressure ~mmonline? ~ Pas~day average ~mmonline pressure 27 7 and Iow pressure Subje~ well's past 7 day average suda~ flowing tubing pressure? ~ ~.~ Past 7 day Iow ~P? ~/0 Reason: ~o~ ~.~ Is the ~P swinging or spiking? How much? ~ Does the ~P versus CML pressure indi~te a choke restriction or undersiz~ choke? Current choke setting is at CFR or high limit (wide open)? ~ Subject well is gas lifted? ~C~j Gas lift is operating smoothly? Any r~ent gas lift va~e changes h~e been enter~ into the WPS 'Well.re Hydraulics Data' Summarize s. en~sitivity analysis below: ' '. ',,." .. ~..: .,; · ,.'.., -/',:._- Drill Site: I Well: ~ Mon Jan '~1 08:41.02 1991 K-VALVE DESIGN SSSV DEPTH (MEAS): ~171 FTP @ CLOSE (PSIG): 192 PRESS ADJUSTMENT: 10 TEMP CORRELATION: LINEAR NOTE: LINEAR CORRELATION doES SEPARATOR TEMPERATURE PI PROFILE USES WELL HEAl CONDITIONS OF WELL TEST: CK LGR FTP OIL %WTR GOR 70 0 200 2950 2.7 619 CONDITIONS AT CLOSURE: 70 0 192 2988 2.7 619 SEF' COML GLR LIQ PWF PI TEMP PRES DATE SE! 602 3034 1705 1.54 120 0 01/05/91 Y 602 3074 1682 1.54 120 0 TEMPERATURE ~ SSSV: 138 PRESSURE @ SSSV: 398 DOME SET PRESSURE: 245 138 387 PRIOR DESIGNS: DATE: 81/01/81 SET PRESSURE: 0 FTF' ~ CLOSURE: 0 TEMF': NA 01101/81 0 .~ NA .., Ol/ 1/81 o o NA ESC=EXZT~ Ft=HELF'~ F2=~L TESTS~ F4=D~S'I'RZB~ I--.~8=~CCEF'T~ =FS-RE~TORE~ Printing contents of current screen - wait for message to clear Drill Site: I Well: 2 CK LGR FTP OIL %WTR 70 70 58 61 61 61 71 70 63 57 57 WELL TEST DATA GOR GLR L!Q 0 200 2950 2.7 619 0 258 2593 2.3 515 0 309 2351 1.9 285 0 271 2551 2.1 436 0 271 2717 1.5 650 0 281 2742 1.4 728 0 234 2126 0.8 882 0 261 2339 0.9 832 0 284 2280 0.9 775 0 470 2583 0.0 914 0 470 2355 0.0 853 Mon Jan 21 08:39:59 1991 PWF PI SEPARATOR DATE TEMP PRES 602 3034 1705 1.54 120 212 01/05/91 Y ~' ~ . 212 503 2656 10~.:, 0 80 117 01/04/91 279 2398 2978 0.00 111 214 12/10/90 427 2606 0 0.00 112 198 12/09/90 640 2760 0 0.00 113 182 11/13/90 7].7 2783 0 0.00 116 181 11/09/90 874 2145 1228 0.00 111 194 10/22/90 824 2362 0 0.00 110 213 10/11/90 767 2303 0 0.80 107 200 10/08/90 914 2583 0 0.00 103 201 08/23/90 853 2355 1926 0.00 105 197 08/20/90 ESC=EXIT: Fi=HELP; F._",=DEoloN] F4=DISTRIB~ F10=ACCEF'T SF8=RESTORE' CFg=CYCLE; SSSV DEPTH (MEAS): 2171 FTP ~ CLOSE (PSIG): 192 F'RESS ADJUSTMENT: 10 TEMP CORRELATION: LINEAR NOTE: LINEAR CORRELATION USES SEPARATOR TEMPERATURE, F'I PROFILE USES WELL HEA Printing contents of current screen - wait for message to clear Drill Site: i Well: 2 _.qun Jan 20 13:57:40 1991 EPOM TABLE FOR A CHOKED WELL EPOM Switch:MAY PRODUCE MIN Oil Rate = 0 GAS RATE []IL RATE WTR RATE FTP CHOKE MSCFD BPD BPD PSIA DEG 0 0 0 456 28 1069 1724 49 423 34 1167 1883 54 390 41 1272 2052 58 357 48 1370 °o10 63 324 == 1465 2364 67 291 61 1554 2506 71 259 68 1646 2655 76 225 75 1733 2795 80 192 82 1830 2952 84 154 90 Current Rate Table INC GOR FGOR 619 619 619 619 619 619 619 619 619 619 619 619 619 619 619 619 619 619 619 619 Printing contents of current screen - wait for message to clear HT57 .1.-2 ~il-21-91 0723 RV~ RV~ RV~ TOTRL LIFT F(~M TOTR. TT;~ ~RIF~ B~rE c~( ~EP FTP SEP 0IL P05 TN~ TEST RES ~ B:~ 01-~ ~ 117 2~9 212 2509 01-~ 70 117 2:58212 2593 12-10 58 111 309 21~ 2351 12-i219 ;1 112 271 198 2551 11-1~ ;1 118 271 182 2717 11-~ Gl lib 2~1 181 27~2 10-22 71 111 23~ 19+ 21Z~ 10-11 70 110 2~1 213 2339 10-0~ ~3 107 2~+ 200 ~ 0~-~7 Gl 11~ 312 1~ 25G5 0~-20 57 I~ ~70 197 ~ 72 1~ 63 1~7 ~7 ~71 S5 111~ ~ t7~7 ~1 199~ 19 187B 23 23 17B7 31 1817 920 603 ~,~ ERY9 515 ~ 9,~ 289 2t~ ~,~ ~ ~.~ ~37 ~ ~.~~ ~.~ 7~ 717 ~,0~ 2.~ ~ 8~ 2.5~ 3.~ ~ 7~ ~.1~ 3.~ ~OI~LAY ~ TO NOI:M:L ~'i~ ---~III.BT~i~--- ---~OT F~--- MINIM~ F~JtIML~ 8.00 90.00 160. O0 300.00 7 1 0 m m L 71. i !15 23 i17 15 119 07 ~ 23 '= - O!5PL~Y PLOT FOR ,. . ,.-,,cLL¢ Lr...i,t~, n ENTEFiEB """' t TNi:' O~ O~SO~IPTION ~IN~ C ~LO~ ~ ~ ---M.OT ~:)N(~--- VALLE MINIMUM N~XIM~ 21~.29 0 I 197, 18B.71 1-17 12-18-9~ STATE OF ALASKA., ~ ~ ~ ~ ALASKA'( . AND GAS CONSERVATION C.(3~?' IISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: Operation shutdown , Stimulate Plugging , Perforate Pull tubing Alter casing Repair well .,.,=..,. Olher X 2. Name of Operator ARCO Alaska, Inc. 3. Address P.O. Box 100360, Anchorage, AK 99510-0360 -4. Location of well at surface 193' S & 1356' E from NW cr, Sec. 8, T10N, R15E, UM At top of productive interval 1214' S & 1002' N from NE cr, Sec. 7, T10N, R15E, UM At effective depth At total depth 1208' S & 1239' Wfrom NE cr, Sec. 7, T10N, R15E, UM 5. Type of Well Development Exploratory Stratigraphic 6. Datum of elevation(DF or KB) 73 RKB 7. Unit or Property Prudhoe Bay Unit 8. Well number 1-2 9. Permit number/approval number 69-119/90-206 10. APl number 50 - 029-20053 11. Field/Pool Prudhoe Bay Oil Pool feet 12. Present well condition summary Total depth: measured true vertical 9930 feet 9285 feet Plugs(measured) Effective depth: measured 9817 feet true vertical 9182 feet Junk(measured) Casing Length Size Conductor 696' 20" Surface 2931' 13-3/8" Production 9804' 9-5/8" Cemented Measured depth True vertical depth 275 sx Fondu 696' 696' 1450 sx Fondu Flyash 3004' 3004' 1800 sx CI 'G' 9877' 9226' RECEIVED Perforation depth: measured 9660-9674'; 9690-9708' true vertical 9028-9041'; 9055-9072' DEC 1 1 1990 Alasla 0il ,& Gas Cons. C0mm~ss~0n ~nchorage Tubing (size, grade, and measured depth) 5-1/2", 17#, MN-80, NPCT @ 8996' MD; 4-1/2", 12.6#, MN-80, NPCT @ 9120' MD Packers and SSSV (type and measured depth) SAB packer @ 8984' MD; 5-1/2", Otis RQ SSSV @ 2171' MD 13. Stimulation or cement squeeze summary Intervals treated(measured) See attached Treatment description including volumes used and final pressure 14. Prior to well operation Represelltative Daily Avere, qe Production or Iniection Data OiI-Bbl Gas-Md Water-Bbl Casing Pressure 213 2038 0 -- Tubing Pressure 2217 Subsequent to operation 2256 1983 23 15. Attachments 16. Status of well classification as: Copies of Logs and Surveys run Daily Report of Well Operations Oil X Gas ... Suspended. 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed ~'-~ 'Z ' ~D'e'~ Service Title Sr. Area Operations Engineer Date 294 Form 10-404 Rev 06/15/88 584 CMH c: J. Gruber, ATO-1478 SH SUBMIT IN DUPLICATE',,~ DS 1-2 DESCRIPTION OF WORK COMPLETED CTU CEMENT SQUEEZE FOR GAS SHUT-OFF 7/27/90: MIRU CTU & Stimulation Equipment. PT equipment to 4000 psi. Performed a fill cleanout down to 9777' MD, then loaded wellbore w/250 bbls of Crude. RIH w/CT & washed perforations at: 9660 - 9674' MD Ref. Log: BHC$ 2/20/70. 9690 - 9708' MD Pumped: 22 bbls 12% HCI w/10% Xylene, followed by, 36 bbls 12-3% HCI-HF, followed by 26 bbls 3% NH4Cl Water, followed by 125 bbls of Crude. Displaced CT w/37 bbls Diesel. POOH. Rigged down. Flowed well. 8/6/90: A CTU Squeeze was performed as follows: MIRU CT & Cementing Equipment. PT equipment to 4000 psi. RIH w/CT and fluid packed wellbore w/seawater. Pumped 20 bbls of class 'G' cement, followed by 44 bbls of matrix cement, squeezing perforations at: 9660 - 9674' MD Ref. Log: BHC$ 2/20/70. 9690 - 9708' MD Placed 8 bbls of cement behind pipe at 3000 psi maximum squeeze pressure. Contaminated cement & cleaned out contaminated cement from wellbore. POOH. RD. 8/7~90: RIH, & tagged bottom at 9798' MD. POOH. RD. 8/10/90: Reperforated: 9660 - 9674' MD 9690 - 9708' MD Ref. Log: BHCS 2/20170. R CEIVED DEC 1 1 1990 AJaska 0ii & Gas Cons. Commission Anchorage' Returned well to production, and obtained a valid production test. PRUDHOE BAY FIELD K-VALVE DOME SETTING PRESSURE DATA SHEET Drlllslte-Well:I i Date:l 9/4/9'~ Comments: SSSV lines are plugged rendering the SSSV useless. First K-Valve design for the well. Production rates are from post GSO test data and assumes the GOR will rise. Previous Settings: Dome Pres. (PSIG) Closure FTP (PSIG) Date None Production Data: ROR= 2565 BOPD CFR = BOPD Swing Well (very high or Iow GOR): No @ 61 Deg choke @ Deg choke Choke Priority Well: No Design Parameters: Basis (one only):I Ratee (if needed): Oil Rate 3800 Watercut 0 Formation GOR 1500 Gas Lift Gas Rate 0 Total GLR 1500 =lowing Tbg. Pressure 250 --Iow. Wellhead Temp. 120 Choke Setting 90 Actual well test and date. Flowing-pressure survey and date. Rates used with hydraulics program (one only)' % SCF/STB MSCF/D SCF/STB PSIG DegF Calc. Dome Set Pres. Conditions at Valve: ~ Temp. @ SSSV 139 Deg F Pres. @ SSSV 388 PSlG Pres. Adjustment @ SSSV 53 PSlG Notice: This adjustment is at the valve, not surface. 208.0 PSIG ~ 60 Deg F IActual Dome Set Pres. I~P at K-valve Closure K-valve Type 210 201 C PSIG ~ 60 Deg F PSIG @ Surface (Ar Br or C) cc: Ferguson / Farmer Wilder / Kennedy (2 copies) State of Alaska cc: D.S. Eng: -,~,:W. Drc, c,~ ~-'", i~-~/'~z"~-°,~ , ..ATO-1555'~ D.S. Supv: ¥, ;;-.t--'~-___~ -"_~-:_~,,':.ay/1~¢ .~&~'~ ,~r?~'~? PRB-'t'~/'~' ..P. re..~._by: ~ j~/, ~, ,,~/~//0 PRB-24 RECEIVED S EP 1 2 1990 0il & Gas Cons. Commission Anchorage Well Spud Date: 1-17-70 Original RKBE: 73' Top of Sadlerochit: 9311' o Alaska Inc.- Prudhoe · APl#: , 0029-20053-a0 Completion Date: 3-21-77 Hanger Type: McEvoy Max Hole Angle:30~ @ 4IX:X]' MD ield Ann Fluid:Diesel & CaCll0.6#Reference Log: BHCS 2-20-70 All De 3ths are RKB Drilling MD to Top of Equipment except where noted. ---- Jewelry ~ DV @ 575' 1 2171" CP @ 586' 2 8885' --- 3 893(~ DV @ 764' 4 8946' FO @ 1291' 5 8950' CP @ 1336' 6 8983' 7 8984' L'I 8 8996' 12 9 c~56' DV @ 6392' 10 9117' 11 9120' 11 9110' Well Type: Producer New I'"1 Workover I~! Hanger: 21' Angle @ Top of Sad.: 20°- Angle @ TD: 24-~ 5 1/2" otis i~ sssv Nipple ID=4.562" Otis XA Sliding Sleeve Otis XN Landing Nipple ID=4.455" BOT Locater Sub BOT PBR Assembly Baker K Anchor Baker SAB Packer Crossoven 5 1/2" x 4 1/2" Otis XN No-Go Landing Nipple ID=3.725" Baker Shear Out Sub Tubing Tail: 4 1/2" ELM Tubing Tail: CNL 5-14-80 3~ 5 6,7 8 10,11 12 13 14 Minimum ID: 9056' Offs XN Nipple ID-3.725" Casing and Tubing 13 3/8" 72# N-80 0 9 5J8"- 47# SOO-95 0 5 1/2" 17# MN-80 0 4 1/2" 12.6~ MN-80 8996' Perforation Data (ELM Depths) Bottom IZe/0t, fll;~ 3004' Casing 9877' Casing 8996' NPC Tubing 912(7 NPC Tubing 3-7-70 SQZ 3-7-70 SQZ 10-12-85 CTU SQZ 10-12-85 CTU SQZ 10-12-85 CTU SQZ 10-12-85 CTU SQZ 5-26-87 CTU SQZ 8-10-(0 Rperf 8-10-90 Rperf 000 9360-9370 '4 10 0 94809440 4 10 0 9455-9485 4 30 0 9495-9525 4 30 0 9545-9575 3 30 0 9585-9615 3,2 33 0 9626-9660 2 34 0 966G9674 2 14 4 9690-9708 2 18 4 PBTD = 9817' TD= 993(7 13 Datum 8700' SS = 9374' MD 8800' SS = 9483' MD Revision Date: 8-10-90 BY WDM Reason: RPERF previous Revision: 2-8-00 L_ i F T G A :-3 I ;".I,.T E C'T' i 0 ?-~ F' L. F! T ..% !:-, .CZ o.. 1 ~:' ' ~. I "' I ~,.. _'~' -,::. i ~. i = · = ........ ' .......................................................................... . ~ ,..,I='...'! ................... I ................... 1 ............................ :.'. ..... r- · .!:~:~.:F ! i~ I · ! '~ n'rL ~:. t ~ I " t ...... ~ .... ~ I ! t , ,, . i PiF;: I ] I"= ~. .~ ...................................................... ~ ....... ~ ............................ 5 .......................................... , .......... t...,3~:::: E } " ...... i ,~ I . = I::, i, ~ i ~ ~ . '.: ,:: Tue Sep 04 '28:2~:-55 ~-' Drill Site~ I Well: 2 IPR TRIAL WELL TEST DATA Current C= .5244&Se-1 N= 0.6999 Entered N= ~'~ Well Hydraulics Model Used is: PRUDHYD Trial C= .5244&Se-1 N= O.&~ T E .~t' FORM TOT Y.. CHK LGR FTP ~L- ~TR GOR GLR LIQ PWF PROD TEST Y D P L DES MSCFD PSIG S~ CUT SCF/B SCF/B STBPD PSIG INDX DATE P T R L M ~ 75~ 1749 ~ . 54 B8/28/9~ 61 0 512 2565 1 ~ 7~B 7~1 -~ !854 1,42 ~8 / ~-~ .... " -'.~ . 15/9B S D 57 ~ 4'7~ ~.:,55 ~ ~ 853 853 '~':' ~' '-' ' ~ w I ~ ~ ..... ' E 56 ~ 584 2653 ~ ~ 1231 1~r ~,'=~ 18~9 1 42 88/ -',-,o7 1476 8 · 8 8729 ~7,~ 1476 '~-~ ' F 1,, 3 23 15/98 R · 49 ~ ,:~- 1538 3 ~ ' 49 ~ o164 1P,~8 ~.D 8457 8457 ~ ~ ~m R G ~_ -,~ ~ 75 86/~.~ .... "~ .~ ~ . ' ........ , ~ ' ~ ~ R H 49 ~3 2195 1~87 ~ ~ 9.~88 9288 ~'~q7 a..~5 - ..... 4 3924 2~6~ 29D3 2.67 05, ~6~ I ~'p~S ~ ~ 4916 4916 ~935 299~ =.84 -- j 48 ~ 1956 1674 ~)- ~ ~788 4788 1674 313k~ 3 ~8 ~4/28/9~ R 48 ~] 1945 1719 0.0 4795 4795 1719 3113 5.B6 ~4t27/9~ R K B ~ D ~. ~ ~8/14/9~ P L Base Reservoir Pressure: 3675 C~rrent Declined Reservoir Pressure:367~ n-re nf Measurement: ~1/D1/9~ Rate of Decline: ~.6 . ~.,a - - wait for message to clear '- Printing c~nten'ts o'f current screen ' t Dr-ill Site: ! Well: LIFT GAS IHJECTION PLOT LGR FTP 01L _~ ZI4TR " L ,2, IJ') t-' ....... --'j- ............. ".': gl J I l 1 ! GOR GLR L i ~]-,~ PWF F"I C:SGP DATE ?~._-i~--i 25'F'F1 I :E:.S 1 I. 4.7:. 10¢-10 0 ::J .--" 2 ::_: ...... ~'0 # FLOH TEMF' : CASE' PR¢'S- ---- TUBE F'RES .... -" SELECT TI::;: l AL F'RES."=;I iF'E"'-; '-"" E,N'T,'EF:ED ]:)EF'TH MERS lrIEF'TH TUI:-:E F'R E'.:; F-; CASE F:'F:E:S TEHF'ERATLiF;E I N,.T DEPTH I-1 i 0,':, :3 150 ' Iu~:' i LGR n. _ 0 F' I.,J F 1 :i-': ,S 1 GLR 700 L......, i.-,, LGF: 2 01 L F'WF GLF: 0 LGF: :3 j F ! =HELP.".. F'7.;=P!.,qN_T.~F;EL_S; i' E!O 1 ..... ,0 1 ._, v_!.~-! ....... '-' F'5 =i-'JL ~ Df. ill '.Bite: 1 Well: LIFT I~A:S INJECTION PLOT T,le Sep 04 21:0I:58 1! LGR FTF' O I L ,'--~W T R iBOR iBLF: L I i_.-.! PWF P I C:SGP .L"-iA T E SELECT ~', I AOA ~-I:-:..."20 ...... -.-,'A -- _ --. · . . ..... ..~1 .-' . .... .. '" :- i ! TF' ! AL ="-'r':":'l l'-'r,-- 13 I # . i '_ i ~ I EHTERE]] TiEPTH ! !" 't I I"IEAS ....... '-' .bEt- TI"', '2 1 ? 1 - · T..I'F,r._- P!:';iF:::;f-'; " C A:B E P i::;: E :5; :..--.; 1 U. 6'4 ! ! ~' ~ I ~ !' """ i TEi',iF'ERATLiF:E i:"-,5 ~..i I-- I- I F" C:' '.~' ¢' '2' i ! ;' "~ I '-' l F::"::" r'"'""-r ' '--'° I : .. 'I 1 I I' " ; . I t._GR .E~.- 0 t ! I GLR ? 6~-';3 1! ~ I LGF: 2: L_GR :3 ~' ~ i Li'3F;: F_"i i.._-i i , "__ I .-, .,., ~..:.~ ~.T'~ , FI=HELF'; F'3=P!~f-4. T.)RE!i_S; I ................ i ,,_:,.~ ~.:..~ ' . i ----~, i ............. 5,...._'5.-,,.,:F~:' ' .. , ._ ._..~.._., F4=RATE:-;; F'5=141_ TEST:--;, FL:DH TEMF' .'= CRSE PRES .... TUBE F'RES ..... ,. ,~ ..~ . ~ Br-i 1 1 '.-:;i~: 1 Wel 1: LIFT GA'.'-'; INJECTION PLOT LGR FTF' 250 i t T E i','i P E F;; ~ T U F; E ' .i..3 '..;" L. GF;: 0 T L. ' F'I.,~F' F ! =HEL_F'; F':7:;=MA.HTJF:EL'.:;; / J,= ..... i ._.,,j,_i Jr ;:;,J,,-;~ .......... i ....j.."'.'.;.Ai~ F4=RATE:.:.:;~ F'5=WL 'T'E:E;T:.:- ..... b i -..,;. ~ .. ,..._ .... "2. _:.. ,~,::,0 .... FLOH TEMF'- ': F:A'.-3E F'F;E'.:-; ..... TU.'RE PRE::_;-- - - - ~ DF. ill Rite: 1 Hell: '.- LIFT GAS iH,.TECTIOH F'LOT LGR FTF' = L i 6.! .-5, '?.'5_,,'? PHF P I CSEiP ]]ATE :E: S' ,5 I. 41 10 0 0 E~ E:.-." 2 ::_,' ...... ~' F4 ,HE~S ]:IEF'TH 2171 T U T-::E F' R E'...--;'.:3 ~ C:RSE F'F:ES.;'.E; :L ';3,':,2 TEHF:ERATLiF-,:E :L 4-0 T t 'r ~%r-r-, I t :.:,., . =. r m m '-"-"~'-' r': :F.:'F,.'F.:.:T L_C~F.', 1 -..-~-~Jl, '~l,l.i I i 0 ! L .'3.,'.-3' Fj 0 G L. F: 1 ';' '"'"' .. .. ,.-; l::l' LGF: ,3 ~ F'I,4F !3 C~, GLR ;:3 ~3 F ! =HELF'.:. F' 5 := h! A .H T': F;: E !_ '.:; .:. F'.~...Fq.,J TEr"!F' ~ CA'SE PRES- ---- TUBE F'RES ..... ]Ir. ill Site: 1 Hell: [ LGR FTP 0 i L ,'-.--' I.,.i T R G Fi R G L F: L i 3950_ 1,0 '.;','~, '..:,' 3':;' :3 $' . 'Fu.e '.Sep El4 21:18:1~3 1 , L i FT ISA:S I i'-.i,_TECT i OH PLOT F'.L,.iF PI i-;SiSF' TiATE ?t I 1 [ 1 .- .- ._. _- : = '.SELECT ,i, EHTE p~-m", ! 'T",.,'!:~ i i"l E ~ S'; .[; r..:. F"i' H , I' I..t ]::: EP F: E '.--'; i t I C:~:.':~S E F'R E S S I T E,r,iF' E F:F:¢F LJF;:E i I ~-, r-, "r- ! i ,. I 't ,. .L.~ $ i- I F1 i l'~'T )"" I ...1_,! ',l ',L--Il ! i I , ,.::~;, ~ I F'HF --::'70 i ! G L F: :2'il;','::,'.;' :2!71 1 ;::.1,,.!:, :L i 4'.:':: !_GF: i I F' ! =F!EL.F'.:. F.T.,=h!F:~.HT-IF:F.L.'...:;.",. i. ,:..,~~ ..... i .... '~~ F.':i.=F:F~TEF; ~ F5=:14l... TE:::TS ...... 'I"UEiE PRES ...... ARC[] ALASKA, P.O. BOX i ANCFIORAGEi ~ ALASKA DATE · 8-~ 7-9~ RFFERENCE' 4-i '~"-' i_,- i 5-i4 ,-6-24 -.-'W~'---".27 · ---'7' S 3 ~.- :,-7.2 .,,~ c;..... 4 '''~ ~9--..4 .... ii .... · :~ 'ii .... ',:z .... · :--:,:- ,-t 3 .... ,j.,3 .... · ? .... 2 4 25 S '2 t2 wi .... R Ii.": C E I V ti:; D B I..IAVE A NIC SALLY HOF'F A T 0 -- i.,~.':'~ '"' ~, AI:;.'CC) CASED HOLE FINAL.$ 8-i 0-90 F'ERF' RECOF..'I) RUN i 8-i3-90 DUAL BURST I"D'¥-P RUN t 8-7-9(') COLI...A R/F:'E F('.F RUN i '7-ii-9(~' DIAGNOSTIC F:'N RUN i 8-" i i -" 9 ~ F:' E R F' R E C 0 R i) R U N i 8-i i .-9(:, COLL. AR/F:'ERt:: RUN 'i 8-'9-9(:' CNL..-G F;~/CCI... RUN i '7-27-9() INJECTION F'ROF'ZLE RUN 8-'i i-'9(:' COLLAR/I::'E:Rt::' RUN i 7 "' 28- 9 ~ I N,.J E: C T ! 0 N P R 0 F Z L E R U N i 8"" 5:"" 9 (~ CBT RUN i 8 '"' 5: '"' 9 ~, (" E T' R U N 8 .... ':?-'--q' ~ C N L---. G R /C C I... R U N i 8 .... i 2-9E~ C 0 L. L A R / F:' E R F: R U N i 7 .-.. 25:...- 9,3F:' R 0 D U C'i" ]: 0 N P R 0 I::' I t... E R U N i 8' 5 -.- 9 ~5 P E R F: R E C 0 R D R U N i '7 .... ,:.."~ ~, .~. -c;,, ~:~,, ...... D ']: A ~ N [I S 'i" :i: C F N R U N i 8 .... 4 .... 9~5 F'ERF: RECORD RUN 7-.'26.... 9 ~') F:'RODL)[::i']: ON PROF'ILE RUN i 8 .... '?'- 9 (~:, CCI... RUN N A N D R F.i: 'l'l..J F;..' N Iii: D A Y ! AUG 2 2 1990 E C K E R 011 & Gas Cons. Rnohorage 'T' I-'Iii.". A T T A C i"t Iii: I) C 0 P Y A 5' R E: C E ]: P T 0 F:' I) A 'T' A $CH SCH Al'LAS CAMCO SCH ATLAS A'[ LAS C A M C 0 CAMCO S C H $ C H A'i' L.A L.:' A C A M C 0 SCH C A Fi C 0 S C t..t C A H C 0 ATLAS I) I S T R ]: B U'T' i 0 N :~. CENTRAL FILES ~,. [:: t.'t E V R 0 N }:,&Fi · ,. E X T E N.., I 0 N E X P t.. 0 Ft A i' I 0 N · "' E X X 0 N FiARA'I'i--tON ~- MOBIL * THE AF'I~: FOR i i-.23 IS 5,3.-.(.,29-...2i6i(~. ** THE CORRECTED AF'I~- FOR i3,'? I$ ARCO Alaska, Inc.(~ Prudhoe Bay Engineering Post Office Box 100360 Anchorage, Alaska 99510-0360 Telephone 907 263 4248 Donald F. Scheve Operations Engineering Manager April 5, 1990 C. V. "Chat" Chatterton Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Re: DS 1-2 Permit No. 69-119 Dear Mr. Chatterton: Attached is the Application for Sundry Approval detailing work to be performed on the above-referenced well. Sincerely, D. F. Scheve DFS/CMH/jp Attachment cc: J. Gruber, ATO-1478 PI(DS 1-2)W1-3 /~P R - 91990 ARCO Alaska, Inc. is a Subsidiary of AtlanticRichfieldCompany AR3B--6132-O STATE OF ALASKA ' /~I~SK¥ : AND GAS CONSERVATION C~~' 'MISSION APPLICA rlON FOR SUNDRY AFPROVALS 1. Type of Request: Abandon Suspend Alter casing Repair well Change approved program 2. Name of Operator ARCO Alaska, Inc. 3. Address P.O. Box 100360, Anchorage, AK 99510-0360 Operation shutdown Plugging Pull tubing Vadance 5. Type of Well Development X Exploratory Stratigraphic Service 4. Location of well at surface 193' S & 1356' E from NW cr, Sec. 8, T10N, R15E, UM At top of productive interval 1214' S & 1002' N from NE cr, Sec. 7, T10N, R15E, UM At effective depth At total depth 1208' S & 1239' W from NE cr, Sec. 7, T10N, R15E, UM Re-enter suspended well Time extension Stimulate _, Perforate Other X 6. Datum of elevation(DF or KB) 73 RKB 7. Unit or Property Prudhoe Bay Unit 8. Well number 1-2 9. Permit number 69-119 10. APl number 50 - 029-20053 11. Field/Pool Prudhoe Bay Oil Pool feet 12. Present well condition summary Total depth: measured true vertical 9930 feet 9285 feet Plugs(measured) Effective depth: measured 9817 feet true vertical 9182 feet Junk(measured) Casing Length Size Conductor 696' 20" Su dace 2931' 13-3/8" Production 9804' 9-5/8" Cemented 275 sx Fondu 1450 sx Fondu Flyash 1800 sx Cl 'G' Measured depth 696' 3004' RECEI £D True vertical depth 696' 3004' 9226' Perforation depth: measured 9660-9674'; 9690-9708' true vertical 9028-9041'; 9055-9072' APR -91990 Alaska 0il & Gas Cons. G~m~ Anch~rag.~ Tubing (size, grade, and measured depth) 5-1/2", 17#, MN-80, NPCT @ 8996' MD; 4-1/2", 12.6#, MN-80, NPCT @ 9120' MD Packers and SSSV (type and measured depth) SAB packer @ 8984' MD; 5-1/2" Otis RQ SSSV @ 2171' MD 13. Attachments Description summary of proposal x . Detailed operations program BOP sketch x 15. Status of well classification as: 14. Estimated date for commencing operation February 1990 16. If proposal was verbally approved I Oil ~ Gas Name of approver Date approvedI Service 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed 2~,~.~¢,~~_~ Title Operations Engineering Manager Suspended Date FOR COMMISSION USF ONLY Conditions of approval: Notify Commission so representative may witness Plug integrity BOP Test Location clearance Mechanical Integrity Test Subsequent form required 10- .4--~ 4' Approval No. ! ..Approved by order of the Commissioner ORIGINAL SIGNED 8Y LONNIE C. SMITH Form 10-403 Rev 06/15/88 Commissioner Date f-~--y~) SUBMIT IN TRIPLICATE 312 C. M. Hightower DS 1-2 Gas Shut Off Procedure AFE # AP 6125 Subcomponent AFE # KS 2288 Obiective; To squeeze leaking squeezed perforations 9470'-9660' BHCS with sodium silicate to reduce GOR and return the well to production from the Zone 2B intervals 9660'-9674' and 9690'-9708' BHCS. 1. RU WLU, test lubricator, and pull SSSV. Make gauge/dummy run through tubing and casing to _ 9817' md PBTD. Mininum restriction is Otis XN LN @ 9056' md (ID 3.725"). POH. 2. RU pump unit and place sand in wellbore to cover perforations 9660'-9708' BHCS. Tag top of sand and rig WLU down. 3. RU CTU and test lubricator/BOPS. 4. Acid wash perforations 9470'-9660' BHCS using 12-3 mud acid to remove cement/ debris from squeezed interval. POH. Backflow well to remove spent acid. 5. Using CTU, squeeze the interval 9470'-9660' BHCS with sodium silicate. Leave sodium silicate in wellbore. POH and RD CTU. 6. Pressure test plug after waiting on sodium silicate and repeat squeeze job if leakage occurs. 7. RU CTU and test lubricator/BOPS. Go in hole with underreamer and cleanout sodium silicate and sand/plug material. POH. 8. Lift well in with nitrogen as needed and RD CTU. 9. RU WLU and rerun SSSV. RD WLU. 9. Return well to production and test. Well Data SBHP: 3723 psi @ 9490'md ( 8800' SS ) SBHT: 195° F @ 9490'md Tubing: 5-1/2" x 4-1/2" to 9110' ELM. Min ID: 3.725" @ 9056' md Otis XN landing nipple Tubing/casing capacity to PBTD @ 9817'md = __ 262 bbls H2S: 6 ppm reported 1 - 9 0 RECEIVED APR - 91990 Alaska Oil & Gas Cons. C0m~'tSSt!~L Spud Date: 1-17-70 Completion Date: 321-77 Original RKBE: 73' Hanger Type: McEvoy Top of Sadlerochit: 9311' Max Hole Angle:30~ O 4[XX)* MD Ann Fluid:Diesel & CaCI10.6~Reference Log: BHCS 2-20-70 All Depths are RKB MD to Top of Equipment. ~-co Alaska Inc.- Prudhoe B~v Field 1-2 ~ APl#: 50.(]2~20053-(]0 . Well Type: Producer New I~ Workover ~ Hanger: 21' Angle @ Top of Sad. · 20° Angle ~ TD: 24~ 5 I/2" Oils I~ SSSV Nipple ID=4,5~2" Otis XA Sliding Sleeve Offs XN Landing Nipple ID=4.455" BaT Locater Sub BOT PBR Assembly Baker K Anchor Baker SAB Packer Crossover:. 5 1/2" x 4 1/2" Otis XN No-Go Landing Nipple ID=3.725" Baker Shear Out Sub Tubing Tail: 4 1/2' ELM Tubing Tail: CNL 5-14-80 DV Q 575' ! 2171' CPO 586' 2 8885' 3 8939 DV O 764' 4 8946' O 1336' 6 8983' 7 8984' 8 8996' 12 9 9056' DV ~ 6392' 10 9117' 11 912Cr 11 911[/ 3,4 C¢~ng and Tu~ 6, 7 12 13 3/8" 72~ N-80 0 30~' Casing 8 13 9 5/8" 47~ SOO-95 0 9877' Casing 5 1/2" 17~ MN-80 0 ~' N~ Tubing 4 112" 12.~ MN-~ ~' 91~ N~ Tubing 9 10,11 14 936G9370 4 ~-~ 10 0 3-7-70 9430-9440 4 10 0 3-7-70 9495-q525 10-12-85 9585.9615 10-12-85' 6-22-87 ~74 ,~ 18 6-22-87 PBTD = 9817' TD= 993t:7 13 870[7 S~ = 9374' MD 880(7 S~ = 9483' MD SQZ SQZ SQZ SQZ SQZ SQZ SQZ Rperf Rperf 2-8-90/by KLW Reason: Perf Correction Previou~ Revision: 1-11-90 Well ]-2 5 4 ,, A~R -,~90 ! , ~ 1· ' '" Oil & 6as Ooa~. O~ss!~ 2 COILED TUBING U1qll' BOP Ei)U ] PHEN~ HIRE:LINE BOP EOUIPHENT _ i i 1. 5000 PSI 7" WELLHEAD CONNECTOR FLANGE 2. 5000 PSI 4 1/16" PiPE RAMS 3. 5000 PSI 4 1/6" HYDRAULIC SLIPS 4. 5000 PSI 4 1/6" SHEAR RAMS 5. 5000 PSI 4 1/6" BLIND RAMS 6. 50(0 PSI 4 1/16" STUFFING BOX 1. 5000 PSI 7" WELLHEAD CONNEC10R IrLANG£ 2. 5000 PSI WIRELINE RAMS (VARIABLE SIZE) 3. 5000 PSI 4 1/6" LUBRICATOR 4. 5000 PSI 4 1/6" FLOW TUBE PACK-Orr ARCO ALA.?KA.. INC,. P. O, BOX ANCHORAGE, ALASKA 995 DATE' 9-6-89 REF'ERENCE' ARCO CASED HOLE FINALS t-2 8-.t6--89 I'EMP/F'LL~ID DENSITY RUN t, 5" t.--t4 8-t7-89 F'RODUC'FION I::'ROFILE RLJN t: S" 2-'2S 8-24-89 COLLAR/F'ERF' RUN t, 5" S-6 8-28-89 COLLAR/F'ERF RUN t, 5" S-28 8-.i9-.89 F'RODUCTION F:'R[)FII..E RUN i, 5" 6-2 8-t4-89 PRODUCTION PROFILE RUN ii-i~ 8-i8-..89 INJECTION PROFILE/TEMF' RUN i ii-iS 8-2i .... 89 F'RODUCTION PROFILE RUN i2-.28 8-.iS-89 F'RODUCI'ION PROFILE RUN t, 5' i4.-S2 8-t~5-89 L. EAK DETECTION RUN ~, 5' ~:~ 0 =' 0 .' i ...-.~...~ 8-'~.~-89 PITS RUN i t 7- t t 8-t 8-89 "" ..... '~ ' FKODUC~ION F'ROFILE ~.JN i, " F'LEA,S'E SIGN AND REI'LJRN THE ATI'ACHED COF'Y AS RECEIF'T OF DATA. CAMCO CAMCO ATLAS A i"L.A S C'.AMCO CAMCO CAMCO C. AMCO (]AMC(] C A M C 0 CAMCO RECEIVED BY FIAVE A NICE ......................... DAY! -~ ...... : ........ iI~ ~ SAi..L.Y HOF'F'ECKER APF'ROVED .!~. ..... ATO-i 529 ~Wi~~~~ TRAN~ 8~78 I) I S T R I B U 1' I 0 N CENTRAL FIL. E$ '"~ PHILLI P,.9 PB WEL. L. F'ILE$ C I-.! E"' V R 0 N D & M R & D EXTENSION EXPLORATION ~' BPX Cq EXXON ~ ,~IAIE OF: ALASKA MARATHON ~ TEXACO MOBIL * THE COI:.F,,:ECTED AF']:~ F'OF~: 1-':',,:. I,S,' 5:0-0':29-;.,':0~53 ..... ARCO Alaska, In{r Prudhoe Bo,, t-ngineering Post Office Box 100360 Anchorage, Alaska 99510-0360 Telephone 907 263 4248 Donald F. Scheve Operations Engineering Manager ORIGINAL August 2, 1989 C. V. "Chat" Chatterton Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Re: DS 1-2, Approval No.8-210 Dear Mr. Chatterton: Attached is the Report of Sundry Well Operations detailing work performed on the above-referenced well. Very truly yours, D. F. Scheve DFS/CMH/jp Attachment cc: T.B. Gray, BP J. Gruber, ATO-1478 PI(DS 1-2) W1-3 RECEIVED AlaSka Oil & Gas Cons. Commission Anchorage ARCO Alaska, Inc. is a Subsidiary of AtlanticRichfieldCompany AR3B--6132-C STATE OF ALASKA ALASI~r )IL AND GAS CONSERVATION (~'"~ /IMISSION REPOR1 OF SUNDRY WELL OPERATIONS 1. Operations performed: Operation shutdown Stimulate Plugging , , Pull tubing Alter casing Repair well Perforate Other X 2. Name of Operator ARCO Alaska, Inc. 3. Address P.O. Box 100360, Anchorage, AK 99510-0360 4. Location of well at surface 193' S & 1356' E from NW cr, Sec. 8, T10N, R15E, UM At top of productive interval 1214' S & 1002' N from NE cr, Sec. 7, T10N, R15E, UM At effective depth At total depth 1208' S & 1239' Wfrom NE cr, Sec. 7, T10N, R15E, UM 5. Type of Well Development Exploratory . .. Stratigraphic 6. Datum of elevation(DF or KB) 73 RKB 7. Unit or Property Prudhoe Bay Unit 8. Well number 1-2 9. Permit number/approval number 69-119/8 -210 10. APl number 50 - 029-20053 11. Field/Pool Prudhoe Bay Oil Pool feet 12. Present well condition summary Total depth: measured true vertical 9930 feet 9285 feet Plugs(measured) Effective depth: measured 9817 feet true vertical 9182 feet Junk(measured) Casing Length Size Cemented Measured depth True vertical depth Conductor 696' 20" 275 sx Fondu 696' 696' Sudace 2931' 13-3/8" 1450 sx Fondu Flyash 3004' 3004' Production 9804' 9-5/8" 1800 sx 'G' 9877' 9226' Perforation depth: measured 9660-9674'; 9690-9708' true vertical 9028-9041'; 9055-9072' Tubing (size, grade, and measured depth) 5-1/2", 17#, MN-80, NPCT @ 8996' MD; 4-1/2", 12.6#, MN-80, NPCT @ 9120' MD Packers and SSSV (type and measured depth) Baker SAB packer @ 8984' MD; 5-1/2", Otis RQ SSSV @ 2171' MD 13. Stimulation or cement squeeze summary R J~ L ~iV E D 14. Intervals treated(measured) See attachment AUG o t989 Treatment description including volumes used and final pressure Alaska Oil & Gas Cons. Commi~Jnn Representative Daily Average produ¢ion or In!ection Data Anchorage OiI-Bbl Gas-Md Water-Bbl Casing Pressure Tubing Pressure Prior to well operation 0 14649 0 -- 2373 Subsequent to operation 2204 ' 345 23 -- 15. Attachments I 16. Status of well classification as: Copies of Logs and Surveys run I Daily Report of Well Operations Oil ~ Gas ..._ Suspended ._- Service 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. 802 Title Operations Engineering Manager Date Form 10-404 Rev 06/15/88 128 C. M. Hightower, 263-4173 SUBMIT IN DUPLICATE DS 1-2 DESCRIPTION OF WORK COMPLETED CTU SODIUM SILICATE SQUEEZE FOR GAS SHUT-OFF 3/15/89 - 3/16/89: A CTU Sodium Silicate Squeeze was performed as follows : MIRU CT. PT equipment to 4000 psi. RIH w/CT and fluid packed wellbore w/seawater. Pumped 15 bbls of 12.5 ppg NaC1/NaBr brine to cover open perfs at: 9660 - 9674' MD Ref. Log: BHCS 2120/70. 9690 - 9708' MD Pumped 40 bbls of Injectrol-U Sodium Silicate, squeezing leaky squeezed perforations at: 9360 - 9370' MD Ref. Log: BHCS 2120/70. 9430 - 9440' MD 9455 - 9485' MD 9495 - 9525' MD 9545 - 9575' MD 9585 - 9615' MD 9626 - 9660' MD Pumped 10 bbls of 9.5 ppg CaCI2 aftefflush, to solidify sodium silicate, followed by 93 bbls 60/40 meth/water. POH. Rigged down. 3/30/89: Injectivity test performed. Test indicated a resqueeze was required. 5/1/89: A CTU Sodium Silicate resqueeze was performed as follows : MIRU CT. PT equipment to 4000 psi. RIH w/CT and pumped 50 bbls freshwater downhole, followed by 30 bbls of Injectrol-U Sodium Silicate, squeezing leaky squeezed perforations at: 9360 - 9370' MD Ref. Log: BHCS 2/20/70. 9430 - 9440' MD 9455 - 9485' MD 9495 - 9525' MD 9545 - 9575' MD 9585 - 9615' MD 9626 - 9660' MD Pumped 10 bbls of 10.6 ppg CaCI2 afterflush, to solidify sodium silicate, followed by 135 bbls meth/water. POH. Rigged down. 5/27/89: A CTU Underreamer job was conducted as follows: MIRU CT,. PT equipment to 4000 psi. Undereamed Sodium Silicate from 9220' to 9792' CTM. Nitrogen lifted to unload. Flowed well and attained a valid production test. RECEIVED Alaska Oil & Gas Cons. Commission Anchorage ARC() AL. ASKA, INC~ F' 0 BOX ~ (:'.,:.'~ 7 z ,:.-) ANCHUf.~,GE:., AL. AS'K A 995: DATE' i t-4-88 RE"F'ERENCE' ARCO CASED HOLE F:'INALS ~t--2 i0/i-2/88 FLUID DENSITY ~'~'-~: i '3, o,~_qo F:NL--GAMMA · .fi,. .,..' -- ~. "T ~ ".,./ '~' 3 -. i..: ~'' i 0 -- i 9 -.-88 V E R T i L. O. ~' S- i 7 i O/i -3/88 TEMP S'(JF;.'.VEY '"-' :..'f-' i 9 i 0-24-88 COLI...AF,' ~.' ~ 3 - i 9 j ~_,..,', -?., ..,.. ,.,,q o C C !_ "- P 1.. U C, ,'".f,' E 'i" T I N 6. ----z~ t 9-28-88 COLI_AR/PERF: · 'x'"'~7....33 9 .... i 6/i 7-88 COI...L. AR/PFF;¢F ~ 7-34 9 t 6'-88 COl. Lr...l',,/F '~ . . ,~'-I ""= 9 '- 2 () t O'- 3- 88 I N,J E C'i" I[] N F'R 0 F:' I L. IT "'-' c,, . ", --~9 -'22 "' 88 , "'.,.:..,.. I N,J E C T i C) N P R 0 F:' I I... Iii: ~"' 9 - 35 ,° -'~,:.. ,..A .