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200-163
1a. Well Status: GINJ Oil 1b. Well Class: 5 Exploratory Service Hilcorp North Slope, LLC 14. Permit to Drill Number/Sundry 200-163 2/13/2001 02/19/2001 GL PRUDHOE BAY, PRUDHOE OIL 4a. Surface: Top of Productive Interval: Total Depth: 2224' FNL, 2368' FEL, Sec. 12, T11N, R13E, UM 1288' FNL, 888' FEL, Sec. 12, T11N, R13E, UM 480' FNL, 411' FWL, Sec. 07, T11N, R14E, UM Surface: x- y- Zone -657852 5969417 ASP-4 11. Gas SPLUG 5Abandoned 20AAC 25.105 Suspended 20AAC 25.110 WINJ WAG WDSPL No. of Completions: 3/20/21 15. 50-029-20600-01-00 16. PBU G-13A Well Name and Number: Surface / Surface 35.47 17. TPI:y- Zone -659310 ASP-4x-5970383 Total Depth: x-y-Zone -660592 ASP-45971219 10844' / 8990' None DNR Approval Number:19. 88-002 5. Directional or Inclination Survey: Yes No Submit electronic and printed information per 20 AAC 25.050 (ft MSL) 20.Thickness of Permafrost MD/TVD: MWD / GR& Mem GR / CNL / TEMP CASING WT. PER FT.GRADE SETTING DEPTH MD TOP BOTTOM HOLE SIZE CEMENTING RECORD AMOUNT PULLED Location of Well (Governmental Section): Field/Pool(s): Date Comp., Susp., or Aband.:6. Total Depth (MD/TVD): CASING, LINER AND CEMENTING RECORD TOP BOTTOM 22. SETTING DEPTH TVD 9-5/8" 7" 2-3/8" 91.5# 72# 47# 29# 4.6# L-80 L-80 L-80 L-80 Surface Surface 8138' 8143' 8649' 9090' 10844' Surface Surface 7852' 7856' 8781' 8349' 8990' 3" 8-1/2" 12-1/4" 8 cu yds Concrete 1104 cu ft Class' G' 336 cu ft Class' G' 73 cu ft Class' G' 25. GRADE PACKER SET (MD/TVD) 26. 3-1/2" 9.2# L-80 DEPTH INTERVAL (MD)AMOUNT AND KIND OF MATERIAL USED PRODUCTION TEST27. Date First Production: Abandoned N/A Date of Test: Flow Tubing Press Oil-Bbl: Oil-Bbl: Gas-MCF:Water-Bbl: Oil Gravity - API (corr): Method of Operation (Flowing, gas lift, etc.): Gas-Oil Ratio:Choke Size: Water-Bbl: N/A Open to production or injection?Yes No 524. If Yes, list each interval open (MD/TVD of Top and Bottom; Perforation Size and Number; Date Perfd): H-40 111'36"20" 13-3/8"Surface 2674'17-1/2"3441 cu ft Arcticset IISurface2674' 8083 / 7798 N/A Gas-MCF: Production for Test Period Calculated 24 Hour Rate Hours Tested: Casing Press: 111' ACID, FRACTURE, CEMENT SQUEEZE, ETC. TUBING RECORD DEPTH SET (MD) Yes No 5Was hydraulic fracturing used during completion? Per 20 AAC 25.283 (i)(2) attach electronic and printed information ADL 028280, 028304 321-026 Other 12. SSSV Depth (MD/TVD): Ref Elevations BF 36.29 (attached) KB Form 10-407 Revised 3/2020 Sr Pet Eng Sr Pet Geo Sr Res Eng STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG Development Stratigraphic Test 2.Operator Name: 3.Address: 3800 Centerpoint Dr, Suite 1400, Anchorage, AK 99503 7. Date Spudded: 8. Date TD Reached: 9. 10. Plug Back Depth(MD/TVD): 4b. 4b. Location of Well (State Base Plane Coordinates, NAD 27): 65.97 Water Depth, if Offshore:13. N/A 0 API Number: Logs Obtained List all logs run and, pursuant to AS 31.05.030 and 20 AAC 25.071, submit all electronic data and printed logs within 90 days of completion, suspension, or abandonment, whichever occurs first. Types of logs to be listed include, but are not limited to: mud log, spontaneous potential, gamma ray, caliper, resistivity, porosity, magnetic resonance, dipmeter, formation tester, temperature, cement evaluation, casing collar locator, jewelry, and perforation record. Acronyms may be used. Attach a separate page if necessary 23. 18.Property Designation: 21.Re-drill/Lateral Top Window MD/TVD: 9090 / 8780 1900' (approx.) 