- ,..,¢::' ,..,'4 F:' R 0 D tJ C 1" I 0 N F:' R 0 F: I L. E ~ i i ....i 1 (')-' i "' R: D 0 N P R 0 i::' I t.. Ii!: ~.. 8 F:' R 0 U C 1" I ~ I,.c-,::; i ¢;'-23""88 CNL-C, AMNA i2'-9 9-i° .. ~' - 66 C 0 t... I.. A R / P E R F' ~ t 4 .... t 8 ~ ()-7-88 GAHMA-CC)I...L. AR ~*""~ 1.5-'t (')A 1 0-9'"'88 [;.AMNA'"'CCi... ~'i 5-' i 9 t ~"-8-88 ..,tJLt..r.-~l'~. ~..--~ ""--J i 5- 2 i 9"-' ;i:; 6,- 88 F' R 0 D U Cl.' "t" I 0 N P R 0 F' I I... E ~i '7 "" 6 9 .... i 4 '"' 88 C': C) t.. L A R /F:' E R F i ()"" 2 '" F) 8 P I T i '3 -'27 "" 88 C 01.. t... A F;,' / P E' R F' (.',: N A N D F;;E'T' tJ F;.: N 'f' jif( - A 't" T r-~ C I"1E I) C 0 F:' i' R 5' R E C b. ii P T RUN 2, 5" RUN i , RUN t , 5 RLJN i , 5' RLJN t , 5" F::tJNi, 5" RUN t , .5" F:.'.tJN i , 5" RLJN t., ~;" RtJN t; 5" RUN i , D" RtJN i , 5 Rt. JNt, 5 RtJN 3., RUN i , 5 RtJN t, I:;'.UN i , .5" F;,'t.JN t , RUN i., ...'~;" RtJN t, RUN t, 5" F;.:tJ N i: RUN i , RtJN t, 5'" 0 F:' D A T A. R i!"' C E I VIE D B Y .............................................................................. HAVE A NICE DA'Y! S A t.. I... Y t"t 0 F:' F:' E C I< E R A'T' 0 .... i ~'~' ''~ 9 ..-' :;.. o 'T' R A N $ ... o o ?, "z c; ~ ~I & Gas Cons. Commission D ]: S'I" R I B tJ'l" I 0 N ~ ~cho~ge · ,-'"- CENI'RAI. FILES ..-'"- CHEVRON ~" E X T E: F!..f.; .... ~,. . . I 0 N tE X r.:'l. 0 R A l" I 0 ii. · "'E X 'x 0 N Fi A R A T H 0 N · ,.'"' t'i 0 B I L (;ANCO Afl_AS A'i"L. AS C A H C 0 ATL. AS' ¢~ Ci--t ;}:.'; C.': FI [:~ E A R G E A R G E A F;..' C A M C 0 C A N C 0 C A M C 0 C A N C 0 C A N C 0 A'rI_A::,: ~'-; E A R C A i'i C 0 C A M C C) C; A H C 0 C A H C 0 C A H C 0 A'f I._AS THE]SE I...OC;S HAVE '7-...33 i 5-t OA 'f'H FZ C 0 I:;.: R iii; C'i' N [] S' A F;.:iiE · WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1. Status of Well Classification of Service Well AMENDED OIL I-X GAS [] SUSPENDED [] ABANDONED [] SERVICE [] 2. Name of Operator 7. Permit Number ARCO A1 aska, I nc. 69-119 3. Address 8. APl Number P. 0. Box 100360, Anchorage, AK 99510 50- 029-20053 4. Location of well at surface 9. Unit or Lease Name 193' FNL, 1356' FWL, Sec.8, T10N, R15E, UM Prudhoe Bay Unit At Top Producing Interval 10. Well Number 1214' FNL, 1002' FEL, Sec.7, T10N, R15E, UN 1-2 At Total Depth 11. Field and Pool 1208' FNL, 1239' FEL, Sec.7, T10N, R15E~ UM Prudhoe Bay Field 5. Elevation in feet (indicate KB, DF, etc.) I 6. Lease Designation and Serial No. Prudhoe Bay 0i 1 Pool RKB 73'I ADL 28329 12. Date Spudded 13. Date T.D. Reached 14. Date Comp., Susp. or Aband. 15. Water Depth, if offshore I 16. No. of Completions 01/17/70 02/20/70 03/15/70' N/A feet MS LI 1 17. Total Depth (MD+TVD) 18. Plug Back Depth (MD+TVD) 19. DirectionalSurvey I 20. Depth where SSSV set 121. Thickness of Permafrost 9930'ND/9285'TVD 9817'MD/9182'TVD YES [~] NO [] 2171 ' feet MD 1900' (approx) 22. Type Electric or Other Logs Run D IL~ FDC/GR~ BHC/CR, PML, GR/CBL/CC1, Gyro 23. CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD CASING SIZE WT. PER FT. GRADE TOP BOTTOM HOLE SIZE CEMENTING RECORD AMOUNT PULLED 20" 94# .... H-40 ' Surf 696' 2~,, ~7~, ~ FnnH,, 13-3/8" 72# N-80 Surf 3004' 17-1/2,, 1/~_~n .~x FnnH,, Fl¥~h 9-5/8" Z7#/43,5#/4C# S00-95 Surf 9877' 12-1//~" 1Rrm _~× £1~.~.~ r, 24. Perforations open to Production (MD+TVD of Top and Bottom and 25. TUBING RECORD interval, size and number) SIZE DEPTH SET (MD) PACKER '~ET (MD) Perforated we]] w/4 spf 5~ / ½ 9120' 8984' 9660'-9674 'MD/9028'-9041 'TVD 9690 ' -9708 'MD/9055 ' -9072 'TVD 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. DEPTH INTERVAL (MD) AMOUNT& KIND OF MATERIAL USED ~SU'-~4~U' 125 sx Class G 9360'-9370' 125 sx C1 ass G Perfs f/9455 '-9660' CTU Squeeze See Sundry, dated ~/1/88, for Acidizing data. 27. ~PRODUCTION TEST Date First Production i Method of Operation (Flowing, gas lift, etc.) 08/03/77I F1 Dwi ng Date of Test Hours Tested PRODUCTION FOR OI L-BBL GAS-MCF WATER-BBL CHOKE SIZE GAS-OI L RATIO 8-4-77 4.1 TEST PERIOD I~ 1978.7 158:~,7 4,1 20° ~_~n/~ Rnn Flow Tubing Casing Pressure CALCULATED. =~ OIL-BBL GAS-MCF WATER-BBL OIL GRAVITY-APl (corr) Press. 781 0 24-HOUR RATE=I~ 11583 9271 24 27° APl 28. CORE DATA Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water. Submit core chips. NoneRECEIVED * NOTE: Workover performed 3/26/77. CTU squeeze performed 10/12/85 & 5/26/87. Perforations added 10/18/85. Acid wash performed 5/25/87. Repe~fl~t~l~Ji~'el~°~~? ...... ~,~,i Form 10-407 (Dani) WC5/015 Submit in duplicate Rev. 7-1-80 CONTINUED ON REVERSE SIDE Top Sadl erochi t 9309 ' 8710 ' N/A · · Base Sadl erochi t 9930 ' 9285 ' · I . 31, LIST OF ATTACHMENTS None · 32. I hereby certify that the foregoing is true and correct to th~ best of my knowledge Signed ~/~ ~/~f)/)~d (~~tCJ~_, Title Associate Enoineer Date ~/~/~ INSTRUCTIONS General: This form is designed for submitting a complete and correct well Completion report and log on all types of lands and leases in Alaska. Item 1: Classification of Service Wells: Gas injection, water injection, steam injection, air injection, salt water disposal, water supply for injection, observation, injection for in-situ combustion. Item 5~ Indicate which elevation is used as reference (where not otherwise shown) for depth measurements given in other spaces On this form and in any attachments. Item 16 and 24: If this well is completed for separate production from more than one interval (multiple completion), so state in i~em 16, and in item 24 show the producing intervals for only' the interval reported in item 27. Submit a separate form;' for each additional interval to be separately produced, showing the data pertinent to such interval. Item 21: Indicate whether from ground level (GL) or other elevation (DF, KB, etc.). Item 23: Attached supplemental records for this well should shoW the details of any multiple stage cement- ing and the location of the cementing tool. item 27: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water In- jection, Gas Injection, Shut-in, Other-explain. Item 28: If no cores taken, indicate "none". Form 10-407 ARCO Alaska, Inc.~ Prudhoe Bay Engineering Post Office Box 100360 Anchorage, Alaska 99510-0360 Telephone 907 263 4248 Donald F. Scheve Operations Engineering Manager July 11, 1988 C. V. "Chat" Chatterton Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Re: DS 1-2 Approval No. 7-249 Dear Mr. Chatterton: Attached is the Report of Sundry Well Operations detailing work per- formed on the above-referenced well. 7~truly yours, D. F. Scheve DFS/JMH/jp Attachment cc: Standard Alaska Production Company J. Gruber, AT0-1478 Pi(DS 1-2)W1-3 RECEIVED .. ,-..- i:jOo A',z~k~ 0i~ & G~s Oons. Commission WELL S / 79 ARCO Alaska, Inc. is a Subsidiary of AtlanticRichfieldCompany~ AR3B--6132-O STATE Of ALASKA AlA ~ OIL AND GAS CONSERVATION COM SSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: Operation shutdown [] Stimulate [] Plugging [] Perforate [] Pull tubing [] Alter Casing [] Other [] 2. Name of Operator ARCO Alaska, ]'nc. 3. Address P.O. Box 100360, Anchorage, AK 99510 4. Location of well at surface 193' S & 1356' E from NW Cr. Sec. 8, T10N, R15E, UM At top of productive interval 1214' S & 1002' N from NE Cr. Sec. 7, T10N, R15E, UM At effective depth At total depth 1208' S & 1239' W from NE Cr. Sec. 7, T10N, R15E, UM 5. Datum elevation (DF or KB) 73' RK:B Feet 6. Unit or Property name Prudhoe Bay Unit 7. Well number 1-2 8. Approval number 7-249 9. APInumber 50-- 029-20053 10. Pool Prudhoe Bay Oil Pool 11. Present well condition summary Total depth: measured 9930 feet true vertical 9285 feet Plugs (measured) Effective depth: measured 9817 feet true vertical 9182 feet Casing Length Size Structural Conductor 696' 20" Surface Intermediate Production Liner Junk (measured) Cemented 275 Sx Fondu 3004' 13-3/8" 1450 Sx 9877' 9-5/8" 1000 Sx 'G' Perforation depth: measured 9660-9674'; 9690-9708' true vertical 9027.9-9040.8'; 9055.4-9072' Tubing (size, grade and measured depth) 5½" 17t/, MN-80 & 4½" 12.6t/ MN-80 @ 9114' MD Backers and SSSV (type and measured depth) Baker SAB Packer @ 8984' MD; Otis RQ SSSV @ 2171' MD Measured depth True Vertical depth 696' 695.99' 12. Stimulation or cement squeeze summary Intervals treated (measured) Attached Treatment description including volumes used and final pressure 3004' 3003.9' 9877' 9226' RECEIVED Anchorage 13. Prior to well operation Subsequent to operation Representative Daily Average Production or Injection Data OiI-Bbl Gas-Mcf Water-Bbl Casing Pressure ~bing Pressure 1300 11,180 0 -- 2450 1400 15,260 0 -- 2400 14. Attachments Daily Report of Well Operations [] Copies of Logs and Surveys Run [] 15. I hereby certify that the foregoing is true and correct to the best of my knowledge Signed ~:~)~v¢, ~~_ ~ Form 10-404 Rev, 12-1-85 J. M. ueusser, ZbiJ-qZbb - Submit in Duplicate /-'Y/ 5/25/87 5/26/87 6/22/87 6/23/87 Drill Site 1-2 Coiled Tubing Unit Cement Squeeze Gas Shut Off Rig up coiled tubing unit. Acid wash perforations with the following volumes plus additives: 75 bbls Xylene 60 bbls 15% HCI 60 bbls 6% HCI:1.5% HF 60 bbls 15% HCI Pump 50 bbls of cement through coiled tubing. Obtained 1500 psi squeeze pressure and held for 1 hour. Contaminated cement. Jetted out contaminated cement. Shut-in well. Perforate (Reference Log BHCS 2/20/70) 9660 - 9674' MD 4 spf 9690 - 9708' MD 4 spf Nitrogen lift to flow well. RECEIVED ARCO Alaska, Inc.~ Prudhoe Ba~,~ngineering'~ Post Office Box 100360 Anchorage, Alaska 99510-0360 Telephone 907 263 4248 Donald F. Scheve Operations Engineering Manager March 23, 1988 C. V. "Chat" Chatterton Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Re: DS 1-2 Permit No. 69-119 Dear Mr. Chatterton: Attached is the Application for Sundry Approval detailing work to be performed on the above-referenced well. Very truly yours, D. F. Scheve DFS/CM~/jp Attachment cc: Standard Alaska Production Company Pi(DS 1-2)W1-3 WELLS/79 ARCO Alaska, Inc. is a Subsidiary of AtlanticRichfieldCompany AR3B--6132-C STATE OF ALASKA ALAS'(i,~ OIL AND GAS CONSERVATION APPLICATION FOR SUNDRY APPROVALS 1. Type of Request: Abandon [] Suspend [] Operation Shutdown [] Re-enter suspended well [] Alter casing [] Time extension [] Change approved program [] Plugging [] Stimulate [] Pull tubing [] Amend order [] Perforate [] Other 2. Name of Operator ARCO Alaska, Inc. 3. Address P.O. Box 100360, Anchorage, AK 99510 4. Location of wellatsurface 193' S & 1356' E from NW Cr. Sec. 8, T10N, R15E, UM 5. Datum elevation(DF or KB) 73' RKB 6. Unit or Property name Prudhoe Bay Unit 7. Well number 1-2 feet At top of productive interval 1214' S & 1002' N from NE Cr. Sec. At effective depth At total depth 7, T10N, R15E, UM 8. Permit number 69-119 9. APl number 50-- 029-20053 10. Pool 1208' S & 1239' W from NE Cr. Sec. 7, T10N, R15E, UM 11. Present well condition summary Total depth: measured true vertical 9930 feet Plugs (measured) 9285 feet Prudhoe Bay Oil Pool Effective depth: measured 9817 feet Junk (measured) true vertical 9182 feet Casing Length Size Cemented Structural Conductor 696' 20" 275 Sx Fondu Surface Intermediate 3004' 13-3/8" 1450 Sx Production 9877' 9-5/8" 1000 Sx 'G' Liner Perforation depth: measured 9660-9674' ' 9690-9708'") 9027.9-9040.8'; 9055.4-9072' Tubing (size, grade ai~d measured depth) 5½" 17(~, MN-80 & 4~" 12.61~ MN-80 @ 9114' MD Packers and SSSV (type and measured depth) Baker SAB Packer @ 8984' MD; Otis RQ SSSV @ 2171' MD Measured depth 696' 3004' 9877' ~ueVerticaldepth 695.99' 3003.9' 9226' Anchorage 12.Attachments Description summary of proposal ~ Detailed operations program [] BOP sketch 13. Estimated date for commencing operation April 1988 14. If proposal was verbally approved Name of approver Date approved 15. I herebfy"~ertify tha~the~or~.~oing is true and correct to the best of my knowledge ~/~~_..---- Title Operations Engineering Manager Signed Commission Use Only Date Conditions of approval Notify commission so representative may witness [] Plug integrity [] BOP Test [] Location clearance Approved Copy ORIGINAL SIGNED BY Returne~ ,~ c. SM, , _ Approved by Commissioner Approval No. ~ --~//~ by order of the commission Date Form 10-403 Rev 12-1-85 WELLS/79 C. M. Hightower, 263-4713 Submit in triplicate DS 1-2 CTU SQUEEZE (OSO) INTENDED PROCEDURE 1. RU WLU and make gauge run to PBTD at 9817' MD. 2. RU CTU and perform HC1 acid wash of perforat'~onZ 9360-96~L~ EL~, 3. POH and backflow acid from well. / -'~""~ / 4. Spot Temblok plug from PBTD to +_9630' EL. . /.~, 5. Using CTU, squeeze leakin~ perforations 9360-9615' EL with sodium sili- cate solution. 6. Using CT and underreamer, clean out wellbore to PBTD of ~9817' 7. Lift well in and test. 8. Reperforate, as needed, 9660-74' and 9690-9708' (BHCS 2/20/70), 4 spf. 9. Return well to production. CMH3/32 ("Arco Alaska Inc.- Prudhoe Field Well 1-2 APl#: ,~]-(729-20053-i30 Well Type: Producer Spud Date: 1-17-70 Completion Date: 3-21-77 New r'l Workover I~1 Originai RKB: 73 ...... Hanger Type: McEvoy Hanger: 21' Top of Sadlerochit: 9311" Maximum Hole Angle: 30~- Angle Through Sad.. Annulus Ruid: Diesel & CaCI 10.6# Reference Log' BHCS 2-20-70 All Depths are RKB MD to Top of Equipment. Jewelry = DV @ 575' 1 2171' [] CP@586' 2 8885' 3 8939' ---- DV @ 764' 4 8946' FO ~ 1291' 5 8950" CP ~ 1336' 6 8983' 7 8984' 2 8 8996' 9 g056' DV @ 6392' 10 9117' 11 9120' 11 9110' 5 I/2" Offs RQ SSSV Nipple ID=4.562" Otis XA Sliding Sleeve Otis XN Landing Nipple ID---4.455" BOT Locater Sub BOT PBR Assembly . Baker K Anchor Baker SAB Packer Crossover:. 5 1/2" x 4 1/2' Offs XN No-Go Landing Nipple ID=3.725" Baker Shear Out Sub Tubing Tail: 4 1/2" ELM Tubing Tail: CNL 5-14-80 Minimum IA 9056' Otis XN Nipple ID,=3.725" 3,4 5 6,7 8 12 13 Casing and Tubing 13 3/8" 72~ N-80 0 9 5/8" 47# SOO-95 0 5 1/2" 17# MN-80 0 4 1/2" 12.6# MN-80 8996' 22°- I I 14 I I I I 9 10,11 PBTD= 9817' TD = 9930' 13 14 Perforation Data 9360-93.70 4 10 0 9480-9440 4 10 0 945,5-9485 4 ~ 0 9495-9525 4 31:] 0 95459575 3 ,.~ 0 9~1~ 3.2 ~ 0 9626-96~ 2 34 0 9660-9674 2 14 4 96g0-9708 2 18 4 Datum 8700' SS = 9374' MD 8800' SS = 9483' MD 2-27-70 2-27-70 ~7:3-7-70 3-~-70 /Sm' 3-9-70 ~S~2.: 10-12-85 3-9-70 SQZ: 10-12-85j '~.o_?n ~7. ~ 1'8--85\ ~.i 5-26-87 10-18-85 SQZ: 5-26-87 RPerf: 6-22-87 10-18-85 SQZ: 5-26-8 7 RPeff: 6-22-87 Revision Date: 6-28-87 Reason: Reperf Previous Revision:5-87 W~ll 1-2 Bo.om ~ ~' Casing 9877' .Casing 8996' NPC Tubing 9120' NPC Tubing 6 ,5 4 3 2 1. 5000 PSI 7" WELLHEAD CONNECTOR FLANGE 2. 5000 PSI 4 1/16" PIPE RAMS 5. ,5000 PS1 4 1/6" HYDRAULIC SLIPS 4. 5000 PS! 4 1/6" SHEAR RAMS 5. 5000 PSI 4 1/6" BLIND RAMS 6. 5000 PSI 4 1/16" STUFFING BOX CO ! LED TUB ! NO UN ! T BOP EOU ! PMEN'I' 1. 5000 PS1 7" WELLHEAD CONNECTOR FLANGE 2. 5000 PSI WlRELINE RAMS (VARIABLE SIZE) 3. 5000 PS1 4 1/6" LUBRICATOR 4. 5000 PSI 4 1/6" FLOW TUBE PACK-OFF 2 EEL ! NE BOP EQU!PMENT Al-~'i..;t.i AI...A,S'K A, ]' Nf'. ,. F'.. ['1.. T~[!X 'J . , COl I ~lg'/F'Ii.."F~'Ff.!F;,' 6'r l' lIN C.f']l. I. ,~R ( F'6P. KFF,' ') Cr)l..I 6F;.' r:rll. ! ¢~F,'/F'FRF'I':1I'-;:T]' t'IN r:OI ..I.. ~[i' / F' [-.-. F~' F' f3 ~' ¢~ 1' :1: f3N f". FI!..I. ,AR / F' F" F,'F' f'! g,' & T '1' F:rll..I ~1:~'/F'E'F?F'[IIq'~T ]' gFII...I ~41:i'/l::'gRl::'rll:-i'~. T T F: 1.'}1 I.. ~ I:~'. / F:' [{ R F:' [i F? A 'T 1' (] N f'". fl I. I. A I;: / I::' i?{ R r' ri F:,A 'l' i1' f') kl C 131. I._ A I;.' / I::' El R F' I~t R"A T 1' CI 1'~: ('11. I f4 F~.'/F' [:' g.? F' I"! R ('.~ 1" T r: O I I A Iq'. ? !::, t::i I:? F:' fl! I;.' A 'I'' ]i 1"'. 1']1 I ~ F.' / F:' t.7 tq' F' f'l I:~.' A '1" T [') f'.' I'il. ! A !:~: / F' !:!i t;.' F:' f) F:: A '1'' ]] f') F;.'IJN I:~' I. I N F['l IN 171 IN RI.IN 171 IN f-~'l IN [~'11NI I:~' I.I N lq'l INI [~'. I..IN F,'! IN F,.'. I lid F,'I IN I:~'I.!N A F:' F' F;.'. C) V E D ............................................... !"., ;1' 5: T F: T 1:~ I.I 'T' T 0 [.'; F.?: N 'T' F;.' ~ t_. r.:' ]' 1 C N 15:' V F,.' r:l N .F X T t!!' N,% 1' .F. IN E' X Y rt M A R' A'1.'t--I [i N! :~: H CI T-", ~ t... Box i )" a g e, A L a .'..; 99~:'~_~ 0 DAI'E' ,..lu [y ::.!8, i 987 R[-[F'ER[!:N['.E:' ARC[J Cased Hole Final. -2 7---'"0---8'? F'¥' od uc + i o'n L. oq ~---~5--1 0 6--.-'?-87 Tub ing Cui'i'er' 2--20 7--20"'-8'? Gamma Ray Log '? .... 1 i 6-24-.87 Spect'r'a log Run 2, Run t, Ru.~-~ t , Run i, '5 ' $ c h Dr e .'.-.:: z: S c h ;'~ , ("" ~:..'.'i: l::'l, ea.?.e .s'ign a'nd ¥'e'l:ct'r"n~~~~~.,~~~~_.h~..:__-i~ I~c:c'.,..~y a.~: 'rec:eip'l: Rece i red By ................................. i ........... ~:...~ _ HAVE A NICE DAY~ 0~~~~~ Ro.s'a nne Peel< A T O. .... ~ ~'., ''~.. o, of data, ARCO Alaska, Inc.~~ Prudhoe Ba~. ,,ngineering Post Office Box 100360 Anchorage, Alaska 99510-0360 Telephone 907 263 4248 Donald F. Scheve Operations Engineering Manager April 10, 1987 C. V. "Chat" Chatterton Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Re: DS 1-2 Permit No. 69-119 Dear Mr. Chatterton: Attached is the Application for Sundry Approval detailing work to be performed on the above-referenced well. Very truly yours, D. F. Scheve DFS/DAR/jp ~t t a chment cc: Standard Alaska Production Company Pi(DS 1-2)W1-3 WELL S / 7 9 ~>' ARCO Alaska, Inc. is a Subsidiary of AtlanticRichfieldCompany S(~' STATE OF ALASKA ( ALA .., OIL AND GAS CONSERVATION COM .~SION APPLICATION FOR SUNDRY APPROVALS 1. Type of Request: Abandon [] Suspend [] Operation Shutdown [] Re-enter suspended well [] Alter casing [] Time extension [] Change approved program [] Plugging [] Stimulate [] Pull tubing [] Amend order [] Perforate [] Other 2. Name of Operator ARCO Alaska, Inc. 3. Address P.O. Box 100360. Anchorage. AK 99510 4. Location of wellatsurface 193' S & 1356' E from t,q4 Ct. Sec. 8, T10N, R15E, tr~ 5. Datum elevation (DF or KB) 73' PJ~.B 6. Unit or Property name Prudhoe Bay Unit 7. Well number 1-2 feet At top of productive interval 1214' S & 1002' N from NE Cr. Sec. At effective depth At total depth 7, T10N, R15E, UM 8. Permitnumber 69-119 9. APl number 50-- 10. Pool 1208' S & 1239' W from NE Ct. Sec. 7_. TiON; R15E. UM 11. Present well condition summary Total depth: measured 9930 feet Plugs (measured) true vertical 9285 feet Prudhoe Bay Oil Pool Effective depth: measured 9817 feet Junk (measured) true vertical feet 9182 Casing Length Size Cemented Structural Conductor 696' 20" 275 Sx Fondu Surface Intermediate 3004 ' 13-3/8" 1450 Sx Production 9877' 9-5/8" 1000 Sx 'G' Liner Perforation depth: measured Measured depth True Vertical depth 696' 695.99' 3004' 3003.9' 9877' 9226' 9226-9674'; 9690-9708' true vertical 8996.5-9071.8' (2 intervals) ~bing(size, grade and measured depth) 5½" 17#, MN-80 & 4½" 12.6# MN-80 @ 9114' MD Packers and SSSV(type and measured depth) Baker SAB Packer @ 8984' MD; Otis RQ SSSV @ 2171' MD 12.Attachments Description summary of proposal [] Detailed operations program [] BOP sketch [] 13. Estimated date for commencing operation 7/27/87 14. If proposal was verbally approved ~~t Work ~ oa Name of approver Forra No./~'~/O¢ Dated-~--////~ Date approved 15. I hereby/~ertify that~j~e f,,oreg,9,ing is true and correct to the best of my knowledge ~O~~~~//"~/'//'//'/ Title Operations Engineering Manager Date Signed Commission Use Only Conditions of approval Approved by L tllqlE IL SIITB Notify commission so representative may witness [] Plug integrity [] BOP Test [] location clearance ~,:. ~:;,;~ ,~ rv ~..~ Commissioner IApproval No. by order of the commission Date Form 10-403 Rev 124-85 WELLS/79 Submit in triplicate WELl, CTU CEMENT SQUEEZE WORKOVER PROCEDURE . R]H with CTU. Clean fill and wash perforations with half strength mud acid. · 0 Fluid pack wellbore with filtered water. Pump 44 bbls cement and squeeze the following intervals: 9455-9485' MD - leaking squeezed perfs 9646-9674' MD Ref: BHCS 2/20/70 9690-9708' MD 4. Contaminate cement with a borax-bentonite mix. . · Jet out contaminated cement with gelled water. Reperforate as follows: 9660-9674' MD Ref: BHCS 2/20/70 9690-9708' MD 7. Test well. DAR/111 4 3 2 I ,I 1. 5000 PSI 7" WELLHEAD CONNECTOR FLANGE 2. 5000 PSI WlRELINE RAMS (VARIABLE SIZE) 3, 5000 PSI 4 1/6" LUBRICATOR 4. 5000 PSI 4 1/6" FLOW TUBE PACK-OFF NIRELINE BOP EQUIPMENT _ 51008111006 REV .1 6 5 1. 5000 PSI 7" WELLHEAD CONNECTOR FLANGE 2. 5000 PSI 4 1/16" PIPE RAMS 3. 5000 PSI 4 1/6" HYDRAULIC SLIPS 4. 5000 PSI 4 1/6" SHEAR RAMS 5. 5000 PSI 4 1/6" BLIND RAMS 6. 5000 PSI 4 1/16" STUFFING BOX 4 3 2 CO I LED I'UB I NG: UN I'l' BOP EQU I PMEN'I' 51008~005 REV. ARC() AI. aska .r-:' ,. 0 ~ Box Ar..cho;-age, Al. aska 99~ DATE' Apr i L F.,E.F EF, ENC.'.E · 7, t986 ARCO Cas'ed Hole Fi'hal. C a m c o C a m C o C a m c o C a m c o C a ~n c o C a m c o TRANS D I S 'T' R I B U T I 0 N :~: C: e r., '~ r a I. F:' i i. e :~i: :,',': C h e v r o n D * M ~..'.: · ,.'"' E. x t' e n .s i o 'n Iii: x p L o r a -t-. i o n .ii, · ,. Iii: x x o n M a r a -t: h o n · "' M c,b i 1. :~f.Phi 1. L i p F:'B WeL!. Fri !.e:=: F;.: & D · ,,. S o h i o ~I~ ;!;: 't' a '~ e o f A !. a :~i: i< a .Ii, '¥' · .' ~ e/, a C: 0 F:'..r)~ Bc, x. t00'360 An,::: h ,.'::,'r' ...'.', g e, A t. a .~ D A"f' E · ..J a 'n ~..t._-"~ '.," y ~ 6: R E F' E R .E N CIE ·A R C.. 0 Ca mc o Oil & uas cons. Oommi~ion Anchor3ge ARCO Alaska, Inc.[. Post Office Bo~, 100360 Anchorage, Alaska 99510 Telephone 907 276 1215 November 20, 1985 Mr. C. V. "Chat" Chatterton Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 Dear Mr. Chatterton: Re: DS 1-2 Permit No. 69-119 1-4 70-20 Enclosed are the "Subsequent" Sundry Notices detailing work completed on the above-mentioned wells. Very truly yours, D. F. Scheve DFS/JEB/dp Attachments cc: SOHIO Alaska Petroleum Co. File Pi(DS 1-2)Wl-3 PI(DS 1-4)Wl-3 le £C£1vEb 41aSka Oil & ~as Con~ Anchorage'Commission ARCO Alaska, Inc. is a Subsidiary of AtlanticRichfieldCompany O(I'L ~M STATE OF ALASKA ALASKA AND GA800NSEFIVATION OO IS,SION SUNDRY NOTICES AND REPORTS ON WELLS DRILLING WELL [] COMPLETED WELL OTHER [] 2. Name of Operator ARCO Alaska, Inc. 3. Address P.O. Box 100360, Anchorage, Alaska 99510 4. LocationofWell 193'S & 1356'E of NW cr Sec. 8 T10N, R15E, UM At Top Producing Interval: 1214'S & 1002'W of NE cr Sec.7, T10N, R15E, UM At Total Depth: 1208'S & 1239'W of NE cr Sec. 7, T10N, R15E, UM 5. Elevationinfeet(indicateKB, DF, etc.)73, RKB I 6. LeaseDesignationandSerialNO.ADL 28329 12. 7. Permit No. 69-119 8. APl Number 50-- 029-20053 9. Unit or Lease Name Prudhoe Bay Unit 10. Well Number DS 1-2 11. Field and Pool Prudhoe Bay Field Prudhoe Bay Oil Pool Check Appropriate Box To Indicate Nature of Notice, Report, or Other Data NOTICE OF INTENTION TO: SUBSEQUENT REPORT OF: (Submit in Triplicate) (Submit in Duplicate) Perforate [] Alter Casing [] Perforations [-IXX Altering Casing [] Stimulate [] Abandon [] Stimulation [] Abandonment [] Repair Well [] Change Plans [] Repairs Made [] Other [] Pull Tubing [] Other [] Pulling Tubing [] (Note: Report multiple completions on Form 10-407 with a submitted Form 10-407 for each completion.) 13. Describe Proposed or Completed Operations (Clearly state all pertinent details and give pertinent dates, including estimated date of starting any proposed work, for Abandonment see 20 AAC 25.105-170). Began perforating operation on 10-18-85. RU perforating unit and pressure tested equipment. RIH w/gun #1 to shoot 9690-9708'MD (6SPF). SI well, POOH, all shots fired. RIH w/gun #2 to shoot 9654-9674'MD (6SPF). SI well, POOH, all shots fired. RIH w/gun #3 to shoot 9626-9654'MD (6SPF). SI well, POOH, all shots fired. Secured well, RD. Ref: BHCS 2-20-77 14. I hereby,~rtify that the foregoing is true and correct to the best of my knowledge. Si§ned . .. ~ Title Operations Enrjineering Mgr. The space below for Commission use Conditions of APproval, if any: Date By Order of Approved by COMMISSIONER the Commission Date Form 10-403 Rev. 7-1-80 Submit "Intentions" in Triplicate and "Subsequent Reports" in Duplicate ARCO Alaska, In~~ Post O ffice~,~ 100360 Anchorage. Alaska 99510 Telephone 907 276 1215 Daft'e: November 7, 1985 Reference: ARCO CH Finals ~-2 ~CE~/ 5-26-85 Run 1 5" Sch ~-6 ~'~Perf 7-4-85 1 5" Sch I~-6/'CET 5-23-85 1 5" Sch w~-7 ·CET 5-23-85 ' ' 1 5" Sch 16"~Collar/Perf 7-7-85 2 5" Sch 19?Perf record 7-5-85 1 5" Sch -13~Perfc)record 7-3-85 1 5" Sch '~-1~' CET 5-22-85 1 5" Sch v~-9~ CET 5-10-85 1 5" Sch v~-15~CET 5-27-85 1 5" Sch 411-1 I~"CET 7-16-85 1 5" Sch ~4-5//CET 7-29-85 I 5" Sch Please sign as receipt of data. Pam Lambert ~O~,f ~ 2 ~ ATO 1429C Atas~'a 0i~ & Gas Cons. Commission Trans 406 'Anchorage. Chevron ' D&M Bxpl. Services Ex=. Explora=ion~ Ex~on , Marathon Mobil . Phi 1 lips, PB Well Files R&D Sohio ' Texaco · ARCO illllkl. Inc. il I Subsidiary o! AlllrtlicRichfieldComplny ARCO Alaska, Inc.( Post Office Box 100360 Anchorage, Alaska 99510 Telephone 907 276 1215 September 26, 1985 Mr. C. V. "Chat" Chatterton Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 Dear Mr. Chatterton: Re: DS 1-2 DS 1-4 Permit No. 69-119 Permit No. 70-20 Enclosed are the "Intention" Sundry Notices detailing work proposed on the above-mentioned wells. Very truly yours, D. F. Scheve DFS:JEB:cb Attachment cc: SOHIO Alaska Petroleum Co. File Pi(DS 1-2)W1-3 File PI(DS 1-4)W1-3 ARCO Alaska, inc. is a Subsidiary of AtlanticRichfieldCompany STATE OF ALASKA ( ALASKA OIL AND GAS CONSERVATION COMMISSION SUNDRY NOTICES AND REPORTS ON WELLS 5. DRILLING WELL [] COMPLETED WE LIX~ OTHER [] Name of Operator ARCO Alaska, Inc. Address P.O. Box 100360, Anchorage, Alaska 99510 Locationof%~/~llSurface: 193'S & 1356'E of NW cr Sec. 8, T10N, R15E, OM At Top Producing Interval: 1214'S & 1002'W of NE cr Sec. 7, T10N, R15E, UM At Total Depth: 1208'S & 1239'W of NE cr Sec. 7, T10N, R15E, UM Elevationinfeet(indicateKB, DF, etc.)73, RKB I ADL6'LeaseDesignati°nandSerialN°'28329 7. Permit No. 69-119 8. APl Number 50--029-20053 9. Unit or Lease Name Prudhoe Bay Unit 10. Well Number DS 1-2 1 1. Field and Pool Prudhoe Bay Field Prudhoe Bay Oil Pool Check Appropriate Box To Indicate Nature of Notice, Report, or Other Data NOTICE OF INTENTION TO: SUBSEQUENT REPORT OF' (Submit in Triplicate) Perforate X~ Alter Casing [-1 Perforations Stimulate [] Abandon [] Stimulation Repair Well [] Change Plans [] Repairs Made Pull Tubing [] Other X~] Pulling Tubing Note: Report multiple completions on Form 10-407 with a submitted Form 10-407 for each completion.) (Submit in Duplicate) [] Altering Casing [] [] Abandonment [] [] Other [] 13. Describe Proposed or Completed Operations (Clearly state all pertinent details and give pertinent dates, including estimated date of starting any proposed work, for Abandonment see 20 AAC 25.105-170). ARCO Alaska, Inc. intends to squeeze existing perforations on DS 1-2 using a coiled tubing unit (CTU). After the squeeze the well will be cleaned and perforated. These operations will be performed in the following manner: 0 e e Cleanout well and load with formation water and diesel.. Pump in cement and squeeze the following perforation intervals: 9455-9485'MD 9495-9525'MD 9545-9575'MD 9585-9615'MD Contaminate the cement. Wait 12 hours and reverse out the contaminated cement from the wellbore. Perforate the following intervals: 9626-9674'MD 9690-9708'MD Test the well. J ECEIVED OCT 0 985 ,~as~a 0~i d, G'~s Cons. Commission 14. i hereby ~l'tify that th~ foregoing is true and correct to the best of my knowledge. Signed Title Regional Operations Engineer Date The space below for Commission use Conditions of Approval, if any: Approved by Ill [Ofl iE C. SMIT COMMISSIONER ~pproved Cogy ~turned By Order of the Commission Date Form 10-403 Rev. 7-1-80 Submit "Intentions" in Triplicate and "Subsequent Reports" in Duplicate Jerry A. Rochon District Operations Engineer November 13, 1981 Reference: ARCO PRESSURE DATA D;~S.1-2 10-7/8-81 D.S.16-11 8-16/17-81 D.S.16-11 8/14/81 D.S.16-11 8/15/81 D.S.16-11 8/13/81 D.S.16-11 8/11/81 Pressure Survey Pressure Survey Pressure Survey Pressure Survey Pressure Survey Pressure Survey Please sign and return the attached copy as receipt of data. Mary'F. Kellis North Engineering Transmittal #737 ~ DISTRIBUTION NORTH GEOLOGY R & D DRILLING ENG. MANAGER D&M GEOLOGY STATE OF ALASKA EXXON < ...... MOB I L ~i' Z) ,,- MARATHON' CHEVRON ARCO O~1 and G,~s Company ~s ,~ D~'~$~¢n of AtlanlicRicnlieldCorapany ARCO Oil and G~ Company North Aldl~ District Post O lfic~~ oox 360 Anchorage, Alaska 99510 Telephone 907 277 5637 Jerry A. Rochon District Operations Engineer December 16, 1980 Reference: ARCO Pressure data D.S. 1-2 10-26/27/80 Pressure survey COMAA COMM COMM RES ENG .... 1 ENG 2 ENG 3 4 ~NG 1 GEO~ SIAl SIAl CONFER: FILF: '~Please sign and retumn the attached copy as receipt of data, · Mary Kel 1 i s North Engineering Transmittal #901 DISTRIBUTION NORTH GEOLOGY R&D DRILLING ENG. MANAGER D&M GEOLOGY STATE OF ALASKA EXXON GETTY PHILLIPS SOH I 0 MARATHON CHEVRON ARCO Oil and Gas Company is a Division of AtlanticRichfieldCompany ARCO Oil and G~' ompany Post Of,i~-,~ c~ox 3o0 Anchorage. Alaska 99510 Telephone 907 277 5637 June 20, 1980 Reference: ARCO Magnetic Tapes ~I~.~5/14/80 Tape #60516 D.S2~=W~ 4/30/80 Tape #60454 ~.S. 3-15 2/13/80 Tape #60324 D.S. 12-8 2/25/80 Tape #60337 oo ease sign and return the attached copy as receipt data. c,k OEOL '--J STAT TTC __ J STAT T~C I CONFER.' 'FILF; .... K. J. Sahlstrom North Engineering TRANSMITTAL #401 DISTRIBL~ION North Geology R&D Drilling Eng. Manager D & M Geology State of Alaska Mobil Getty Phillips Sohio Marathon Chevron ARCO Oil anal Gas Company is. a Division of AttanticRichfie~dCompany ARCO Oil and .~ Company Pos! Of L~. Box 3GO Anchorage. Alaska -00510 Telephone g07 277 5657 June 20, 1980 Reference: ARCO Magnetic Ta~es 3 _.4ENG ' OEOL 3 GEOL 7~ STAT TEC - 5/14/80 Tape #60516 4/30/80 Tape #60454 2/13/80 '"Tape #6D324 2/25/80 Tape #60337 //~lease sign and ret~'rn the attached copy as receipt ~ of data. STAT TEC-- CONFER: 'FILl=: K. J. Sah.lstrom North Engineering TRANSMITTAL #401 DISTRIBL~iON North Geology /2cxon R & D biobil Drilling Getty Eng. Manager Phillips D & M Sohio Geology blarathon State of Alaska Chevron ARCO Oil ancI Gas Company ~s ,'1 Division of AttanhcRichliel~JCompany ARCO Oil and ~Gf ".ompany Post Of,ice Box 300 Anchorage. Al3ska 99510 Te!er~hone 907 277 5537 June 4, 1980 Reference: · D.S. 4-7 D.S. 5-5 D.S. 5-7 D.S. 5-12 D.S. 5-17 ARCO Cased Hole Logs 5/14/80 CNL Run 2 5" 5/15/80 " Run 2 5" 5/15/80 " Run 3 5/16/80 " Run 4 5" 5/16/80 " Run 4 5" 5/16/80 CNL Run 3 5" 4/4/80 Spinner 5" ¢ 'P/~lease sign and return t'he attached copy as receipt of data. K. J. Sahlstrom North Engineering TRANSMITTAL #360 DISTRIBUTION R ~ D Mobil ~illing Getty Eng. ~ager Phillips D & M Sohio Geology Marathog State of ~aska ~e~on ARCO Oil and Gas Comoany ~s ~ Dials,on of AtlanlticRichtieVJCompany ARCO Oil and Gas' Company · · . ~l~rch 18, 1980 Reference: ARCO Pressure Buildup i-I COrM /"-~J 1ENG JI 2 ENG J'~l-' 1 g~OL I 3 O~OL'/_. j STAT ~STA T T CONFER~ FILF: y,~p.S. 1-2 2/17-18/80 Camco lease sign and return the attached copy as receipt of data. K. J. Sahlstrom North Engineering TR~qSMITrAL #164 DISTRIBL~ION North Geology R&D Drilling Eng. Manager D&M Geology State of Alaska Exxon Mobil Getty Phillips Sohio ~.larathon Chm,~on ~ ' i',a n ticR ic h ~ieid C;o m.p..":ny Norh.,,m-.L..---.nPro .... cm~jDivision Nor,. Ala Post OfSr~' ~ox 360 Anchorage, Alask~ 9~510 Telephone ~07 277 ~37 November 7, 1979 Reference: ~nclosed~are Pressure SUrveys for the following ARCO ~ells: 8/5-6/79 Camco. 8/30--9/1/79Dresser Atlas D,S. 7,-3 9/3-4/79 " " D.S.. 14,.1 7/28~.29/79 Camco 'D,S. 14~4 7/30-.31/79 " D.S. 14,5 8/6~-7/79 " ~/~Please~/ sign and return the attached copy as receipt ~' of data, :K',, J, Sahlstrom North Engineering TRANSMITTAL # 465 DISTRIBUTION North Geology Drilling -Eng. Manager R&D Geology State of Alaska D&M Exxon Mobil Getty Sohio Marathon Phill. ips Chevron HKVP Reference: Enclosed is the following Pressure Survey: D.S. fJl-4 4/11/78 Plea.se sign and return the copy as receipt of data. Sincerely, V.G. Reimei~s North Engineering TRANSMITTAL #585 Reference: Enclosed are copies of the following data: Transient Pressure Surveys: ¢/D.S. #f%2 "' 9-22-78 Go Wireline v/D.S. #1-5 9-24-78 Go Wireline CD.S. #1-6 9/26-27/7'8 Camco ~/D.s. #1-i0 9/28-29/78 Camco v/D.S. #2-2 9/8~8/78 Camco v/D.S. #2-4 9/6-7/78 Camco ~D.S. #2-5 9/1-2/78 Camco v/D.S. ~2-6 9/3-5/78 Camco W~D.S. #2-9 9/11-12/78 Camco w/D.S. #9-1 10-10-78 Go Wireline vzD.S. #9-6 9-9-78 Go Wireline HKVP Please sign and return attached copy of enclosed transmittal as receipt of data. Very truly yours, R. A. Logue North Operations Engineering Transmittal # 574 . J. A:. Rocho~/R. ^. Logue :tn..-;.,,i ttcd herc;-.'ith are the following for the subject well' i No. Scal~ .. Xerox Sep.ia 'BL Acid or Fracture ]¥eatment Log · · ' B['IP Buildtp ~ Flow Profile Survey Borchole GeometlT Log ...... Carbon Oxygen Log .... Casing Collar Log Cement Bond Log "-~'--Compensated Neutron Log - Cased ltole - ---~ Core ;malysis - Interval Core No. --'-Core Descripti°n (~IC) - Interval ---~ dore Description {Cony.) - Cpre No. ..... .Directional Surv.ey- Gyro ..... . - Singl~e- Shot · - ~k~ltishot ,__~'.Engineering Producti. on' Log Fluid Analysis · '- --.Fluid Density Ganuna' Ray Location Plat ...... Monthly l~:ell Test Data - Nud Log -- Perforating Record State Reservoir Pressure Report Surveillance Reports Temperature Log ~ Transient Pressure Surveys TVD Logs - Iklel Induction I,at.er°log - Compensated Formation D~nsity Log - Compensated Neutron-Fm~nation Density Log - Borehole Compensated Sonic Log - Porosity Log _.(..q I. ' _ . :;asc Ret:tu'n P, eccipt To: Ms. R. A. Logue ~' Atlantic Richfield Company P. O. B. ox 360 Anchorage, Alaska 995] 0 Date' __J. A..Rocho~/R' A. Lpgue · _ ~ .2 lfell Name: . · . · ,.,...,~[t'cd ],.(:re',.:ith are thc following for the "'' ' ~//~~ ' :-,. ,s a,9 ect we! 1 No. Scal~ ]Xerox Acid or Fracture 'lk'eatment Log · -'- };!-IP Buildup [ Flow Profile Survey };orehole Geomet~}- Log ._~ Carbon Oxygen Log . Cement Bond. Log .... Compensated Neutron Log - Cased Hole Core Pmalysis - Interval Core No. ...... Core Description (~IC) - Interval .... Core Description (Cony.} - Core No. ..... Directional Survey- Gyro . - S~gle Shot - lk~l'tishot ]'Engineering Production' Log' Fluid Analysis =-.Fluid Density . ..... 'Gamma' Ray l,ocation Plat _ }.'!onthly Ifell Te~t. Data ~lud Log Perforat~g Record. ..... State Reservoir Pressure Report Surveillance Reports Temperature Log · Transient Pressure' Surveys i TVD I,ogs - Duel Induction Laterolog ...... -. Sef, fta 'BL L5 . .. L - Compensated Formation Density 1.og - Ccm~pensated Neutron-Fo~m~ation Density Log . - Borehole Compensated Sonic Log - Porosity Log · ip't: Acl:now].edged l~): · Date- :s;e Ret:rrm Receipt To: Ms. R. A. l,o~¢~e Atl. antic Richfield Compan7 P. O. Box 360 Anchorage, Alaska 99510 o 'J' R A N (' ' ,') ,-I I 'i' T A [(:' };ro;It ' J. A. Roclion/R. A. Logue ,n:.-.~.';~.:d l,(:rcwith are thc following for thc subject well' ) No. 'Scale.' Xerox Sepia BL Ac].d or Fracture Treatment Log · l;[IP Buildup 6 Flow Profile Survey Bm-ehole Ceomet:o~ Log Carbon Oxygen Log Casing Collar Log Cement Bond Log. Co:npensate~ Neutron Log - Cased I IoZe Core Anal),s~s - Interval Core No. Core Description (S).IC) -'Znterval Core I)escrjption (Com~.) - Core No. · Directional Survgy - Gyro.__ - Single Shot. - Multishot ........ · l{ng]nee, ring. ProductiOn' Log }:luid Analysis (;~flnma' Ray ].,ocat~.on Plat .... }4onthly Well Test Da'La ..... ~.lud_,.Log Per:~orat.~g Reco~d . __ State Reser~o~ Pressure Report Surveillance Repo~s _ - _ Temperature Log TVI) Logs - Duel Induction Laterolog - Compensated Fomation Density Log - Compensated Neutron--Formation Density Log - BOrehole Compensated-Sonic Log - Porosity Log ::(::ipt Acknow].edged By' . /-J.. / ::asc Return P, eccipt To' Ms. R. A. I,ogue Atlantic Richfield Company P. O. BoX 360 Anchorage, Alaska 99510 _ ! _ AtlanticRichfieldCompany North American Producing Division North Alas~ 'istrict Post Officel~ x 360 Anchorage, Alaska 99510 Telephone 907 277 5637 February 13, 1978 Mr. Hoyl e Hamilton State of Alaska Department of Natural Resources Division of Oil and Gas 3001 Porcupine Drive Anchorage, A1 aska 99501 Subject: DS 1-1 (32-8-10-15) Permit No. 69-82 ~~-7-10-15) 69-119 DS 1-4 (23-5-10-15) Permit No. 70-20 .DS 1-5 (23-9-10-15) Permit No. 70-40 DS 1-6 (13-4-10-15) Permit No. 75-13 Dear Sir: Enclosed please find a Completion Report for the above-mentioned wells. Very truly yours, Frank M. Brown District Drilling Engineer /am Attachments 3, 9930'MD & 9285'TVD! 9817'MD & 9182'TVQ 22. PRODUCING !INTa;HVAL(S), OF THIS COMPLETIOAT--TOi~, BOTTOM, NAME (MD AND TV]]))* Fm'm P - 7 .... SUBMIT IN D~_ ,£E* STATE OF ALASKA <se,, othor 1,1- st ructions on CONSERVATION COMMITTEE OIL AND GAS 50-029-20053 II WELL (OMPLETIO~ OR R[(OMPL[IIO~ REPORT ASD LO~* WELl. WELL ~ DRY Other b. TYPE OF COMPLE~ON: WELl. OVER ~ EN ~ BACK ~ESVR. Other _ ~. ~.,~ o~ o~,~o~ Prudhoe Bay Unit Atlantic Richfield Company ~.wm~o. ~ o~o~,o~ ~S 1-2 (32-7-10-15) P.0. Box 360; gnchora~e, ~laska 99510 Loc~rms oF W~L[ (Re~or~ toeat~on c[~ar~ and in accordance w~th ~ State requ~rem~t~)* At ~ufface 193'S & 1356'[ fr ~ cr Sec 8, 110~, R15[, ~ it top prod. Interval reported below 1214'S $ 1002'~ fr ~[ cr Sec. 7, 110~, ~15[, ~ At total dep~ 1208'S & 1239'~ fr ~[ cr Sec 7, 110[, R15[, ~M ~.~m~o. 69-119 . INT~RVAL8 D~[LL~D BY 9309' to 9930'MD & 8710' to 9285'TVD, Sadlerochit 24. TYPE ELECTRIC AND OTHEI:t LOGS RUN 6. LEASE DESIGNATION A-ND SERIAL NO. ADL 28329 T. IF INDIA~N, A3_J~ OR TRIBE NA.NIE 10. FIELD AND POOL, OR WILDCA. T Prudhoe Ba Fi eld Prudhoe Oi~ Ponl 11. SEC., T., R., M., (BOTTOM HOLE OBJECTIVE) Sec 7, I10N, R15F, UM CABLE TOOLS 23. '~VAS DIRECTION,a,L SURVEY MADE Yes Schlumberger DIL, FDC-GR, BHC-GR, PML, GR-CBL-CCL CASING RECORD (Report all strings set in well) CASI~4G S1ZE13- 3/8"20" ][72#[94#wEIGHT' LB/FT' ~ 'GRADE '1DV'PTH SET (MD) I HOLE SIZElIN_Rtl! H--40 / ] 3004'696l 17-- 1/2"? '2~" '. 50(]275 s×sx CEAILNTING RECOE,D~f~ndiiF0ndu F1 vA~h z Rn~lJ] A~/IOUNT PULLED,:(.0:0 9-5/8" 47,43 5.40# s00-9~ 9877'. 12rl/4" 1st Sta.~e 1000 sx "~" lq]EC O I-rD I 27, 26. LINER TUBING REC OF~lZ) SIZE , 5- " 9120' ' 8984' 28. PEI{FORATIONS OPF_~4 TO PRODU~J'ikON (interval size and number) 29. 4-1/2" holes/ft 9615' - 9585' ) 9575'-9545') 9525'-9495' )~ 9485'-9455') 20. DATE FIRST PftODUCTION 8-3-77 DATE OF T~ST, 8-4-77 FLOW, TU BI!N'G t~s. 781 DIL Measurements i I i PF~ODUCTION I-~OURS TESTED . ']CI-!OXE SIZE iPROD'N FO,I~ ' 4.1 ~0o CASLNG PRESSURE [CALC~T~ OI~BBL '~AS (Sold; used ~6r /ueI, ve~ted, etc.)' ACID, Si'~OT, FZI;~C~'URE, CF~'~IENT SQUECZ.~, ETC. D~TIi I~¢TF. LRVAL (MD) [ AA'iOUNI~ £~'~D I~21ND OF M,z~I'E?~IAL USD 9430'-9440' j 125 sx Class "G" cmt "9360'-9370' 125 sx Class "G" cmt PTtODUCTION MEII{O.D (FlowingS, gas till pumping--size and type of pump) iV, tELL STATUS (Producing or Flow(n9 ] =~'~) Producing OI~BDL. G~%~CF. VCATE~BBL. ] GAS-OIL ILkTIO ! 1978.7 I 1583.7 i 4.1 ] 800 GA~-~CF. ~k~EBL. ]OIL GR~VZTY-~I (CORR.) I 9271 I 24_ ~ ~270 API Fuel and re~njected LIST OF ATTACHMENTS 23.'I hereby certify that the foregoing a~d attached information l~ complete and correct as determined from all-available records SIGNED *(See Instructions and Spaces FOr Additional Data on Reverse Side) General: This form is designed for subrnitting a complete and correct well completion report end Io9 on all types of lands and leases in Alaska. item: 16: Indicate which elevation is used as reference (where not otherwise shown) for depth measure- ments given in cther spaces on this form and in any attachmer~ts. Items 20, and 22:: If this well is completed for separatc, production fror'n more than one interval zone (multiple completion), so state in item 20, and in ite'~- ?2 show the p~c;tuci~.0 interval, or intervals, top(s), bottom(s) and name (s) (if any) for only the interval reported in iten~ 30. Submit a separate report (page) on this form, adequately identified, for each additional interval to be seperately produced, show- ing the ad~litional data pertinent to such interval. Item26: "Sacks Cement": Attached supplemental records for this well should show the details of any mul- tiple stage cementing and the location of the cementing tool. Item 28: Submit a separate complelion report on. this forrn for each interval to be separately produced. (See instruction for items 20 and 22 above). 34. SUMMAI[[Y OF I;'()II. MATION TgS'I'S IN('LUI)IN(; INTERVAL TF.,STET), PIlES.SURE DATA AINt'D P~COVERI-ES OF OIL. GAS, WAT~Il. AND MUD No Formation Tests None A'N'D ~l')~Ig-'.lq~C~l'E~l) SII'C~Ws O!;' (')IL, :GA. IS O11 IVATE:I1. · . G I~)I_,OG I C M A RKl~q~ NAIVlE Top of 6adleroCh Top of Sag River MEAS. DE'PTIt t 9309 919 7 DEP~ OF NA'I~UPAL RES~dR~ ~ Di~ of Oil and (~s Ccnservaticn O. K. Gilbreth, Jr Feh~_~y 9, 1978 Chief Petroleun Eng~iv' Test Surface Safety Valves (SSV), Subsurfaoe Safety Valves (SSSV), ic~ Pressure Pilots and Annular Pressures on ARfD's Drill Sites 41, 94 Subject t~st involved two separate trips to ~ Bay, the first on January 16, 1978, and the second on January 22, 1978, with eight ~- tire days spent testLng. Part of the second trip was u~lized retest- ing eert_~n wells on drill site 41 after guide lines w~re agreed upcn at a ~eet/ng be~=en agency and AROD production personnel cn January 20th. Listed below are the ~sults of the te~ts: L.P.Pilot Initial SSV SSV- SSSV SSSV 9 5/8" Actuated Flowing Tested Test' Tested Test Annulas 1-1 1-3 1-4 1-5 1-6 1-7 1-8 .1-9 1-10 4-1 4-2 4-3 4-4 4-5 4-6 4-7 4-8 4-9 4-10 720 1550 640 OK 825 OK 25 700 1270 675 CK 720 OK 0 700 790 620 OK 660 Failed 0 660 1020 680 OK 700- OK 0 700 900 740 .. OK 700 CK 90 700 1550 800 OK 810 CK 0 700 1140 695 OK 650 Failed 60 700 1140 740 OK 750 Failed 0 700 1600 970 Failed 1000 Failed 0 * ** Inoperable 780 1400 700 CK 700 OK 0 2075 * *** Failed 0 680 1300 750 OK 750 OK 0 775 1450 750 OK 750 C~ 0 670 1560 700 OK 890 OK 0 700 1300 * *** Failed 100 700 1500 775 OK 700 OK 0 700 1350 700 OK 760 Failed 0 650 960 660 OK 650 OK 100 650 1450 700 OK *** Failed 50 * Not tested ** SSSV inoperable. Being~pulled. *** SSSSV would not close.. 13 3/8" ~Annulas PSI 0 0 0 100 0 5O 0 0 100 0 250 0 0 0 0 0 0 0 ARCO D.S. #1, ~4 February 9, ]~78 Of the t~enty SSSV's tested, nine, or 45%, ~ere ~able cr failed. Fifteen SSV's tested sucoass~:]ly and c~e failed. Three SSV's ~_re not tested aft~_r it was found the SSSV's in the w~Lls ~Duld not .test. These Field inspection reports were p~=pared and copies mailed to A1 Brown, producticn ~tanfent, and Dc~ Franks, assistant productic~ superintendent. Originals of the field inspection reports are attached to this re~. Atta~t Drlg. Permit_ No. Opera tor_~~0 All Oil and Gas Conservation Commi Field Inspect~on Report Wel 1/P,~T==- Sec T R _,_. _M Represented by~,~'-,~-,~K~ Name & Number Satisfactory Type Inspection Yes No Item ( ) Location,General () () () () () () () () (~- ( ) () () () () () () () () () () 1. Well Sign 2. General Housekeeping t. Reserve Pit-( )open( )filled 4. Rig (~"Safety Valve Tests_ 5. Surface-No. Wells / 6. Subsurface-No. Wells / ( ) Well Test Data 7. Well Nos. , , , 8. Hrs. obser , , , 9. BS&W , , , 10. Gr. BOls. , , ( ) Final Abandonment ll. P&A Marker Satisfactory Type Ins?ecti~?~ Yes No Item ( ) BOPE Tests () () () () () () () () () () () () () () () () () () () () () () () () () () () () 15. "Casing set @ 16. TesL fluid-( )wtr.---]--~ )mud ( ) oil 17. Master Hyd. Control Sys.= psig 18. ~2 btl s. ,__,__, psig 19. Remote Controls 20. Drilling spool- "outlets 21. Kill Line-( ) Check valve 22. Choke Flowline ( ) HCR valve 23. Choke Manifold No. valvs flos 24. Chokes-( )Remote( )Pos.(-]~-dj. 25. Test Pluo-( )Wellhd( )csg( )none 26. Annular Preventer, . psiQ 27. Blind Rams, psiq 28. Pipe Rams ~psiq ( ) ( ) 12. Water well-( )capped( )plugged ( ) ( ) 29. Kelly & Kelly-cock ~psig ( ) ( ) 13. Clean-up ( ) ( ) 30. Lower Kelly valve psio ( ) ( ) 14. Pad leveled ( ) ( ) 31 Safety Floor valves-~-(- ~BV / )Dart Total inspection observation time~ hrs/dt~9~ Total number leaks and/or equip, failures 0 Remarks .cc:~ ~c~~/ .Notify in days or when ready AtlanticRichtieldCompany North Amedcan Producing Division North Alas~' 'strict Post Office b,,x 360 Anchorage, Alaska 99510 Telephone 907 277 5637 May 16, 1977 Mr. Hoyle Hamilton State of Alaska Department of Natural Resources Division of Oil and Gas 3001.Porcupine Drive Anchorage, Alaska 99501 Subject: DS 4-1 (23-35-11-15) Permit No. 70-42 DS 4-2 (13-26-11-15) Permit No. 70-63 ~~34-11S=.D.~_~_Z_2_.(3~ ~15)Permit No. 71-5 7-10-.5, Permit No 69-119 Dear Sir: Enclosed please fi nd copies of the gyroscopic directional survey for your files on each of the above-mentioned wells. Very trulb, yours, Frank M. Brown District Drilling Engineer /jw Enclosures RECEIVED Divi~!~n oi 0[t ~, !3~ NOrth Alaska District TRAN S N I TY J. A- Rochon/p. Hellstrom.' # Date: ~.~y 10, , 1977 Well ..-_,.- - . D.S. 1-2 - :_.-- ., ~-_: .- -~ o Transmitted herewith are ~he fOllowing for the sub~ject well:'. · . o : Scale Run No. · ! .' BHC S6nic/Celi. p~r Log- . - -- '-- BHC Sonic/Cz!iper -' Ga~a Ray ~L. og -.'.. . ~HC ~onic/S~ .P,~. ~og . . ---.~- -' - C~l~per/CCL.-- . "- · ...._ Cement BOna.Lgg/VDL ' ' " ~o:mP--~ns~t~a Neutro~-~ormation Co~e Anal)sis - I~erval .. ........ .. "'~ ' Core' Es.' ._ ... :. Core ' ~' "'-------- D~scrxp~on [Cony.) - Core No-U · : "-'- Directional Survey -. Gyro . . .. _ .- . Single Sh6t .. . -------- SYnergetic Log :-"""- : C m-- e" r -- 3VD-Porosity Log __ . . ._ r t~31tishot Drill Stem'Test - Test No. . Dual Induction Late~olog. _-__ . . l~ormgtion DenSity Log _. :Oorr~ation D-=nsity Lo~S~ R~y .~- . . _' .... Laterolog ~--2' ' " -. / Lo~tion Plat '. ........ - ·. 'Receipt Acknowledge& ~0r: . .Date: tqcase return Atlantic Richfield Co.,.-~. any North Alaska Engineering P. O. Box 350 ;, '~ ""',~ Al:::.:: '3:'! #329 CONFIDENTIAL STATE OF North Alaska District En=in=~in.= ( (' T RAN S M I.T T A L · , TO. OIWSION OF'OIL & GA~ . From: Date. . Ap,ri! .18,.. 19.77 ....... ]Veil Trans~tted here~ith are the follm~ing for the subject well- Run No. Scale Xerox BHC S0nic/Calitmr Log- BHC Sonic/Caliper ' Gamma Ray L. og BHC Sonic/Gamma Ray Log 'Caliper/eCL · '- . Cement Bona Lpg/VDL Compensat~t Format_ion Den~.i_~z.' Log Compensated Neu~ron-Forma~on DenSity Compensated Neutron Log Core Analysis - Interval -,. . . Core No. ' ~ "' : ...... ." Core Descript. ion-(~VC) - ihte~val ...... ' ": "' i - ._. Core Dascription (Cony.) - Core No''[ - . Directional .Survey- Gyro . Mmtltishot · . Drill Stem Test- Test No. ~ Dual Induction Late~olog Formation Density Log / -'. '~ Fomation DensiV Log/Gma Ray' Gmma Ray/ECL ...... .: .. ~.: · _ Laterolog.. '" ~.ocation Plat _ Microlog ~h~dlog' - Inte~ral - "s~p~e Log (A.A. Co'-'.)-~n~erv~)'_'" - Synergetic Log ~A)-Poros'it~ Log '_--.x~ CCL ...... · ............ · ..:. ~',. · . _ , . ,, ,. ,,, ._ _ - . _ .. _ . , · , ,, . . , , · , , ~ ,, Receipt Acknowledged For: Date: Please return receipt to' ' ~lantic Richfield North Alaska Engineering Mmaager P. O. Box 360 Anchorage, Alaska _c.~_~;9 #231 AtlanticRichfieldCompany North Am ~ Producing Division North AI;~ ~istrict Post Office Box 360 Anchorage, Alaska 99510 Telephone 907 277 5637 April 15, 1977 Mr. Hoyle Hamilton State of Alaska Department of Natural Resources Division of Oil and Gas 3001 Porcupine Drive Anchorage, Alaska 99501 Subject: DS 1-2 (32-7-10-15) Permit No. 69-119 Dear Sir: Enclosed Please find a Sundry Notice outlining our plans for the above-mentioned well. Very truly yours, Frank M. Brown District Drilling Engineer /vp Enclosure RECEIVED APR ! 5 ! 77 Form 10-403 REV. 1-10-73 Submit "1 ntentlons" in Triplicate & "Subsequent Reports" in Duplicate STATE OF ALASKA OIL AND GAS CONSERVATION COMMITTEE SUNDRY NOTICES AND REPORTS ON WELLS (Do not use this form for proposals to drill ~'l~te~pe~n ::; Use "APPLICATION FOR PERMIT--~' for s~ prol~oS~ls.)l'''* ::'I:,: '~ !--! 1. DweLL.L WELL OTHER ::~, ?):~) ~ 2. NAME OF OPERATOR "~j '{~ ~ ~ '~'%'~' Atlantic Richfield Company n~'~,~,~ ~ ~',~ ~:. P. 0. Box 360, Anchorage, Alaska 99510A~;~h~'¥~'~'~.,-,~... 4. LOCATION OF WELL At su trace 193' S & 1356"E fr NW cr Sec. 8, TION, R15E, UM 13. ELEVATIONS (Show whether DF, RT, GR, etc.) 73' KB 14. Check Appropriate Box To Indicate Nature of Notice, Re 5. APl NUMERICAL CODE 50-029-20053 6. LEASE DESIGNATION ANO SERIAL NO. ADL 28329 7. IF INDIAN, ALLOTTEE OR TRIBE NAME 8. UNIT, FARM OR LEASE NAME Drill Site I 9. WELL NO. ~I-#2 10. FIELD AND I~OOL, OR WILDCAT (32-7-10-15) 11. SEC., T., R., M., (BOTTOM HOLE OBJECTIVE) Sec. 7, TION, R15E, UM. 12. PERMIT NO. 69-119 )ort, or'Other Data NOTICE OF INTENTION TO: TEST WATER SHUT-OFF FRACTURE TREAT SHOOT OR ACIDIZE REPAIR WELL (Other) PULL OR ALTER CASING MULTIPLE COMPLETE ABANDON* CHANGE PLANS sUBSEqUENT REPORT OF: WATER SHUT-OFF ~ FRACTURE TREATMENT ~ SHOOTING OR ACIDIZING ~ ~ (ot,,r) Workover R~a-Olhp 1 REPAIRING WELL ALTERING CASING ABANDONMENT* etion (NOTE: Report results of multiple completion on Well completion.Or Recompletion Report ancl Log form.) 15. DESCRIBE PROPOSED OR COMPLETED OPERATIONS (Clearly state all pertinent ¢letall$, and give pertinent dates, including estimated date of starting any proposed work. )egan rigging up Rowan 26 on March 1, 1977. Finished rigging up and accepted rig March 10, 1977. iD tree and NU and tstd BOPE. PU 12¼" bit. Tagged 9-5/8" casing stub at 1,325' Cond mud. PU ~" bit and RIH to 2430' Circ and warmed mud. WIH w/ 11-3/4" wash pipe. WashJd over 9-5/8" :asing to 1,357'. PU dressing tool and dressed top of 9-5/8" stub. Ran casing collar log with ~chlumberger. RIH w/casing cutter and spear.. Cut casing at 1,337'. Laid down cut piece of :asing. Dressed top of 9-5/8" casing. Changed and tested 9-5/8" BOP rams. Ran 9-5/8" 47# SOO- }5 buttress casing with Joy/ARCo casing patch. Engaged stub and pulled 250,000# over string ~eight. Pressure tstd csg patch to 3000 psi. OK. Installed and tested 9-5/8" packoff. RIH and )pened F.O. tool at 1,291'. Set RTTS pkr at 1,285'. Circulatedo165 barrels of 9.5 ppg Arctic ~ack w/49.5#/barrel Geltone added in 9-5/8" x 13-3/8" annulus. 0% contamination in final returns. ;losed F.O. and pres tstd to 3000 psi. RIH w/8½" bit ~conditioned mud to top of BP @ 9029. Tstd :sg to 3000 psi OK. Drilled up .EZ drill retainer, Ran 8½" bit and casing scraper. .Conditioned hud. Thawed 20"x30" annulus to 35 feet. Encountered gravel bridge. Placed Super Pack in 20"x30" ~nnulus. Changed to 5½" pipe rams and tstd BOPE. Ear~5~-~7# MN-80 LT&C A-B Modified tubin ~/Baker SAB pkr set at 8,934', ball valve nipple~'~ 2'171]~,~ Tstd tubing hanger to 5000 psi.g )ropped ball and set pkr. Found tubing hanger dama~d-~-~l~r~placed and retested tubing hanger. ~ressure tstd control and balance lines. Tstd 5½" x 9-5/8" annulus to 2000 psi, OK. ND BOP. NU ~nd test tree to 5,000 psi. RIH and pulled dummy ball valve. Ran GR/CNL/CCL. Opened sliding ~leeve. Displaced tubing w/205 barrels of warm diesel. Closed sliding sleeve. Ran and set ball /alve. Secured well and rel~a~_d ~g ~.t 0600 hrs March 26. !977. 16. I hereby cert~Lfy that the foregoing is true and correct S'GNED_~~? ~ TITLE District Drilling Engineer DATE.,/~/~/>:A? (This space for State office use) APPROVED BY CONDITIONS OF APPROVAL, IF ANY.' TITLE DATE .... See Instructions On Reverse Side .,~ompany North Ame. ~ Producing Division · _ September 13, 1971 State of Alaska Department of Natural Resources Oil & Gas Division 3001 Porcupine Anchorage, Alaska 99504 ATTENTION: Mr. Homer Burrell RE: Drill Site #1, Well #2 ( 32-7-10-15 ) Dear Sir: Attached is a P-3 Subsequent Notice of repairing the above mentioned well. Very truly yours, B. T. Loudermitk Dist. Drlg. Supervisor ~T~,/WTJ/mm Enclosure: Ic. ~EOf'l~ I c. m~ [~1 ~ I ,EN~ '1¥~ I 3 ENO },~_\ J 4 J 5ENG J -I ~ '~°~" I ~ . .~ ~ REV I' ID,A~ I Is~cI CONFER: FILE: AI',4CHORAG~ ~i' Form P--3 REV. 9-30-6 9 r, Smbmtt "Intentions" in Triplicate & "Subsequent Reports" in Duplicate STATE O'F AL~KA OIL AND GAS CONSERVATION COMMITTEE SUNDRY NOTICES AND REPORTS ON WELLS (Do not use this form for proposals to drill or to deepen use "APPLICATION 'FOR ~'El]~%/iI'['~." 'for such'pi:o~)osal$.) · WELL WELL OTHER 2. NA3IE OF OPERATOR Atlantic Richfield Company 3. ADDRESS OF OPERATOR P. 0. Box 360, Anchorage, Alaska 99510 4. LOCATION OF WELL At surface 193' S & 1356' Efr NW er Sec. 8, T10N, R15E, UM 13. ELEVATIONS (Show whether DF, RT, GR, etc. 73' KB Check Appropriate Box To Indkate N, ature of NOtice, Re NOTICE OF INTENTION TO: FRACTURE TREAT MULTIPLE COMPLETE SHOOT OR ACIDIZE ABANDONS REPAIR WELL CHANGE PLANS ~Other) 5. AP1 NUIVIF_,RICAJ., CODE 50-029-20053 6. T.F.A~F. D~GNATION A.ND SERIAL NO. ADL 28329 7. IF IN-DIA.N. AT.I-O'I'I1~-'~- OR TRIBE NAM~,~ 8. UNIT, FABNi OR T.~.~.SE NAME ' pr~ahoe Bay 9. W~.T- NO. I),5. #1-2 (R2-7-10-15) 10. FT~.T.V) A~T) POOL, OR WILDCAT Prudhoe Bay-Sadlerochit Pool 11. SEC., T., R., M., (BOTTOM HOI~ OBJECTIVE) Sec. 7, T10N, R15E, UM 12. PERMIT NO. ~or~, or Other D~t~ ' WIT,, SHUT-OFP [~ REPAIRING WELL ~ FRACTURE TREATMENT ALTERING CASING SHOOTING OR ACIDIZING , . ABANDONMEIffT$ (Other) (NOTE: Report results of multiple completion on Well Completion or Recompletton Report and Log form.) 15. DESCRIBE PROPOSED OR COMPLETED OPERATIONS (Clearly state all pertinent details, and give pertinent dates, including estimated date of starting any proposed work. Began operations 8-22-71. Killed well w/reverse circulation 3:00 AM 8-23-71. ND tree & NU BOPE. Tested BOPE w/5000# OK. Tested Hydril w/3000# OK. Ran 4 arm caliper & collar locator from 2000' to 30' RKB. Ran & set E-Z drill plug @ 9204'. Set 75 'sx Class "G" cement plug w/top ~ 9015' Cut 9-5/8" casing ~ 1225'. Pulled 28 its 9-5/8" casing. Ran 4 arm caliper log & C~L in 9-5/8" & 13-~/ · Cut 13-3/8" ~ 485'. No recoverT. Cut 13-3/8" @ 90' - ~ ~8" * Pulled 466' 72# N-80. Ran 4 arm caliper & collar locator, on 20" casing. Cut 20" casing i 8" ~ 80'. Ran 24" patch skirt on one jt 20" Vetco casing. Ran~ 3-3/ casing patch, cement stage collar & 3 its 16" skirt made up above stage collar. Tied. into 13-3/8" stub & tested w/1500 psi OK. Dropped bomb.. & opened stage tool. Circulated & cemented w/600 sx Fondu Neat cement. Bottom 16" skirt ~ 680', top of patch ~ 586'. Cut 9-5/8" casing ~ 1325'. Recovered 100' (2 jts) 9-5/8" casing & patch. ~R~_/4%-hole to~.~:?.QO0'. Closed Hydril & tested casing w/1500 .psi OK. ND BOPE & NU tr/~. Suspended well Released Rig ~ 12:00 Midnight 9-9-71. 16. I hereby certify th~the foregging tg tr~e &n~d correct SIGNED ~' /'~f' ;" ~ TITLE Dist. Drlg. Supervisor DATE (This space for State office use) APPROVED BY CONDITIONS OF APPROVAL, IF AN~: TITLE See Instructions On Reverse Side DATE Form P--3 ~ REV. 9-30-6? STAT[ OF ALASKA Submit "Intentions" in Triplicate & "Subsequent Reports" in Duplicate OIL AND GAS CONSERVATION COMMI'I-I'EE SUNDRY NOTICES AND REPORTS ON WELLS (Do not use this form for proposals to drill or to deepen or plug back to a diffierent reservoir. Use "APPLICATION FOR PF_.KNIIT--" for such proposals.) APl NUME~CAL CODE 50-029-20053 $. I_EASE DESIGNATION AND SEE ADL 28329 7. IF INDIA.N, A.LJ-~ OR TR.[ 0IL ~ GAS ~-I WELL WELL OTHER 2. NA1VIE OF OPERATOR 8. UNI~ FA/{Ni OR LF_.~SE NAME Atlantic Richfield Company Drill Site #1-~ 3. ADDRESS OF OPERATOR 9. WELL NO. P. 0. Box 360, Anchorage, Alaska 99501 32-7-10-15, f. 4. LOCATION O,F WELL At surface 193'S & 1356'E fr NW cr Sec 8, T10N, R15E, UM 13. ELEVATIONS (Show whether DF, RT, GR, etc. 73'KB 10. FIELD A~TD ]FOOL, OR WYL,DC Prudhoe Bay Field 11, SEC., T., R., M.. (BOSOM O~E~IVE ) Sec 7, T10N, R15E, UM 12. PEH/VIIT i~O. 69-119 Check Appropriate Box To [nd',i,cate Niature of N~oti'ce, Report, or Other 'Data NOTICE OF INTENTION TO: FRACTURE TREAT I I MULTIPLE COMPI,ETE SHOOT OR ACIDIZE ASANDONs REPAIR WELL CHANGE PLANS (Other) Revise Test Procedure SUBSEQUENT REPORT OF: FRACTURE TREATMENT ALTERING CASING SHOOTING OR ACIDIZINO ABANDONMEBfT* (Other) Current us NOTE: Report r~sults of multiple completion on Well ompleti~n or, Recompletton Report andLog form.) 15. DESCRIBE PROPOSED OR COMPLETED OPERATIONS (Clearly state all pertinent details, and give pertinent dates, including estimated date of starting an.y proposed work. The decision was made to eliminate the lengthy test procedure submitted July 28, 1970, and approved July 29, 1970. While in the process of checking out equipment prior to cleaning up and testing the well, it was determined that the packer had failed. The well was shut in pending a remedial decision. Injection of residual from our crude oil topping unit operation will continue in the Sag River State Well No. t until further notice. 16. I hereby certlf~ that :-the forejotnl~ is true and correct TITLE No. Dist. Sr. Prod. Supvr. DATE January 6, 1971 (This space for State office use) APPROVED BY CONDITIONS OF APPROVAL, IF ANY: TITLE DATE See [nstrucfions On Reverse Sid,e ........~-'~ AtlanticRichfieldCompany North Ame~ Producing Division Alaska Di~ Post Office ~,X 360 Anchorage, Alaska 99501 Telephone 907 277 5637 October 7, 1970 State of Alaska Department of Natural Resources Oil and Gas Division 3001 Porcupine Drive Anchorage, Alaska 99504 Attention: Mr. Homer Burrell Dear Mr. Burrell: Attached please find a P-3 form for repairing Well #2 at Drill Site 1 (32-7-10-15). Very truly yours, C. R. Knowles Senior Drilling Engineer CRK: 11 Enclosure REV. 9-30-69 STATE OF ALASKA OIL AND GAS CONSERVATIO.N COMMITTEE SUNDRY NOTICES AND REPORTS ON WELLS (Do not use this form for proposals to drill or to deepen use "APPLICATION 'FOR ~'EP,~ilT-2-'' '~or such 'pt~o~)osals,) · . 1, oi, ,~ GAs 7q WELL WELL 0TH~:R 2. NAME OF OPERATOR Atlantic Richfield Company 995Ol 3. ADDRESS OF OPERATOR Box 360~ Anchorage, Alaska 4. LOCATION OF V~F_.LL At sur£ace 193' S & 1356' E fr EWcr Sec. 8, TiON, R15E, UM 13. ELEVATIONS (Show whether DF, RT, GR, etc. 5. API N~CAL CODE 50-029-20053 6. LEASE DESIGNATION A. ND SERIAL NO. ADL 28329 7. IF IN-DIAN, AJ~LO'A-rI~E OR TRIBE NANI_E 8. UNIT~ FA. RNI OR LEASE NAiVIE Prudhoe Bay 9. WELL NO. 10. FLELD AND POOL, OR WILDCAT Prudhoe ~y-Sadlerochit Pool 11. SEC., T., R., M., (BOTTOM HOLE OBJEC'TIVE) Sec. 7, TiON; R15E~ UM 12. PEE.M/T NO. j 69-]]a Check Appropriate Box To lndi,cafe Nature of NOtice, Report, or Other Dafa ' NOTICE OF INTENTION TO: TEST WATER SHUT-OFF PULL OR ALTER CASING FRACTURE TREAT MULTIPLE COMPf,ETE SHOOT OR ACIDIZE ABANDONs R£PAIR WELL CHANGE PLANS ~Other) SUBSEQUENT REPORT OF: WATER SIIUT'OFP REPAIRING WELL FRACTURE TREATMENT ALTERING CASING SHOOTING(0ther) 011 ACIDIZING -- ABANDONMEN'T* (NOTE: Report results of multiple completion on Well Completion or Reeompletion Report and Log form.) I5. L)k'SCRIBE PROPOSED OR COMPLETED OPERATIONS (Clearly state all pertinent details, and give pertinent dates, including estimated date of starting any proposed work. RIG IN PLACE @ 6:30 AM 8-16-70 Removed x-mas tree, installed BOPE~ tstd BOPE w/4800 psi. Swedged out tubing~ circulated & killed well on btm. Cut & recovered tubing @ 1770'. Cut & recovered 9-5/8" csg @ 1317'. Ran qP-1/4" bit through 13-3/8" csg & pressure tested to 2000' psi OK. Tied back 9-5/8" csg & tested OK to 2000 psi. Pulled 9-5/8" pkr and 2-3/8" tubing. Ran 4-1/2" tbg on 9-5/8" pkr and set @ 9251'. Ball Valve @ 1843'. Removed BOPE~ installed x-mas tree. Tstd tree w/5000 psi for 30 rain OK. Left well filled w/141 bbls diesel. Released Rig @ 10:O0 PM 9-12-70. CONFIDENTIAL ,,,,' ~K';,'.bl OF C'~. Ab~9 GAS ANCf,'.iORAG~ 16. I hereby certify that the~0i~s true and correct (This space fOr State ~use) TITLE District Drilling Supervis O~DATE ./~7 ~'z~ -- ~/~ ., APPROVED BY CONDITIONS OF APPROVAL, IF ANY: TITLE DATE See I:nstrucfions On Reverse Side ApprOVal Copy R~ned~/ ~ ,AtlanticRichfieldCompany North Am Producing Division , Alaska District Post Office Box 360 Anchorage, Alaska 99501 Telephone 907 277-5637 August 7, 1970 State of Alaska Department of Natural Resources Oil and Gas Division 3001 Porcupine Dr~ve Anchorage, Alaska 99504 Attn: Mr. Homer Burrell Dear Sir: Attached please find a P-3 form for the proposed workover of DS #1-2 (32-7-10-15). Very truly yours, C. R. Knowles Senior Drilling Engineer CRK:cs Enclosure RECEIVED AUG 10 1970 DIVISION OF OiL AND GAS ANCHORAGE Form REV. Submit "Intentions" in Triplicate & "Subsequent Reports" in Duplicate STATE OF ALASKA OIL AND GAS CONSERVATION COMMITTEE SUNDRY NOTICES AND REPORTS O'N WELLS (Do not use this form for proposals to drill or to deepen or plug back to a diffierent reservoir Use "APPLICATION FOR PERMIT--" for such proposals.) 