5 Submit within 30 days of Completion, Suspension, or Abandonment Surface - 1540 / 7981 - 9090 By Samantha Carlisle at 4:33 pm, Apr 05, 2021 RBDMS HEW 4/7/2021 Abandonment Date 3/20/2021 HEW xGSFD 4/7/2021 DSR-4/7/21 MGR24JUN2021 If yes, list intervals and formations tested, briefly summarizing test results. Attach separate sheets to this form, if needed, and submit detailed test information per 20 AAC 25.071. Permafrost - Base Formation at total depth: Contact Name:Oliver Sternicki Contact Email: Oliver.Sternicki@hilcorp.com Authorized Name:Stan Golis Authorized Title:Sr. Area Operations Manager Authorized Signature with Date:Contact Phone:907.564.4891 32. I hereby certify that the foregoing is true and correct to the best of my knowledge. INSTRUCTIONS General: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. Submit a well schematic diagram with each 10-407 well completion report and 10-404 well sundry report when the downhole well design is changed. All laboratory analytical reports regarding samples or tests from a well must be submitted to the AOGCC, no matter when the analyses are conducted. Item 1a. Multiple completion is defined as a well producing from more than one pool with production from each pool completely segregated. Each segregated pool is a completion. Item 1b. Well Class Service wells: Gas Injection, Water Injection, Water-Alternating-Gas Injection, Salt Water Disp, Water Supply for Injection, Observation or Other. Item 4b. TPI (Top of Producing Interval). Item 9. The Kelly Bushing and Ground Level elevations in feet above mean sea level. Use same as reference for depth measurements given in other spaces on this form and in any attachments. Item 15. The API number reported to AOGCC must be 14 digits (ex: 50-029-20123-00-00). Item 20. Report true vertical thickness of permafrost in Box 20. Provide MD and TVD for the top and base of permafrost in Box 29. Item 22. Review the reporting requirements of 20 AAC 25.071 and, pursuant to AS 31.05.030, submit all electronic data and printed logs within 90 days of completion, suspension, or abandonment, whichever occurs first. Item 23. Attached supplemental records should show the details of any multiple stage cementing and the location of the cementing tool. Item 24. If this well is completed for separate production from more than one interval (multiple completion), so state in item 1, and in item 23 show the producing intervals for only the interval reported in item 26. (Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval). Item 27. Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut-in, or Other ( explain). Item 28. Provide a listing of intervals cored and the corresponding formations, and a brief description in this box. Submit detailed description and analytical laboratory information required by 20 AAC 25.071. Item 30. Provide a listing of intervals tested and the corresponding formation, and a brief summary in this box. Submit detailed test and analytical laboratory information required by 20 AAC 25.071. Item 31. Pursuant to 20 AAC 25.070, attach to this form: well schematic diagram, summary of daily well operations, directional or inclination survey, and other tests as required including, but not limited to: core analysis, paleontological report, production or well test results. 8689 8728 8806 9404 8388 8426 8502 9007 Sag River Shublik Sadlerochit Ivishak Zone 1A Ivishak Zone 1A 28.CORE DATA Conventional Core(s) Yes No 5 Sidewall Cores Yes No 5 If Yes to either question, list formations and intervals cored (MD+TVD of top and bottom of each), and summarize lithology and presence of oil, gas or water (submit separate sheets with this form, if needed). Submit detailed descriptions, core chips, photographs and laboratory analytical results per 20 AAC 25.071. Well Tested? Yes 9404 9007 Top of Productive Interval 8808 8502 5NoPermafrost - Top TVDMDNAME 30. FORMATION TESTS29. GEOLOGIC MARKERS (List all formations and markers encountered): Form 10-407 Revised 3/2020 Submit within 30 days of Completion, Suspension, or Abandonment 31. Daily Operations Summary, Wellbore Schematic, Well PhotosList of Attachments: Information to be attached includes, but is not limited to: summary of daily operations, wellbore schematic, directional or inclination survey, core analysis, paleontological report, production or well test results, per 20 AAC 25.070. Digitally signed by Stan Golis (880) DN: cn=Stan Golis (880), ou=Users Date: 2021.04.04 12:40:18 -08'00' Stan Golis (880) FULL ABANDONMENT - WELLHEAD CUT 4' BELOW TUNDRA ELEVATION, MARKER CAP INSTALLED & BACKFILLED (03/20/21) ACTIVITY DATE SUMMARY 3/20/2021 **P&A** Pad Elevation=34.1'. Tundra Elevation=31'. Excavate down to 9.5', found suspended well casing at ~3' below pad elevation. Cut cemented strings 4' below tundra elevation. Witnessed by AOGCC Rep. Matt Herrera. Welded marker plate, back filled excavation and delineated site. Pictures taken for documentation. Job Complete Daily Report of Well Operations PBU G-13A MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: Jim Regg �� 4I1 �Zl DATE: 3/20/2021 P. I. Supervisor � "I FROM: Matt Herrera SUBJECT: Surface Abandonment Petroleum Inspector PBU G -13A Hilcorp North Slope - PTD 2001630; Sundry 321-026 3/19/2021: 1 traveled to PBU G-1 3A and met Hilcorp representative Jaycen Sala for P&A cutoff and final inspection prior to marker plate installation. PBU G-1 3A was drilled and completed in 1991, sidetracked in 2001 and later found with collapsed tubing in 2009. In 2016 well was "temporarily capped P&A" per Sundry Approvals 316-282 and 316-575. 1 went over paperwork with Jaycen and verified correct well information. Inspection of the casing stub in excavated cellar, showed casing top to be sufficiently below Tundra Grade with solid cement to surface on all casing strings. Excavation was dry and clear of debris. Marker plate size was verified to fit outer most casing string and well information verified per latest P&A Sundry 321-026. Operator to backfill upon completion of welding marker plate on casing stub. Attachments: Photos (4) 2021-0319_Surface_Abandon_PBU_G-13A_mh.docx Pagel of 3 Surface Abandon — PBU G -13A (PTD 2001630) Photos by AOGCC Inspector M. Herrera 3/19/2021 2021-0319_Surface_Abandon_PBU_G-13 A_mh. docx Page 2 of 3 AM ' � 1 2021-0319_Surface_Abandon_PBU_G-13A_mh. docx Page 3 of 3 s 2021-0319_Surface_Abandon_PBU_G-13A_mh. docx Page 3 of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a &RQGXFWRU *,1- 5 3RVW,QLWLDO,QMHFWLRQ0,75HT G" <HV 1R 5 &RPP 67$7(2)$/$6.$ $/$6.$2,/$1'*$6&216(59$7,21&200,66,21 $33/,&$7,21)25681'5<$33529$/6 $$& 6XUIDFH a ,QWHUPHGLDWH a6XUIDFH 6XUIDFH $GGUHVV &HQWHUSRLQW'U6XLWH $QFKRUDJH$. 1R 5<HV &DVLQJ /HQJWK 0'79' %XUVW 7XELQJ*UDGH 7XELQJ0' IW 3HUIRUDWLRQ'HSWK79' IW &ROODSVH 0363 SVL :HOOERUH6FKHPDWLF &RPP6U3HW(QJ 6U3HW*HR 6U5HV(QJ )RUP5HYLVHG$SSURYHGDSSOLFDWLRQLVYDOLGIRUPRQWKVIURPWKHGDWHRIDSSURYDO 6XUIDFH By Jody Colombie at 3:49 pm, Jan 14, 2021 'LJLWDOO\VLJQHGE\6WDQ*ROLV '1 FQ 6WDQ*ROLV RX 8VHUV 'DWH 6WDQ*ROLV DSR-1/14/21 10-407 SFD 1/15/2021MGR22JAN21 Photo document as described. <HVWLRQ5HTXLUHG" &RPP 1/25/21 dts 1/25/2021 JLC 1/25/2021 RBDMS HEW 1/27/2021 WůƵŐĂŶĚďĂŶĚŽŶ tĞůů͗'Ͳϭϯ Wd͗ϮϬϬϭϲϯ W/͗ϱϬͲϬϮϵͲϮϬϲϬϬͲϬϭ *$3OXJDQG$EDQGRQ :HOO,QWHJULW\(QJLQHHU 2OLYHU6WHUQLFNL 2SHUDWLRQV(QJLQHHU 'DYLG:DJHV ([SHFWHG6WDUW'DWH +LVWRU\ 3UXGKRH ZHOO * ZDV GULOOHG DQG FRPSOHWHG LQ *$ 37' ZDV &7' VLGHWUDFNHG RQ DQG WKHQ VXVSHQGHG RQ DIWHUIDLOXUH WR SXOO OLQHU IRU D VXEVHTXHQW&7'VLGHWUDFN&ROODSVHGWXELQJZDVIRXQGDWa¶LQ :RUNZDVFRPSOHWHGLQ ODWHWRFHPHQWDOOWXEXODUVWRVXUIDFHFXWDQGWHPSRUDULO\FDSWKHWXEXODUVDSSUR[LPDWHO\ IRRWEHORZSDGVXUIDFHXQGHUVXQGU\ 2EMHFWLYH ([FDYDWHDQGFXWRIIDOOFDVLQJV¶EHORZRULJLQDOWXQGUDSHUPDQHQWO\LQVWDOOZHOOQDPHFDSDQG EDFNILOOH[FDYDWLRQ 3URFHGXUH ([FDYDWHDQG&XWRIIDOOFDVLQJV¶EHORZRULJLQDOWXQGUDOHYHO $2*&&ZLWQHVVRIFXWRIIFDVLQJVEHIRUHDQ\WRSMREFRPPHQFHV $2*&&ZLWQHVVFHPHQWWRSVLQDOODQQXOL7RSRIIZLWKFHPHQWDVQHHGHG %HDGZHOGPDUNHUFDSRQRXWHUPRVWFDVLQJVWULQJ3KRWRGRFXPHQWDOOVWHSVDQG$2*&&ZLWQHVV RILQVWDOOHGFDS0DUNHUFDSWRUHDGDVIROORZV +LOFRUS1RUWK6ORSH//& *$ $3,1R 37'1R Operator Name:2. Development Exploratory Service 5 Permit to Drill Number:200-163 6.50-029-20600-01-00 PRUDHOE BAY, PRUDHOE OIL BP Exploration (Alaska), Inc 5. Well Name and Number:8. 10.Field/Pools: Well Class Before Work4. Present Well Condition Summary:11. Total Depth: measured feet feet Plugs measured feet feet Effective Depth: measured feet feet Packer measured feet feettrue vertical true vertical 10844 Surface Surface 8083 None SXUIDFH 7798 Casing: Length: Size: MD: TVD: Burst: Collapse: Structural Conductor ~75 20" Surface - 111 Surface - 111 1490 470 Surface ~2638 13-3/8" Surface - 2674 Surface - 2674 5380 2670 Intermediate ~8613 9-5/8" Surface - 8649 Surface - 8349 6870 4760 Liner 952 7" 8138 - 9090 7852 - 8781 8160 7020 Perforation Depth: Measured depth: None feet True vertical depth: feet Tubing (size, grade, measured and true vertical depth)3-1/2" 9.2# L-80 6XUIDFH 6XUIDFH 8083 7798Packers and SSSV (type, measured and true vertical depth) 4-1/2" TIW HBBP Packer Liner 2701 2-3/8" 8143 - 10844 7856 - 8990 11200 11780 12. Stimulation or cement squeeze summary: Intervals treated (measured): Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Suspended Representative Daily Average Production or Injection Data Prior to well operation: Subsequent to operation: 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Name: Contact Email: Sternicki, Oliver R Oliver.Sternicki@bp.com Authorized Name:Lastufka, Joseph N Authorized Title: Authorized Signature with Date:Contact Phone:+1 907 564 4301 Treatment descriptions including volumes used and final pressure: 13. SIM Specialist Operations Performed1. Abandon Plug Perforations Fracture Stimulate Pull Tubing GSTOR WINJ WAG GINJ SUSP 5 SPLUG 16. Well Status after work:Oil Gas Exploratory Development 5 Stratigraphic 15. Well Class after work: Service WDSPL 14. Attachments: (required per 20 AAC 25.070.25.071, & 25.283) Daily Report of Well Operations Copies of Logs and Surveys Run true vertical measured8990 Sundry Number or N/A if C.O. Exempt: N/A Junk Packer Printed and Electronic Fracture Stimulation Data 5 Suspend Inspection Operations shutdown Change Approved Program 5 Senior Pet Engineer:Senior Res. Engineer: STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS Suspend Perforate Other Stimulate Alter Casing Plug for Redrill Perforate New Pool Repair Well Re-enter Susp Well 3.Address: P.O. Box 196612 Anchorage, AK 99519-6612 7.Property Designation (Lease Number):ADL 0028304 PBU G-13A 9. Logs (List logs and submit electronic and printed data per 20AAC25.071): Stratigraphic Other: API Number: Form 10-404 Revised 03/2020 Submit Within 30 days of Operations By Jody Colombie at 2:53 pm, Jun 26, 2020 Joseph N Lastufka Digitally signed by Joseph N Lastufka Date: 2020.06.24 10:19:31 -08'00' RBDMS HEW 6/29/2020 MGR26JUN20 DSR-6/26/2020 SFD 6/30/2020 , ADL 0028280 SFD 6/30/2020 ACTIVITYDATE SUMMARY 6/4/2020 Pre AOGCC SU Inspection. Well has been cut off and buried. Gravel area over and around well is clean and dry. 12:45 6/9/2020 SU well inspection (AOGCC witnessed by Bob Noble). Well has been cut off below pad grade. Pictures taken. 