5. API N~CAL CODE 50-029-20053 6. LEASE D~IGNATION A_ND SERIAL NO. ADL 28329 2. NAME OF OPERATOR Atlantic Richfield com~an~ 3. ADDI~ESS OF OPERATOR P.O. Box 360, Anchorage, Alaska 99501 4. LOCATION OF WELL At surface 193'S & 1356'E fr NW cr Sec. 8, T10N, R15E, UM 13. ELEVATIONS (Show whether DF, RT, GR, etc. 73'KB 7. IF INDIA-N, AT.T,O'J.-I',tt;I~ OR TRIBE NAM~ 8. UNIT FA.R1VI OR T .F, tSE NAME Prudhoe Bay 9. WELL NO. Ds #1-2(32-7-10-15) 10. 1,'[~:,' .r~ AiND POOL, OR WILDCAT Prudhoe Bay-Sadlerochit Pool 11. SEC., T., R., M., (BOTTOM HOLE OBJECTIVE) Sec. 7, T10N, R15E, UM 12. PEI~/VIIT NO. 69-119 ~ort, or Other 'Data Check Appropriate Box To I~nd, i'cate Nlature of N~oti'ce, Re, NOTICE OF INTENTION TO: TEST WATER SHUT-OFF ~ PULL OR ALTER CASING I 1 FRACTURE TREAT MULTIPLE COMPI,ETE SHOOT OR ACIDIZE ABANDON$ REPAIR WELL CHANGE PLANS (Other) SUBSEQUENT REPORT OF: FRACTURE TREATMENT ALTERING CASING SHOOTING OR ACIDIZING ABANDONMENT* (Other) NOTE: RePort results of multiple completion on Well ompletion or Recompletlon Report and Log form.) 15. DESCRIBE PROPOSED OR COMPLETED OPERATIONS (Clearly state all pertinent details, and give pertinent dates, including estimated date of starting an}' proposed work. ' While preparing this well for injection (as approved on Form P-3 on 7-29-70), we found indications of partially collapsed 4 1/2" tubing. We propose to swage out the tubing, kill the well on bottom w/85# oil base mud, retrieve the tubing and packer and set a bridge plug ~ 9200'· We will then inspect and, if necessary, repair the casing strings. We plan to recomplete this well with 7" tubing set in a packer. Work will start on 8-14-70. CON F IDENTIAL CONDITIONS O~ ~,PPROYAL, IF ANY: Dist. Drlg. Supvr. TITLE Chief Petroleum TITLE See 1,nstrucfions On Reverse Side DATE Approved Copy Returned ,.__ FORM SA- lB MO ANDUM TO: I- Homer L. Burrell Director ·, State of Alaska /' DEPAR~ OF NA~URAL~ RESOURCES DIVISION OF OIL O. K. Oilbreth, Jr. Chief Petroleum Engineer THRU: FROM: Lonnie C. Smith ~'~, Petroleum Engineer~cA,?~/.~.. _ DATE : August 7, 1970 SUBJECT: . Field Trip Report.- Witness BOP Test. and Flowing Test on North Slope On July 29, 1970, I departed Anchorage by commercial air carrier, arriving Deadhorse at approximately 1:10 p.m. I went to the Mukluk base camp and checked out the contract vehicle. I was informed that the radio, survival gear box and beacon had arrived for our vehicle but had not as yet been in~ stalled, and it would be several days before installation could be accomp- lished. After departing the Mukluk camp for the ARCO base camp and proceeding about three-quarters of"a mile the pickup ,died from fuel starvation. The mechanic at the Mukluk garage determined that debris in the 125-gallon extra fuel tank was the problem and this tank would have to be cleaned when time allowed and the tank could be emptied. The fuel lines were cleaned and I proceeded to drive the vehicle using only the 20-gallon 'tank for gas supply and filled this tank by hand pumping fuel from the 125-gallon 'tank. When I returned from the North Slope on Wednesday, August 4, I had used approximately 40 gallons of gas and driven the vehicle 227 miles (last odometer reading 1536). Mukluk agreed to have .all additional equipment installed and the gas tank clean prior to our next trip to the Slope. I checked in at the ARCO base camp at approximately 3 p.m. with Langdon Kelly the ARCO production manager. Mr. Kelly informed me that the well test had been delayed slightly because of their inability to pull the check valve from the downhole safety shut-in valve mandrel in Drill Site 1-3 (Well No. 32-7-10- 15) and the equipment was now being rigged up on Drill. Site 1-2 (Well No. 32- 8-10-15) so that entry of this well's tubing could be checked. I also talked to Mr. Kelly about witnessing the next BOP test on the Drill Site 1-5 well now drilling. I then drove some of the roads and visited many of the well sites in the area before proceeding back to Prudhoe Bay and checking into the room at 9:30 p.m. On Thursday, July 30, I checked with the production crew on Drill Site 1-2 and 1-3 and found that they were still having difficulty in getting Wire- line tools into the proposed injection well (1-3), but had successfully passed thrpugh the tight place in the 1-2 well with some smaller tools. was told there was a ~rost buildup, or icing, at 143 feet. I met .the drilling supervisor for Drill Site 1, Mr. Bob Hines, and witnessed the last part of a BOP test on Well No. 1-5 (Well No. 23-9-10-15). The well's current depth was 11,353 feet. · The hydril had been tested to 3,000 psi while the blind rams, pipe ra__m~_, choke manifold and the kellycock valves were tested to 5,000 psi (check list attached). Homer L. Burrell -2- August 7, 1970 I again checked with Carl Robinson the ARCO production foreman at Drill Site 1-3 on the progress of the work on the test wells and they were still unable to enter the tubing deep enough to pull the valve from 1-3 and were waiting on additional tools whichwete to arrive on the plane the next day; however, they still indicated to me that the trouble was icing inside the tubing. I visited ARCO's Drill Site No. 2 and met Mr. Ike Huvall,-the d:illin§ supervisor, and discussed with him the operation of their well (DS 2-3, Well No. 23-31-11-15). They were drilling the surface hole and expected to be setting the 20-inch surface casing by Sunday. We made arrangements so that he would attempt to contact me prior to the testing of the BOP a£ter he had rigged up his 2,000 psi stack on the 20" casing. It would possibly be the middle of next week before this test would be ready. On Friday, July 31, ARCO received and ran the additional tools in DS 1-3, which consisted of impression blocks and swedges for the tubing. They were apparently unsuccessful in working past the tight place at 143' and ceased operations. Saturday, August 1, Langdon Kelly informed me that ARCO had temporarily cancelled the test program until further study of the tubing problem could be evaluated, and investigated. I checked out of the ARCO base camp at 9 a.m. and proceeded to Deadhorse to check with Mobil (see Hobil BOP report on Pad 37, Kuparuk State Well No. 33-11-12, dated 8-7-70) · · Attachment Sat i sfactory I tam Yes ~;o () ( ) .(v) ( ) () () Ramarks: Drii ling Petrol t Number ..-...-,-'.. Satisfactory · ;' ..:. Yes .:-,,, No - ,.:.... 1. Well Sign ':'.",. '";';-:.::' .:'. 'll,~ ~lnnlfold P~ol~uPa 2, ~afocy Volvo~-~loo, . IA.. 'BOP Pressuea Tess 3, .Safety Valves-Kelly ':'..:.;?/;' ('~;'"';"~k ~'";': 13, Reserve 4, Select Valves-Subsurface:.-::" (~'.~::.;.- · ]~, Pit 8erin :- 5, BOP Closing STstem :.:--.'i?:.(~c--~.: ( ).' 15, Location Berm ' ' 7. Dri lllng Spool-outlets~'::~:'~?:.':~: (~)~.:.:.:~:.( ) - 17, Ope~aCi~s off "Pad':' es "'" ........ '"""' ~:(~;.' 19, Abd, Harker in p lac~ lO' ' ~enlfold Chokes ":"":"""~"':"~ "~~ ZO, ~e~er ~ell c~vered: .. .... Contr, Rig' No, .. "1 t~m · ' .... Dril ling Permit' Operator .......... Well Name & No. .... Number ......... ,, · , , _ - ......... , 11 11 ,,, Inspected by _ . Operator's Rep_,_. - Contr. <.,~ ..... mlmmm -- -- , · - - -- Satisfactory item Yes () () I, () () 2. () () () () () () 5. () () 6.' () () 7. () () () () () () 10.' Well Sign '>" Safety Valves-Floor . · Safety Valves-Kelly Safety Valves-SubsurfaCe.:.. BOP Closing System., Remote Controls . Drilling Spool-out: Flo~ Lines , .!.: -.?. .... · . .:..., '. t<i 11 Li Man i fo I d Chokes . · '" Rig No. . Sat i. sfactory' Yes ( ) ;...:. 'Item , . ., (') : : L~OP Pressure Tes~ . ( ) :;":..:::: geserve P i ( )"::~::;'/::.( )'"-,,' 15, Location Berm ( ) ~":~:'.;. (')" 17,: Operations off "Pad" ( )";').:.( )."'. 18,' ~General Housekeeping" ( ) .-".:::.~ (")" '1~, Abd, ~arker in place (). '":'( ) gO, Water ~all covered . Remarks i -. : .... i .......... i ........ i ......... P · : .' :, · .. · , . . ,',. ...,- : ...,....,,,..:.'?: j ",': ;. .-:..:,.,.-:: ...- .~ .,: ~ ~ ."...,': ::". .- : .:. ',, ,:..,-: .,. ,, ..,., '~ .' .- ..... - ....... , .,. .......... : ....... :~:.:.,.-~:-. ,:Jif: . ..~,'z. :/.'- ..:..,J.L'&:L~:~',..~.':, .:.-.....'<';~.~-~...;,~,~~z~;,'¢~.~T:;~,:~.:~,~,'..~,~;~ *~*~¢,..'~.~;~:,,~.~: r- - ' ~' - P~EV. 9-3069 STATE OF AL~KA 8abrntt "Intentions" in Triplicate & "Subsequent Reports" in Duplicate OIL AND GAS CONSERVATION. COMMII~EE SUNDRY NOTICES AND REPORTS ON WELLS (Do not use this form for proposals to drill or to deepen Use "APP-LIC.a-TION 'FOR ~'El~I'r-2'' 'for such 'pi;o~osaL~.) . . WELL WELL OTHER 2. NAME OF OPERATOR Atln.ntic Richfield Compn._~y 3. ADDRESS OF OPERATOR P. 0. Box 360} Anchorage, Alaska ~01 4. LOCATION OF V~F_J~L At sur£ace 193'S & 1356' E fr NW er Sec 8, T10N, R15E, UM 5. AP1 NU~C.aL CODE 50-029-20053 6. LEASE DEC~IGNATION A. ND SERIAL NO. ADL-28329 17. IF II%UDIA/%I, AJ_J~O'i-i'~E OR TRIBE NA/VLE 8. UN~T, r~ OR L~*SE NA~E l)ril] Site #] 9. w~-,.L NO. 32-?-10-15 10. FIELD ~ P~L, OR WI~CAT 11. SEC., T., R., M., ~BO~M O~E~IVE) Sec -7, T10N, R15E, 13, ELEVATIONS (Show whether DF, RT, GR, etc. !12. PEP, MIT NO, 73' KB I 69-119 14. Check Appropriate Box To Indi,cate Nature of N~ti'ce, Report, or Other Data NOTICE OF INTENTION TO: TEST WATER SHUT-OFF I I ] ]1 I PULL OR ALTER CASING FRACTUaE TREAT MULTIPLE COMPI,ETE SHOOT OR ACIDIZE I ] ABANDONS REPAIR WELL ] [ CHANGE PLANS ~Other~ Revise Test Procedure SUBSEQUENT RlePORTOF: WATER SIIUT-OFF __ REPAIRING WELL FRACTL'RE TREATMENT ALTERING CASING SHOOTING OR ACIDIZING ABANDONMEKTs __ (Other) (NOTE: Report results of multiple completion on Well Completion or Recompletion Report and Log form.) 15. DESCRIBE PROPOSED OR CO,MPLETED OPERATIONS (Clearly state all pertinent details, and give pertinent dates, including estimated date of starting an}' proposed work. The test procedure submitted on Form P-3 July 1, 1970, and approved July 2, 1970, has been shortened and will be performed as ~hown on the attached procedure. Estimated starting date of the test is July 29, 1970. RECEIVED JUL 28 19iu DIVISION OF OiL Ai'~D ANCHORAGII 16. I hereby certffy~J~a.t the foregoin~ is true and correct (This space for St~te office ~ CONDITIONS OF XPPROV~-L, Ir AN'~': ~ ' TITLE Sr. Dist. Prod. Supervisor DATE July 28, 1970 TITLE / / See Instructions On Reverse Side Approved Copy Returned D.S. NO. 1-2 .( 32-7-10-15 .WELL TEST PROCEDURE 1. Check and record all tubing, tubing-casing annulus and casing-casing annulus pressures. 2. Bleed any pressure off of tubing-casing annulus and check to see that annulus ball valve is holding. 3. Retrieve 4½" input safety valve from tubing. 4. Run 4½" ball valve in tubing. 5. Open tubing and tubing-casing annul.us ball valves. 6. Run 1.750" gauge ring on bottom of 15' dummy string of tools throuc~h tubing from surface to PBD. 7. Run 3 Sperry Sun (SS) pressure bombs in tandem on wireline and hang (a 9322 . (While going in hole, pick up every 1000' to assure that tools are free.) 8. Open tubing-casing annulus to flow and clean well to pit. 9. Lower pressure bombs to 9482'. 10. Open tubing to flow and continue cleaning well to pit. ll. After cleanup, turn combined flow stream (tubing and tubing-casing annulus combined) to test separa'tor (400 psig operating pressure) at the final cleanup flow rate. Record Combined flowing rate, flowing temperatures, and flo~wing pressures. (Flow period through test separator should be as short as possible.) 12. Shut well in for 48 hours. Record reservoir pressure buildup. Check test separator and clean out if necessary. 13. Retrieve pressure bombs making gradient stops at the f611owing measured depths' 9162', 8631', 7547', 6426', 5276', 4126'. , 3073', 2073', 1873' 1073' . , and surface 14. Run 3 SS pressure bombs in tandem and hang at 9482'. 15. Open well at lowest possible stabilized flow rate (200 to 500 BOPD)' for 24 hours and collect surface separator samples as follows: 3- 9 gal stainless steel cylinders oas 3- 1 gal' cylinders liquid 2 - bbls STO 16. During above sampling period record' ~ ~ ~' ~! V ~ D a. Crude oil flow' rate, BPD b. Gas flow rate, MCFPD c. _Water cut d. Oil' gravity, OAPI e. Gas gravity - Ranorex gravity balance Revised 7-23-70 '~6.S.'No. 1-2 (32'7'(~d-15) Well Test Procedure Page 2 of 2 16. f. Acid gas es' (1) H2S"- Draqer Instrument (2) H2S - Cd SO4 method - NGPA 2265-65 (3) Mercaptans - Drager Instrument (4) CO2 -Draaer Instrument (5) Total aci~] gas -Orsat g. Flowing temperatures and pressures at wellhead and separator. Tem- peratures and pressures at wellhead to be continuously recorded. 17. Shut well in for a minimum of 6 t~ours. · 18. Retrieve pressure bombs making gradient stops at the following measured depths' 9162' 8631' 7547' 6426" 5276' 4126' 3073' 2073' 1873' 1073' and surface. '! 19. Run bottom hole sampler with Amerada pressure gauge. Obtain a minimum of 4-600 cc bottom hole samples. ,. 20. Retrieve tubing ball valve. 21. Run 4½" input safety valve in tubing. 22. Test hydraulic control line and close tubing-casing annulus ball valve. 23. Bleed pressure off of tubing and tubing-casing annulus and shut well in. 24. Tie w~ll into 4" residual injection line from COTU. RECEIVED JUL g8 1970 I~iVI$1ON OF OiL AND OAS Revised 7-23-70 AtlanticRichfieldCompany North Americ~""s roducing Division Alaska District Post Office Box 360 Anchorage, Alaska 99501 Telephone 907 277-5637 July 14, 1970 state'.Of Alaska Department .of Natural Resources 0il and GaS Division '3'001 PorcUpine 'Drive ~ AnchOrage,' Alaska' 99'504 .Attention: Mr. Homer~ Burrell~' Gentlemen: As reqUested,.attached'is a.schematic diagram.shoWing the inhole Completion asSembly in'Drill Site No; 1-2 . (.32-7-10,15) for.attachment.to.our.FormP-3.1Submitted. July 1,:1970.. You wi!l note.that.we'Propose.to remove one SafetY valve and install a back CheCk. at that : position, and leave the SecOnd safety valve in place in the'Closed position. VerY'truly yours, J. M, Tricke~' Sr. Dist. Prod. SuperVisor JMT: pa Enclosure RECE!VEO. DIV',$1ON O~ OIL AND GAS ANCHORAGE t Safety Valve removed'and back check installed ,. Safety Valve instailed'' in closed position ! ,/:' PBD 9817' 9-5/8"- 40tt, a3.5tt, 47// S00-95 Casing (a 9877' ~? PRUDHOE BAY FIELD 2. Ro~:l:woll f) 5/P, X 4b l'li ' 1.5r' 3. 4;~" i)uttre~s Pup Joint 2.3F, 4.._ 63 its ~'.~" 12..6// N-SF) Buttress 'Tuhing 5 a:~" 12 G" N-AO llydril Pup Joint 6'.. Otis 9 5/F1 X ab" Dual Nipple.Twin Flow Con- verter,..JH Hydraulic -. Packer Hookup' - . 7. Otis ~' 7/R" STidino · ,.~ '- -" sleeve ' . , t~. 2 7/8" EU 8rd Pup Jt. 9.. Otis 2:-313 ID N Landing Nipple and Reverse Flow , Check lO. 239 Joints 2 3/8" N-80 Buttress Tubing Il. Otis 1.875 ID N Landinq Nipple ~w/1.791 ID 12.' Otis 2' 3/8" Shear-out Sub A- 4" Otis Ball Valve 1R53.22 19.90 B. 4" Otis Flow Tube C -'"'4" Otis Input Safety Valve. 28.69 2.65 4 2.25 7406.65 D - Otis Sleeve i · · .62 .97 Pei-forations: (l,- ~.~" spf 9455- - 94a5_[ 9J95- 9525 9545,- 9575 95,q5 - 9615 ,-'~ i! ' ~ ' . · ': .:. _ V.7 '::~' : · "':, :'L': [ ' ' DivIsION OF OIL AND OAS t.1~. ~' E'CEIVFD JuL 14_- ig'i 9342.. Z.l, Form REV. Submit "Intentions" in Triplicate & "Subsequent Heports" in Duplicate STATE OF ALASKA Oil AND GAS CONSERVATION COAAMI~EE SUNDRY NOTICES AND REPORTS ON WELLS (Do not use this form for proposals to drill or to deepen or plug back to a diffierent reservoir. Use "APPLICATION FOR PEI~MtT--" for such proposals.) OIL [] OAS ~] WELL WELL OTHER 2. NAME OF OPERATOR At ln.~t i e Ri ehfi eld 'Company 3. ADDRESS OF OPERATOR P. O. Box ~60~ Anchorage~ Alaska 99~01 4. LOCATION O,F WELL At surface 193'S & 1356' Efr NW cr Sec 8, TiON, R15E, UM 5. API 1N-UNIEH~CAL CODE 50-029-20053 6. T.~.A~E DmTGNATION AND ADL-28329 ?. IF INDIA.N, .~r.T.O'l-l'~:~: OR 8. UNIT, FA,TM OR T.P,A.gI~. NAiVIE 9. W~,T~ 10. F~ s:l ,r) AND FOOL, OR WIIA)CAT 11. SEC., T., R., M., ( HOLE OBJECTIVE) 13. ELEVATIONS (Show whether DF, I~T, GR, etc. 73' KB 69-119 14. Check Appropriate Box To [ndi'case Nlature of N~oti'c'e, Report, or .Giber 'Data NOTICE OF INTENTION TO: FRACTURE TREAT MULTIPLE COMPI,ETE SHOOT OR ACIDIZE ABANDONS REPAIR WELL CHANGE PLANS SUBBEQUENT REPORT OF: WATER 8IIUT-OFF ~ REPAIRING WELL FRACTURE TREATMENT ~ ALTERING CASING SHOOTING OR 'ACIDIZING ABANDONMENT* (Other) (NOTE:'Rep0rt .resUlts'of multiple completion on Well (Other) Commence,I, nri ectio~ Completion or Recompl~tioii"Report and L,og form.) iii, . 15. DESCRIBE I'ROPOSED OR COMPLETED OPERATIONS (Clearly state all pertinent details, and give pertinent da/es, iineluding 'estimated dat~ of startin~ any proposed work, After completion of previously approved clean up andres% Work, this well'~will be utilized to provide the residual injection well requir'edfor our topping~nit operation. Injection will be in compliance with existing state of Alaska, orders, rules and regulations. Estimated date of initial injection is August 1, 1970. ANCk~O~AG~, cos.moss or ~,/,~0VAL, ~ A~: ' / - TITLE Sr. Dist. prOd. Supervisor DATE See instructions On Reverse Side July 10, 1970 Approved Cop') Returned Form P--.~ REV. 9-~67 STATE OF ALASKA Submit "Intentions" in Triplicate & "Subsequent Reports" in Duplicate OIL AND GAS CONSERVATION COMMrI-I'EE SUNDRY NOTICES AND REPORTS ON WELLS (Do not use this form for proposals to drill or to deepen or plug back to a diffierent reservoir. Use "APPLICATION FOR PEI~NIIT--" for such proposals.) OIL WELL WELL OTHER 2. NAME OF OPERATOR Atlantic Richfield Company 3. ADDRESS OF OPERATOR P. 0. Box 360~ Anchora~e~ Alaska 99501 4.LOCATION O,F VFELL At surface 193' S & 1356' E fr NW CE Sec 8, T10N, R15E, UM 13. ELEVATIONS (Show whether DF, I~T, GR, etc. 73' KB 14. Check Appropriate Box To I~n,cJi'cate Nlature of N~oti'ce, Re, NOTICE OF INTENTION TO: TEST WATER SHUT-OFF I I FRACTURE TREAT SHOOT OR ACIDIZE REPAIR WELL (Other) Test Well PULL OR ALTER CASING MULTIPLE COMPI.ETE ABANDON* CHANGE PLANS 5. AP1 NI/MIIRICAL CODE 50-029-20053 6. ~E DESIGNATION A-ND SElqff~a_L NO. ADL-28329 ?. IF INDIA_N, ALIX)'i-r.:~: OR TRIBE NAME 8. UNIT, FAB.Bi OR LEASE NAME Drill Site #1 9. w~L NO. 32-7-10-15 10. F~.D ~ POOL, OR WILDCAT Prudhoe Bay Field~ Sadlerochit 11. SEC., T.. R.. M., (BOTTOM HOLE OBJECTIVE) Sec. 7~ T10N~ R15E~ UM 12. PEP./VIIT I~O. )or~, or Other Data SUB,SEQUENTREPORT OF: WATER SHUT-OFF ~ REPAIRING WELL ~J FRACTURE~ TREATMENT ALTERING CASING SHOOTING OR ACIDIZING ABANDONMEIqT$ (Other) NoTE: Reporl results"of multiple completion on Well ompletion Or Recompletion Report and Log form.) 15. DESCRIBE PROPOSED OR COMPLETED OPERATIONS (Clearly state all pertine,~t details, and give pertinent dates, including estimated date of starting an}' proposed work. . Propose to test well according to the attached procedure for the purpose/of obtaining necessary engineering data and cleaning up prior to use as, an injection well, if approval requested under separate cover is granted' Test date is expected to be about July 10, 1970. 16. I hereby certify that ~the foregoin~ is true and correct TITLESr' Dist. Prod. Supervisor DATE July 1, 1970 (This space for State office use)/ CONDITIONS OF APPROVAL, IF ANY: The Division of Oil and Gas will be further notified at least 2.4 hrs. prior to commencement of this test so a witness from this of~,ice may be present during the See Instructions On Reverse Side testing. D.S. NO. 1-2 (32-7-10-15~ WELL TEST PfiOCEDURE 1. Che~k and record all tubing, tubing-casin.~.,~nnulus and casinq-casing annulus pressures. 2. Bleed any pressure off of tubing-casing annulus and check to see that annulus ball valve is holding. . 3. Retrieve 4½" input safety valve from tubing. 4. Run 4½" ball valve in tubing. 5. Open tubing and tubing-casing annulus ball valves. 6. Run 1.750" gauge ring on bottom of a 15' dummy string of tools through tubing from surface to PBD. 7. Run 3 Sperry Sun (SS) pressure bombs in tandem on wireline and hang ~ 9300'. (While going in hole, pick up every 1000' to assure that tools are free.) 8. Open tubing-casing annulus to flow and clean well to pit. 9. Lower pressure bombs to 9482~. 10. Open tubing to flow and continue cleaning well to pit. Il. After cleanup, turn combined flow stream (tubing and tubing-casing annulus combined) to test separator (400 psig operating pressurelat the final cleanup-flow rate. Record combined flowing rate, flowing temperatures, and flowing pressures. (Flow period through test separator should be as short as possible.) 12. Shut well in for 24 hours. Record reservoir pressure buildup. Check test separator and clean out if necessary. 13. Retrieve pressure bombs making gradient stops at the following measured depths' 9162' 8631' 7547' 6426' 5276' 4126' 3073' 2073' 1~73' 1073' and surfac~ 14. Open well at lowest possible stabilized flow rate (200 to 500 BOPD) for 24 hours and collect surface separator samples as follows' 3- 9 gal stainless steel cylinders gas 3 - 1 gal cylinders liquid 2 - bbls STO 15. During above sampling period record: a. Crude oil flow rate, BPD b. Gas flow rate, MCFPD c. Water cut d. Oil gravity, °API e. Gas gravity - Ranorex gravity balance 'JUL.. ANCI-~ORAG~ '~D.S NO. 1-2 (32-7 -15) Wel 1' Test -Procedure Page 2 f. Acid gases' (1) H~S - Drager Instrument (2) H~S - Cd SO~ method - NGPA 2265'65 (3) M~rcaptans ~- Drager Instrument (4) CO -Draqer Instrument (5) To~al aci~ gas - Orsat g. Flowing temperatures and pressures at wellhead and separator. Temperatures and pressures at wellhead to be continuously recorded. 16. Shut well in for a minimum of 6 hours. 17. Run bottom hole sampler with Amerada pressure gauge. Obtain a minimum of 4 - 600 cc bottom hole samples. 18. Run 3 SS pressure bombs and recording thermometer in tandem on wireline and hang @ 9482'. 19. Open well (tubing and tubing-casing annulus combined) to test separator and imcrease flow to maximum possible stabilized rate. At this point obtain the following: a. Combined stream oil rate, BPD b. Combined stream gas rate, MCFPD c. Water cut d. Separator oil samples (1) Measure oil gravity, °API (2) Collect 2 - 1 gal cylinders of oil & 2 - bbls STO. ~. Separator gas samples (1) -Run gas gravity - Ranorex gravity balance. (2) Run acid gases: (~') H~S '- Drager Instrument (b) HZS - Cd SO~ method - NGPA 2265-6'5 (c) M~rcaptans -* Drager Instrument (e) Total acid gas - Orsat (3) Collect 2 - 9 gal stainless steel cylinders gas f. Flowing temperature and pressures at wellhead and separator. Temperatures ,' and pressures .~t wellhead to be recorded continuously.. g. Indications of crude foaming h. Indications of sand production NOTE' Be prepared to inject foam suppressant at wellhead if required. Dow Corning 200 suppressant or equivalent to be diluted with diesel @ 1 part suppressant to 10 parts diesel. Suppressant- Diesel mix to be injected @ 3 ppm initially and thereafter as r. equi red. 20. Retrieve pressure bombs and temperature recorder making gradient stops at the following measured depths' 9162', 8631', 7547', 6426', 5276', 4126', 307 2073' 1935' 1890' 1073' ·and surface RECE V[O D.S~' NO. 1-2 (32-7-10-15) Well Test Procedure Page 3 21. Run '3 SS pressure bombs in tandem on wireline and hang @ 9482'. 22. Shut well in and record 24 hour pressure buildup. 23. Retrieve pressure bombs making gradient stops at the following measured depths: 9162', 8631', 7547', 6426', 5276', 4126', 3073', 2073', 1873', 1073', and surface. 24. Close ball valves and shut well in to await DS No. 1-1 (32-8-10-15) wel 1 test. 25. Prior to initiation of DS No. 1-1 (32-8-10-15) well test run 2 SS pressure bombs in tandem on wireline to 9482' and leave in well during DS No. 1-1 well test to monitor possible interference with DS No. 1-2 (32-7-10-15). Additionally, record SITP of DS No. 1-2 continuously throughout DS No. 1-1 well test. 26. Retrieve pressure bombs 27. Retrieve tubing ball valve. 28. Run 4½" input safety valve in tubing. 29. Test hydraulic control line and: close tubing-casing annulus ball valve. 30. Bleed pressure off of tubing and tubing-casing annulus and shut well in. WELL TEST D. S. No. 1-2 (32-7~10-15) PRIMARY OBJECTIVES 1. Well clean up preparatory to future residual injection. 2. High rate capacity determination. 3. Producing characteristics such as fluid ratios, temperatures, pressures, sand production, foaming, etc. 4. Surface equipment performance evaluation. 5. Gas and liquid sample collection and analysis. DATA REQUIREMENTS 1. Static and flowing BHP throughout teSt including buildup after shut in. 2. Flowing and shut in wellhead pressures. 3. In hole, wellhead and separator temperatures. 4. Gas, oil, and water samples with in-field analysis of H2S, mercaptans, and CO2. 5. Gas, oil, and water rate measurements for combined streams and for tubing and casing phases individually. 6. Oil and gas gravities. 7. Indications of sand production and crude foaming. ANCHO~AO~ Form ,,Mo. P--4 REV. STATE OF ALASKA O]L AND GAS CONSERVATION COMMITTEE SUBMIT IN DEi~LICA, TE MONTHLY REPORT OF DRILLING AND WORKOVER OPERATIONS 0IL WELL ~ GA~ WELL ~ OTHER ~i_c_ Richfield ComDa~v , ,~P..~0~:._B_ox 360 Anchorage. Alask . ~. LOC.~TmN OF wm_z. a 99501 TRM OKG 50-029-20053 ADL-28329 . 32-7-10-15 193' S & 1356' Efr NC/ Cr i~ c ~ ~ ~ V [ ~ om-scrnm~ ~OrTO: Sec. 8, T10N, R15E, UM ~"~ ~'' ' Sec. 7 T10N, R15E, UM A?;q 2'7 R~eport for March, 1970 Fished out wireline plug. Ran and checked sleeve @ 9363'. Ran pressure recorders in tailpipe @ 9439'. Set "N" plug @ 9408', set pressure recorders. Ran vertical permeability test, began @ 8:52 P.M. 3-1-70. Second flow period ended @ 9:30 A.M. 3-2-70. Shut in 3-hrs. Retrieved.upper pressure bombs. Closed lower sleeve. Bled 200 psi off drill pipe, plug held okay. Clock set for 2-minute reading. Read okay. Both 1-minute clocks failed. Pulled equalizer plug and "N" plug. Re- trieved lower pressure bombs. To°l released @ 8000'. Ran in and recovered pressure bombs. Ail charts on lower pressure bombs.good. Opened upper and lower sliding sleeves. Upper sleeve plugged off. AttemPted to unseat packers. Top packer free. Fluid dropped 40, when upper packer unseated Could not release. Circulated through upper sleeve. · Close~ Hydril. Displaced oil out.of drill pipe back into fo ' psi ~hut zn pressume. 650 psi. Pumn~a l~ ..... rmation to 1700 . ~o~o_¢3:¢~ ~~+=~;~=+~ ~,,~L,~oa~rems. Opened Hydril. Began ~.b barrels pe~ minute. Pressure 45~2~0 ~§Y?~°~Bf~,~ while pumping. Circulated until MW 81~ in and 79¢ out. Ran'..:,9 5/8" retrievable cementer to 9237'. Circulated 1-hour. Set cementer @ 9237,:. Broke downformation w/1000 psi. Pumped 7 barrels mud @ 2 1/2 barrels per minute w/1500 psi, tested surface lines w/5000 psi - Okay. Opened circulating valve, un- set tools, lowered tools, could not reset tools. Pulled out of hole. Cha~ged re- trievable cementers. Ran 9 5/8" retrievable cementer on 5" 195~ drill pipe. Set cementer @ 9237'. Tested lines w/6 barrels mud. Closed tool. Pumped 4 barrels mud into formation @ 2 1/2 barrels per minute rate @ 1500 psi. Opened tool, PmeSsure indicator 10 barrels water, smm:D _= /%J"F~ ~ ~T~ R~. 1~1 l~n~ ~.n~n~,ow DAn:r: Ap~ 1 94, ]qT0 NOTE--Report on this form is required for each calendar month, regardless of the status of operations, and must be filed in duplicate with the Division of Mines & Minerals by the 15th of the succeeding month, unless otherwise directed. State Monthly Report - March DS # i (32-7-10_15) Page 2 April 24, 1970 150 sacks class "G" cement w/.2% D-13 retamder. Displaced w/10 barrels water and 107 barrels mud @ 4 barrels per minute rate. Pressume increased fmom 800 to 3500 psi in last 12 barrels of displacement. Cement pressumed up @ 2:15 P.M. Could not reverse out cement. Pulled out of hole. ' C' Ran in hole w/8 1/2" bit to 981[ . mrculated 2-hours. Pulled out of hole. Squeezed Perforations 9360-98?0 and 9430-9440'. Ran 9 /8" retrievable test treat squeeze tool cementer on 5' 19.5# drill pipe 9237'[ Tested surface lines to $000 psi, opened tools. Pressume indicator 10 barrels water, 150 sacks class "G" cement pre-mixed w/0.3% D-13 retarder. Displaced w/10 barrels water and 114 barrels mud w/1000 psi @ 8 1/2 barre~-.pem~xminute rate. Closed tool Squeezed 9 barrels mud, 10 barrels water and[135.3,'slurry through.perforations. Last 73.3, ~in 3 stages. Pressured 10 minutes~ ......... cement in place at 3:00 A.M. 3-7-70. Released retrievable test treat squeeze tool, reversed circulation drill pipe clean. Recovered approximately 1 barrel contaminated cement and water. Pulled out of hole~,~ Displaced last 13 barrels of squeeze job w/diesel oil. Air temperature at[?40~. Ran 8 1/2" bit. Drilled out cement 9342-9460'. Ran in to 9817, spotted 50- barrels 82# invermul mud 9817-9167. Perforated 4 1/2" holes/feet. 9615-9585, 9575-9545, 9525-9495,~ 9485_9455. R~n and hung 2 3/8" 4.6# N-80 Buttress tubing, 2 5/8'i x 8 1/2" rev flow check 3 1/2" "N" niPple~ 2 ?/8" x 4' pup joint, 2 7/8" sliding sleeve, 4 1/2" x 9 5/8" packer, 4 1/2 x 20' Hydril tubing X-0 su~, ~n'4'!~1/2'' 12.6# N-80 Buttress tubing 2 1/2" x 4 1/2" tmbing hanger T9343. Spaced out tubing. Pulled up 10". Dropped ball and set packer w/1500 psi. L~nded tubing on adapter w/31000#. Sheared sub w/2800 psi. Press t~bing with 1000 psi to check packer - okay. Installed BP valve. Set tree. Tested tree and lines of 5000 psi for 45 minutes - okay. Displaced mud with 601 barrels diesel oil. Pulled dummy sleeve on tubing side. Opened Sleeve @ 1925'. Ran back check valve. Hydraulic actuating lines could not hold. Pulled back ~heck valve. Fished for flow tube. Reran new flow tube and back check valve. Tested Hydraulic actuating lines - okay. Closed ball valve. ~led tu~ing and casing to zero psi Released rig @ 6:00 P.M. ~-15-70. · April 20, 1970 State of Alaska 0il & Qas Division / . As per our conversation, enclosed please find two. copies of log/Radius of Curvature Method. This should be included with the completion notice on well #32-7-10-15. Thank you, Patti Arline Secretary Drilling & Production~ ~Bo621 2/69 Form P,--7' · STATE OF ALASKA reverse side) OIL AND GAS CONSERVATIC~ COMMITTEE WELL COMPLETION OR RECOMPLETION REPORT AND LOG* la. TYPE OF on,,vE,.,, bi ~ASw~LL ~] ~, ~ ot~&, Injee%ion ~. TYP~ OF ~OMPLE~ON: %%' ELL O%'gR ~N BACK ' ~EgVR. Other ~. s.~g or O~*TO~ Pru~oe Bay 'Atlantic ic ield Co ~y - ,.w~o. (32-7-10-15) ~. ,,~ o~ o~,~o~ Drill Site ~1-2 P. O. Box 360, Anchorage, Alaska 99501 m. ~ ~ ~u. o~ w~m 193'S & 1356'E fr 1214'S & 1002'W fr NE cr Sec 7, T10N, R15E, ~1208'S & 1239'W fr NE er Sec 7, T10E, R15E, ;~ 69~119: ~.~~n~ 4. ~ ~.~. ~c~! ~ ~ co~,sus~,~ ~. t~.". , . . .1-17-70 [ 2-2~-70 . ! 3-15-70 ] 73' ,.I 39' 18' T~ D~H ~ & TVD ~9. pLUG ~CK MD & ~D~. ~ ~LT~LE ~L., ~ ] 21. ' .[ b~¢ [ ~W ~Y* . ' ( ROTARY TOOLS 99~o'~ ~ 9~SS'w 19~77m ~ 9~S~'~ ~ ...... I 0-9930 ~ PRODUCING ~VAL($) OF ~ ~MP~TION~, BOSOM N~E (~ ~ ~)* 9309' to 9930'~ 24.'.TYPE ELECTRIC A_ND OTHER L~OGS'~RUN S4hlumberger DIL, F.D~-._, BHC-GR, PML, GR-CBL-CCL; :i ~$, - ,, ~ CASING RECORD (Report all strings set in w~ll) J CASING SIZE 20" ~ 9-5/8" SIZE ,43.~ LINER F~:C O'I~ TOP (MD)! " BOTTOM (MD) DEPTH SET (MI)) HOLE SIZE 9877' CEMENT* 28. ~ PERFORATIONS OPEN TO (Interval, size and number) 4-!1/2" holes/ft i! '<' ~ 9615-9585) [ '~' '.: ~' O (~ ~ 95i75-9545) DIL Me~S~ement~% ~: % ~ ~ V SUBMIT IN DUPLI structions on 50-029-20053 K~v ~L 28329 Prudhoe Bay SadlerOchit 11. SEC., T.,,R., M., (BOTTOM HOI~E OBJ--) See 7,' T10N, R15E, UM 12. PERMIT NO. C~BLE T0 0~,,~,L S WAS DIREL.tTIONAL SURVEY IVIADE CEA~G RECOi~D AiVIOUNT PULbED ;%~' sx Fondu '& 0 P~CKER SET 2nd sta 27. TUBING SCREEN (MD) SIZE DEPTI-I SET (MD) ~). ~ . , ~ C: , PRODUCTION DATE FIRST P~ODUC~ON [ ~DUC~ON METHOD ~4~J~, ~p~--~lze and~type of p~P) ]WE~ pTA~S (~od, Uc~ ,0r , [: ~. -:.: ' ; ; ":" :: [ : Shu~-Zn :' , DATE OF TEST, [HO~S T~ ,' ' [~OKE SIZE [PEOD'N FOR OI~BBn. ':G~F. WA~B~ ,[ a~:om ~O , ,[ I ':i t WOW WBING I~ma P~S~ ICAL~~ OI~BB~. GA~[ WA~B~. l OIL GRAVITY-~I (C~.) ~ 1~00 I -0- ,:; ::,[ ; [ ~180 I . 2260 I -0- I ~8.~° : ~=ea ~= ~es~ ~::?~ t ~=o~ ~=es ~ 8~ LIST 0~' ATTAC~M~NTS '~ ~.' ,<,, Drzllzng Hzsto~: Dzyee%zonal Survey 33. I hereb~ certify that the [oregoin~ and attached inform~tion ii complete and: correct as determined from allTavatl~ble records ~ StoNED ~~ ~~~T,TLE District Drilling SuDv. ~.TE ~-1~-70 ~... ~ :../ - . : . . . // "~e instructions and S~ces For Additional Data on ReVerse Side) INSTRUCTIONS General: This form is designed for submitting a complete and correct w. ell completion report and log On all types' of lands and leases in Alaska._ Item: 16: Indicate which elevation is used as reference (where not otherwise shown) for depth measure- meats given in ether spaces on this form and in any a~'tachments. Items 20, a.d 22:: If this Well is completed for separate production from more than one interval -zone (multiple completion), so state in item 20, and in item 22 show 'the prcducing interval, or intervals, 'top(s), bottom(s) and name (s) (if any.)" for ionly the interval reported in ite.~ 30. Submit a separate report (page) on this form, adequately identified, for each additional interval to be seperat~'ly produced, show- ing the additional data pertinent to such. interval. Itom2&: "Sacks Cement": Attached supplemental records for this well should shoW the detaiJs of any mul- tiple stage cementing and the location of the cementing tool. Item 28: Submit a separate:completion report on this form for each interval to be separately produced. (See instruction for items 20 and 22 above). 34. SUMMARY OF' FORM,~TION T~-,~'I~ INCLUDING 'iNTERVkL'TESTE~)'. ~-~UR~ DATA. ~ ~OV~ OF OIL. G~. :~' C~' WA~ AND MUD '>' ., '. Top of SadlerochJt No Formation Tests , ,' - · " " Top of Sag River ~ ...... .... a6. CORE DATA. A3'rACII BRIEF D~CRIPImONS OF LITtIOLOGY. POnOSlTY. FRAC~-R~. APP~NT DIPS '' AND ng'r~Cn'gl) SIIOWS OF OIL. G~ OR WATM. ~3 ~NSTftU(iT[ONS: Prepare and ~ubmit the INITIAL REPORT on the £irst Wednesday a£ter a well is spudded or started. Daily wox'k ~ri%r to spudding should be summarized on the £orm 6~viaf¢. inclusive dazes only. DAILY WELL H]STORY-~D4I'F~AL'REPORT District Alaska County or Parish North S!o~e State Lease or Unit DS Title Drill 32-7-10-15 Field Well ~!' o. Auth. or W.O. No. 18-7151 Operator 6pudded or W.O. Begu~ Atlantic Richfield Company Spudded D~te 1-17-70 TARCO'S W.l. Prior. Status Hour5:00 PM if a W. O. POx, Date & Depth as of 8:00 A.M. i-!9-70 780' 1-20-70 800' 1-21-70 800' 1-22-70 864' 1-23-70 1292 ' i-26-70 3055' i-27-70 3055' Complete Record for each Day Reported (780') MW 70#, Vis 105 Drlg 17-1/2" hole Finished RU. S~udded ¢ 5:00 PM !-!7-'70. Dr!d i7-1/2" hole 0-468'. Flow line plugged w/gravel. POH, Cin out flow line. Cond mud to 105 vis. Drld 468-780'. (20') MW 73#, Vis 200, PH 10-.0 Circ& cond hole Drld 17-1/2" hole to 800'. POH. PU 26" HO & o~nd hole to 26" to 779 Fin opng hole ¢ 7:00 AM 1-20-70. Gravel running. Circ& cond hole run 20" csg. (0') Circ 20" c~g ~ 695'. Ran 13 jts 542.69' 20" 94# H-40 esg w/Veteo thds w/3 2~gan 20" slip .i_t_s (110.40')., Loc ~ igt', 320', & 442'. Hung csg o--"~--~ Rockw-~l'2~0" f~uted hgr w/RockWell "EC" lndg clr ~ 52!~ Has Ho~co duplex float shoe ~ 692'. Csg iaqde~ ~ 6~9~.59~'. Centralizers on btm 3 ~ts. Cmtd 20" csg w/275 sx Fondu Neat ~mt.--Disp! w/400 CF mud. CIP ¢ 11:00 PM 1-20-70. PO of Duplex shoe, set back 1 std & circ .out. (64') M~ 71#, Vis 68 Drlg Instld 20" Hydril & flow line. Tst Hydril w/lO00 psi. OK. Ran 17-1/2" bit. Top cmt ~ 674'. Tstd csg w/750 psi. OK. WO soft cmt 674-695' DO'.~shoe ~ 695', tstd forma w/35 psi. OK. Drld !7-1/2" hole 800-964~. (428') MW 69#, Vis 110, WL 9.5 Drlg Drld 17-1/2" hole 864-1050'. Plugged bit ~ 1050'. POH. Ran sharp . q O ~. bit, cond mud & raised vis to 110 Drld 17-1/2" hole ~050-12~2 (1763') MW 72#, Vis 108, ~ il.5 Prpg to run 13-3/8" csg Drld 17-1/2" hole 1292-3055'. (0') MW 72#, Vis 108, ~ 11.5 Prepg cmt !3-3/~" C.sg...& 300~'... Ran 78 jts 13-3/8" 72# N-80 buttress csg (30!3' £ncl shoe, FC& Rockwell tndg jt & DV clr). Csg stopped ~ 2941'. Had 4" compression w/full ~t of csg string. ~G h..~ng~r ~J. Circ& worked csg 3/4 hr & csg dropped free, tite ~ 2961 (dragging i0>). Lnded on Rockwell EC hanger ~ 521', shoe ~ 3'004' , FC& baffle ~ 2936' ~ DV clr ~ 764~, Rockwell.yas~ >a~t~ ~ 520'. Circ 1 hr. Prepg cmt. Dowel'i----' egu~p broke~do~._~ Circ 7 hrs w~iting-~~-~irs & another bulk trk. REcff VFO Distribution: Orig.: Drilling Section- Dallas cc:- District Office Engineering Division - (?20) Co-Owner(s) - As Appropriate l~egional Office, Well Record File PAGE NO. The Above is Correct: :-:.?':.', -':2:? .... : - ' '7 '(' /: '?"";"""': -'"" -' " S IG~ATUR,~ _. / District/Pti!ling Supervisor TITLE: (NUMBER ALL DAILY WELL HISTORY FOR~$ CONSECUTIVELY AS THEY ARE PREPARED FOR EACH WELL.) January 29~ 1970_ DATE INSTRUCTIONS: This form is used during drilling or workover operations. If testing, cor~nz-, or per~oratlng, show ~ormat{on name in describing work performed. Number all drill stem tests sequentially. Attach description of ail cores. Work per- formed by Producing Section will be reported on "INTERIM" sheets until final completion. Report official or representative test on "FINAL" form. (1)Submit "INTERIM" sheets when filled out but not less frequently than every 30 days, or (2) on Wednesday of the week in which oil string is set. Submit weekly for workovers and following setting of oil string until completion. DAILY ~?ELL HISTORY - JNTER~N District Alaska County or Parish North Slope State Alaska Field Lease or Unit DS #1 #32-7-10-15 Wel I No. Date & Depth at S:O0 A.M. 1-29-70 3055' 1-30-70 3055' 1-31-70 2-1-70 2-2-70 3134' 2-3-70 3196' 2-4-7'0 40t6' Complete Record for each Day While Drilling or Workover in Progress (0') Cutting off 13-3/8" csg to instl speed head Circ until 10:10 AM 1'27-70. Started to mix 1st stage. ~mp suct on cmtr failed. Circ til 7:30 AM 1-28-70. Heated rig wtr from 40° t.~o 80° F. to cmt. Started..to cmt 1st stage ~ 8:00 AM 1-28-70. Pmpd 500 sx Fondu ~'fyash followed w/800 sx Class "G" neat (70 min mix time). Dry cmt -I0° F slurry '60° F mix wtr 80° F. Displ w/435 bbl mud in 80 min. Bmmd plug w/1500. CIP ~ 10:'30 AM 1-28-70. Opnd DV ~ 764' w/600 psi. Circ 2 hrs. Pmpd 150sx Fondu l:l ~"~y~ Uispl-~-~4~ mud. Bmpd plug & closed DV w/1500 psi. CIP ~ 2:30 PM 1-28-70. Op~nd Rockwell wash ports. Circ _ 420 bbl mud 1 hr. ~_q ~cmt. Pm~d 150 bbl_ fresh wtr ~o_~lowed w~_2~0 _ ,1, __ - ,, ~ ~ ~ ~ ~ ~ ~ ~ t~_~a_ted wdt~ sugar--eared was~a ports w/77 bbl wtr. Clos t~a~-e ~/1500 psi for 15 min. OK. Had 6000 ft-lb lefthana torque to close, 8000 ft-lb to open. PU Hydril. Lnded 13-3/8" in 20" permafrost head on dbl opposed slips w/30,000# net pull on csg. Now cutting off 13-3/8" to instl speed head. (0') Prepg to tst BOPE Tnstld Rockwell speed head. ~-std packing w/2000 psi. OK. Plastic packed secondary seal. Instld ROPE & accumulator lines. Tstd CS0, pipe rams & manifold w/'5'0'00 psi. Tstd Hydril w/3'0'00 psi. Ran 12-1/4" bit. DO DV clr ~ 761', closed rams, tstd DV clr, EC hanger &' 13~3/8" csg w/1500 psi. RI to 2921'. DO plugs, FC' '& cmt 2921-2983~ closed rams, t~std ~_lug. w/l'500 psi,: bled to. 1i'00 msi in .~. rain & bled ~i00 -1000 psi in 5 min. Repeated tst w/same results. Tstd all surfa'ce lines & valves. POH. RU to run Sperry~-Sun Gyro multi-~shot survey on Hallib unit. Unit would not pick tools up. LD Sperry Sun. LD 90 jts DP. · RU sand line (12,000'). Ran Sperry-Sun Gyro multi-shot survey. RIH. PO & LD DP. (75') MW 67#, Vis 44, WL 19.4 Drlg LD DP & 9" DC's. Ran 12-1/4" bit. Top cmt @ 2983'. RI & PU monel DC. RIH. DO med firm cmt 2983-3004'. Pressured csg shoe w/205 psi. Broke do~-n forma w/24 gal/min ~ 440 Psi. Drld 12-1/4" hole 3055-3075". Circ & took survey. POH. Ran turbo drill #1. Dir drld 12-1/4" hole 3075- 3134'. Turbo drill plugged. Cond mud. (62') MW 69#, Vis 53, WL 15.3 Drlg Dir drld 12-1/4" hole 3134-3196'. Tstd BOPE ~ State's request. Tstd Hydril w/3000 psi & CS0 & pipe rams w/50'00 psi. Tst kill manifold w/5000 psi, bled to 4500 psi. Found valve to gas knockout leaking. Bled to 4500 psi & held 4500 psi. Survey: 3151' 3°15' 3150.81 N66W N109.!6 W23.84. (820') MW 72#, Vis 45, WL 12 Drlg Dir drld 12-1/4" hole 3196-4016'. PU square DC. Survey: 4006' 28045' 3952.52 S65W S24.10 W266.67. PAGE NO. PRINTED IN U.S.A. The Above is Correct: ..- ,, - ~,~..- ~.I.~' .,>; -'> .,,;..,. ~; ..-:. ~ ..... ~ -- .. SIGNATURE ~'// DATE Di'sCrIct D~'~llin~ Sh~ervi'sor TITLE 2 (NUMBER 'ALL DAILY WELL HISTORY FORMS CONSECUTIVELY AS THEY ARE PREPARED FOR EACH WELL. ) 3B-459-2 12/67 INSTRUCTIOn!S: This form is used during drilling or workover operations. If testing, coring., or perforating, show £ormation name in describing work per£ormed. Number all drill stem tests sequentially. Attach description off all cores, Work per- formed by Producing Section will be reported on "INTERIM" sheets until £inal completion. Report of£icial or rep:esentative test on "FINAL" form, (1)Submit "INTERIM" sheets when filled out but not less frequently than every 30 days, or (2)on Wednesday of the week in which oil string is set. Submit weekly for workovers and following setting of oil string until complegxon. DALLY WELL ~ISTORY - INTERJ~ District Alaska County or Parish North Slome State Alaska Field Lease or Unit..DS #i ~.32-~7..-10-15 . .Well No. _ Date & Depth at 8:00 A.M. 2-5-70 5135' 2-6-7o 5873' 2-9-70 75 30 ' 2-1o-7o 7810 ' 2-11-7o 7925' 2-12-70 7925 ' 2-13-70 8051' 2-16-70 8967' 2-17-70 9240 ' 2-18-7o 9400' 2-19.-70 9718' · 2-20- 70 9930 ' Complete Record for each Day While Drilling or Workover in Progress (1119') Mw 75#, Vis 54, WL 9.9 Drlg Dir drld 12-1/4" hole 4016-5135' (738') MW 74# Vis 43, WL 9.3 'Drlg Dir drld 12-1/4" hole 5135-5873'. Survey: 5503' 30© VD5252.90 S69W S321.07 W945.95. (1657') MW 75#, Vis 47 WL 8 Drlg Dir arid 12-1/4" hole 5873-7530' Survey: 7342' 26o15' VD6876.02 ~64W S670.96 W1734.79. (280') MW 76#, Vis 44, WL 8.1, 0il 2% GIH w/sharp bit Dir drld 12-1/4" hole 7530-7810'. Tstd CS0 & pipe rams w/5000 psi, tsts Hydril w/3000 psi-OK. Tst witnessed by P.E.I. Survey: 8710' 24°15' VD7302.74 S67W S746.06 W1911.72. (115') MW 75#, Vis 38, WL 6.9, Oil 2% Cite @ 2900' Dir drld 12-1/4" hole 7810-7925'. #1 turbine intake iced up ~4:00 P.M. 2-10-70. Pulled up to 2900' & circ..;-~g-lternateiy thawing #1 & #2 intakes. (0') Circ ~ 2980' for ~4 hrs WOW. Filling wtr tanks. ... . _ ~ '-' -. ? . - ~ ~--~-~-~- .~i ...~=..~-~._~ (126') MW 74#, Vis 45 WL 6,5, Oil 2% Drig Dir. Drld 12-1/4" hole 7925-8051'. Circ 11 tits due to weather. (916') MW 80#, Vis 47, WL 4.8, Oil 2% Drlg Dir drld 12-1/4" hole 8051-8967'. Survey: 8832' 18o15 ' VD8262.81 S70W S874.28 W2236.06. (273') MW 81#, Vis 47, WL 4.8, 0il 1%. Pulling wear bushing for BDPE tst. Dir drld 12-1/4" hole 8967-9240!. Pulling wear bushing for ROPE tst, now hung in_ Hydril. (160') MW 82#, Vis 45, WL 5.2, Oil 1% Drlg . Wear Bushing sheared studs while pulling for BOPE tst. Btm 1/2 caught in Hy~ ~' Remvd Hydril & recov bushing. Instld Hydril, tstd Hydril w/3000 psi, CS0 ~'pmpe rams & manifold w/5000 psi. Dir dr!d 12-1/4" hole 9240-9400'. (318') MW 82#, Vis 45, WL 4.6 Oil 1% Drlg Dir drld 12-1/4" hole 9400-9718'. Survey: 9561' 22-1/4© TVD8944 West S879 W2496 .......... Dir drld 12-1/4" hole 9718-9930', Made 15 strand wSper trip-OK, Circ, S~ey: 9792' 23-1/2° TVDg155.66 N85W S871.16 W2587.35. 'AG~ NO. ~ XNTED IN U.S.A. The Above is Correct: . ~ ~ ..... ~ ~ ./>' ..... ~J,-c~/ ~~dd:~?:':'v:;": .'-i~ March 9 ~ 1970 Dis%ric% Drilling Supervisor. TITLE _(NUMBER ALL DAILY WELL HISTORY FORMS CONSECUTIVELY AS THEY ARE PREPARED FOR EACH WELL. ) 3B-459-2 12/67 INSTRUCTIONS: This £orm is used during drilllng or workover operations. !£ testing, coring., or per£orating, show formation name in describing work performed. Number all drill stem ~ests sequentially. At~ach description of all cores. ~ork per- formed by Producin~ Section ~ill be reported on "INTERIM" ~heecs unzil final complec£on. Reporz official or repr~s~n:a~ive ~es~ on "FINAL" form. (1) Submi~ "INTERIM~ shee~s when filled ouc bu~ no~ less £requen~ly ~han every 30 days, or (2) on ~ednes~ay of :he week in which oil s~ring is se~. Submit weekly for workovers and followin~ ~et~in~ of oil s:ring un~il comple~ion. DAILY WELL HISTORY -, INTERIM District Alaska County or Parish North Slope State Alaska Field Lease or Unit DS #] #59-7-10-15 Well No. Date & Depth at 8:00 A.M. 2-24-70 99 30 ' 2-25-70 TD 9930 ' ?BD 9787' 2-26-70 TD 9930 ' PBD 9817' 2-27-70 TD 99'30 ' PBD 9817' Complete Record for each Day While Drilling or Workover in Progress (0') - Standing cmtd. 2-21-70= Circ ~ 9930 for l'ogs. Ran Schl DIL, FDC-GR, BHC-GR 9930-3004'. Ran PML Sonde to 9930' tool would not completely open POH SurVey: 9930' 24-3/4° VD9280 N86W S868.03 W2644.99. 2-22-70= RD Schl. RIH w/12-~4" bit to 9930', circ & cond mud 5 hrs. Had viscus mud off btm. POH. Reran Schl PML 9930-8800' , normal curve, did not record, changed tools & ran PML OK. RD Schl. Instid 9-5/8" csg rams. Pulled 13-3/8" bowl protector. 2-23-70= Remvd flow nipple. Retrieved 13-3/8" bowl protector. 9-5/8" cs__g ~ 9877'. Ran 25 jts (1076') 9-5/8" 47# Soo-95 buttress inc! Hall float s~'~'~diff clr, 63 jts (2617') 43.5# Soo-95 buttress incl. Halli DV cir, 140 jts (6069') 40# Soo-95 Buttress::.& 2 jts (87') 47# Soo-95 Buttress on Rockwell Boll Weevil hgr; Inded csg on hgr ~ 25' KB, shoe ~ 9877' (wv of csg on Hook 290-350,000#), Diff clr ~ 9788' DV stage clr ~ 6392'. Start circ@ 6:00 AM. Lost 150 bbls mud after est~circ,~ slowed~pmp down, had full returns. Circ. 2-24-70= Cmtd 9-5/8" 'csg ~9877' in 2 stages. 1st stage w/1000 sx Class "G" premixed w/.2% D13. Slurry 116#. Dry cmt -4° Slurry 56° Water 78°, mixing time 45 min. Displ w/734 bbls mud in 77 rain (60 bbls w/Dowell bai w/rig pmp). Bmpd plug w/2500 psi; float held OK. CIP ~ 3:00 PM--2-23-70. L. ost 18 bbls mud after displ 400 bbls mud. Had. good circ after losing 18 bbls. Opnd~DV stage cir ~ 6392' w/800 psi. Circ freely 3 hrs. Had wall cake but no returns. 2nd"stage: Mixed 800 sx Class "G" premixed w/lO~ gel 104#' S]'Urry. Dry cmt -5°, Slurry 70°, Mix wtr 88°. Mixing time 75 min. Displ w/485 bb!s mud .in 55 'min w/rig pmp. Closed DV clr w/2500 psi. CIP @ 9:35 PM 2-23-70. Instld Rockwell 9-5/8" x 13-3/8" pack- off' Tstd w/5000 psi for 20 rain-OK. Instld 5" rams. LDHWDP & sq stabilizers. · P0H MW.79#, Vis 40, WL 7.5. Tstd CS0, DP rams & kill manifold w/5000 psi-OK'. Tstd Hydril w/3000 psi-OK. Measured in hole w/8-1/2" bit on 180' HWDP to 6389'. Tstd csg w/1500 psi-OK. DO DV clr ~ 6392. RI CO firm cmt 9035-9787'. (Bit dropped wt ~ 9750'). Will measure out. Mixing Mud MW 82#, Vis 39, WL 6.9, 0il 1% Ran G-R CBL-CCL 9817 - 9100'. Good Cmt. Bond. 1st stage cmt top, ~ 74Q0' with probable contaminated cmt ~ 6392; 2_nd .stage ~mt to~ ~ !550'.. Mixing Invermul slug. Preparing to pull Otis Plug. Msrd in hole w/DP. Corrected PBD 30' from 9787_' ~o 9817[. Spot 50 bbl 82# -Invermu! slug 9200-9500'. Perforated w/4 1/2" jet shts per ft 9360-9370~ 9430-9440'.~ Rill w/permeability tst assembly. ~e~"~'op '~kr ~ 9322; btm @ 9401'. ~eated Otis plug in "N"' nipple at 9408'. Opnd Otis sliding sleeve @ 9319'. PAGE NO. PRINTED IN U.S.A. The Above fs Correct: ANCk-~O?~AG~ SIGNATURE y/ D~strict Dri!!ins Supervisor.- TITLE 4~ ,, (NUMBER ALL DAILY WELL HISTORY FORMS CONSECUTIVELY AS THEY kRE PREPARED FOR EACH WELL.) March 9, 1970 DATE 3B-459-2 12/67 INSTRUCTIONS: This form is used during drilling or workover operations. I£ testing, coring., or perfora:ia6, show formation name in describing work performed, Number all drill s~em tests sequentially. Attach descripzion of all cores, Work per- formed by Producing Section will be reported on "INTERIM" sheets until final .completion. Report official or representative test on "FINAL" form. (1) Submit "INTERIM" sheets when filled out bu~ not less frequently than every 30 days, or (2) on Wednesday of the week in which oil string is'set. Submit weekly for workovers and following setting of oil string until completion. DALLY WELL ~4~STORY - INTERIM District Alaska County or Parish North ..S~ope . , State Alaska Field Lease or Unit DS #1 #~2-7-10-15 Well No. Date & Depth at 8:00 A.M. 3-2-70 TD 9930' 3-3-70 TD 9930' 3-4-70 TD 9930 ' 3-5-70 TD 9930' Complete Record for each Day While Drilling or Workover in Progress PBD 9817' - Preparing to test. Open top sleeve ~ 9319'. Pulled plug ~ 9408'. Rig up Dowell. Displacd mud w/diesel in DP. PI 40 Bbls ~ 2 bbls/min. Pres increased to 1800 psi. LC. Ran Otis & chkd sly - sly opn. Bk flwd 10 bbls diesel, sly unplgd. Displacd totl 155 bbls DO. Final pressure 2200 psi. ISI 2000 psi. Ran Otis. Clsd sleeve ~ 9319'. Rig up tst hd, IP 650 psi, 1/2" choke, opn ~ 6:50 PM 2-27-70. Gas & mud to surf in 45/min..,Flwd l_powr ~.~e ~, ~180 BPt~. GOR 710. TP 1300 psi. SI ~ 10:06 PM. Ran Otis. Opnd mid sly ~ 9363'. RI to set plug ~ 9408'. Could not rls rrm plug. 3-1-70 - Cut Otis line. F~lw~_upper zone 9360-9770'. 0pn ~ 8:30 ~M. 5/8" choke 4~70 B/D, ~770 GOR_~ TP %060 psi ~ 10:~45 D~M opnd to .11/16" choke 4310 B/D~ 832 GOR, TP 980-1050 psi. SI ~ 12:00 N. Oil 28.5°API. Ran 0tis. Fished line cutter & plug setting. 3-2-70 - Jarred plug loose w/well flowng. Plug hung in sir ~ 9363'. RI & rcvrd plug (plug also hung in up sly). Ran & chkd sleeve ~ 9363'. Ran Sperry Sun presure recorders in tailpipe ~ 9439'. Set "N" plug ~ 9408', set Sperry S~n presr rcdrs (3 runs. Releasng tool would not rels). Start vertical permeability test ~ 8:52 PM 3-1-70. Tst in progrs. PBD 9817' - Killi_ng well. Vertical Permeability.~Test contd: 2nd flow per ended ~ 9:30 AM 3-2-70. SI 3 hrs. Retrvd upper press bombs. Closed lowr sly. Bled 200 psi off DP, plug hld OK. Clock set for. 2 min rdg. Rd OK. Both 1 rain clocks failed. Pulld equalizer plug & "N" plug. Plug hld up in both slvs = jarrd loose. Retrievd lowr press bombs. Tool releasd ~ 8000'. RI & recovrd press bombs. All charts on lowr press bombs gd. Open .uppr & lowr slidng Slvs. Uppr sly plugged off. Atmpt unseav pkrs. Top pkr free. Fi drpd 40' when uppr pkr unseated. Could not release. Circ thru uppr sly. PBD 9817' MW 80#, Vis 36, WL 6.8, Oil 3% - Cond mud Closd H/dril. Displd oil out of DP back into formatn. Displd oil ~ 2 bbl per min. Begin press ~ 2600 psi decrsd to 1700 psi. SI press 650 psi. Pmpd 150 bbls. Open H/dril. Began circ. Hole clr of contaminated mud. Unabl to revers out. Max circ rate 3.5 bbls per min. Press 450-1250 psi. Unmbl to move DP dn hole while pmpg. Circ until MW 81 in & 79 out. S0H w/tst tools. Chngd out 1st 8 studs due to torque. Top pkr tore off & dm on lowr pkr. Metl sly in clsd positn. Upr sly had wt. metal in upr ports~. PBD 9817' MW 80#, Vis 37, WL 6.6, Oil 3% - GIH Cond mud ~ 9817'. POH. Ran 9-5/8" Dowell 43#-53# retrievable cmtr 9237'. Cite 1-hr. Set cmtr ~ 9237'. Broke down formatn w/1000 psi. Pmpd 7 bbls mud ~ 2-1/2 bbls/min w/1500 psi, tsts surf lines w/5000 psi-OK. 0pnd circ valve, un-set tools, lowered tools, could not re-set tool. POH. Chngd retrievable cemtrs. APR 'i!iiTO ... The Above 'is Correct: Dt/t,:t ..... OiL AtqD ~AS ~.,~/~__~.:::~ ~-:~h~,~.,~-:r-,'-/;.-~.,- March 17, 1970 SIGNATURE // - DATE Distri~( Drilling Supervisor TITLE PAGE NO. ~ ,(NUMBER ALL DAILY WaLL HISTORY FORMS CONSECUTIVELY AS THEY ARE PREPARED FOR EACH WELL.) PRINTED IN U.S.A. 3B-459-2 12/67 INSTRUCTIONS: This form is used during drilling or workover operations. If testing, coring., or perforating, show format~ name i~ describing work performed. Number all drill stem tests sequentially. Attach description of ail cores. Work per~ formed by Producing Section will be reported on "INTERIM" sheets until final completion. Report official or representativ% test on "FINAL" form. (1) Submit "INTERIM" sheets when filled out but not less frequently than every 30 days, or (2)on Wedn~ of the week in whxch oil string is set. Submit weekly for workovers and following setting of oil string until completion. \ DAILY ~ELL HISTORY - INTERIM District Alaska County or Parish North Slope State Alaska Field Lease or Unit DS fl #32-7 !0=!5 Well No. Date & Depth at 8:00 A.M. 3-6-70 TD 9930' 3-9-70 TD 9930' 3-10-70 TD 9930' Complete Record for each Day While Drilling or Workover in Progress PBD 9817' MW 80#, Vis 37, WL 6.6, 0il 3% - RIH w/12-1/4" bit Ran 9-5/8" Dowell Retrievable cmtr on 5" 19.5# DP. Set Cmtr ~ 9237'. Tst lines w/5000 psi OK. Open tool. Broke circ w/6 bbl mud. Closd tool. Pmpd 4-bbl mud into formatn ~ 2-1/2 b/rain rave ~ 1500 psi. Opnd tool, PI 10 bbl wtr, 150 sxs Class "G" cmt w/.2% D-13 retarder (cmt -5°, wtr 80°, 86°, slurry 60°). Displacd w/10 bbl wtr & 107 bbl mud ~ 4 bbl/min rate. Press incresd from 800-3500 psi in last 12 bbl of displacemnt. Start mix 1:15 PM, Mixng time 15 min. Cmt pressured up ~ 2:15 PM (164 bbl cal to reach tools). Could not reverse out cmt POH. LD 58 jts of cmtd DP. Top 15' off btm. Single was cmtd. 7 stands clean pipe belo cmt plug & tools clean. PBD 9817' - MW 80#, Vis 38, WL 8, Oil 3%. RIH w/8-1/2" bit 9817'. Circ 2-hrs. POH. ~eze p,erfs 9360-~'. Ran 9-5/8" RTTS cmtr on 5" 19.5# DP 9237'.~ ~~ir~ 4~-~s wtg on Dowell to thaw prop lines & repar hydraulic line. Tstd surface lines w/5000 psi, opnd tools° PI 10 bbls vtr, 150 sxs Class "G" cmt pre-mixd w/0.3% D-13 retardr. (dry cmt -5°, mix wtr 88°, Slurry 65°). Mixg time 13-min. Displcd w/10 bbls wtr & 114 bbls mud w/1000 psi ~ 3-1/2 b/m rate. Closd tool. Squeezd 9-bbls mud, 10-bbls wtr & 135 cuft slurry thru perfs ~ 9360-9370' & 9430-9440 Last 73 cuft 2000-3500 psi. .Staged last 16 cuft in 3-stages. Press 10-min.. Bled-off press, re-press to 3500 psi. Held 15-min. CIP ~ 3:00 AM 3-7-70.. Releasd RTTS, Reversal circ DP clean. Rec approx 1-bbl contAm- inated cmt & wtr. POH. Disp last 13-bbls of squeez job w/die oil. Air temp -40°. 3-8-70 - 9930' TD, PBD 9817' - MW 79-1/2#, Vis 44, WL 8~ 0il 3%. Stood cmtd 16-hrs. Ran 8-1/2" bit. DO firm cmt 9342-9460'. RI 9817'. Circ 6-3/4 hrs while 'm6x'g 82# Invermul 50 bbl pill. Spotted Invermul on btm ~ 9817-9167. POH. Ran Dresser-Atlas Perfs. 3-9-70 - 993"0'TD, PBD 9817' - MW 79-1/2#', Vis 44, WL 8, Oil 3% Perf'd 4 1/2" hole/ft 9615-9585' 9~.7~-9545' 9525-9495 ~p±~. measurmts) w/DA-. NCF II csg guns 480 holes 7 runs (8-hfs). Install 4-1/2" tubing rams. Pulld bowl protectr. Ran.._.63 its 4-1/,2" N-80 Buttress tubing & set same in derrick, Ran 135 its 2-3/8" 4.6# N-80 Buttress tubing w/Otis shear sub & "N" nipple on btm in progress. PBD 9817' MW 79.5#, Vis 44, WL 8, Oil 3% -Removg BOPE& insta!lg tree Ran tbg. Otis shear sub + "N" nipple, 239 jts (7407') 2-3/8" 4.6# N-80 Buttress tbg, 2-3/8" x 3-1/2" rev flo check., 3-1/2" "N" nipple, 2-7/8" x 4' pup jr, 2-7./8" Otis slidg sly, 4-1/2" x 9-5/8'! pkr, 4-1/2" x 20' H/dril X-0 sub, 63 jts (1853'), 4-1/2" 12.6# N-80 Buttress tbg, 2-1/2' x 4-1/2" tbg hngr. Spcd out tbg. PU 10". Drpd ball & set pkr w/1500 psi. Lnd tbg on adapter w/31000#. Sheard sub w/2800 psi. Press tbg w/1000 psi to ck pkr - OK. Installed BP v. alve. (Tbg tail ~ 9343',,pkr bt~. ~ 1925~.) PAGE NO. The Above i's Correct: SIGNATURE '--'//- '"' District ~rilling Supervisor TITLE 6 (NUMBER ALL DAILY WELL HISTORY FORMS CONSECUTIVELY AS THEY ARE PREPARED FOR EACH WELL. ) PRINTED IN U.S,A. ANCHO~A~ March 17~ 1970 ,, DATE 3B-459-2 12/67 INSTRUCTIONS: This form is used during drilling or workover operations. If testing, coring., or perforating, show formation name in describing work performed. Number all drill stem tests sequentially. Attach description of all cores. Work per- formed by Producing Section will be reported on "INTERIM" sheets until final completion, Report official or representative test on "FINAL" form. (1) Submit "INTERIM" sheets when filled out but not less frequently than every 30 days, or (2) on Wednesda7 of the week in whxch oil string is set. Submit weekly for workovers and following setting of oil string until completion, DAILY WELL HISTORY - INTERIM DistriCt Alaska County or Parish North Slope .. State Alaska Field Lease or Unit DS # ! #22-7~10..-_!5 Well No.__ Date & Depth at 8:00 A.M. 3-11-To TD 99 30' 3-1.2-70 TD 9930' 3-13-70 TD 9930' Complete Record for each Day While Drilling or Workover in Progress PBD 9817' - Completing well - Removd BOPE. Installd Rockwell tree. Tstd tree & pack off faild. Replacd ssmle, replacd tree & tstd w/5000 psi 45-min OK. Retard BP vlv & disp mud w/die (WO Dowell 2-hfs to thaw lines & get gauge). Startd displcg ~ 2:00 AM 3-11-70 - 82# mud 601 bbls diesel 1000-2000-(67-6 b~l'calc) diesel in place ~ 7:30 AM. SI well w/1300 psi tbg, 1250# psi csg. PBD 9817' - Wtg on jars - Pulld dummy on tbg side. Opnd sly ~ i925'. Ran back ck vlv. C~d._hydraulic lines. Hydl side held 1500, bal side bled to 1200 psi. Re-seated vlv. .~al side not holdg. CoUld h66 r&~s rrm bk ck vlv.- 'BO rng tool. Ran fshg tools & hydl jars. Hyd jars not wkg. Sheared loose. Replcd jars. Jrd on fish-jars did not wk. PBD 9817' - Completg well - Pulld back-ck vl¥- pkg torn. Re-dressd back-ck vlv, flushd & unpluggd act lines. Back-flwd act lines. PI 5- gal transformr oil into each line. Re-ran ck vlv. Vlv holding but unable to press up act lines. Pressd & relsd press attptg to actuate seals. Would not hold press. Pulld back-ck.vlv. Seals showd normal wear. Re-dresd & re-ran back-ck ¥1v. Seated OK. Wkd press to acs ?eals._- youl4 not hold pre_ss. R CE VED APR PAGE NO, PRINTED IN U.S.A. The Above fs Correct: SIGNATURE //- ' ~Ls~-~ ~+.. n~ ~ ~ ~ ~g S~.~ervisor TITLE 7 .(NUMBER ALL DAILY WELL HISTORY FORMS CONSECUTIVELY AS THEY ARE PREPARED FOR EACH WELL.) March 17, 1970 DATE Abandoned, or Sold. FINAL ~EPO~T ~hould b~ ~ubmi~ed ~lso ~h~n oper~zion~ ~r~ ~u~pend~d f~r ~ ind~fini~ o~ ~pp~c'~abi¢ length of ~imc, ()n workover~ ~en an official =es% is noz required upon completion, report comp).a~ion ~nd represea~iv~ %esg data in block~ provided. T~e FINAL REPORT form may b~ used for reporting the entire operation if ~p~c~ i~ ~v~ii~b!~. DAILY WELL District Alaska County or Parish · Field Lease or Drill 32- 7-i0-15 Operato~;__ /itlantic Richfield Com'~ Spudded or W,O. Begun ~;p_pudde,~ Date l_.z~lV-70 Hour i PM TARCO'S W. I~ Prior Status if aW.O, Date & Depth as of 8:00 A.M. 3-Io-70 TD 9930' Complete Record for Each Day Reported PBD 9817' - Could not rels f~m ck vlv. Partd line trying to get free. RI fishg tools. Took hold of fish. Fishg svring sheard loose. Marks on skirt indicate wire on top of fish. Bled tbg press 1200#-250#. Bled csg press rrm 1250#. Well flwd i0 bb2. s. SI csg. Csg press i350#. Ran wire line blind 'box 'to clean top of rope socket & 'try to drive fish dm. Ran wire line grab - no recov:c/. Ran fishg tools. Jarrd on ~z~,n. Sheard off ~rm ~unng tool. ~a:n blind box. Jarrd dn on runng tool. Ran fishg tools. Jarrd runng tools loose. Jarrd ue hole 1.0' & then free. Found frozen, mud in j ai~s,_o_,:a rzm. ng tools. Equaizd csg & tbg. Ri & pulid back-ck v3"'tro "Jaz2r,~ up hole 35' before free. Meas'arer;mts show back-ck vlv 30~ hi£~:. Ran ,~ retrYd flo 'tube~ dragged 40' 'then free. F!owd well 'to CO ic~. ~ Flo tube not seated properly. Btm seat shoulder badiy' bat'terd (side · , ' ~m of tube) Ran new ~' ~ . . . zi.c tube Bled csg press pocket mark on 0 psi Purged hyd . ~.~ne~ Ran Otis back-ck "civ. Press c.u ...... zo_~ iznes t_o 1500 }s'i OK. Opend ball. viv. Open a closd OK. Bled-t~ to 0' psi. Bled csg to 0 psi. ltD Otis. Clnd mud pits & suction hoses Drained props. _R~g released ~e 6:00 PM 3-15-70. Old TD ..... ~' New TD PB Depth Released Big_ ~;O0..~M Classifications (Oil, Gas, etc.) Date Kind of Rig ',- , · Type Completion (Single~ Dual, etc.) . .~~ __ _ Producing Method Official Reservoir Name(s) Potential 'rest, Data: NONE TAKEN WELL NO. DATE PU}dP SIZE, SPM X LENGTH , RESERVOIR D i s t r i b u t i o n: PBODUCING INTERVAL OIL OR TEST TIME I- ' GAS { OIL ON TEST T GAS PER DAY : GRAVITY C~R j ~ ALLOWABLE ~ EFFECTIVE DATE CORRECTED ~ The Above is Correct: ~ ........ ~ / -:"., .'-4~:'-':;" ~"~-~--'""~'":n 3_7 1.97o SIGNATURE / / DATE / TITLE I CHOKE SIZE 17. P. ~ C. P. I WATER Orig.: Dr:ill:lng Section - Dallas cc:- District Office Eng:[neering Division - (720) Co-Owner(s) As Appropriate Regional Office, Well Record File ALL DAILY WELL //AtlanticRichfieldCompany North America~Producing Division Alaska Distric[ Post Office Box 360 Anchorage, Alaska 99501 Telephone 907 277 5637 S. W. Kingsbury District Engineer April 7, 1970 Harry W. Kugler Oil and Gas Division Dept. of Natural Resources 3001 Porcupine Drive Anchorage, Alaska Dear Mr. Kugler: Transmitted herewith for your files are copies of the 2" Dual Inductien Laterolog on our Drill Site No. i (32-7-10-15) Well~ ~Prudhoe Bay Field. Includ- ed are i Blue Line and i Sepia. Yours very ~truly, ~. W. Kingsbury SWK:kb Form No. P--4 P~V. 9-30-6~ STATE Of ALASKA OIL AND GAS CONSERVATION COMMITTEE SUBMIT IN DEPLICATE API NLr~ER/CAL CODE 50-029-20053 ~,4ONTHLY REPORT OF DRILLING AND WORKOVER OPERATIONS 2. NA/V[E OF OP~TOi~ Atl anti c Ri chfi el d Company 3. ADDRESS OF OPEI:~kTOR - P. 0. Box 360. Anchorage_. Alaska gq501 4. LOCATION OF W.:i.T. 193'S & 1356'E fr NW cr Sec 8, TION, R15E, UM 6. Llq~%SE DESiGNAiION AND ~:~AL ADL-28329 -- 7. IF INDIA.N, ALOTTEE OR Ti~LI~_-N'AME 8. T~.-NIT,F.4~o~%{ OR LEASE NA-%IE Drill Site. ~1 9. WE~ ~2-7-1fl-1~ 1~ F~ ~ND2~L.~~ %~DC~ _. vruonoe gay tie/o, baalerochi t 11. SEC., ~., R., M.. (~0~0~ HO~ 0~~) Sec 71, T10N, R15E, UM 1~. ~IT NO. 69-11~ 13. REPORT TOTAL DEPTH AT END OF MONTIni, CI-IAiNTGES IN HOLE SI~E, CASING A_N-D Cl~-¥IENTING JOBS INCLUDING DEPTH SET AAT~ VOLLrNIES USED, PERFORATIONS, TESTS A/NTD I:LESULTS, FISHING JOB~, JI/1NTK IAT HOLE A. ND SIDE-TI:LACKED HOLE AND AlgY OTHER SIGNIFICA2gT CI-[A2gGES IN HOLI[I CON-DITIONS. February, 1970 Ran Gyro multi-shot survey 2983-0'. Ran 12-1/4" bit. Top cmt @ 2983' DO reed firm 2983-3004'. Pressured csg shoe w/205 psi. Broke down formation w%24 .~allOn/min @ 440 psi. Tstd Hydril w/3000 psi & CSO & pipe rams w/5OOOpsi. Tstd kill manifold w/5000 psi. Bled to 4500 psi. Found valve to gas knockout leaking. Bled to 4500 psi & held 4500 psi. Repaired valve leading to gas knockout. Dir drld 12-1/4" hole 3055-9930'. @ 9240' while preparing to test BOPE, wear bushing sheared studs. Btm 1/2 caught in Hydril. RemOved Hydril & recovered bushings. Instld Hydril. Tstd Hydril w/3000 psi, CSO & pipe rams & manifold w/5000 psi. Ran Schl DIL, FDC-GR, BHC-GR 9930-3004'. Ran PML Sonde to 9930' (tool would not completely open). Reran $chl PML 9930-8800'. Instld 9-5/8" csg rams Pulled 13-3/8" bowl protector; 9-5/8" csg @ 9877'. Ran 25 ,.its 9-5/8" 47# SO0-~5 Buttress incl float shoe & diff clr. 63 its (2617') 43.5.# SOO-95 Buttress incl ~DV clr. 140 its (6069') 40# S00'95 Buttress & 2 its (87') 47# S00-95 Buttress on ~.OP. Lndd csg on hg.r: ~ 25" KB ~'Shoe @'98'77' (Wt of csg on hook 290M-350M#). Diff Clr ~ 9788'. DV stage C)r ~ 6392'. Start circ ~ 6:00 AM 2-23-70.. Lost 150 bbls mud after 1st circ. Slowed pumP dn. Had .full rets, Circ;'C~t.'9,5/8"'csg'0'9877' in 2 stages. 1st stage W/lO00 sx Class "G" premixed wJ~% D-13. Slurry ll6~Dfy cmt -40~',~lurry 56°, water 78°, 'mixing ti~ 45-min. Displ w/734 bbls mud in 77 min (60 bbls w/Dowell, bal w/rig pmp). Bmpd plug w/2500 psi, float held OK. CIP 8 3:00 PM 2-23-70. Lost 18 bbls mud after displ 400 bbls mud. Had qood circ '~'fter losing 18 bbls Opnd DV stage clr ~ 6392' w/800 pSi. Circ freelY'3 hrs Had wall cake but no rets. NFIDE ' " t970, .., ,, 14. I hereby certify that the foregoing is~rue and correct smwsD ...... T~rLE Bi~'~i~-~ II~llqnn q~v DATE Mmv'nh lq lq7O NOTE--Rep this form is required for each calendar month, regardless of the status of operations, and must be filed in duplicate with the Division~,~'f Mines & Minerals by the !Sth of the succeeding month, unless otherwise directed. MONTHLY REPORT OF DRILLING AND WORKOVER OPERATIONS Drill Site #1 (32-7-10-15) Page 2 of 2 March 19, 1970 2nd stage: Mixed 800 sxs Class "G" premixed w/lO% gel, 104# slurry, dry cmt -50°, slurry 70°, mix wtr 88°, mixing time 75-min. Displ '.~/485 bbls mud in 55-min w/rig pm~ closed. DV clr w/2500 psi. CIP @ 9'35 PM 2-23-70. Instld 9-5/8" X 13-3/8" pack off. Tstd w/5000 psi for 20-rain - OK. Instld 5" rams. LD HWDP & tstd Hydril w/3000 psi - OK. Measured in hole w/8-1/2" bit on 180' HWDP to 6389'. Tstd csg w/1500 psi OK. DO DV clr @ 6392' RI CO firm cmt 9035-9817'. Ran GR, CBL-CCL 9817-910~. Perfd 4 1/2" holes/p~ 9360-9370' & 9430-9440'. Ran vertical permeability tst. Set pkrs @ 9322' & 9401' w/sliding sleeve valves @ 9313' & 9363. Set pkrs. Opnd top sleeve v. alve. Displcd mud w/diesel oil in DP. Closed sleeve valve. Flowed lower zone to clear up same ~ 3180' B/D ~nte. SI zone @ 10:06 PM 2-27-70. Opnd lower sleeve. Flowed upper zone to clean up same @ 4370' B/D rate. SI zone @ 12'00 noon 2-28-70. Fishing out wireline plug. RECEiVeD 1970 / fianticRi fieldCompany North Ame ,,1 Producing Division .- Alaska District Post Office Box 360 Anchorage, Alaska 99501 Telephone 907 277-5637 March 3, 1970 Mr. Homer L. Burrell, Chairman Alaska Oil and Gas Conservation Committee Department of Natural Resources State of Alaska 3001 Porcupine Drive Anchorage, Alaska 99504 Dear Mr. Burrell- TRM KLV . REL ~ FIL~ We have checked into the violations reported to us on February 17, 1970, and we have the following re~ort from our field people. Drill Site No. 1 - (32-7-10-15) The lower kelly cock is now in use on the well and has been installed on the kelly. The high pressure le~k.referred to has been repaired. The stab-in ball type valve has still not arrived at location. This was ordered January 2 by our local office and the purchase order copy attached was placed January 13, 1970. As- of today, the valve is in route, having actually left the factory February' 24, 1970. We did not realize the large amount of lead time to procure these high pressure valves. _BeecheS Point State No. 1 We have received the second valve for this rig and we now have both the lower kelly cock and the stab-in ball type valve on the rig floor. Again, we were faced with late delivery on these valves. Regarding the actuation and testing of the kelly cock, we have incorporated this into our blowout preventer test procedure on all wells on the North Slope. Very truly yours, L. E. Wilson LEW: ve Encl os ure cc: Mr. R. F. Cox Form No. P--4 REV. 9-30-67 STATE OF ALASKA SUBI~%IT ~N D~iPLICATE AND GAS CONSERVATION COMMITTEE MONTHLY REPORT OF DRILLING AND WORKOVER OPERATIONS 1 0IL ,~ GA8 ~ WELL -- WELL OTHER NA/~E OF OP~-'~ATOR Atlantic Richfield Company 3. ADDRESS OF OPEI~kTOR P. 0. Box 360, Anchorage, Alaska 99501 4. LOCATION OF WELL 193' S & 1356' E fr. NW cr Sec 8, T10N, R15E, UM APl NL'A~ERICAL CODE KLV i._~f~j 50-029-20053 ~u~, ~ REL 5~ !~ - ~-2832g 7. IF INDIA.N, ALOTTEE OR TRIBE i~.'~Xi~: ,1 - FILE _ , - 8. Lq~'IT, F.~RAI OR LEASE Drill Site #1 9. WELL NO. 32-7-10-15 10. FIELD A.N'D POOL. OR WILDCAT Prudhoe Bay Field $ ~_d!erochit 11. SEC., T., R., A~.. (BOq~O.%{ HOLE OBJECTIVE) Sec 7, TiON: R15E; UM 12. PE/RAClT NO. 69-119 13. REPORT TOTAL DEi~TH AT END OF MONTH, CI-L~NGES IN HOLE SIZE, CASING A_N/) CE!ViENTING JOBS INCLUDING DEPTH SET ~ VOLLrNfES USED, PERFORATIONS, TESTS A/ND RESULTS, FISHING JOBS, JUNK IN HOLE A/~D SIDE-TRACKED HOLE A.ND ANY OTI-~R SIGNIFICANT CIiANGES IN HOL~ CONDITIONS. JANUARY, 19 70 Spudded @ 5:00 PM 1-17-70. Drld 17-1/2" hole 0-800'. Opnd 17-1/2" hole to 26" 0-779'. 20" cs5 @ 695'. Ran 13 jts 542.69' 20" 94# H-40 csg w/Vetco thds w/3~Regan 20'' slip jts (110.40'), loc @ 197', 320', & 442'. Hung csg on 20" fluted hgr w/"EC" clr@ 521'. Has Howco Duplex float shoe @ 695'. Csg lnded..@ 695.59'. Centralizers on btm 3 jts. Cmtd 20" csg w/275 sx Fondu neat cmt. Displ w/400 CF mud. CIP @ 11:00 PM 1-20-70. PO of Duplex Shoe, set back 1 stand & circ out. Instld 20" Hydril & flow line, tst Hydril w/1000 psi-OK. Ran 17-1/2" bit. Drld 17-1/2" hole 800-3055'. At csg shoe broke formation down w/440 psi. 13-3/8" cs.~ @ 3004'. Ran 78 jts 13-3/8" 72# N-80 Buttress csg (3013' incl shoe, fc & lndg st & DV clr). Cmtd csg in two stages. 1st stage w/500 sx Fondu 1:1 FlyAsh cmt followed w/800 sx Class "G" neat cmt. CIP @ 10:30 AM 1-28-70. Opnd DV @ 764' w/600 psi. 2nd stage cmtd w/150 sx Fondu 1:1 FlyAsh. Displ w/134 CF mud. Bmpd plug & closed DV w/i500 psi. CIP @ 2:30 PM 1-28-70. Displd mud behind 13~3/8" x 20" annulus w/20 bbls-wtr treated w/sugar. Instld speedhead. Tstd packing w/2000 psi-OK. Instld BOPE & accumulator lines. Tstd CSO, pipe rams & Manifold w/5000 psi. Tstd Hydril w/3000 psi. Ran 12-1/4" bit. DO DV clr@ 761', tstd csg w/1500 psi-OK. · 14. I hereby certify that the Ior?.g4~g is ~e and correct ,,sw~ ....... /c~ ~/~/~~Z.~ =wn~ District Drlg Supervisor,A.,., ~--//~-' 70 NOTE--Repo/~/~ this form is required for each calendar month, regardless of the status of operations, and must be filed in duplicate with the Divisional Mines & Minerals by the 15th of the succeeding me nth, unless otherwise directed. ANCHORAGE 99502 December 29, DEP~%RT~ffENT O~ F~SH AND GAM'E Mr. R..D. Johnstone District Drilling Supervisor Atlantic Richfield Company P. O. Box 360 Anchorage, Alaska 99501 FILE Re: Drill Site #1 - 32-7-10-15 Atlantic Richfield Co., operator Dear Mr. Johnstone: In reference to the subject drilling locati.o~ in Section 7, Township ION, Range 15E, U.P.M., the following stipulations are required to preserve and protect fish and game resources: 1. Prior. to the start of drilling a gravel pad of thickness sufficient to ~. prevent degradation of permafrost will be constructed. 2.' Access to this site will be-only by an all-season gravel road or by aircraft. 3. Prior to the beginning of drilling, a sump of sufficient size to contain all waste fluids will be constructed. This sump must be impervious to oil and oil products at all seasons during the year. Prior to abandonment of the site, the sump must be cleaned of oil and covered. 4. The operator must dispose of all waste, including garbage, by burning, with non-combustible material and unburned residue disposed of in a manner and at a location acceptable to the Alaska Department of Fish and Game, i.e., in some locations burial may be necessary, in others removal from the. site may be required. 5. -No stream or body of water will have any sewage or waste water added to it. 6. At no time will streams be blocked to fish movement. 7. This office will be notified on completion of drilling at this location. s~atement: The foregoing provi'si.oas do not relieve the lessee and/or his contractors or assignees of any responsibilities or provisions required by law or regulation of the State of Alaska or the federal government. cc: B. Hilliker G. Van Wyhe H. Butte11 S. Braden ~J¥ _J~ION OF OIL ~ .G~&~ ANCHO~E S~rely [ours,,/~ Habitat BiologTst ALASKA OIL A~D OAS CO~SgRVATION ~TTEE December 22, 1969 ~ro R. D. Johnstone A~lan~t¢ Richfield Cc~pany P. O. ~ 360 A~ehorage, Alaska 99501 Re: Drill Site tl - 32-7-10-15 Enclosed ia the a~proved a~plleation f~ pe~mlt, to drill 't~e above ~e~er~'~e~d well o~ ~r ~.~t ~~.be~ 22, 19~9 a.~ a lo.eatlo~ In ~e.etl~ 7:~, Te~nahtp 10~., ~ tSE, U~, ~t~ed. A l~eKAst.~ su~e.e~ .pla~ must be .~any ~"Ivea, s 1~ Alaska ~ thele draina~e $2~ have b~n el~at-- la~l~ p~~lga.ted t~e~de~ (Title 5, Alaska ~dmtnia~ative C~e). offlee, ~~~n~ Of FiSh ~ O~e, 1015 I~terna~l~a.1 ~ :~ o~a~. AI~ 99502. and the r~gula~t~ns~, S~! lnelu~ ~he ealib~att~ file (1) ~ of In ~ ~le. (2) eh~gea ~.~d type ~ addttloaal Alaska District Post Office Box 360 Anchorage, Alaska 99501 Telephone 907 277-5637 ; November 28, 1969 State of Alaska Department of Natural Resources Oil and Gas Division 3001 Porcupine Drive Anchorage, Alaska 99504 Attention:" Mr. Homer Burrell Gentlemen: SUBJECT- Drill Site No. 1 Well No. 32-7-10-15 In compliance wi th Paragraph 2009 of the "Oil and Gas Con- servation Regulations and Statutes'~ we wish a variance to Paragraph 2056 in Sub-Chapter 2 - Drilling. In lieu of cementing surface casing to the surface, we wish to continue the procedure used in Well No. 32-8-10-15, i.e. cement 200' around the shoe of.the;20" casing, using 20" slip joints in the casing string to compensate for any subsidence that may result if the permafrost is thawed and then stage cementing the next casing string (13-3/8") from its setting depth (3000') back 200' into the 20" casing string. The above procedure has been explained in detail at the hearing when the. Permit to Drill Well No 32-8-10-15 was submitted and again during the Prudhoe B~y Field Rules Hearings in November, 1969. We are enclosing the Application for Permit to Drill, location plat, and the $50 filing fee for the above referenced well. Very truly yours, Oo h 'to.e stric~.Dril ling Supervisor RDJ' ve .Enclosures. STATE OF ALASKA SUBMIT IN TRIPt (O~her instructions 6n reverse side) 50-029-20053 OIL AND GAS CONSERVATION COMMITTEE APPLICATION FOR PERMIT TO DRILL, DEEPEN, OR PLUG BACK 1tu. TTPm Or WORK DRILL [~ °'" r~ °"[2 9. NAME OF OPEI~kTOR Atlantic Richfield Company 3. ADDRESS O~ OPF_.R~TOR P.0. Box 360, Anchorage, Alaska 99501 4. LOCATION OF WELL At surface 193'S & 1356'E fr NW cr Sec 8, TION, R15E, UM At proposed prod. zone 1320'S & 1320'W fr NE Cr Sec 7, TION, R15E, UM DEEPEN []] PLUG BACK J-] MUI.TIPI.E ~_~ ZONE 13. DISTANCE IN MILES AND DIRECTION F.-~OM NEAREST TOWN OR.POST OFFICE' 360 Mi les North of Fairbanks 6. LEASE DI~I/HGNATION A. ND S~RIAL NO. ADL 28329 7. IF INDIAN, A.I_ff~O'l-.-J~; OR TRIBE NA1V~ 8. UNIT FARM OR LEASE NAME Dr(il Site #1 9. WELt. NO. 32-7-10-15 10,..FIEI.~ AND P...OOL, ~ WILDCAT ' Pruanoe Pay ~lelCl HOLE OBJECTIVE) Sec 7, TION, R15E, UM 14. BOND INFORMATION: Statewi de TYPE Surety and/or No. DISTANCE FROM PROPOSED* LOCATION TO NEAREST PROPERTY OR LEASE LINE, FT. (Also to nearest dr(g, unit, if any) Federal Insurance Co. #8011-34-40 i l0. NO. OF ACRES IN LEASE 1320' J 2560 J lg. PROPOSED DEPTH 19950' DD (9250' 18. DISTANCE FROM PROPOSED LOCATION* TO NEAREST WELL DRILLING, COMPLETED. OR APPLIED FOR, FT. 52 80' $100,000 Amotmt 17. NO. ACRES ASSIGNED TO THiS WELL 20, ROTARY OR CABLE TOOLS Rotary 160 VD) 21. ELEVATIONS (Show whether DF, RT, C-R, etc.) 22. APPROX. DATE WORK WILL STA, RT* 73' KB December 20, 1969 23. PROPOSED CASING AND CEMENTING PROGRAM SIZE OF HOLE SIZE OF CASING! WEIGHT PER FOOT GRAI)E SETTING DEPTH qUANTITY OF CleMENT 39" 30" 157.5 B 125' KB 130 sxs Fondu circ to surface 26" 20" 94 H 700.' 300 sxs Fondu ~'//~ 17-1/2" 13-3/8" 72. · N 3000' lO00 "G" & 1000 Fondu 12-1/4" q-5/a" L47. aR 5. 40 .~ 9050 2000 "G" Staae /:,'/?'~ Well to be directionally drilled below 13-3/8" casing. 20" 2000# Hydri l on 20" casing 13-5/8" 5000# Hydril and Cameron gates w/CSO and DP rams on 13-3/8" casino. Logs at T.D. DIL & Sonic from TD to 3000'. el Density-GR and Microlaterolog across zone of inter No cores. No mud logs. ~ ABO~ SPA~ D~BE ~OPOS~ PR~R~: If ~1 is ~ dee~n or plug ~, give ~ on present p~u~K~ pro~ ~w produ~ive ~. If propel M W drill or d~n dMe~o~lly,, give pertinent ~ on ~bsu~a~ ~t~J~~Y~ ~ue ye.(col dept. Give blo~ut preventer p~gram. -- S_G , ,' ~/ . , , , ' / ', ------------ .... ,-- ' ' (This space for State ofiic~us~ CONDITIONS OF APPROVAL, IF ANY: jS~LESANDCOREC~REQUII~D, ~_.,, ~ .... [~~u~Exception t° 2056(a) granted jby f~ ~No ~ck;~s~,.l~;+~'t~~c~'~ J C.0.~85. See Transmittal Letter J ' ~~o"~'s~w~ ~~ - I *'.~.L '~~ ~o~, ' ' ', ,,, v -m .. ~ ./~f -.' ' '~~er,Alaska 0i< & ~s ~onse~~Cte $2- 7-10-15 ~,~ 7 J ATLANTIC RICHFIELD CO.": PROPOSED LOCATION 32-7-10-15 DRILL SITE NO. I ARCTIC SLOPE AL ASK&i-~. . . SCALE I"= i/2 Mile II- Company ~/~ ~ Lease & Well No. ~,/,/~/~ '~x--,yZ- 7_ /6 , /,F CHECK LIST FOR NEW WELL PERMITS Yes No Remarks 1. Is well to be located in a defined pool ................. ?~ Do s tatewi de ru 1 es apply ..................... K/~AC Is a registered survey plat attached , , ................. Is well )ocated p, oper distance from property line ........... ~ Is well located proper distance from other wells ............ %/~X~ Is sufficient undedicated acreage available in this pool ........ ~/~ ~ i ' Is we to be dev a ted ......................... 8. Is operator the only affected party ................... ~ 9. Can permit be approved before ten-day wait ............... ,/7~)h< ~ 10. Does operator have a bond in force .... , ............... ll. Is conductor string provided ........ . .............. 1" 'Is enough cement used to circulate on conductor and surface ...... 13, Will cement tie in surface and intermediate or production strings . . . 14. Will cement cover all possible productive horizons ........... .~ 15. Will surface casing cover all fresh water zones ............ ...~~ ............................... 16. Will surface csg. internal burst equal .5 psi/ft, to next st,'ing .... 17. Will all casing give adequate safety in collapse and tension ...... lb, Docks BOPE have sufficient pressure rating .......... ~ .... ...................................... - . 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. ?aPe veti~tcation b~st:~n~ Sch~umbet~ez' ~aska ¢om~uttn. Center 26-0CT.~994 i5:06 **** REEL HEADER SERVICE NAME I EDiT DATE : 94/07/20 ORIGIN : FLZC REEL NAME .. : 94230 CONTINUATION # PREVIOUS REEL CO~ENT : ARCO ALASKA INCo, PR[!DHOE BAY, DS DATE : 94/07/20 O~I~IN : rblC T P~ NA~E : 94230 CONTINUAT~O~ # ~ 1 PREVIOUS TAPE : COMMENT I ARCO ALASKA ~NC,~ PRUDHOE BAY, DS ~"2' 5002~2005300 T~PE HEADER PRUDHOE BAY CASED HOLE WIRE~INE LOGS NELL NAMEI APl NUMBER: OPERATOR: L~GGING COMPANY1 TAPE CREATION DATE: dOB NUMBER: LOGGING ENGINEER~ OPERATOR WITNE~S~ SURFACE LOCATION SECTION~ TONN~HIP~ RANGEI FNLI FSL: rwb: ELEVATION~FT FROM MSL 0) KELLY BUSHING: DERRICK FLOOR: GROUND bEVEbI ~EL£, CASING RECORD ~,ST STRING 2ND STRING 3RD STRING PRODUCTION STRING 500292005300 ARCO ALASKA' :INC' ' WEL~ V SCHLUMBERGER :SEA ICES 20~Ub-94 0, WARNER D, REEM 8 ION 1356 73' O0 72'00 34,00 OPEN HOLE CASING DRILLERS eASING BIT SIZE (IN) S~ZE (IN) DEPTH (FT) WEIGHT (bB/FT] 13,375 :3004,O 72,00 9'625 9877,0 47,00 5'500 ~996,0 ~7,00 CURVE SHIFT DATA = ALL PASSES TO :STANDARD(MEASURED DEPTH] PAGE,,' 1 ~Is Ta~e Vert~/catton Llst[nc Schlumber.qer Alaska ¢omP~tino ~enter ~ASELIN RUN PASS DATE LOGG E CURVE FOR SHIFT8 TOO5 CODEI BCS CURVE COOE~ GR NU~BE~ NU~BER~ LO¢¢EDI lNG CONPANY~ RASELINE DEPTH 9690 5 9680 $ 9665 0 9661 0 9629 $ 9624 0 9584 5 9533 0 o 94 0 9468 5 944? 0 9440 0 9427 5 9423 $ 9405 5 9395 5 9392 5 9391 0 9372 0 9359 5 9353 5 9343 0 9308 O 100 0 RE~ARK$1 --'-'-----EQUIVAbENT UNSXIFTED DEPTH'''''''--' GRCH CNTD 885' 9679,0 9660,::5 9660.5 962,4,0 9624,0 9585.0 9532°O 9532°0 9470,0 9470 9440,0 9429°0 9424°5 9405,5 9395°5 9394°O 9394.0 937t,5 9361.5 9355,0 9345,0 9310°0 9309:0 lo2.o ~o1.:o THE I~FOR~ATION PERTAINING T0 THE.OPEN.HOLE b0G suCH A6 bOGGING DATE. bOGGING: COMPANY. PASANUMBER AND RUN NUMBER WAS NO? PROVIDED WITH'THE TAPE SUPPLIED BY THE: CLIENT, THE DEPTH. CORRECT!ON SHOWN ABOVE REFLECT CASED HOLE GR TO OPEN HOhE GR AND CASED =HO~E NPH! =TO OPEN HO~E GR,., AL5 OTHER CNT CURVES WERE CARRI. ED WITH THE NPHI~SHIFT$. $ LIS 'raPe Verification L~st~nq Schlumberger laska Computing Center :26,,0C?.J~99~ 15106 3 **** FILE HEADER ~*~, FILE NAME : EDiT ,001 SERVICE : PGIC V~RSION i 001C01 DATF ~ 94/07/20 MAX REC SIZE : 1024 FIeF TYgE : LO LAST FILE : FTLF HEADER EDITED CURVES · - DeRth shtZted and cl~Pped curves for~each Pass ~n:seParate~':~iles,. PASS ~U~BER, 1 D~PTH INCREME~T~ 0.5000 ~IL~ SUMMARY LDWG TOOL CODE START DEPTH mmmmmmmmmmm 9687.0 9700.0 stop :9290.0 9290'0 CNTD $ ~URVE SHIFT DATA - PASS TO PASS(MEASURED DEPTH) 9ASELINE CURVE FOR SHIFTS LDW CURV PASS NUMBER~ # ----------EOUIVALE,T UNSHIFTED DEPTH'''''''''' BASELINE DEPTH # ~E~ARKS: THIS FILE cONTAINS PASS #1 OF THE CNTD. NO pASS TO PASS SHIFTS WERE APPLIED TO THIS DATA. $ LTS FORMAT DATA TASTE TYPE : CONS TUN! VALU · - DEF mmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmm"mmmm~mmm~mmm~m~mm~'m~mm~m*~! CN ARCO ALASKA, INC :Company Name ' Field Name FN PRUDHOB BAY WN DS ~-2 We~1 Name APIN 50'029'20053'00 API Serial NumbeT FL ~93''FNb &:1356"PWG 'SectlonField Location S~C? TuWN ION Township RANG 15E Range LIS TaPe verXficatXon Listinc~ $chlumberqer Alaska Computlnq Center 26..0CT'"1994 15106 PAGE" 4 TUN! COO~ NORT~ ~bOPE STAT ALASKA NAT! USA SON 873 PDAT MSL EPD rT 0 APD rT 73, EKB FT 7~, EOf FT 7 , EG~ FT ~4 TOD FT 9B~7o TDL FT 9703, BLI FT 9700. TLI FT 9290. OFT CRUDE TLA8 OllOB i9-APR-94 VALU DEF! County Witness Name service Order Number Permanent datum Elevation of ~ermanent Datum Log ~easured From ADoYe Permanent Datum . Elevation of Kelly Bushing Elevation cZ DerricE Floor Elevation of-Ground Level Total DePth.>'- Drftler Total Depth- Logger Bottom Log interval Top Log'Interval DrilliLg'FlUXd T~pe TABLE TYPE ~ CURV DEF! DEPT Depth · NPH! Compensated. Neutro~ Porosit¥,.8$ ~atri~, Cal!& dead ~time curt, N~AT Neutron ~ation Non Dead time Corrected (N/F) CRAT Neutron Ratio, Dead Time Corrected (RN/RF) · NCNT Raw Near Detector count Rate, Dead~imeCotrected FCNT Raw rat Detector Count rate, Dead Time Corrected CfTC Corrected Far Detector Count~Rate CNTC Corrected Near Detector Count Rate GRCH Gamma Ray &n,~Casing ?~NS Surface ~en~on COL CCb. Amplltude GR APl Corrected Gamma Ray · · mmmmmmammmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmammmmmmmmmm!mammmmmm FORMAT SPECIFICATION RECORD SET TYPE - 64EB,*I TYPE REPR CODE VALUE 1 66 0 2 66 0 3 73 48 4 66 ! 5 66 ?aPe Verification bistinq chl~mbe~geg AlasK Comput.tnq Centeg PAGE~ mmmmmmmmmmmmmmmmmmmmmmmmmmmm!mm TYPE REPR CODE VAbUE ? 65 8 68 0 5 1~ 66 21 1~ 6B 1) 66 0 14 65 ~T 15 66 68 16 66 1 0 66 0 mmmmemmmmmmmmmmmmmmmm~mmmm~#m ** SE? TYPE - CHAN ** NAM~ SERV UNIT SERVICE API AP1 APl API FILE NUMB NUMB SIZE REPR PRDCES.& ID ORDER # bOG TYPE CbAS$ MOD NUMB SAMP EbEM CODE (HEX) D~PT FT 467873 O0 000 O0 0 I I I 4 68 0000000000 NPH! CNTD PU-8 487873 O0 000 O0 0 I i I 4 68 0000000000 NRA~ CN?D 487873 O0 000 O0 0 I I I 4 68 0000000000 CRA? CNTD 487873 00 000 00 0 I 1 t 4 68 0000000000 NCNT CNTD CPS 487873 O0 000 O0 0 I I 1 4 68 0000000000 FCNT CNTD CPS 487873 O0 000 O0 0 I I I 4 68 0000000000 CFTC CNTD CPS 487873 O0 000 O0 0 I 1 I 4 68 0000000000 CNTC CNTD CPS 487873 O0 000 O0 0 I ! 1 4 68 0000000000 GRCH CNTD GAP! 487873 O0 000 O0 0 I I I 4 68 0000000000 T~NS CNTD bB 487873 O0 000 O0 0 I ! I 4 68 0000000000 CCh CNTD V 487873 Gm OH GAP! 487873 O0 000 O0 0 I ! I 4 68 0000000000 O0 000 O0 0 I I I 4 68 0000000000 DATA NCNT.C~TD -999,250 FCNT,CNTD -999,:250 ~:CFTC'.'CNTD .999-.250 GRCM.CNTD -999,250 T~NS'CNTD -999:.250 CCb'CNTD 999.250 NCNT.CNTD -999'250 FCNT.'CNTD .,99g.250 ,C~FTC'CNTD ~g99.~250 GRC..CNTD -999.250 ?ENS'CNTD 999.:250 ~CCb,!~CNTD 999-:250 CNTC~CN?D ,GR,-.O~ CNTC'CNTD GR-O~ ' 99.000 -999j2~0 -999'250 ~09~,,200 END OF DATA LIS ?eve Verification Llstinq Schlumberqer Alaska Computin~ Center 26-0CT-1994 15106 **** FILE TRAILER **** FZL~ NAME = EDiT .001 SERVICE { FLOC VERSIO~ { OO1CO! DtT~ : 94/07/20 MAX REC SIZE { 1024 F~LE TYPE : LO L~$T FILE { **** F~LE HEADER FILE NAME { EPlT .002 S~RVlCE { FLIC VERSION { 001C0{ DATE { 94/07/20 M~X REC StZE { 1024 FILE TYPE { LO LAS? FILE FILE HEADER FILE NUMBER{ 2 EDITED CURVES Depth Shifted and cl[PUed curves for each Pass in separate ~tles, 2 0.5000 PASS NUMBER{ DEPTH INCREMENT~ # FILE SUMMARY LDWG TOOL CODE START DEPTH :S'OP:DEP?H ';;;;:;'"' '""""' CN?D 9700.0 :9290,0 $ CURVE SHIFT DATA - PASS TO PASs(MEASURED DEPTH) BASELINE CURVE FOR SHIFTS LDWG CURVE CODE{ GRCH PASS NUMBER{ 1 RASELINE DEPTH ~8888 0 9691 5 9687 5 9677 5 9672 5 9668 0 9662 5 9656.0 9627.5 9625,0 9601.5 ----------EQUIVALENT UNSHIFTED DEPTH''---'''-- GRCH CNTD 9690.5 9686'0 9677.0 967!.5 9666-5 9661.0 9654,5 9626,5 9623,~ 9600.~ C, I ! r~ bis ~a~e Veri~Ication ~lst~ng Schlumberger Alaska ¢omp~t!ng Center ~26-0C?'1994 ~S)06 PAGE) 8 TU~! VAbU D¢~! TDL FT g703,, TOtal Depth BLI FT 9-/00,. BOttOm ~o~ InterVal TLI FT 9290. Top boo Interval~ DFT CRUDE Drtll!n~ :Fluid Type TLA~ Oil08 ~I9'APR'94 Tlme.bo~ge'r at Bottom T~BLE TYPE I CURV DEPT NPH! NRAT CRAT NCNT FCNT CFTC CNTC G~CH T~N~ DEF! Depth ¢om~ensated, Neutro2 Porosttv, SS Mat Neutron Ration Non Dead t~me. Corrected Neutron Rat~o, Dead Tlme Corrected ~aw ~ear Detector_Cpu.Pt Rate,,Dead ~lme ,Raw Far Detector count rate' Dead :?$me,Corrected Corrected Par Detector CoUnt Rate Corrected Near Detector Count Rate ~amma Ray 8urtace.Tenslon COb COb ~mplltude DATA SET mmmmmmmmmmmmmmmmmmmmmmmmmmme~m: TYPE REPR CODE VAbUE ! 66 2 66 3 73 4 66 5 66 6 '/3 '7 65 8 68 9 65 Il, 66 !2 68 13 66 14 65 !5 66 16 66 0 66 em mi lei 44 l ~0 68 ! mmmmmmmmemmmmmmmmmmm, mmmmeem: LIS Ta~e VerI~ication Listing Schlumberger AlasKa Computing Center 2e-oc?'!994 ts:oe ~* SET TYPE~- CHAN ~ NAME SERV UNIT SERVICE APE APl AP! AP! FILE NUMS NUMB SIZE REPR PROCESS ID ORDER # bOG TYPE CLASS MOD NUMB SAMP ELEM CODE (HEX) DEPT FT 487873 O0 000 O0 0 2 ! I 4 68 0000000000 NPHT CNTD PU-S 48787~ O0 000 O0 0 2 I 1 4 68 0000000000 NRAT CNTD 487873 O0 000 O0 0 2 I I 4 68 0000000000 CPAT CNTD 487873 O0 000 O0 0 ~ ! ! 4 68 0000000000 NCNT CNTD CPS 487873 O0 000 O0 0 2 ! I 4 68 0000000000 FCNT CNTD CPS 487873 O0 000 O0 0 2 I I 4 68 0000000000 CFTC CNTD CPS 487873 O0 000 O0 0 2 1 I 4 68 0000000000 CNT¢ CNTD CPS 487873 O0 000 O0 0 2 ! 1 4 68 0000000000 GRCH CNTD GAPI 487873 O0 000 O0 0 2 I ! 4 68 0000000000 T~NS CNTD LB 487873 O0 000 O0 0 2 I I 4 68 0000000000 CCL CNTD V 487873 O0 000 O0 0 2 I ! 4 68 0000000000 DEPT NCNT:CNTD GRC~.CNTD GRCH.CNTD 9700.000 2562'563 '999*250 9290.000 3356'733 45.188 NPHI'¢NTD FCNT'CNTD TENS*CNTD NPHIJ{CNTD FCNT!,CNTD TENS.CNTD 49-578 NRATi'CNTD 4!6~834 CFTC~CNTD 1410'000 CCb~C~TD O0 ~CFTCj~CNTD ,1315.000 CCb!~CNTD 398-~499 ~CNTC*,CNTD 0.000 786'80g CNTC*CNTD ~0.000 · 6' 471 26! I~.-747 4-550 35)2,93.1 END OF DATA FILF NAME : EDIT ,002 SERVICE : FbIC VERSION ~ OOiCO! DAT~ ~ 94/07/20 MAX ~EC SIZE : 1024 F~LE TYPE ~ LO LAST FILE ~ FILE NAME I EDIT ,003 SERVICE ] FLIC VERSION I OO1CO! DATE I 94/07/20 MAX R~C SIZ~ ~ i024 FILE TYPE I LO LAST FILE = LIS ?a~e veri~.car,~on ~ist~na Schlumberger Alaska ¢om~utlnc Center 26-0C?"1994 I5:06 PAGE~ FILE HEADER FILE NUMBER~ 3 EDITED CURVES Depth shifted and clipped curves ~or ,each pass DEPTH INCREMENTI 0.5000 FILE SUMMARY tDWG TOOL CODE START DEPTH 9700.0 CNTD $ ~URVE SHIFT DATA - PASS TO PASS{MEASURED 'DEPTH) BASELINE CURVE FOR .sHIrTS bDWC CURVE CODE~ GRCH PASS NUMBERI 1 BASELINE DEPTH mem..mm.mmm 9290,0 ----------EOUIVA.LENT U.$.Ir~ED DEPTH-''-."''-'' 9690 5 9682 0 9662 0 9658 0 9651 5 9628 5 96 0 959~ 0 959 5 9584 0 9570 0 9548 5 9522 0 951~ 0 950 0 9476 0 9466 5 9465 5 943] 0 9420 5 9385 0 9363 0 9346 5 9344 0 9340 0 9305 5 9300 5 100 0 GRCH CNTD, .-..... .......! 88891-.0 88891.0 69 .5 ~685,5 9665.0 9661.0 9654 9624.0 9610.0 600594!1 9588 9574 9525 9521.0 9506.0 9478,5 9469.5 ~9468'5 9434~0 9423.5 9388.0 9366'5 9349'O 9347.,0 9343,0 9308-5 9300.0 9303.5 103.0 103.0 REMARKS= THIS FILE CONTAINS PASS #3 OF THE: C~TD' THE DEPTH LIS ?ame vert~ication L~st~ng SchIumberger AlasKa ¢omputlng Center CORRECTIONS SHOWN ABOVE REFLECT PASS #3 GRCH TO PASS #! GRCH AND PASS #3 NPHI TO PASS Wt NPHI. ALL OTHER CNTD CURVES WERE CARRIED WITH THE NPH! SHIRTS. $ bis FORMAT DATA TABLE TYPE I -CONS TUN! VALU DEE! CN ARCO ALASKA, INC. Company Name FN PRUDHOE BAY rleld Name w~ DS 1-2 ~ell Name API~ 50-02~-20053-00 APl Serial Number FL Ig3''FNL & ~356' F~ Eield Location S[CT 8 Section TOWN iON Township R~.NG 1SE Range COUN NORTH SLOPE County STAT ALASKA State or Prov~nce ~aT! USA ~atlon ~ITN ~ REEM witness Name SON ~7873 Service Order Number PDAT MSb Permanent datum EPD FT ~ £1evation bt Permanent Datum b~F ~ bog Measured From ADD rT 7 7~'3 Above permanent Datum Bushing · . , Elevat~on bt Kell¥cK~ EOF rT 72. Elevation bt Derr Floof ~D FT ~7 Elevatlon bt. Ground Level · Total Depth: Driller T~-L rT 9703, Total Depth'- Logger BLI FT 9~00' Bottom bog Interval TLI FT 9~90.o TOp LOg IntervaI DrT CRUDE Drilling Fluid TYpe T~AB Oil08 19-APR-94 Time bo~qer at Bottom TABLE TYPE I CURV DEPT NPH! N~AT CRAT FCNT CFTC CNTC GRCH TENS Demth Compensated Neutron Porosity, 85 Matrix, calf & dead time corr. Neutron Ration Non-Dead time Corrected Neutron Ratio, Dead Time Corrected (RN/RF) Raw Near Detector Count Rate, Dead Time Correcte.d ~aw rat Detector Count rate, Dead Time Corrected Corrected rat' Detector.Count Rate Corrected Near Detector Count Rate Camma Ray In. Casin~ Surface ~enston ,TaPe ye tt~cat~on bist~no Schlumeetge~ AlasHa Computtnq Center .DEF! COL CCL~AmoZ!tude 12 ** DA?A FORMAT SPECIFICATION RECORD ** ** SET TYPE - 64EB ** TYPE REPR CODE VAbUE ! 66 0 2 66 0 3 73 44 4 66 5 66 6 73 7 65 1! 66 23 12 68 [3 66 0 14 65 15 66 68 16 66 ! 0 66 mmmmmmmmmmmmmmmmmmmmmmm~#mmmmm ** SET TYPE - CHAN ** m~m~mm~mmm~mmmmmmm~mmm~m~mmm~mm~m~mmmm~m~m~~m~m~mmmm~mmm~m~mmmm~mmmm~ i . · . NAME SERV UNIT 'SERVICE APl APl APl AP! FIbE NUMB NUMB SIZE REPR PROCE$ !D ORDER # bOG TYPE CbASS NOD NUMB- 8AMP EbEM CODE (HEX) ~m~m~mm~mm~m~mmm~mm~m~m~m~mmm~~mm~m~m~mmmmmm~m~mm~m~mmmmm~m~mmm DEPT FT..- 4878?3 O0 000 O0 0 3 1 I 4 68 00000000 NPH! CNTD PU '$ 487873 O0 000 O0 0 3 ! 1 4 68 00000000 ~.A? CN?D ~487~73 oo ooo OD o 3 ~ ~ ~ 6e oooooooo CRAT C~D 487873 O0 000 O0 0 3 ! I 4 68 00000000 NCNT CNTD CPS 487873 O0 000 O0 0 3 ! I 4 68 00000000 FeN? CNTD CPS 48787~ DO ooo DO o 3 [ I 4 6B oooooo00 cr~c c.~o cps 4sve?~ OD ooo OD o 3 1 ~ ~ 68 oooooooo CNTC CN?D CPS 4.878730..0 000 O0 0 3 1 1 4 68 00000000 GRC" CN?D GAP/ 487873 O0 000 O0 0 3 I I 4 68 00000000 ~s c.~o ~n .48?873 oo ooo OD o 3 i i 4 6e oooooooo CC~ CN?D V 487873 O0 000 O0 0 3 ! I 4 68 00000000 . m~mm O0 O0 O0 O0 O0 O0 O0 O0 O0 O0 O0 .tis ~Te.~e ver~cat~on L~st~n~ SChlumberqer Alas~a Co~PuclnO Center .. D~PT. 9700' 000 ~PHi:.~ C~TD ~C~T'CNTD 2468!;938 :FCNTi~C~TD GRCH'C~TD -999'250 T/:N$i:'CNTD 4~.402 NRATi~CNTD !400'802 CFTC'CNTD 370.000 CCL-CNTD 0o000 PAGEz 6,345 2493.987 13 ****' FiLE TRAILER FYLE NAME = EDIT '~.003 SERVICE : FLIC VERSION = 001'C01, DATE = 94/07/~0 ~AX REC~SIZE ~ !024 FILE TYPE : LO L.~ST :FILE F'~'LE NAME ~ EDIT °004 SERVICE ~ FL:IC VER$ION : O01C01 DAT~ : .94/07/20 ~X ~EC:sIZ~ : 1024 FIL~ TYPE ~ LO LAST FILE ~ FILE HEADER FILE NUM'BERI 4 AVERAGED CURVES Compensated Neut'ronl Ar~thmeti¢.average.ot edited Passes tot all curves Pulse~ Neut.ron} Unavera~ededtted.pasm~i Gamma Rav and backround counts{ arith, met~c average oi edl:ed S:atlc baseline uasses tot ali o:hercurves, DEPTH INCREMENT 0,5000 PAS~ES INCLUDED IN AVERAGE [DWG TOOL CODE PASS NUMBERS -.......-..... ............ CNTD 1, 2, 3, ~E~ARK$I THIS FILE CONTAINS THE ARITHMETIC AVERAGE OF THE THREE NTD PASSES.. ALL DEPTH CORRECTIONS WERE MADE BEFORE HE AVERAGE WAS COMPUTED. $ LIS FORMAT DATA 26-0CT-~994 15:06 PAGEI ~4 C~ ARCO ALASKA, INC. FN PRUDHOE W~ DS [-2 APIN 50-029'20053-00 FL 193' FNL & 1356' S~CT 8 TOW~ 10N RANG COUN NORTH sLOPE TAT ALASKA AT! USA WITN D..REEM PDA? EPD FT O, ~NF RKB APD FT ?~.. EKB FI 7 EDF FT 72, EGb FT 34 Tnb FT TD.b FT 9703. BL! PT 9700. TLI FT DFT TLA~ TUNI VALU FWL DEFI Company Name Field Name Well Name API Serla! Number Field Location Section Township Range County State or Prov~nce Nation Witness Name Service Order Number ~ermanent datum Elevation of Permanent Datum boq Neasured From A~ove Permanent Datum Elevation o~ Kelly Bushtnq Elevation o~ Derrick Floor Elevation of Ground bevel Total De,th .- Driller Total .Depth:- 5o~qer Bottom 5og Interval 9290. TOp boq Interval UDE D~lllinq FlUid Type uI~08 ~9-APR-94 Tlme boqoer atBottom TABLE TYPE ~ CURV ~m~ DEPT NPH! NRAT C~A? NCNT CFTC C~TC DEFI ..... epth . o~Pensated:...Neutron Porosity, SS:~atriX, calf & ~dead~ttme corr. Neutron Ration ,Non-..Dea~:~tlme CorreCted. (N/F) Neutron Ratlo,~Dead TlmeCorrected (RN/R~) .~ . Ra~ Near Detector Count Rate, Dead Time coffee[co Raw,Far DetectOr Count :rate"pea~ Time COrrected Corrected Far De~ector ¢ounf:Rate ' Cor.recte4 Near Detector'Count. Rate GRC~ Camma Ra~ ln..casln~ T~NS .Surface Tension '... PAGE~ ?¥PE REPR 2 6 3 7 4' 6 5 6 7 6 8 6 1! 6 13 6 ~.4 15 0 CODE .... VAbUE 0 0 40 :! 6 0 65 66 68 66 66 ! mmmmm,mmmmmm#mmmmmmmmmmmmm#mm~m ** SET TYPE - CHAN mmmm~mm~mmm~mmmmmmmmmmmmmmmmmmmmmmmmm~mm~mmmmm~m~m~m~mmmmmmmmmmmmmmmmmmmmmmmmmmmmmm NAME SERV UNIT SERVICE APl API lPI APl FILE NUMB NUMB SIZE REPR PROCESS ID ORDER # bOG TYPE CHAOS MOD NUMB SANP EbEN CODE CHEX) DEPT FT 487873 O0 000 O0 0 4 I I 4 68 0000000000 NPH'! CNAV PU-S 4878~3 O0 000 O0 0 4 t ! 4 68 0000000000 N~AT CNAV 487873 O0 000 O0 0 4 I I 4 68 0000000000 CRAT CNAV 487873 O0 000 O0 0 4 I I 4 68 0000000000 NCN~ CNAV CPS 487873 O0 000 O0 0 4 I I 4 68 0000000000 FCNT CNAV CPS 487873 O0 000 O0 0 4 ! I 4 68 0000000000 CFtC CNAV CPS 487873 O0 000 O0 0 4 I ~ 4 68 0000000000 CNTC CNAV CPS 487873 O0 000 O0 0 4 1 I ~ 68 0000000000 GRCH CN.AV GAPI 487873 O0 000 O0 0 4 ! ! 4 68 0000000000 TENS CNAV bB 487873 O0 000 .00 0 4 I ! 4 68 0000000000 I5 ,.* DATA ** D~P?. 9700"000 NPN{JCNAV 43'042 NRAT~*"¢NAV 6'460 CRAT'CNAV NCNT-CNAV 2536~j959 ?CNT~CNAV 398'242 CFTC~'CNAV 389.305 CNTC.CNAV G~CHiCNAV 389~,305 TENS~CNAV ~379.862 6 528 2552:197 END Or DATA ** So~l~mber~er A~a$~a Co~Puttn~ ~ente~ **** F~SE TRAILER FISE NAME : EDIT ,004 SERVICE VE~iO~ ~ 001C0 L~$T FILE **** FYLE HEADER FILE NAHE : EDIT ..005 'SERVICE : FLOC YERSION : DAT~ : 94/07/20 MAX EEC StZE : 1.0'2.4 FILE TYPE : LO LASTFILE F~LF NUMBER '5 RAW CURVES Cur'ves and [:°e ~eader:data ~or eech ~ass in:se.~arate .o.soOo PASS NUMBERI DEPTH INCREMENT: F!LE :SU~M,ARY VENDOR TOOL~CODE ~N?D llliili/llllI 9714.5 DATE LOG~EDI SOFTWARE VERSION:: TIME LOGGER ON BOTTO~I TD DRILLER CFT)~ TD LOGGER(FT)= ~Op LOG iNTER~A~i('FT) BOTTOM LOG INTER~AL ~FT')~ LOGGING,.SPEED (FPHR).' ~EPTH CONTROL USED (YES/NO)t TOOL ~$TRING~ (TOP ~TO BOTTOM) VENDOR TOOb CODE TOOL~TYPE CNTD CNTD CNTD CNTD CNTD .9279.0 AUXI. LLIARY MEASUREMENTS COMPENSATED BEUTRON AUX~LLIARY MODULE ::raw back:qround .!9.APR'94 108 :9703.0 9290 ~1800~'0 ~0 :.E~F! CAL-U~6i4 :c cio ilo AT~ AB 283 TaPe verif~cat~on SChlumberqer Alaska ComPutino Center PAGEI 9O"EHOLE AND CASIN~ 9A?A BOREHOLE CONDITIONS FLUID FLUID DENSITY (LB/G)i . SURFACE TEMPERATURE (DEGF)= BOTTOM HOLE TEMPERATURE (DEGF)= FLUID SALINITY ('PPN)I FLUID LEVEL FLUID RATE AT NEbLHEAD (BPM)I WATER CUTS (PCT)I GAS/OIL RATTO= CHOKE NEUTRON TOO 6 TOO[, TYPE (iEPI'THERMAL OR THERMAL)t MATRIX= MATRIX DENSITY1 HOLE CORRECTION (IN)= BLUELINE COUNT RATE NORMAL.IZATION IN OIL Z~NE TOP NORMALIZING WINDOW BASE NORMALIZING WINDOW( BLUESINE COUNT RATE SCALES SET BY FIELD ENGINEER FAR COUNT RATE LOW SCALE (CPS)= FAR COUNT RATE HIGH'SCA~E NEAR COUNT RATE LOW SCALE NEAR COUNT RATE HIGH SCALE (CPS)= TOOL STANDOFF REMARKS= TIED INTO BHC (SWS) DATED 2-20-?0. UMPED A TOTAL OF 5~ BBLS CRUDE.. PUMPED AT 1,5'2!:~.5 BBL/NIN WHILE LOGGING.. $ bis FOR~A'T DATA 3004.0 CRUDE THERMAL SANDSTONE 2.65 TABLE TYPE : CONS TUNI VALU . DEFI CN ARCO ALASKA, INCo Company Name FN PRUDMOE BAY Field~ame WN DS ~-~ Well Name APIN 50-029-~0053-00 API Serial Number F5 ~93' FNL & ~356' FWL r~eid Location SECT 8 Section TaPe Yerl~Ica~lon L~st~n~ Schlumberger Alaska ComPuting Center 26-0CT-1994 15=06 PA~E= 18 TUN! VA~U DEF! 'ON Township TOW~ 15~ Range RANG COUN NORTH SLOPE County STAT A~ASKA State or Prov~nce N~T! USA Nation WITN P. REEM Witness Name SON 487873 Service Order Number EPD FT ~ Elevation o~ Permanent Datum b~F ~B boq Neasured From APD FT 73. AboVe Permanent Datum EDF FT 72, Elevation ot Der c Floor Elevation of Ground Level ECU FT 34 TDD FT 98~?. Total Depth - Driller TDb FT 9703; Total Depth*- boqqet BL! FT 9?00° Bottom boq Interval T~I F'T 9290. Top boq Interval DFT CRUDE Dr111tnq FluidType TI, AB Oi108-19-APR-94 Time bo~ger at Bottom imm m mm mmmmmmmm m~limmmmmmm mmmlmmm~immmmllmmllmmmm,mmmmmmm~mmmmmmmmmmmm~ m#lt imm mmwlmmmlmmlmllltm mm m mm mm mmmmmm mm T~B5E TYPE I 'CURV .DE,FI .... DEPT NPHI T~RA RCNT ReFT CFTC G~ TENS CCh ComPensate~ Neutron Pot Raw Thermal Neu~ron,~Rat Therma! Neutron Ratio C~librated RAW NEAR CN? COUNT8 Corrected Neat Detector Count~ Rate Corrected Far'Detector Count Rate APZ~¢Orteoted Gamma Ray · Surface Tension COb Amplitude Cai! & dead time corr. DATA FORNAT :SPEC~[CATtO. 'RECORD ** SET TYPE -:64EB ** lmmmllwmmlmmmllllmlmemlmlmlm:mm TYPE REP~:!CODE . VALUE t 66 <2 66 3 73 44 4 66 ! Alaska Com er Schlumberqer putln~ Cent 26-0CT-i994 15106 PAGEI 19 TYPE REP~ CODE VALUE mmmmmmmmmmmmmmmmmmmmmmmmmmmmmm ? 65 8 68 0,5 9 65 F'T I! 66 23 12 68 13 66 0 !4 65 15 66 68 16 66 0 66 SET TYPE - CHAN ** NAM~ 8ERV UNIT SERVICE APl AP1 AP! ID ORDER # LOG.-'TYPE CLASS API FILE NUM~ NUMB SIZE MOD NUmB SAMP EbEM D~PT FT 487873 O0 000 O0 NPH! PS'I PU 487873 O0 000 O0 RTNR-PS! 487873 O0 000 O0 T~RR PSI 487873 00 000 00 RCNT PSi CPS 48.7873 O0 000 O0 RCFT P$I CPS 487873 O0 000 O0 CNT~ PS! CPS 487873 O0 00.0 O0 Cr?c P$1 CPS 487873 O0 00.0 O0 TENS PS! bB 48~87 00 000 O0 0 5 CCh PS1 V 48 87 O0 000 0'0 0 5 mmemmemmmemmmmmmmmmmmmmmmmmmmmemmmmmmmm~m~mmmmm' . 0 5 ! 1 4 0 5 ! i 4 0 5 I I 4 0 5 I i 4 0 5 ! I 4 0 5 I I 4 0 5 I 1 4 0 5 1 I 4 0 5 1 I 4 I 1 4, I I 4 REPR PROCESS CODE CHEX) 68 0000000000 68 0000000000 68 0000000000 68 0000000000 68 0000000000 68 0000000000 68 0000000000 68 0000000000 68 0000000000 68 0000000000 68 0000000000 ** DATA Gn.PS , 4?.8?5 mZ.S- St V3S'.O00 RCNT.-PSt 4~ 1217.2 47.:~ 787 RCFT~P$! 1 7 G~oP$1 37'.063 TEN$!gP8.! ~255.000 RTNRi'P81 6.000 TNRA. P$i CN?C'P$! 2504..524 CFTC.PSi CCh. P81 0.000 o:.Ago 6,283 398.605 ** END OF DATA Schlumbercje'r Alaslca. CompUttn~ center :26-0CT'1994 I5:06 PAGE~ 20 **** FILE TRAILER **** FILE NAME : EDIT .005 VERSZON : 001C01 DATE : 94/07/20 MAX RECSIZE :1024 F~LE TYPE : LO LAST FILE : **** FILE 'HEADER: **** r~bE NAME I .EDIT ,.006 SERVICE { FLIC VERSION : 001C01 DATE ~AX R~C Ft'LE TYPE LAST FILE : FILE HEADER RAW CURVES Curves and log ~eader data tot each ~ass in.separate PASS NUMBER: 2 DEPTH INCREMENT: 0,5000 F~DE SUMMARY VENDOR TOOL CODE START DEPTH CN?D LOG HEADER DATA sTOP DEPTH 9274.,5 SOFTWARE VERSXON: TD DRILLER 'TD LOGGER(FT), TOP LOG I.NTERVAb ~OTTOM LOG INTERVAL LOGGING SPEED (FPHR~I DEPTH CONTROL USED 19'APR'94 8 9817,0 g703'0 9290,0 9700,0 1800'0 NO TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE TOOL NUMBER C~ EOF1 C~TD ~OLLAR LOCATO~ CAL-UB-614 CNTD AUXILLIARY MEASUREMENTS ATC-CB-Ii6 CNTD COMPENSATED NEUTRON CNC-DA-I01 CNTD AUXIb~/ARY ~ODULE ATM-AB-283 $ tt. ies~ raw baclcqround pass in last fi 19-APR-94 LIS :?aPe Ver~icai:~on Listing SChlUmmerger Alaska Computing center PAGE= 21 BOREHOLE AND CASING DATA OPEN HOLE BIT StZE DRILLERS CASING DEPTH (FT)~ LO~GERS CASING DEPTH (FT)= BOREHOLE CONDITIONS FLUID TYPE= BOTTOM HOLE TENPERATURE ( : FLUID SALINITY (PPN}I G.AS/O{~ aATIO, CHOKE NEUTRON TOOL TOOL TYPE CEPITHERNAb OR THERNAL)= NAT~IX DENSZTY~ HOLE CORRECTION (IN)= BLUELINE COUNT ~ATE NORMALIZATION IN OIL ZONE TOP NORMALIZING WINDOW BASE NORMALIZING WINDOW (FT){ BLUELINE COUNT RATE SCAhES SET BY FI~D ENGINEER FAR COUNT RATE LO~H$CALE CPS)I FAR COUNT RATE HIG.' SCALE (CPS} CPS) NEAR COUNT RATE LOW SCALE · NEAR COUNT RATE HIGH SCALE (CPS)I TOOL STANDOFF TIED INTO BHC (SW8) DATED 2-20-?0, 30.04.0 CRUDE THERNAL SANDSTONE .2.65 ~UMPED A TOTAL OF 511 BBbS PUMPED AT 1',5'2!~§ BBb/MIN $ bis FORMAT DATA CRUDE,~ ~HISE bOGGING~ :TUNI . ...... VALU. DEF! N ARCO ALASKA. INC.. Company Name ~N PR. UDHOE BAY Field Name ~ DS t-~. ~ell Name ADz. 50-029.20053-00 AP! Serial Number Fl., 193''rNb &,1356':rwL Field Location $~CT 8 Section $chlumberqerAlasKa Computtn~ Center TUN! VA~U DEF! TOWH t. ON Townshtp RAN~ ISE Ranoe COU~ NORTH SLOPE County STAT ALASKA State or Province NAT! USA Nation W~T~ D..'REEN ~Itness Name SON 4878.73 Service O.rder Number P~AT NSL Permanent datum EPD FT O, Elevation of Permanent Datum b~F RK.~ Lo~ ~easured From APD PT 73. Above Permanent Datum EKB FT 73, Elevation o~.Kelly Bushln~ EDF FT 72. ElevatJo~ o~ Derrick Floor EGL FT 34 Elevation o~ Ground Level Total DePth - Driller TDL FT 9703. Total DePth.- Logger BLi FT 9900. Bottom boq Interval TLI FT 9290, Top Log Interval DFT CRUDE Drllllnq Fluid Type TLAB OtCOS.19-APR-94 T~me bo~ge'r at Bottom TABLE TYPE : CURV DEF! DEPT ~epth NPH! compensated ~eutron Porosity, 85 ~atr[~, call & dead time RTN~ Raw ~hermal Neutron..~eatio.. ' d T~RA Thermal Neutron Ratio Calibrate RCNT RAW NEAR CNT COUNTS RCFT RAN FAR cNT COUNTS CNTC Corrected Near Detector Count Rate CFTC Corrected Far Detector Count Rate G~ APIeCorrected Gamma Ray T~N8 Surface Tension · COL ,. CCh ~mpIltude ~ ** ~ATA ** SET :TYPE - 64EB ** :. TYPE ~EPR CODE VALUE. 2 66 0 3 73 44 4 66 ! LIS ?a~e Yerl~t¢~tio~ blsttno Schlumberger Al&stOa ComPutlnq. Center 26~0CT-~994 t5~06 23 TYPE REPR CODE VAbUE 5 66 6 73 ? ~5 9 65 ti 66 23 1,2 68 13 66 0 14 65 I5 66 68 16 66 0 66 I mmmmmmmmmmmmmm.mmmmmmmm.mmm#mmmm **.SET TYPE - CHAN NAME SERV UNIT SERVICE .APl APl AP! APl FlbE NUM~ NUMB SIZE REPR PROCES6 ID ORDER # bOG TYPE CbA$8 MOD NUMB SAMP EbEM CODE (HEX) ~ ~ ~,?.?~ oo ooo oo o s I I I s. oooooooooo .~.~ .s~ ~o,,?~?.~ oo ooo oo o s i ! , s~ oooooooooo .~...s~ ,0~ oo ooo oo o s I i , s~ oooooooooo ~.R~ .s~s.?.?~ oo ooo oo o s ~ 1 , $. oooooooooo .¢., .s~ c.s s,?,?~ oo ooo oo o s ~ ~ s s. oooooooooo ~¢~ .s~ cps 4s?.?~ oo ooo oo o s ~ ~ 4 6~ oooooooooo N?c P$~ cPS 4878~3 oo ooo oo o 6 ~ I 4 68 oooooooooo c~c ~s~ c.s 4~:?$~ oo ooo oo o s , ~ s s, oooooooooo ~. ~s~~A~ ~.707~ oo ooo oo o s ~ ~ s 6. oooooooooo ,~.s .s~ ~.so?~ ooooo oo o s ~ ~ 4 6o oooooooooo c¢~ .s~ v so? oo ooo oo o s ~ ~ 4 ~. oooooooooo D~P~ 9714~:000 NPHI~P$2 4t<*799 RTNR~PS2 6,.:100 RCNT~P$2 :2541~i:667 RCFT~P82 4t6:~:667 :CNTCi'PS2 2546.267 GR..PS2 47;875 ,TEN$:i~!PS2 885':000 :.C:Cb~:~:*,P$2 '0,000 ~' ..2141'500 ~PHI;iPS2 19,734 RTNR'P$2 3'595 CN?.PS2 41 3~861 RCFT~PS2 1.209~397 :CNTC'P$2 4250',204 GR:.P$2 39*844 T;~&~PS2 I320'000 ,CCb*~PS2 0.000 TNRA.PS2 CFTC.PS2 TNRA*P$2 CFTC.PS2 6.388 398.605 '/17 ** END OF DATA ** SChlumberger. Alaska CompuCLng Cancer FYLE NA~E = .EDZT ,-006 SERVICE VERSION : ~OOtCO! DATE : 94/07/20 ~AX ~REC S~ZE ~: !024 FI~ TYPE ~ ~0 LAST FILE ~FI~E NAME =: :EDIT ~.,007 VERSZON 001C01 ~AST FILE 26-0CT"!9~4 t5106 PAGE: 24 FYSE HEADER FYhE NUMBER 7 RA~ CURVES Curves and log header data for each pass in separate DEPTH INCREMENT: 0,5000 F~LE SUMNARY VENDOR.:TOOL CODE START DEPTH STOP DEPTH CHTD 971t,5 928~,0 gOG .HEADER DATA ~ATE ~OGGED~ $OFT~ARE VERSION~ TI~E LOGGER ON BOTTOM~ TD DRI. L~ER TD ~OGGER('ET), TOP LOG INTERV~h~ (FT)i BOTTON bOG ']N~ERYAL [FT){ LOGGING SPEED (FPHR), DEPTH CONTRO~ {'BED! (YES/O){N ~'iles~ raw backqround pass in last 19'APR'94 981' 0 970:0 929( 0 970< 0 1800i. o NO TOOL STRING.~(TOP TO BOTTOM) VENDOR TO0~ CODE TOOL TYPE TO0~ NUNBER C~T~ EOFI cNTD ~O~LAR ~OCATO~ CAL-UB-6~4 CNTD COMPENSATED NEUTRON CNC-DA-IOI CNTD AUXI~LIARY MODULE ATM-AB-283 $ mput:lno Center 26'OCT-1994 15:06 PAGE: 25 NG DATA :SING DEPTH ~ING DEPTH (LB/G): ATURE (DEGF): ~PERATURE (DEGF): WELLHEAD 3004,0 CRUDE THERMAL 0R THERNAL): THERMAL SANDSTON~E J tIN): 2.65 RATE NORMALIZATION IN OIL zONE JING WINDOW'-(FT): ' ;ZING WINDOW (FT)~ ~TE LOW SCALE (CPS): TE HIGH SCALE CCP$)i ATE LOW SCALE (CPS) ATE HIGH SCALE (CPS . TO BHC (SW8) DRTED 2-20-70. A ?OTAL OF 511BBLS CRUDE. AT 1,5-2.5 BBL/MIN WHILE bOGGING. VALU DEFI ARCo ALASKA, INC. Company Name PRUDHOE BAY Field ~ame DS 1-2 50'02q-20053-00 ~ell Na~e - ! Serial Number ~93' FN[, & 1356' rWL ~eld Location Section ~$ Ta~e Verification I~ist~n~ Schl,mberger Alaska Co, put,hq Cente~ TUN! VALU DEF! lON Township 1SE Range NORTH 8hOpE County AbASKA State or Province USA Nation D..RE~N ~itnes. a Name 487873 Service Order Number MSb Permanent datum Elevation ot Permanent Datum FT ~S bog Measured From FT 73. AbOVe Permanent Datum ~ Elevation of Kelly Bushin~ rTFT 77 ,' Elevat$On of Der cK Floor FT 34 Elevation of Ground bevel FT 9B[7. Total Pepth': Driller FT g~o3. Total DePth bogger FT 970o. Bottom boq Interval FT 9290. Top bog Interval CRUDE Drilling FluidType 0!:08 19-APR.-94 Time bogger at.Bottom TOWN RANG COUN STAT NAT! W!TN SON PDAT EPD APD EKB TDD DFT TLA~ TABLE TYPE I CURV DEr! HPH! Compensated:Neutron porosity, :Ss ~atrtx. Calx & dead time corr.': RTNR ~awTnermal.~eutrOn~Rat~o, ... TNR~ '~ThermaI,Neut'ton Ratio CaZlbretee RCNT 'RAW NEAR CNT COUNTS RCFT ~AW.~TA~ CNT COU~T~ CNTC ¢orrec~e4 Near,~uetector,Count Rate CFTC Corrected 'Far Detector Count Rate GR Apl"Corrected Gamma Ray TENS :surface Tension COL CCL Amplitude mm~mmmmmmmm~m~mmmmmmmm~mmmmmmmmmmmmmmmm~mmmmmmmmmmmmmmmmmmm DATA FORMAT SPECIFICATION RECORD mmmmmmmmmmmmmmmmmmmmmmmemmmmem TYPE REPR~,!CODE , VAbUE t 66 0 2 66 0 3 73 44 4 66 Ie Ta~e. VeriJ~:~tCat;ion b~st~na chiUmberqet AlaslCa Computtn~ Center 1:5: 06 PAGE! TYPE REPR CODE VALUE 5 66 7 65 8 68 05 ~! 66 23 12 68 13 66 -0 14 65 r~ I5 66 68 16 66 1 0 66 1 mm~mmmmmmmmmmmmmmmmm~mm~mmmm~m ** SET TYPE - C~AN ** . NAME SERV UNIT SERVICE APl APl API API FILE NUMB NUMB SIZE R.EPR PROCESS ~D ORDER # bOG TYPE CbA~S MOD NUMB 'SAMP ~bEM CODE (HEX) RTNR P&3 73 O0 000 O0 0 7 I I 4 68 0000000000 T~RA PS3 487873 00 000 O0 0 7 I 1 4 68 0000000000 RCNT P~3 CPS 48.7873 00 000 O0 0 7 I I , 68 0000000000 RCFT PS3 CPS 487873 00 000 00 0 7 I I 4 68 0000000000 CNTC PS3 CPS 487873 00 000 O0 0 7 I I 4 68 0000000000 CFTC PS3 CPS 487873 00 000 O0 0 7 I I 4 68 0000000000 G~ PS3 GAP, 48787'3 O0 000 O0 0 7 I I 4 68 0000000000 T~N8 PS3 GB 487873 00 000 O0 0 7 I i 4 68 0000000000 CCh PS3 V 487873 O0 000 00 0 7 I I 4 68 0000000000 ** DATA ** 3 .CNT.PS3 2439i:j644 RCFT~PS3 426,938 CNTC:~i!!PS3 ::2444-060 Ge,PS3 53!gi094 TENS~*PS3 .835;.000 CCb~P$3 ' :0'000 D~PT': 928!;000 NPHZ'i~,PS3 !5.993 'R. TNRi'PS3 RCNT,PS3 5t31.~i767 ~CFT!~P83 !667.~335 CNTC~iiP83 4945.749 Ge.PS3 46!;O94 TENSi;:p$3 1260'O00 CCb~PS3 0..000 TNRA'PS3 CFTC. PS 3 TNRA.PS3 CFTC.PS3 4085''984 ,431 3.2~2 1479.712 END 0r DATA SChlu~beroer~las~a'Co~puting Center PAGE** FILE ~A~E : EDIT ~,007 SERVICE : F~IC VERSIOB : 00!C01 DATE MAX REC SIZE ** !.024 ¥IL~ TYPE~ i LO LAST FI~E DATE : 94/07/20 ORIGIN : F~IC TAP~ NA~E .. : 94230 C~NTINUA. TION # : 1 PREVIOUS TAPE .~ COMMENT : ARCO ALA8KA INC., PRUDHOE BAY, DS.~-2, $00~92005500 **** REEL TRAILER S~RVICE NAME : EDIT DATE : g4/07/2'0 ORIGIN : FblC REEL ~AME .. : 94230 CONTINUATIO~ # ~ PREVIOUS REE~ CO~ME~T : ARCO ALASKA INC., PRUDHOE ~AY, DS 1'2, 500~92005300 fl 000000 7777777777 11 000000 7777777777 111! O0 O0 77 1111 O0 O0 77 11 O0 0000 77 11 O0 0000 77 11 O0 O0 O0 77 11 O0 O0 O0 77 11 0000 O0 77 11 0000 O0 77 11 O0 O0 77 11 O0 O0 77 111111 000000 77 11111i 000000 77 000000 000000 O0 O0 O0 O0 O0 0000 O0 0000 O0 O0 O0 O0 O0 O0 0000 O0 0000 O0 O0 O0 O0 O0 000000 000000 7777777777 7777777777 77 77 77 77 77 77 77 77 77 77 77 77 666666 000000 5555555555 11 666666 000000 5555555555 11 66 O0 O0 55 1111 66 O0 O0 55 1111 66 O0 0000 555555 11 66 O0 0000 555555 11 66666666 O0 O0 O0 55 11 66666666 O0 O0 O0 55 11 66 66 0000 O0 55 11 66 66 0000 O0 55 11 66 66 O0 O0 55 55 11 66 66 O0 O0 55 55 11 666666 000000 555555 111111 666666 000000 555555 111111 666666 666666 66 66 66 66 66666666 66666666 66 66 66 66 66 66 66 66 666666 666666 *,START* USER PCAL [1;0707'60516] dOB Slt!P SEW.; 6297 DAT~ Il-dUN-80 15:53:41 MONITOR 6W,S KL10E37 APR'80~ ,START* ' : *,START* USER PCAL [10707'60516] *EtJ-6297 DATE Il-dUN-80 15:53141 MONITOR SW,S KLIOE3? APR-80' *START* · SSSSSSSS ~H MM SSSSSS$S HB HH SS HM H~ SS H~ HH SS HB H~ SS HH HH SSSSSS ~H~HHHHHMH SSSSSS ~HH~HHHH~H SS HH HH SS HH MM SS HH HH SS HH HH SSSSSSSS HH HH SSSS$SSS HH HH IIIilI IIIIII I1 ii II II II II ii II ll IIilli IIIIII PPPPPPPP PPPPPPPP PP PP PP PP PP PP PP PP PPPPPPPP PPPPPPPP PP P PP PP PP TTTTTTTTTT O,OOOO0 TTTTTTTTTT TT O0 O0 TT O0 O0 TT O0 O0 TT O0 O0 TT 00 00 TT O0 O0 TT O0 OO TT O0 O0 TT 00 O0 TT O0 O0 TT 000000 TT 000000 *START* USER PCAL [10707,b0516] 000 SHIP SEQ. 6297 DATE Il-dUN-80 MONITOR SWS KLIO~3? APR'80. *START* FILE: DS~H:SHIP.TO<255>[10707.60516] CREATED: ii-J[]N-80 15:35:35 PMiNTED: il-JDN-80 I5:54:00' QUEUE SWITCHES: /FILE:~ORT /COPIES:! /SPAC1NG:J /bi I%.107 /FORNS.NURMAL 15:53:41 SHIP TU : SHIPPING INSTRUCTIONS ISSUED II-JUN-80 15:35 BY GHB PCCC VENTURA, CALi~'URN[A 93003 PCCC VV qV EEEEEEEEEE RRRRRRR~ YV VV EEEEEEEEEE RRRRRRRR VV VV EE R~ RR VV V¥ EE RR RR VV VV EE RR HR VV VV EE ~R RR VV VV EEEEEEEE HRRRRRRR VV VV EEEEEEEE ~RRRRRRa VV vV EE RR RR VV VV EE RR RR VV VV EE RR RR VV VV EE RR RR VV EEE~EEEEE RR RR VV EEEEEEEEEE RR RR Iillii 1iilli ii Ii 1i II ii ii ii II II II Illiii IIiiii YY YY YY YY Y~ YY ~Y YY YY 000000 000000 I1 000000 000000 11 00 O0 O0 O0 1111 O0 O0 O0 00 1111 00 0000 O0 0000 11 00 O000 O0 0000 11 00 O0 00 O0 O0 O0 11 00 O0 O0 O0 O0 00 I1 0000 O0 0000 O0 11 0000 O0 0000 O0 11 00 OO O0 O0 11 00 O0 O0 O0 11 000000 000000 111111 000000 000000 111111 *START* USER PCAL [10701,60516] dOB SHIP S~. MONITOR S~S KL10E]] APR-80. *START* FILE: DS~.?ilVER1FY.~01<057>[107~7.60516] CREATED: P~INTED: I-jUN-80 15:54:09 QUEUE SWITCHES: /~ILE:F'ORT /COPIES:I /OPACING:I /LIMIT:107 /FORMS:NOBMAL O297 DATE Il-JUN-80 II-jUN-BO 15:53:10 15:53:41 SCNBUMBERGER COMPUTING CENT~R 10707~60516 RI~,EL READER LENGTH: 132 BITE8 EEE, L NAME: P.C,A.L, SERVICE NAME: EDIT REEL CONTINUATION NUMBER: Ol PREVIOUS ~EEL NAME: COMMENTS: LIS FORMAT CUSTOMER TAPE DATE: 801 6111 rAPE HEADER 6ENGTH: 132 BYTES TAPE NAME: 60516 SERVICE NAME: EDIT TAPE CONTINUATION NUMBER: PREV1UUS TAPE NAME: COMMENTS: Ol EOI~ f'IbE HEADEE LENGTH f'ILE N MAXI. MU PREViO THE f' THE 0 RUN 0 : 62 B~TE$ AME: EDIT .001 M PHYSICAL RECORD LENGTH: US FILE NAME: k COMMENTS I~ST NPMI iS THE DIGITIZED THLR CURVES AR~ fROM PASS N 14-~A¥-80. DATE: 80/ 6/11 1024 OXTES BASE LOG RUN ON 2~-NA~-77. ONE AND PASS TWO LENGTH COMPAN WELL: FIELD: RANGE: TOW N: SECTIO COUNTY STATE: 1TH : INFORMATION RECORD 196 O~TES ATLANTIC RICH~'IELD CO. D.S. 1-2 PRUDH,OE ~A~ 15E 1UN 7 DATA ~ORMA'I SPECIFICATION LgNGTId: 490 B~TBS gNTR~ BLOCKS: 0 SIZE REP CODE ENTR~ I 66 0 DATU~ SPECIFICATION BbOCK8: lC TOOL I DEPT 2 NPHi CNL ] G,~ CNb 4 NPHI CNL 5 NRAT CNL 6 NCNL CNn 7 ~'CNL CNL 8 GR CNL g NPHI CNL 10 NRAT CNL 1 1 NCNL CNL 12 ~ CNL CNL SVORD# UNITS AP1 AP1 AP1 API FILE# S1Zk EXP PROC SAM REP DEPT SHIP'T FT 0 0 0 0 0 4 0 0 1 68 0 0 PO 42 68 2 0 0 4 0 0 ! 68 0 0 GAPI 42 31 32 0 0 4 0 0 1 68 0 0 PU 42 68 2 0 0 4 0 0 1 68 0 0 C/C 42 42 1 0 0 4 0 0 1 68 0 0 CPS 42 34 92 0 0 4 0 0 1 68 0 0 CPS 42 34 93 ~ 0 4 0 0 1 68 0 0 GAPI 42 31 32 0 q 0 0 1 68 0 0 PO 42 68 2 0 0 4 0 0 1 68 0 0 C/C 42 42 I 0 0 4 0 0 1 68 0 0 CPS 42 34 92 0 0 4 0 0 I 68 0 0 CPS 42 34 93 0 0 4 0 0 1 68 0 0 D~PTH 9640.000 9600.000 9500.000 9400,000 9300,000 9200.000 9100.000 9000.000 8975.000 MNkM(]NIC NPHI NCNb NRAT NPHI NCNb NRAT NPH! NCNb NRAT NFHi NCNb NRAT NPHI NCNb NRAT NPHi NCNb NRAT NPHi NCNb NRAT NPHI NCNb NRAT NPHI NCNb NRAT VALUE 28.438 0.000 0.000 24.250 233.376 2.952 28.922 241.527 2.904 27.125 231.231 2.962 ]0.109 260.403 3.040 29.156 185.328 3.104 53.78i 261.690 2.428 64.750 207.636 2.226 74.063 999.141 0.000 MNEMONIC GR NCNb GR FCNL NCNb GR FCNL NCNb GR FCNL NCNL GR F'CNL NCNb (JR FCNL NCNb GR fCNL NCNb FCNL NCNb GR FCNL NCNb VALUE 0.000 0.000 0.000 27.100 81.081 238.095 22.600 84.942 256,113 32.200 77.649 231.231 69.800 98.670 265.551 118.600 44.187 196.911 71.100 109.395 251.394 3~.400 70 785 200:772 199.800 998.712 0.000 MNEMONIC NPHI GR FCNb NPHI fCN~ NPHI GR FCNL NPHI GR FCNL NPHI f'CNL NPHi GR FCNL NPHI GR FCNb NPHI GR FCNL NPHI ~r'C ,N b VAb UE .0 .0 .0 17.5 24.8 83.2 21. 24. 90. 22. 31. 77. 22. 72. 94. 21. 113. 47. 11. 73. 107. O, 0. 64. 20. 0. 0. 00 00 00 2O 00 26 20 O0 19 80 O0 49 20 O0 80 40 00 90 60 00 5O 00 00 79 00 O0 00 MNEMONIC NRAT NPHI NRAT NPHI NRAT NPHI NRAT NPHI NRAT NPHi NRAT NPH1 NRAT NPH1 NPHI NRA1 NPHI VAbUk 0.000 0.000 2.764 18.800 3.126 19.700 3.162 20.400 3.148 21.000 3.008 21.260 2.436 12.420 2.284 0.000 2.304 -5.000 ,,StIMNtAIRY OF DATA RECOiqD,S NUMBER OF HEC,ORD8: b4 LENGTH O~' RECORDS: 1014 BYTES LE;NGTE OF LAST RECORD: 390 BYTES LENGTH: 62 BYTES FILE NAME~: EDIT .001 MAXIMUM PHYSICAL RECORD LENGTH: NEXT' flLk NAME: 1024 BYTES EOI~ TAPL TRAIL~R LENG%B: 132 BYTES TAPE NAME: 60516 SERVICE NAME: EDIT TAPE CONTINUATION NUMBER: O1 NEXT ~APE NAME: DATE: 80/ JOB NO'. AK-701 ATLANTIC RICHFIELD COMPANY DRILL SITE NO. I WELL 32-7-10-15 5LOT 2 PRUDHOE OAY, ALASKA ELEVATION 73 FT. K.B. RECORD OF SURVEY ALL CALCULATIONS PERFORMED~ NY I B !.'i ELECTRONIC COMPUTER TRUE MEAS, DRIFT VERTICAL DEPTH ANGLE DEPTH D ~ SUB DRIFT SEA DIREC DEG, SLOT NO, 2 FROM CENTER SLOT NO, 3 100 0 20 99,99 200 0 10 199,99 300 0 15 299,99' 400 0 15 399,99 500 0 15 499,99 600 0 10 599,99 700 0 15 699,99 800 0 15 799.99 900 0 15 899,99 1000 0 20 999,99 26,99 N 11 E 126.99 N'23 E 226.99 S 22 E 326,99 N 85 426,99 N 80 W 526,99 N 40 E 626,99 S 77 E.. 726,99 S 73 E,- 826,99 N 61 E 926,99 N 19 W 1100 0 15 1099,98 1026,98 S 63 w 1200 0 15 1199,98 1126,98 N 49 E 1300 0 15 1299,98 1226,98 N 10 .W 1400 0 10 1399,98 1326,98 N 89 E 1500 0 1'0 1499.98 1426.98 N 7 E 1600 0 25 1599.98 1526,98 S 21 w 1700 0 10 1699,98 1626,98 N 89 w 1800 0 20 1799.98 1726,98 S 21W 1900 0 15 1899,98 1826,98 S 35 W 2000 0 30 1999.97 1926.97 S 3~ E 2100 0 15. 2099,97 2026,97 S 36 E 2200 0 10 2199.97 2126e97 S 77 E 2300 0 15 2299.97 2226.97 S 74 E 2400 0 15 2399.97 2326.97 S 74 w 2500 0 25 24q9.97 2426.97 $ 12 E TOTAL COORDINATES NORTH' 118,00 118.72 N 21,81 W 118.72 N 21.51 W 118.42 N 21.73 W 118.48 N 22.1~ W 118,63 N 22.21W 118.74 N 21.88 W 118,63 N 21.45 W 118.67 N 21,03 W 118,80 N 20,98 W 118.97 N 21.4~ W 119.18 N 21.55 W 119.26 N 21.52 W 119.3~ N 21,44 W 119,55 N 21,2~ W 119.62 N 21,52 W 119,35 N 21.9~ W 119.11 N 22,29 W 118,65 N 22,53 W 118.04 N 22,5~ W 117,50 N 22,16 W 117,30 N 21,85 W 117.21 N 21.49 W 116.88 N 21.49 W 116,4~ N 21.76 W c ~. o $ u k E $- D I STANCE ANGLE D Y S 120.30 N 10 ~0 32 W 120.71N 10 24 35 W 120,65 N 10 10 21 W 120,40 N 1-0 23 55 W 120.~4 N 10 3b ~6 W 120,69 N 10 3~ 29 W t20.74 N 10 26 26 W 120.55 N 10 lp 12 W 120.52 N !0 ~ 7 W 120,$4 N 10 1 7 W 1~0.88 I~ 10 iZ 5 W 121,11N 10 lb 0 W 121.18 N 10 13 51 W 121.27 N 10 lA 9 W 121,42 N 10 4 1~ W 121.54 N 10 Ag 9 W 120.77 N 10 45 5 W 120.17 N 10 4~ 31W 119,9'7 N 10 40 49 W 119,32 N lO 33 13 W 119,16 N 10 23 25 W 118.44 N 10 35 19 W DO~ L~G SEVERIIY UEGIAOOFT O,IoR 0,426 0.3Z7 O,19~ 1,917 2.OOD 0,27~ 0.104 0,2bO O,lZ9 0,608 SECTI~., DISTANCE -15,99 -16.2B -16.19 -16.56 -17. -Z6.80 -15,92 -15,55 -~,77 -£5.98 -1~.58 2600 0 45 2599,96 2526,96 S 10 E 2700 0 40 2699.95 2626,95 S 17 w 2800. 0 30 2799,95 2726,95 $ 37 E 2900 0 45 2899,94 2826,94 S 39 E 2983 0 45 2982,94 2909,94 $ 1 w 115.42 N 21.57 W lla.20 N 21.64 W 113.23 N 21.47 W 112.37 N 20.8U W 111.36 N 20.45 W 117.42 N lO 3~ 6 W 116.23 N 10 43 b& W 115.25 N 10 4~ 19 W 114.28 N 10 29 17 W 113.23 N 10- 2~ 30 W U.J3Z -15,45 ABOVE INFORMATION FROM SPERRY-SUN GYRO SURVEY ~x~<3, 5U-3-1655~ 3075 0 1.5 3074.93 3001.93 S 36 W 3151 ~ 15 3150.89 ~077.89 S 66 W 3241 6 45 3240.53 3167.53 S 65 W ]515 13 30 3510.11 3~7.11 S 55 W 379~ '21 15 3776.18 3703.18 5 61 W 4006 28 45 3968.18 ~895.18 S 65 W ~295 29 30 4220.63 4147.63 S 65 W 4607 29 ~5 4&91eS5 4418.85 S 65 W ~912 29 30 4756,98 ~683.98 S 66 W 921~ 29 ~5 5019,50 ~9~6,50 S 67 w 5503 30 0 5270,10 5197,10 $ 69 w 5874 30 0 5591,39 5518,~9 $ 68 w 6240 29 15 5909,54 5836,54 S 68 w~ 6560 27 45 6190,76 6117,76 S 6~ W 6912 27 ~ 0 6503,~ 6&30.34 S 54 w 7342 26 15 6887.74 6814.74 S 65 W' 7810 24 15 7311.00 7238.00 S 67 W- ~*~&,~4~17~ 22 15 764~.50 7571.50 S 66 W 110,61 N 20,70 W 109,17 N 22,49 W 10~.92 N 29.62 W 81,88 N 71.26 W ~7.78 N 1~1,83 W 2.85 S 221.5~ W 62,29 S 3~9.07 W 127.4T S ~88.~5 W 189.99 S 626.04 W ~03,~4 S 896.40 W 371,~3 5 1068,99 W 439,20 S 1236,74 W 500,08 S 1~76.75 W 569.76 S 1522.~3 W 652.72 S 1696.76 W 733.91S 1~79.12 W 791.0~ $ 2~1~.~1W 877.46 S 2224.~2 W 22 15~ 894'6¢51 BOTTOM HOLE CLOSURE 2766,20 FEET AT S 71 5 ~) ,g .~. 9086.34~> N 85 W 901.12 S 29b0.60 W 9212.29 N 86 W-$!7%%896.69 S 2616.83 W 112.54 N 10 ~ 10 W 111.~6 N 11 38 25 W 109.98 N, 15 ~'! 39 W 108.55 IN 41 2 2 w 14~,78 N 75 ~ 56 W 2Zl.60 S 89 lb ~5 W ~54.58 S 79 52 52 W ~09,i9 S 75 2~ 4 'W 654,23 S 73 7 2 802,71S 71 5} 21W ' 94~,~7 S 71 17 5} W 1131,68 ~ 70 50 2~ W 1~12,41 $ 70 26 54 W 1464.7~ S 70 '2 13 W 162~,93 $ 69 29 12 W ld17,98 ~ 6~ 51 ~2 W 2017,~5 $ 68 39 58 W 2391,23 S 68 28 20 W 2b23,06 S 69 1 41W 2631.~5 S 69 53 0 W 271~.5~ S 70 30 43 W 2766.20 $ 71 5 6 W MEASURED DEPTH A,ND~OTHER--'DAT'A FoR EVERY ~VFN 100 FEEl' OF '[l{O~ VERTICAL o.~o -14.78 2,711 4Z,21 0.200 O,I~D 802,7~ 0,633 1464,02 0.2~ 1624,55 U.202 1~19,b6 0,46U 20A~,2~ 0,560 2166.90 0.960 2~7,08 1,54~ ~20.OU 0.818 2629.90 0,968 27~5, TRUE MEASURED VERTICAL MD-TVD 'VERTICAL DEPTH DEPTH DIFFERENCE CORRECTIDN TOTAL COORDINATE~ 30O 400 5OO 6O0 7OO 8O0 900 1000 1100 1200 1300 1400 1500 1600 1700 1800 1900 2000 2100 2200 2300 2400 2500 2600 2700 2800 2900 3000 3100 3200 3301 3403 3505 3609 3714 3820 3931 /~157 4271 4386 4501 4616 4731 300. 400. 500. 600. 700, 800, 900, 1000. 1100. 1200. 1300. 1400, 1500. 1600, 1700· 1800. 1900. 2000. 2100. 2200. 2300, 2400, '2500· 2600. 2700. 2800. 2900. 3000. 3100. 3200. 3300. 3400. 3500, U 0 0 0 0 0 0 0 0 0 0 -0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 5' 0 118.72 N 21.51W 0 llS.WZ N 21.73 W 0 118.48 N 22.16 w 0 118.63 N' 22,21 W 0 118.74 N 21·~8 W 0 118.67 N 21.45 W 0 118·67 N 21,03 W 0 118.80 N 20,9~ W 0 118.97 N 21.40 W 0 119,18 N 21.55 W 0 119,2b N 21,52 W 0 119,35 N 21,44 W 0 119.55 N 21.23 W 0 119.62 N 21-52 W 0 119.35 N 21.93 W 0 119.11 N 22,29 W 0 118.65 N 22,23 W 0 118,04 N 22.5~ W 0 ' 117,50 N 22.16 W 0 117,30 N 21.89 W 0 117.21 N 21.49 W 0 116,88 N 21.49 W 0 116.49 N 21.76 W 0 115,W2 N 21-,57 W 0 114,20 N 21,64 W 0 113.23 N 21.47 W 0 112,37 N 20.80 W 0 111,22 N 20.~0 W 0 110,14 N 21,29 W 0 ~07.39 N 26.39 W 1 100,61N ~8.81W 2 91.70 N 54.25 W 2 ~2,78 N 69.70 N 4 ~6.98 N 95.10 W 5 50.41 N 121,62 W 6 ~2.7~ ~ 151,72 W 3600, 3700, 3800. 9 14 20 3900, 4000, 4100. 4200· 4300. 4400. 4500, 4600. 42 57 71 86 101 116 131 11 11.57 N 193.2o W 11 10.3~ $ 237.65 W 15 33,89 S 288.15 W 1~ 57.~3 S 338,b5 W 15 81.37 S 389.9/ W 15 105.40 S 441.51W 15 129.39 $ 493.0~ W 5077 5192 5307 5422 5538 '5653 5768 588~+ 5999 611~. 6229 6.570 6683 6796 6908 7020 7132 7244 7356 7~+66 7577 7687 7798 7907 8016 8125 8232' 8339 '8553 8659 8766 8873 8979 4900, 5000. 5100. 5200, 5300, 5400, 5500, 5600. 5700. 5800. 5900. 6000, 6100. 6200, 6300. 6400, 6500, 6600, 6700. 6800, 6900, 7000, 7100. 7200, 7300, 7~00, 7500. 7600e 7700, 7800, 7900, 8000, 8100, 8200, 8300, 8400, 9084 ~0 9297 9404 9511 9619 9728 8500. 8600. 8700. 8800, 8900. 9000. 9100. 177 192 2O7 222 238 253 268 299 343 357 396 408 z+32 456 477 z+98 5O7 516 525 532 546 559 566 579 584 59O 597 604 611 619 628 A~ 16 15 15 16 15 16 15 15 15 13 13 12 12 12 12 12 10 11 10 11 9 9 9 7 7 7 7 7 7 6 222 266 ~09 330 373 394 qSO 502 590 674 712 76~ 798 812 840 868 el~ ,42 .~0 ,77 .09 .26 .17 ,78 .43 .72 .62 ,20 .?8 .07 .2~ .61 .~0 .29 .81 .82 .82 .82 700.62 752.77 d05.81 859.0T 912.~ 9~,1~ 1073.53 1~78.~ 1231.7~ 1281.77 1~81.05 ~427.80 1921.27 1566.D7 1611.8~ 1657.06 ~702,04 1745.12 1788.~ 187~.37 1992.9~ 2029,7b 2099.07 2133.72 2168.3~ 2203.0~ 2237,50 227[,6~ 899.92 S 904,05 5 90~,72 S 904.05 S 902,21 S 2305.7~ 2339.92 2376.31 2414,$9 245~.07 2493.46 2535.~9 MEASURED DEPTH AND OTHER DATA FOR EVERY EVEN 100 FEET OF SUB 3EA' DEPTH. TRUE MEASURED VERTICAL SUB ,VlD-TVD VE~'TICAL DEPTH DEPTH SEA DIFFERENCE CORRECTION TOTAL · COORDINATES 173 173. 100. 0 273 273. 200. 0 373 373. 300. 0 473 473. 400. 0 573 573. 500, 0 673 673. 600. 0 773 773. 700. 0 873 873. 800. 0 973 973. 900. 0 1073 1073, 1000. 0 1173 1173, 1100, 0 1273 1273, 1200, 0 1373 1373, 1300, 0 1473 1473, 1400, 0 1573 1573. 1500. 0 1673 1673. 1600. 0 1773 1773, 1700. 0 1873 1873, I800, 0 1973 1973, 1900, 0 2073 2073. 2000. 0 2173 2173. 2100, 0 2273 2273. 2200. 0 2373 2373. 2300'. 0 2473 2473. 2400. 0 2573 2573. 2500. 0 2673 2673. 2600. 2773 2773. 2700. 0 2873 2873. 2800. 0 2973 2973. 2900. 0 3073 3073. 3000. 0 3173 3173. 3100. 0 3274 3273. 3200. 1 3376 3373. 3300. 3 3477 3473. 3400. 4 358-1 3573, 3500. 8 3686 3673.. 3600. 13 3791 3773. 3700, 18 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 1 2 1 5 5 118.60 N 118.72 N 118.50 N i 18.47 N 118.59 N 118.71 N 118.66 N ' 118.66 N 118.76 N 118.92 N 119.12 N 119.2~+ N 119,33 N 11~).49 N 119.60 N 119.42 N 119.17 N 118.78 N 118,20 N 117,65 N 117.3:5 N 117.Z3 N 116.97 N 116.55 N 115.69 N 114,53 N 113.49 N 112.60 N 111.48 N 110.63 N 108,37 N 103.02 N 94,11 N 85,19 N 71.46 N .54.88 N 38,31 N 21.8~ W 21.b9 W 21.67 W 22.04 W 22.20 $ 21.97 W 21.57 'W 21.15 W 21o00 W 21.29 ~ 21.51W 21.~3 W 21.46 W 21,2~ W 21.4~ W 21.82 W 22,1~ W 22,~6 W 22,53 W 22.26 W 21,~3 W 21.5~ W 21.49 W 21.69 W 21,62 W 21,62 W 21.52 W 20.98 W 20.49 W 20./0 W 2~,25 W 34.6~ w 50,08 W 65.53 W 87,9~ W 11~,46 W 110,99 W 4012 4126 4240 4355 4470 ~585 4700 /+815 4930 5045 5161 5276 5391 5506 5622 5737 5853 5968 6083 6198 6312 6426 6540 6653 6765 6878 6990 7102 7212~ 7926 75/+7 7657 7768 7877 7986 8095 8203 8310 8~+17 852/+ 8631' 8737 884~ 8950 3973, 4073. /.173, /+273, 4373, 4473. /*573. 4673, 4773. 4873, 4973, 5073, 5173, 5273, 5373, 5/+73, 5573. 5673, 5773, 5873. 5973, 6073, 6173. 6.273, 6373, 6473, 6573, 6673, 6773, 6873, 6973, 7073, 7173, 7273. 7373. 7/*73. 7573. 7673, 7773, 7873, 7973. 8073° 8173. 8273. 8373. 3900. 4100. /+200, 4300. 4400. 4500, 4600. 4700. 4800, 4900. 5000, 5100. 5200, 5300. 5400. 5500, 5600, 5700. 5800, 5900, 6000, 6100, 6200. 6300. 6400. 6500. 6600. 6700, 6800. 6900. 7000. 7100,- 7200. 7300. 7400, 7500. 7600, 7700, 7800, 7900. 8000. 8100, 8200, 8300, 39 53 67 82 97 112 127 1~2 172 188 2O3 218 233 249 264 280 29~ 310 325 339 353 367 38O 392 417 /+29 453 463 ~74 484 5O/+ 513 522 530 537 55~ 558 571 577 11 15 i5 15 15 15 15 15 16 15 15 15 16 15 15 15 13 12 13 12 12 12 12 10 11 10 11 9 9 9 8 7 7 7 7 7 6 3,9~ 5 27.53 5 51.08 S 74,8~ S 98,91 S 122.9/+ 5 170.19 5 216.30 5 Z38.98 5 ~1.09 S 282,55 S ~4,0~ S 325,22 S 388.81 S 410.11 $ 431,42 S 452,9~ 5 4'14,59 S 5~0.70 $ 562.99 $ 584,79 $ 606,37 S 649,54 S b88,25 5 707.4~ S 761,66 5 778,7~ 5 795,03 5 823e04 $' 837.04 S 851.04 S ~65,05 S ~7~.22 S 224.02'W 274.52 w ~25.0~ W 376,05 W ~27,59 w ~79,13 W 582,9~ W 586,5~ W 738,69 W 791.~3 W ~97,96 W 951,~ W 1059.11W 1112.02 W 1217.47 W 1266.3~ W 131~,12 W 1367,90 w 1461,92 w 1508,~5 W 1599.60 w 1690,09 w 1733,49 W 1776,57 W 1819,66 W 1~62~74 w 19~2.34 W Z05~05 W Z089,71 W 2159,0~ W 2193.68 W 2228.28 W 2262.42 W 9162 8573, 8500, 9268' 8673. 8600. 9375 8773. 8700. 9482 8873, 8800. 9590 8973. 8900. 9698 9073, 9000. 589 595 602 609 617 625 6 898.12 S 2330.70 6 903.20 S' 2365.95 7 904.54 S 2442.71 8 904.55 S 2482,0d 8 902.71S 2524.22 INTERPOLATED VALUES FOR TRUE MEASURED VERTICA DEPTH DEPTH lO00 999, 2000 1999. 3000 2999. 4000 3962. 5000 4833. 6000 5700. 7000 6582. 8000 7485° 9000 8420, EVE'N lOgO FEET OF ~EASURED DEPTH. SUB SFA TOTAL COORD I NAI'ES 926, 118,80 1926, 118,04 2926. 111,22 3889, 1,70 4760, 207,34 5627. 394.76 6509, 586.74 7412, 8347. 20.98 22,53 20,50 219,33 665,93 11Z6,7~ 1598.43 763.81 S 1947.89 W ~EASURED DEPTHS ~EASURED DEPTH 3944 4176 4389 FOR EVERY , DISTANCE OUT 200.00 300,00 400.00 500.00 IOOFT DISTANCE OUT(PLANE OF OOTTOM HOLE CLOSURE 5208 800.00 5409 900.00 5610 1000.00 5810 1100.00 6012 1200,00 6'21~ 1300,00 5423 1400,00 6636 1500.00 6855 1600.00 7077 1700.00 7301 1800.00 7534 1900.00 7769 2000.00 8019 2100.00 8285 2200.00 8571 2300.00 8859 2400.00 9168 · 2500.00 9467 2600.00 9751 2700.00 CODE NAME INTERPOLATED TRUE VERTICAL DEPTHS, COORDINATES AND TRUE MEASURED VERTICAL TOT'AL COORDINATES DEPTH DEPTH CLOSURES FOR GIVEN DEPTHS C L O S U R g DISTANCE , ANGLE D M 9200 8609.10 900.52 S 2343.03 w 2510.12 S 6~ 58 34 w 8~36.10 9314 8715.94 903.49 S 2382.43 W 2547.99 S 69 13 ~4 w 8642.~4 9430. 8824.23 904.21S 2423.99 W 2587.19 S 69 32 34 w 8751e23 9615 8996.27 904.12 S 24V1.~9 W 2b~0.84 S 70 3 28 W 8923.27 9755 9125.25 901.74 S 2545.24 W 2701.Z0 $ 70 29 54 W 9052.25 t L , JOB "'NO, AK-?O1 %T6ANT IC ~ICHFISLD DRILL SI TF NO. 1 WELL ~2-7-}.O-.1..-.-.-5 SLUT .~ Ft~-~ATION 7~ mT. RECORD 'OF SURV/LY ALL CALCUL. ATIO?~$ DEI{FOR,~ED ,RY ! 8 r~ EL£CTR.~J,',IC CO,'~HU[ER DRIFT VFRT iCAL SLJB DRIFT ANGLE DEPTH SEA DIREC SLO~ NO. 2 FRO~, CE'<TE~, SLOT N'O~ ~ TOTAL CO01{D!NAT~ u C L u S U ~ E S STANCE A t'x ~.~ L Ir_ 118 .OO WEST 22.00 ~;lOO 0 20 99.99 ~00 0 10 199.~9 ~00 0 15 299,99 ~00 0 15 399.99 ~00 0 15 499.99 600 .0 10 599,O9 700 0 15 699,99 800 '0 t.5 799.q9 .,1~..00 0 l~ 899,99 0 0 2,0 999e9~ 26,gg ~'~ 11E 126.99 N 23 F 226,99 S 22 E 326,99 N 8D W ~26.g9 N 80 W 526.99 N 40 E 628.99 S 77 E 726.99 $ 7~ E 826.99 N 61 £ ~2~.95 N 19 W 1100 O 15 1009,9a 1026,98 S 63 W 1200' 0 15 1199.98 1126,98 N 49 F 1~O0 0 15 1299.~8 1225,98 N 10 W 1~O0 0 lO 1399.~a 1326,98 1500 0 10 1~99.98 1~26.98 N 7 E 1500 0 25 1599.98 1526.98 S 21 w 1700 0 10. 1699.9~ 1626.98 [~ 89 W 1800 0 20 1.790.98 1726,98 . lgoo 0 15 1899,98 1826.98 S 35 2000 O 30 1999.~7 1926,97 · ~100 0 15 2099.07 2026,97 S 36 2200 0 10 2199,97 2128.97 $ 77 2~00 0 15 2299.97 2226.97 $ 74 -2~00 0 15 2399,97 2326,97 $ 7~ 2500 0 25 2~99.97 2426.97 S 12 F 118.58 N 21.8a 118,87 N 21,7~ 118.46 N 21,~O 118,50 N .22.0~ !18,58 N 22.~ 118,82 N Z2.2~ 118,72 N Zl,S~ 118.59 N 21.~2 ~18.80 N 21.0~ ~19.36 N 21.23 119.17 N 21.6Z t19.45 N 21.2~ 119,8~ N Zl.36 119,89 a 21.u~ 120,20 N 21.01 119,51N 21.2'7 118.61 q 22.05 117,88 N 21.5b 117,53 N 21,31 117,46 ~ 21.00 117,34 N 20.58 117.,22 ~ 21,00 116e90 N 20,85 120.58 r: 10 Z! ~b W 120.~ '~ ]0 22 3b W 170.~2 ?~ IO 20 0 W 120,53 ~ lO 3z d w 120,69 '~ 10 43 38 ~' 120.71 ~ 10 2b Ju W 120.51 r~ ~0 1~ 1/ W 120.65 '~ 10 Z 31 w 1~1.33 a IO ~ Z2 ^ !21,39 ~ 10 5 ~0 ~ 120,95 ~. 10 2~ ~ ~ 120.{,4 ", 10 31 99 .~ 119.45 ;'.!O lb 3b W 1~9.32 N ~0 c ~ w 11~.13 ~ 9 b6 b8 W 11~.;)9 N 10 9 2~ W D ,3 ~,.~ L ~- ~ t'[(,/1oul-' I . -16,~ -10.37 -1;.~7 -l/.O1 -ll. Ou -lb.)/ -lb.v7 -1 -17.01 -lm-/l -16.J4 -15.V9 -1~.22 -16.36 ~0() 0 45 2599,96 2526.96 $ 10 E 2800 0 30 2790,'9~ 2726.95 $ 37 ff 2900 0 45 2899.9& 2826,94 $ 39 E 2983 0 ~5 2982.93 2909.93 $ 1W . 115.21N 20,62. w 114,10 N 20.96 A13,40 N 20,4w 112.38 N 19.61 111,30 N lq.b3 ALCOVE INFOR'.IATI(:N F~,,thy. SPERRY-SUN GY'~O SURVFY NO, SU-3-16553 . , 3079 0 15 3074.93 3001.93 S 36 w ~1~! 3 15 3150,81 3077.81 5 6'6 w B~I 6 45 3240,18 3167.18 S 65 W 3~I5 lB 30 3506.61 3~3.61 ~ 5~ W ~607 29 4~ 447~.92 ~#01,92. S 65 W ~ 74912 20 30 4740,38 46~7.38 $ 66 W ~21~ 29 ~5 5002.57 ~929,§7 S 67 w 587~ 3-0 0 557~,15 5501.15 S 68 W 6240 29 15 5893.~8 5820.~8 S 68 W ..... ~.0 27 ~5 6176,~8 5103.68 S 65 w 6917 ~7 0 6490.31 6g17.31 S 6~ W ~ 73~Z ~6 15 ~875,97 6807.97 $ 65 W 7810 ~ 15 7302,67 7229,67 5 67 W 81'73 22 15 7~8.65 7565,65 $ &6 W · 8832 1R ~5 R262,67 81~{9.&7 $ 70 W 9S61 22 15 8943,77 8870.77 a .0 w ~ '0 24 45 92aO,ga 9207,9~ N 88 W 110.97 109,22 N 23.50 W 104,75 N 33.39 w 68.06 N ~5.7u W 2~.05 S 266.54 ~ 84.19 S 39b.62 W 149,62 S 535.94 ~ 210,71 S ~73.i~ ~ 321,05 S 945.V~ W ]90,5~. S 1117,9.~ 457,53 S 1283,7%~ 520,50 S 1411.1.83 590.5~ $ lb62.46 746,03 5 1911. /6 801.9~ S 2~37.33 ~79.20 S Zb/~.17 ~'79.20 S ~gD. 7~ 871.17 S ~5~7.~8 867.1~ 5 26~5.11 117,05 N 10 ~ 54 ~ 114.08 i, 9 b4 4 ~ 113.01N 10 0 19 ~ 111.78 ~' 12 17 4~ ,' 109.94 ;4,17 40 bi W 109.~1 ~t 51 34 Zl W lf5.2/ h ~3 4~ ~'/ w 7o5.3~ S 72 3z o ~ 998.~8 S [1 15 13 ~ 1i~.4,23 b /0 q4 j~ W 13o2.89 S f0 23 3 w 1~11.29 b ¢,9 bl 15 a 1~70.34 3 09 I / z.a W 1~60.U5 ~ 68 51 23 W 2052.17 S ~.~ 40 5~ W 21~9,48 S 68 30 bl W 25~1,73 S ~9 ~0 ~5 w 2~46,0~ S 70 3~ 36 ~ 2730,20 S Zl 23 31 w 2-/~3.b2 S /1 ~0 b/ w O.b~2 U.251 U, ZoO o.ld2 0.355 O. IJ5 ~.2~3 O.bOZ 1 · .~ .} 0 -lb*hZ -lb,3b -16.Ui -15.os -11.39 -O.~9 bO,hZ l~,O~ 70b.29 1352.4~ lb10.3'/ 2d~9.O~ Z1U~.77 Z3VT.49 2o~b.o2 2130.11 BOTTOI~ HOLE CLOSURE 2783.62 FEET AT b 71 50 57 ,, -,. ?,F.A:.~URED DEPTH AND OTHER DATA FOR FVERY LVi.!N 100 FEET OF TkU' vr_'-(T1CAL DL. PTH, TRUE r~EA, SURFD VERY I CAL ~f,-TVl) VEt~T I CAL DF. oTH DF",:-' T H DI FF'F RcNCr:' CORRECTION TOTAL COOk L; I ,":A TES -%¸ moo soo ?oo moo 1 o0o 1100 1200 1400 1500 leOO ~oo 1~00 1900 2000 2100 2~00 2~00 2500 ~600 2700 2800 z oo )ooo )201 340~ 350~ 4061 ~290 4521 4636 300, &O0,, 500, (%00. 70 0, BOO, 10 O0. 1100. 1200. 1300, 1400, 1600. 1700, 1RO0, 1900. 2000, 2100, 22~0,' ~400, 2500, 2600, 2700, 2800. 2900~ 3100 ~ ~200~ ~300 · 3~00~ 3600~ ~700~ ~800~ 3900, 4000. 4100, 4200. 4300, 4400, 4500, LJ 0 0 0 0 0 0 -0 0 0 0 0 0 0 0 0 O. 0 0 0 0 0 0 0 1 22 32 46 61 75 9(3 106 121 136 U 0 0 0 0 0 0 0 0 0 0 c 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 1 2 2 3 7 10 14 15 15 15 15 AA~eO I ~18.~8 118.82 118.72 118.59 118,80 119,17 119,45 119.88 119,89 120.20 11~o~1 119.b2 118.9~ 118.61 11?.88 117. b '~ 11 117.34 117.22 116.~0 115.21 114.1o 113.40 112.3~ 111.24 110.39 106,76 96.51 82.74 68.97 b0.~5 31 °60 11.30 N. N N N N N N N N N N N N 11,87 S 35.40 S 59.31 S ~3.22 S 107.37 S 131.52 S 195.39 S '. 5096 5326 5557 5675 578~ 61~ 6~47 6360 6~73 6586 6698 6811 6923 703~ 7~6 72~7 7368 7588 7697 7807 8660 8872 8978 5000, 5100, 5200, · 5300, 5qO0, 5500, 5600, 5700, 5800, 5900, 6000, ~100, 6200. 6300, 5~'00, 6500. 6600. 6700, &800, 6900, 7000, 7100, 7200. 7300, 7500, 7600, 7700. 7800. 7900. 8000. ~100. 8200. 8300, 8400, 9084 '9190 929& 9406 9622 9731 8500, 0600. 8700, 88'00. 9000. 9100, 181 196 226 242 257 273 288 304 318 333 '347 36O 373 386 398 ~11 423 ~3~ ~57 478 497 GO7 515 523 531 549 56O 572 578 15 15 16 15 16 15 16 14 14 13 13 1'3 12 13 1.2 11 11 11 10 10 9 10 8 6 5 6 6 59o 60~ 614 631 22~..02 S 246.3~ S 268 · 6~9 S ~89.~2 S 310,11 $ 331.24 ..5 362,8-1 5 37~.50 S 395.9° S 415.94 437.92 S ' ~ 5B .98 S 481.21 S 503.49 S 525.71 b'~8.04 S 57v.3~ S 592.57 S 613.41 S 655.09 S o75.16 S ~92.7~ S /10.36 S /,+b. 56 S '/b2.23 S /9~.51 S 809,06 S 82D ,67 S 832 .ZU S 8~3. ~9 5 ~b5 · 50 S 875.11 S ~77.36 S 878.61 S ~79.20 5 879.20 S '8/'9.20 S' ~77.07 S 873.28 S /O~+, b l 751.12 d09.73 863 · b9 917,90 W'/1,22 102~.7b 1078 · Z~ 1131.~o 1235.2b 1286.90 138Z, Zb 1'+29. bi i~75.30 lb~6. 79 1611,4~ 165b. 18 1700,~1 1744. '/W 1869,1~ t946 · i~ 1985.51 2056.9U 2120 · /0 2152.:9 218~,49 2216 · 39 2285 · (,~ 2321 · 54 w 2357..'+2 w 2395.':/J '.~ 2436,89 ~/ 252o.0 / w 2563.38 w 1,4EASURED DF'.OTH ANP OTHER D~,TA FOR FVERY i-VL',: 100 FrET (IF SUB ,,5~.A P~EA SHRED VERTICAL St~B M~)-TVD VERTICAL DEPTH DFPTH S~'A DI FFFRENCF' cORRECTI°N TF)T rkL COC)?,D I hA '1 E S 173 273 3?3 573 673 7'73 873 97~ 1073 1173 1273 1~73 1~7~ 157~ ~67B 1773 1873 ~173 227~ 2373 2~73 257~ 2673 277~ 2873 ~973 3173 3378 3~86 3801 ~915 173, 100. 0 O. 2'?3, 200, 0 O 373, 300., 0 O 473, 400° 0 0 5 73. 500 · 0 0 67-3, 600. O 0 773, 700. 0 0 8 73. 800. 0 0 973. 900. 0 0 1073, 1000, .q 0 1173, 1100. 0 0 ]273, 1200, 0 0 1373, 1300. 0 0 1~73. 1400, 0 0 1573, 1500, 0 0 I673. 1AO0. 0 ~ 1773, 1700. 0 ~' 1873, 1800. 0 0 1973. 1900, 0 0 2079. 2000. 0 0 217~. 2100. O 0 2273. 2200, 0 0 2373. 2300. 0 0 2~+73, 2~00. 0 0 2573, 2500, 0 0 2673. 2500. 0 0 2773, 2700. O 0 2873. 2800, 0 0 2973, 2900. 0 0 3073', 3000, 0 0 3173, 3100, O 0 3273. 3200* 2 2 3373, 3300, 5 3 3473. 3~OOe 7 2 3~73, 3500. 13 6 3.",73, 3600. 21 B 3773, 370{), 2~ 7 3873. 3800. ~2 1~ 118,79 118.5/ 118,49 118.56 11B.t5 118.74 118.63 lls.7~ llg.zl l19.J-/ 119.~ 119.d9 120.11 119,70 119.52 119.12 11~.7o 118.08 117.63 117.4B 117.31 117.25 116.70 11'5.5~ 114 · 4o 113.b9. 112,66 lll.z+3 110.98 lo8 · 11 72.69 55,~4 11.56 b.61 N N N N N N 'N N N .N N 21,b~+ gl .91 22,34 ZZ.BI 21 ,g') 21.5 ~ 21.1~ 21.1~ 21.~] 21,3~ 21.~ 21, lJ 21.02 21,20 21.~0 21.9~ 21 · ~') 21.37 20,8 ~ 20. bo 19.83 19.03 19.dO 39,84 59.91 79.1b 1 /7.3~ 227 · I I e.o~o ~7~ ~,~90 &605 ~720 ~950 5295 ~11 ~6~ 6102 6217 6330 666~ 67~0 6893 700~ 7227 766~ 7777 7886 79'9~ 8209 e~2o 8526 ,86~2 B7~7 8B~3 e9~9 3973, 4073, 4273, 4~73. ~573, a673, 4973, 5073, %173. 527B. 53?3. 5~73. 5573, 5673. 5773, 5873. 5973, 6073, 6173. 6273. 6,373, 6573. 6673. 6773. 6873° 6973, 7073, 717.'5o 7273, 73 7473. 7573. 7673. 7773. 7873. 7973, 8073. 8173, ~273. 8373, 8473, 3900, 4000, ,100. ~200, ~300. 4aO0. 4500, ~600° 6700e 4800, 4900e 5000. 5100, 5200, 5300. 5~00, 5500, 5600 · 5700, ~800, 5900. 6000. 6100. 6200, 6300. 6400. 6500. 6600. 6 ~00. 6800. 6900° 7000. 7100, 7200. 7300. 7~00. 7500, 7600, 7700, '?~00. ?go0. 8 o00. 8'100 · ~2001 8300. 8~00o 57 71 86 10'1 117 132 162 177 192 207 222 238 253 ~00 314 ~29 357 370 383 4O7 ~20 431 443 '~+85 5O4 5~3 536 553 570 15 15 15 16 15 15 15 -15 16 15 16 15 15 15 13 13 13 11 11 lP- 10 10 9 8 7 5 6 5 6 6 28. ~) ;6.7/ 100.85 125.00 1~+9. lo 1 ;2.19 1';5,20 21 /.99 24.0,~2 262.~6 2~3,83 3o4,52 325 .~0 347. u3 3o8.60 390.29 411,27 ~z.2b ~7~.Zl ~97.44 519.6U 542,01 5o~.35 586.68 007 · 78 ,6 /0.31 6~8. oo 705.61 7~O.Ui /b/,'/3 / /4,3 / 7'~1.01 ~29 · 15 840.76 852.37 853.98 8 875.77 8~7.02 Z 17.15 3/'9 483, 14 ~'34.94., 586.6 3 o38.31 090 · ~0 '/~2.9A 795 · 902 · 94 lolU.30 1063 · ~3 1117. 1Z21.25 12'73.15 1 .~69 · 39 1462 · ~ 1508. / 3 1599.g] 1733 · t 775. 1.-:16. b2 1HSl.gv 1:t9V.40 1938.0~ ]975.~2 2"~48 · 2V 2~0. 21~3.v~ 2175.~6 2207 · 78 22~U,09 2311.~5 9162 9268 959~ e?o2 8573, 8500. 8673, 8600, 8773, 8700" 8873. 8800. 8973. 8900. 9073, 9000* 589 7 595 . 6 603 8 612 9 62O R 629 9 INTERPOLATFD VALLJFS F~>R T~UF ~EASURFD VERT I CAL DFDTM DEPTH 1000 999, 2000 3000 2999, AOOO 5000 ~816, 6000 70O0 8000 7478° ~000 1000 FF'[-F CF rz.'..:'ASURE'.h D!.k;Tft, SUB SF.A TOTAL CuOkt)I NATF5 926, 119.36 :'~ 21,23 1926, 117.88 N 21,)6 2926'. 111,24 ~ 19,67 :B874. 22.8~ S 26~,0~ 47~3, 227,77 S 713,3q 5611. ~,13.~0 $ 117~.06 6~96, ~O'/.O0 S 1~97.74 7605. ~75.29 S 1977.q9 -8347, -~76,37 S Z293,12 MEASURED DEPTHS FOP CVE~ Y lOgiT DISTANCL (PLAN,. MEASURED DFPTH *07, 4696 D I STANCE 200,00 *00,00 500,00 600,00 700,00 5906 6111 6320 ~756 ;6979 7es& 9~31 1000, O0 1100.00 1200.00 13na,o0 1~00,00 1500,00 16 O0, O0 1 ?0,0 · O0 1800.00 l gO'O, O0 2000.00 2100,00 2200e00 2500.00 2~00,00 2500.00 2600,00 27no. go ~: ~;:f': INTERP.t'~t,,AT .F_D T~UE VE~T ICAL TRUE C~ ~EA;SURFD VFRTICAL DEPTHSt COOaD[~ATr.:s A,~D CLOSUi:~ES F()i~ ~[V~':',' DEPTHS TUTAL COOaD I NATh..$ C t ~ S DISTAl'iCE ANGLt D ~ ,~L.A 9200 9'31~ 961~ 8609,03 8715.16 8822,53 8993.29 9121,68 879.20 879.20 877°32 S (,9 ~6 bi w S ~9 53 50 w S 71 lb 3 w · COMPLETION REPORT ..... ATL:ANT I C R I CHF ! ELD CO. ' GY'R'~'SCOP I C" SURV'E'Y " ~-IUS OF CURVATURE ME'T-~OD Of COMPUTATIONS COMPUTED FOR EA'$'TMAN""WHI'P$-TOCK INC, BY F. M. API~IL 1/+, 1977 DRILL SITE 1-2 KB ELEVATION 71 FT. LINDSEY AND ASSOC, , RECORD' OF SURVEY ALL"'CALCULATIONS"'PERF'ORMED BY I B M ELECTR'~NIC COMPUTER NEA$ ." DR'I F'T "'DE'P'TH ANGLE TRUE' VE'RT'I C'AL SUB ' DEP"T~ .... S'E'A ' DOG LEG IDRi'FT TOTAL COORDINATES C I 0 S U R E S SEVERITY,, DI'~EC DISTANCE ANGLE DEG/iOOFT D M DEG. D M 0 0 100 0 200" 0 3"00 0 400 0 0 0.00' · '-71.00 S30.OOE 118'.00 N 0 '100,'00 29.00 $30.00E 118,00 N 21.80 W 119,99 N 10 28 1W 0.000 21.80 W 119.99 N 10 28 1W 0,000 S30.OOE 118.00 N 21.80 W 119,99 N 10 28 1W 0,000 0 200.00 129,00 15 299,"99 ~ 228.99 20 5'399,99 328.99-- S30.OOE 117.81 N 21,69 W 119,79 N 10 25 56 W 0,250 S76.00W 117.40 N 21.86 W 119.42 N 10 32 59 W 0,090 -19,50 -19,50 -~.50 -19,24 500 0 15' '499,99' 428,99 S89.00W 117.33 N 600" 0 ~'0 599,99" '528,99 N83,0'OW 11'7,35 N 7~J-O---O--1-5 ' 699'9-9 - 6-2-8-J, 9-9---~2-0~-'-5~ N 800" '0' 15'' '7'99.'99 728.99 N68,00E .... 1~-'~,93 N 900 ..... 0 15 '899,99' 8~8,9'9 Sg0.~'0'E' 118'.01 N 1000 0 20' 999.99 ' "92-~~~E 118.27 N 22.37 ~ 119.44 N 10 47 44 W 0,090 -18.74 22.7~ W 119,53 N 10 57 58 W 0.080 -1~..40 23,01 W 119,80 N 11 ~ 28 W 0.080 '13,22 22,85 W 120.12 N 10 57 59 W 0.347 -18.49 ' 22.42 W 120.12 N 10 45 34.W O.09D -1~.92 22.01W 120.30 'N 10 32"33 W 0.090 -19,40 1100 0 20 1099.99 1028.99 S79.00w 118.65 N .... 1200 0 15 1199.98 '1128.98 $42,00W 118.40 N 22.30 W 120.73 N 10 38 ~4 W 0.609 -19.25 22.74 W 120.56 N iO 52 23 W 0.09.0 -~"~75 ' 1300 0 10 1299,98 1228,98 SiO,OOW 118.07 N 22,90 W 120,27 -N 10 58 36 W 0,080 -i. 49 1400 ,0 10 1399,98 1328,98 $86,00E 117.87 N 22.74 W 120,04 N 10 55 10 W 0.253 -18,57 . 1"50~ 0 0 1499,9~ ..... 1428,98 586.005 ........ 117.86 N 22.59 W 120.00 N 10 51 4 W 0.170 -i8.71 118,06 N 22.50 W 120.~19 N 10. ~7 3b W 0,340 -16.~ 1~00" 0 20 15~528.98 NSO.OOW -----i700 0 30 1699.981628,98 N82.00W 118.36 N 2'3.16 W 120.60 N 11 4 31W 0.160 -18.3~ ..... i'800' '0 30 '"i7'99".9'8 ..... 1'728'98 "S"]~'%,OOW' -i1:.?"9'2 N ' "2'3.84 W 120,31 N 11 25 43 W 0.656 =17,56- --!--9-0--0' 0 i'5 "'1899,97 ..... 1828,9-7 ' S'3'~.OOW ':'.:.?:;i1"7.3'3 N 24,10 W 119.78 :N 11 36 35 W 0,250 -17.11 20-Ob 0 20 i9'99,9'7 .... 1928.97 St'"O,"O'Og 116,83 N 24.20 W 119,31 N 11 42 9 W 0.090 -16.85 2100 0 45 2099.97 2028,97 S29,00E 115,9/+ N 23.88 W 118,37 N 11 38 25 W 0.410 -16,84 2200 0 30 2199.96 2128.96 S66,00E 115:.22 N · 23.09 W 117.51N 11 20 3 W 0.250 -17.34 2300 0.20 2299,96 2228,96 $39,00E 114,77 N~ 22,51 w 116.96 N 11 ~ 0 W 0.160' -17.73_ 2400 0 15 2399,96 2328,96 S15,00W .114.29 N 22,'41 W 116.47 N 1i 5 46 W 0,090 -i7.67 RECORD C)F SURVEY ALL CALCULATIONS PERFORHED BY I B M ELECTRONIC COMPUTER TRUE DOG. L,,'~G F'EAS, DRIFT VERTICAL SUB DRIFT TOTAL COORDINATES C L O S.U R E S SEVEN! TY ,SECTION DnPTH'- AF"G:, LE DEPTH SEA DIREC DI STANCE ANGLE DEG/iOOFT DISTANCE D M DEG. D M 2500 0 35 2499,95 2428.95 SIO.OOE 113,56 N 22,44 W 115,76 N 11 10 51 W 0.340 2600 0 45 2599.95 2528.95 S22.00E 112.44 N 2-2.12 W 114.60 N il 7 54 W 0.160 -...31 2700 0 40 2699.94 2628.94 S28.00E 111.32 N 21.60 W 113.39 N 10 58 54 W 0.~80 -17.42 2800 0 45 2799.93 2728.93 S36.00E 110.27 N 20.94 W 112.24 N 10 45 18 W 0.080 2900 0 45 2899.92 2828.92 S35.00E 109.20 N 20.18 W 111.05 N 10 28 21W 0.013 -18.04 3000 0 20 2999.92 2928.92 S13.00W 108.30 N 20.00 W 110.-13 N 10 28 5 W 0.410 -17.90 3100 3 0 3099.87 3028,87 S62.00W 106.05 N 21.73 W 10~'26 N 11 34 44 w 2.663 -15.52 3200 5 50 3199,56 3128.56 S71.OOW 102,98 N 28,78 W 106,93 N 15 37 4 W 2,842 -7.84 3300 8 45 3298.74 3227.74 S59.50W 97.68 N 40.30 W 105.66 N 22 25 10 W 2.922 4.78 3400 11 45 3397.13 3326,13 S55.50W 88.12 N 55,30 W 104.04 N 32 6 39 W 3.005 22,14 3500 13 30 3494,71 3423.71 S55.00W 75,66 N 73,26 W 105.32 N 44' 4 29 W 1.750 43.26 ~00 16 15 3591,35 5520.35 559,00W 3'700"- i'9 ..... 2~ ....... ~'~-6~-~"~ .... ] 36'15 ,'55 ........ S'59'-,-'~0~ 61,68 N 94,78 W 113,09 N 56 56 33 W 2,768 46.06 N 121,04 W 129.51N 69 9 94 W 3.090 6~.24 98,25 3800 22 45 3779.87 3708.87 S61.OOW 28.24 N 152.21 W 154.81 N 79 29 11 W 3.417 133.61 3900 26 10 3870.88 3799.88 S63.50W 8.97 N 188.85 W 189.06 N 87 16 45 W 3.454 17~.61 4000 29 40 3959,23 3888.23 $64.00W 4100 30 5 4045,94 3974.94 S64.00W 11.73 S 230.84 W 231.13 S 87 5 26 W 3.902 221.14 33.57 S 275.61 W 277.65 S .83 3 19 W 0.420 2 .67 4200 29 45 4132,61 4061.61 S64.50W 55,24 S 320.54 W 325.26 S 80 13 19 W 0,362 4300 30 0 4219,32. 4148e32 'S65.00W 76-48 S 365.59 W 373.51 S 78 10 59 W 0.280 369,86' 4400 30 0 4305.92 4234.92 S65,00W 97.61 S 410.91 W 422.34 S 76 38 9 W 0.000 ~+19.66 4500 30 0 4392,52 4321.52 S65,00W 118,74 S 456.22 W 471,42 S 75 24 37 W 0.000 469,46 4600 29 55 4479.16. 4408,16 S65.50W 139.66 S 501,58 W 520,66 S 74 26 26 W 0.143 519,.2_2, 4700 30 0 4565.79 4494,79 S66.50W !59.97 S 547,21 W 570.11 S 73 42 14 W 0.260 569,03 4800 30 0 4652.39 4581.39 S65.50W 180.31 S 592.88 W 619.70 S 73 5 3 W 0.500 6 !. 4900 30 5 4738.96 4667,96 S65.50W 201.07 S 638.44 W 669.36 S 72 31 6 Wr 0'090 66U.80 5000 30 10 4825,45 4754,45 S66.00W 221.69 S 68~.21W 719.23 S 72 2 50 W' 0.149 718.85 5100 30 0 4911.97 4840.97 S66.00W 242.08 S' 730.01W 769,10 S 71 39 13 W 0.170 768,84 5200 30 5 4998.54 4927,54 S67.00W 262.04 S 775,92 W 818.98 S 71 20 21 W 0,267 818,81 5300 30 0 5085.10 5014,10 .567.00W 281.60 S 822,01 W 868,91 S 71 5 21 W' 0,090 .868,80 RE~'bR'D OF SURVEY ALL CALCULATIONS PERFORMED BY I B M ELECTRONIC COMPUTER T-~O-£' DOG LEG' ...,- ME'A'$';' 'DR'I FT" V~'RT'iCAL SUB DRIFT DEPTH ANGLE DEPTH SEA DIREC TOTAL COORDINATES C'L 0 S U R E $ SEVERITY DISTANCE A!)LG_L.___E:_ ........ D__E_G_/1 O_Q_ F T D M DEG, D ~ '5-z;-O-O---2P--5-O~T?i;-?7 510 o ,-? ~ s 6 e . 0 o w 5-5"0-0-- 72-'9- 30 5258,66 5187.66 S67.00W 300,69 $ 868,09 W 918,69 S 70 53 40 W 0,295 319,63 S 913,82 W 968,11 S 70 43 16 W 0_,.418 10lJ_, 31 ____iD_6 6 · 6o_ 1115.g6 115_5_, 52 --5-6-~--2~3~ 5345,66 5274,66 567,50W 338,70 S 959.30 W 1017.34 S 70 33 10 W ' 0~52 5-7-0~ 29 30 5432,65 5361,65. S69,00W 356,97 S 1005,10 W 1066,61S 70 26 47 W · 5800 29 40 55~'9,62 5448,62 S69.50W 374.47 S 1051,26 W 1115,97 S 70 23 37 W Q..210 5'9-0-0--2-~ 45 5606~"~7---5535.47 569,50W 391,82 S 1097,69 w 1165,52 $ 70 21 20 W 0.,OS0 6000 30 5 5693,14 5622,14 S69,00w 409,49 $ !144,33 w 1215,39 S 70 18 37 W 03~62 6~00 29 55 5779,74 5708.74 S69,50W 427,21S 1191,1'0 W 1265.40'S 70 16 6 W Q;203. 6200 29 30 5866,59 5795,59 568,50W 444,98 $ 1237,38 w 1314,96 S 70 13 14 w Q3_4~4 6300 29 15 595B,73 5882.73 $68,50w 462,96 S. 1283,02 W 1~6~,99 S 70 9 ~! W 0.250 1,215,39 1363,99 6400 29 0 6041,09 5970,09 567,00W 481,38 S 1328,06 W 1412.62 S 70 4 3.2"W 0,4~.2 6500 28 10 6128,90 ~057,90 $67'00W 500,08 $ 1372,10 W i460e40 S 69 58 30 W 0,8~,~ 660'0 ....2'? ..... ~"r3----6~-i"'7"~'~'~.- .... ~i"~'~',22 S66.00W 518.77 S 1415.10 W i507.20 ,5 69 52 1 W 0.47.~ 1507.17 6700 27 30 6305,82 6234.82 S65,50W ~ 2 6 9 ,5-9----63~'3,59 S65,50W 6900 27 15 6483,~-5 641-2,45 565,.50W-- 537.82 S 1457,38 W 1553.45 S 69 44 39 W 0.272 -5-56~'92 $ 1499.28 W 1599.38 $ 69 37 19 W 0.160 575,93 S 1541.01 W 1645,12 S 69 30 26 W 0,090 1553,40 1599,30 1645.01 __7000 27 0 6572,46 6501,46 S64.50W 595.20 S 1582.33 W 1690.57 S 69 23 9 W 0.324 7100 26 50 6661.62 6590.62 S65,00W 614.51 S 162B,28 W 1735,70 S 69 15 54 W 0,190 1690.41 1 7200 26 20 6751.04 6680,04 S65.50W 633.25 S 1663,93 W 1780.36 S 69 9 51 W 0,510 17b~.O~ 7300 26 15 6840.70 6769.70 S64.50W 651.97 S 1704,08 W 1824.54 S 69 3 47 W 0,215 ----'7~--26 15 6930,38 6859.38 $64.50W 671.02 S 1744,00 W 1868.63 S 68 57 19 W 0.000' 7500 25 55 7020.19 6949.19 S66.00W 689,4~ $ 1783.93 W 1912.52 S 68 '52 12 W 0,430 7600 25 30~. 7110,29 7039,29--S66,00W 707,07 $ 1823,57 W 1955,86 $ 08 48 23 W 0,430 1824.20 1868.21 1912.02 1955.30 1862,69 W 1998,48 S 68 45 26 W 0,531 1997.87 1901.18 W 2040.27 S 6 0.570 20~9,61 ---'-7Y~-5-~ --0 -:72 O0 , 7'3' '?/~9.-J'7-3----g~-TTOOV,£ -- 724 . 08 ----T8O0--2-4 25 T2~,-5~2-2--0--,--5-7--$-6-7-~. 00 W 7-40 . 42 --7-9-0'0 24 0 7382.7-~----7'311,77 S66,00W 756,78 ~000 23 15 7474,39 7403,39 $64,00W 773,71 8. 4~ 16 W S 1938.79 W 2081.26 S 68. 40 39 W 0.461 2080.54 S 1975,11 W 2121.25 S 68 36 29. W 0.812 2120.45 ---'~-~'00--22 50 7566,41 7495,41 S65.00W 790,56 $ 2010.44 W 216'0,29 $ 68 32 1W 0,437 2159,~0 62g0 22 BO 765fl,69 7587,69 563,50W 807,~1S 2045,!5 W 2198,73 5 68 27 31'w 0,40~ Z197,74 RECORD OF ALL CALC"ULAT!ONS PERF'~ORiVlED BY SURVEY I B M ELECTRONIC COMPUTER ['.lEAS. DR --~E-¢ T H AN TRUE IFT" VERTICAL SUB DRIFT G k E D-E-¢ T H S TOTAL COORDINATES DQ~LEG ' ' C L 0 S U R E S SEVERITY SECTION DISTANCE ANGLE DEG/IOOFT DISTANCE! '1 D M D E ~ · D l'q 5 8300 22 0 7751.24 76~0.24 $63.00W 824.35 S 2078.97 W 2236.44 S 68 22 14 W 0.505 22~,5-~3_~, 8400 21 30 7844.12 7773.12 S64,50W 840.74 S 2112.20 W 2273.38 S 68 17 43 W 0.539 227 8500 20 35 79~7,45 7866.45 S65.00W 856.06 S 2144.68 W 2309.22 S 68 14 25 w 0.912 2~07,90 8600 20 0 8031.24 7960.24 S66.00W 870.44 S 2176.24 W 2343.86 S 68 11 59 w 0.601 2~42.47 8700 19 15 8125.43 8054.43 S68,00W 883.56 S 2207.15 W 2377.44 S 68 10 58 W 0.781 2376.00 BSO0 lB 35 8220.03 8149.03 S68.00W 895.71S 2237.22 W 2409.86 S 68 10 49 W 0.660 2408.40 8900 18 10 8314.93 8243,93 $71.00W 906.75 $ 2266.75 W 2441.38 S 68 11 50 W 0.511 2439.93 9000 18 0 8409.99 8338.99 S74.50W 915.95 S 2296,39 W 2472,33 $ 68 15 16 W 0.375 2470.95 9100 18 45 8504.89 8433,89 S79,00W 923,18 $ 2327,07 .W 250~,50 $ 68 21 39 W O.bb2 2~02.2~ 9200 19 30 8599.37 R528.37 S83.50W 928,16 S 2359,44 W 2535.44 S 68 ~1 24 v, 0.902 2534.39 9300 20 10 8693,4~3 8622,43 S85.50W 931.41 S 2393,21 W 2568.08 $ 68 44 ~+ W 0.711 2667,26 <~P~::>21 0 8787.05 8716.~D~5 S86.00W 9~4"02 S 2428.28 W 2601,72 S 68 57 ~9 w 0,832 2601,13 :,~, ~,, , .... ~ ~.L~O,06 8~,~9.06 S~7.C,U¢~ 936.26 S 2464,93 W 2636,75 S 69 12. 5 w 1.099 26~6.37 ......... 980'0 .... 2-~"-'-E6'---~-~%;~ ........ 8-'f~'i'-"53 $88.00W 937.92 S 2502.97 W 2672.93 S 69 27 28 V',' 0.599 267.~.,72 9700 23 30 9064.52 8993,52 N89.00W 938,26 S 2542,17 W '2709.79 S 69 44 ~0 W 0.957 2'/09,72 9800 24 20 9155.93 9084.93 N88.50W 937.38 S 2582.71 W 2747.56 S 70 3 6 W 0.844 2747.55 9840 24 20 9192 B7 9121 37 N88,50W 936.95 S 2599 19 W 2762.91 S 70 10 ~6 W 0.000 276k,91 70 10 36 W --iT(~T T Orq HOLE CLOSURE 2762'91 FEET AT MEASURED DEPTH AND OTHER DATA FOR EVERY EVEN 100 FEET OF SUB SEA DEPTH, TRUE -- V'~K-,,CA'[~S U.---B-~D- T V D VERT I CAL DEPTH DEPTH SEA DIFFERENCE CORRECTION TOTAL COORDINATES !71 2-71 171. 100 0 0 271. 2OO 0 0 118.00 N 21.80 W 117.90 N 21,74 W --~-7I -$-7-1 . -3-0-'0 ~-"/--! ~W-I. 'Z~'UO 5'7-'I' ¥?'!. 50U '7-"-Y?'i ................................ -67-i , ............ 600 77'1 ~7'-i · 700 0 0 0 0- O' 0 0 0 0 0 117,~9' N 21,73 W 117.34 N 22.23 W 117.34 N 22.54 W 117,47 N 22.94 117.85 N 22,95 W 971 97'1-, ......... ~-'00-- i-'~Y71 1071 · 1000 0 0 118.00 N 22,55 W 0 0 0 0 118.14 N 22.11 W 118.39 N 21,66 W i 1-'71' 1-1-Wi--,-----1--I-O-O I--2V1 I2-71 1-3-7-1 1-~-W' Y 118.50 N 22,64 W 118,17 fi 22.88 W 117,90 N 22.82 W 14-7-1 I-6-7-1 1'77"1 i5-7'i-" ............ 15-0 0 1-6-7ig ....... 1-50-0 1871. 18'0'0 197-1-. 1900 117.86 N 22,60 W 117.75 N 22.51 W 118.30 N 22,93 W 118.14 N 23.72 W 117.45 N ,~4.02 W 117.00 N 24.20 W 20'7-1 -2-IT1 2'2-71 2-0-7-i-S-~2000 2-i-71 · 2100 2-2-TI · 2200 116.26 N 24.03 W 115.34 N 23.34 W 114.92 N 22.64 W 2~+V1 2-'57 1 26-Y'i 2":3'7 K. '" 2-3-0-0 ~4-'/I · '2400 2571, 2500 2'6'7i · 2600 114.43 N 22.39 W 113.84 N 22,46 W 112.79 N 2-~-~25 W 111.63 N 21.7~ W 2771 2771. 2700 110.58 N 21.16 W 2871 2'9'7 '1 2871. 2800 2-9~1 · 2900 109.51 N 20.40 W 108.50 N 19.95 W '3-OT1 3-07I · ~000 , 106.95 N 20.~0 w 3-!'7-I %I-YI. 3 I00---- 103.97 N 26.23 w 3-2-7-2 32-7T, 3200 99.:.57 iq 36,70 W '3U3-7-1-. 3 300 90.97 N 50.83 3-5"F9 3500 2 78.79 N 68.62 3 64.73 N 89.82 W '~EASURED DEPTH AND OTHER DATA FOR EVERY EVEN 100 FEET OF SUB SEA DEPT~_~ .. TRUE ~'~fE-~A-S-L~ED VERT-I-CAL SdB -~-~)-'---i'VD VERT I CAL 'r'D1yP'TH D-L=~A--BTFF E 'R g N C E ' C 0-;"-~,~0 N TOTAL COORDINATES 3684 :.¢ 79"0 z:i:244 4. 3-6'-O 4'4 '~ ~ '4'-590 '4-'/05 ................... Z+-937 b16-8 5-2-8-4 56-27 b859 -5-9T4 52O5 5-4-3 4 5-E6-1 577-~ '5'8~ 8 Tl-I-O 7 '2-2-2 7556 B 6'71-F-----~O 12 3 TT'lq~Z~-O ...... 3 8-7I-,- .... 3-8U0------_2-~' $~FTI-,---'~-gOO--- '" 42 407'i · "40'00 5'8 42717-----ZF2FO'O-- "89 4'3-7I-, : 4%~0 ' 104 4 .~TI~ .... -4-7-7 I'. .......... 74 7'0'0 ..... :[-6 6 Z~:-'71-.-- --4-8-0-0----1-8-2 4-9 7 l .-7----'4-9-0-0 1-9-? '507IV----5'0-0-0 .... ~I' 3 b IT'l: ..... 5q.-00-----2-2: 5' 4-7-'i-g~~'4-0-0 -27"3 5'T?-I- · 6 0 71 · 6-TfO-d-~'6 3 6 ~ 71-,--6-I0O "' '3 ~'7 6-3--F~-'F----~-3-O-O -----4-0 2 64Yi"." '6407Y--~5 65 71-~----ES-O-O-~ 6571. 67'~7%'. ~670-0 ..... 45I 68 ? 1-~---~-~YO--v----4-6-2 5 48,72 N 116,36 W 7 29,98 N 148,79 W 10 8,97 N 188,85 W 13 14,55 S 236.62 W i6 39,92 S 288,63 W 15 64.75 S 340,23 16 89,09 S 392.63 15 113,46 S 444,89 W 15 137.74 S 496,96 W 16 161,19 S 549.95 W 1-5 184.75 S 602.40 16 208,86 S 655.29 16 232.44 S 708.36 W 15 255.73 S 761.18 W 16 278,42 S 814,50 W 1'5 300.50 S 867.62 W 15 322,33 S 920,17 W 15 364.75 S 1025.35 W 15 384,94 S 1078.55 W 15 405.03 S 1132.10 W 16 425.61S 1186.31 W ~ 15 445.90 S 1239.66 w ~ 466.59 S 1291.97 W 14 .487,80 S . 1343.17 14 508,9'4 S 1392.73 ~. . 530,38 S 1440.80 12 552,04. S "13 5"7~3-;-~ 8 S 1487.U6 w 1535.02 W 12 595.16 S 1581.34 w 12 ~16.42 S 1627.37 W 12 637.39 $ 1672.76 ','~ 1'2 658.52 S 1717.51 W i1 679,58 5 1-~1,91 w 1"1 699,34 S 1806.20 'F'.£ASURED DEPTH--AND OTHER' ['JAT-T-A--F-O-R~'' EVERY EVEN I00 FEET OF SUB SEA 'DEPTH. T-R'U E MEASURED VERT ! CA-L- SUB-:----~',~--'~D VE'RT I'CAL DEPTH DEP TH'--SEA D I-F-CE'-R-~q C E ........ CO--ION TOTAL COORDINATE5 T83'7 ......................... Tg-~ 8-1-0-,5 8-2-i-3 8429 7 1:7 1 .-----?-1-0i%" 4. 9 6 7-3'7E-. .... 7-~TT-,-~'T400: 7657"f'; ....T~O0-- .TS-7T-,~ .... TEC,O-----5-zF2~ 7 8 ZT'T; "¢1'-00 .... -5 77 11 718.58 $ ld49.83 W I0 736.69 S 1~92.39 W 1-0 754.b2 S 1933.94 W 9 773.02 5 1973.6~ W 9 791.3~ S 2012.19 W 8 809.56 S 2049.58 W 8 827.90 S 2085.97 8 845.32 S 2121.60 7 861.32 $ 2156.05 W 6 875.14 S 2189.31 W 6 889.44 S 2221.71 8-8-54. 8271. 8200 583 6 901.86 S 2253.09 5 912.45 S 2284.18 5 920.93 S 2315.79 5 926.98 S 2349.53 7 930,95 S 2384.97 6 933,73 S 2422.14. 8 93~06 S 2461.18 93'7,89 S 2502.i~ Ye 938.21 S 2544.97 9 937.15 S 2589.30 v7 INTERPOLATED VALUES FOR EVEN 1000 FEET OF MEASURED DEPTH, T'RUE .,,,~~'~F' ASU'R ED VER'T']'CAL SUB D-E'P~ D~FP-TH SEA TOTAL COORDINATES lOOO 9-CY~. 928. 118.27 N 22.01 W 2-0!70 I'999. 1928. 116.84 N 24.20 W 4000 29-28. t08.30 N 20.01 W 3888. 11.91 S 230.?4 W 5-00-0 4-8-2-5-.----~4-7-5-4-. 221 · 88 S 684.11 w 6000 56-9-3-.' 56-~-~. 409.70 S 1144.25 W '?OOo 65-?2. 650"1. 5:'95'.-5~ S 1582.16 W B 0 O0 74-T4~-,---'-7-4-~. 77-3-~-7 ! S 1975.11 W .~O-O-D ~-4-C~9-~l ' 8~3-3~g, 916.08 S 2296.35 W RTiCA E L SECTION · -' ' ~-~CA'LE '"'"' I =1000.. - ......... ' ATLANTIC'- RICHFIELD ,COMPANY ........... ~ -- iff.~.D.R!LL ..S I__T_.E. .! .-; 2,'_~._.._'_-' .__.6 .~L_._~._; RADIUS OF CURVATURE ' GYROSCOPIC SURVEY ......... : . ! · '1 TVD= 9192' TM D= 9840' : : I _HORIZONTALd V.IEW ! __ SCALE i"= 500' ATLANTIC RICHFIELD (~oMPANY DRILL SITE I-2 RADIUS OF ' cUR~/AT-URE ........ GYROSCOPIC SURVEY; .................. :-- · ._ ....... ~ .... i 4ooo ....................... 4800 5200 _ ....... TVD=9192~-; ............. 7zoo : F : ~'~ ; TMD = 9840 ............ .... 7600_ ~ .............. ~ .................... ' .... ; ...... ~ -' ~: '" ..'..~.~ ~. ........ .~7~ *;;7~' _;._; .................... 88oo 8400 ............................... ~ ............. i"": ........ ~ ................ i - ;' ................ L_. ....... ~ ............ L._: ............ : .............. : ............ ~ .............. ..',_~--~ ..... ALL _DEPTHS SHOWN ~* ............ ~ .... ~"~ ........ ~"--ii~" ;~-_~.~ ...... ..... ....... : .......... ~ ..... ~ .......... ~ ................. ~ ................... ~ ....................... ; - ..... ~' . - ~ ~ .... i ....... ............................. ~ .................... ' .............................. ~ .............. :'-~ ...... ~ "'?-~-.' ~i-~ .... .Li . ..~_. ~ '. , ...... ~.- ~.S--'& __- .. ...... ~ ' : ' · ~ : ~ .... ~ : ......... : ...... ~': ........... i .... ~ ....... F ..... ~-': ........... . ................... ~ ................. .............. ~ ......... I ...... ? .......... . .......... , ~ .... ~ .... : .... t ........ . ..... ~ .... :'= ........ ~-'~-':"'-~-~- ......... ~ ........ :-':-':--~"-:---: .... ~ .......... ~ .... : ; . ' i '. j '.-~.L ~ .... ~ . '.- . .~"-~ ~ .'_'._.~'_;~ <". L.'.l_i".~' ';~ '~.~Liii~.':ii-.] '. _i;; ~ ~.-'~"L."7 _'L'i ~'..L L~.~.-L~'.' .~ .--.T._-;'i_i . ~.'.,:; .' ]~ ~ ~" ~.' - : ..... ~. ............... ' ~ ................ ~ ....... :. L..: ...... ~._~ ........... :.2..:.__: ........ :__: .......... ~ ...... : ...... ~ ......... ~ ........ .... : . . ~ .......... ~ ............... ~ ............ ~ - .. ~ .......... ,~ ............... j ................. ~-: .................................... l ...... : t . , f - ~ ..................... ~ ..................... ~ : ............ ~ .........; .......... ~ --~ ..........................