0950. Daily Report of Well Operations PBU G-13A Suspended Well Site Inspection Form Notify AOGCC Inspectors at least 10 days prior to inspection to allow witness Well Name: Prudhoe Bay Unit G-13A Field/Pool: Prudhoe Bay / Prudhoe Oil Permit # (PTD): 1791070 API Number: Operator: BP EXPLORATION (ALASKA) INC Date Suspended: 10/6/2008 Surface Location: Section: 12 Twsp: T11N Range: 13E Nearest active pad or road: G Pad Take to Location Digital camera Map showing well location /Aerial photos Brief well history Wellbore diagram showing downhole condition Latest Sundry or Completion report Past Site Visit documentation Site clearance documentation Pressure gauges, fittings, tools Sample containers for fluids on or near pad Condition of Surface Location AOGCC requires: 1) a description of the condition of the surface location, including discoloration, fluids or sheens visible on the ground or in any nearby water, 2) photographs showing the condition of the location surrounding the well General location condition: Clean Gravel Pad or location surface: OK Location cleanup needed: None Pits condition: OK Surrounding area condition: OK Water/fluids on pad: None Discoloration, Sheens on pad, pits or water: None Samples taken: None Access road condition: Good Photographs taken (# and description): See Folder Condition of Wellhead AOGCC requires: 1) a description of the condition of the wellhead, 2) well pressure readings, where practicable, 3) photographs showing the wellhead condition Wellhead/tree/valve description, condition: Tree / Wellhead cut off below grade Cellar description, condition, fluids: N/A Rat Hole: Wellhouse or protective barriers: N/A Well identification sign: N/A Tubing Pressure (or casing if no tubing): N/A Annulus pressures: N/A Wellhead Photos taken (# and description): See Folder Work Required: None Operator Rep (name and signature): Ryan Moore AOGCC Inspector: Bob Noble Other Observers: Randy Mork / Jeff Curren Inspection Date: 6/9/2020 AOGCC Notice Date: 6/8/2020 Time of arrival: 9:45 AM Time of Departure: 9:55 AM Site access method: Truck 500292060001 Re-Inspection Suspended Well Inspection Review Report InspectNo: susRCN200609163548 Date Inspected: 6/9/2020 Inspector: Bob Noble Type of Inspection: Well Name: PRUDHOE BAY UNITG-13A Permit Number: 2001630 Suspension Approval: Sundry rr 309-180 Suspension Date: 6/2/2009 Location Verified? 0 If Verified, How? Other (specify in comments) Offshore? ❑ Well Pressures (psi): Tubing: IA: OA: Wellhead Condition Wellhead cut off below pad grade. Condition of Cellar No cellar ✓ Surrounding Surface Condition Good clean dry gravel. - Comments Well location confirmed from pad map. ✓ Subsequent I Date AOGCC Notified: 6/7/2020 Operator: BP Exploration (Alaska) Inc. Operator Rep: Ryan Moore Wellbore Diagram Avail? PI Photos Taken? P1 Fluid in Cellar? ❑ BPV Installed? ❑ VR Plug(s) Installed? ❑ Supervisor Comments Cutoff depth does not meet AOGCC P&A requirements. Photos (1) attached. ✓ v'' iz- �llq/evz© Friday, June 19, 2020 Suspended — PBU G -13A (PTD 2001630) AOGCC Inspection #susRCN200609163548 Photos by AOGCC Inspector B. Noble 6/9/2020 2020-0609_Suspend_PB U_G-13A_photos_b n.docx Page 1 of 1 STATE OF ALASKA LASKA OIL AND GAS CONSERVATION COMM! WELL OMPLETION OR RECOMPLETION REPO AND LOG la. Well Status: Oil 0 Gas ❑ SPLUG 0 Other 0 Abandoned 0 Suspended ® • 1b.Well Class: 20AAC 25.105 20AAC 25.110 • Development lel Exploratory 0 GINJ 0 WINJ 0 WAG 0 WDSPL ❑ No.of Completions: Zero Service 0 Stratigraphic Test 0 2. Operator Name: 6. Date Comp.,Susp.,or Aband.: 14.Permit to Drill Number/Sundry BP Exploration(Alaska),Inc 12/5/2016 . 200-163 316-282,316-575 3. Address: 7. Date Spudded: 15. API Number: P.O.Box 196612 Anchorage,AK 99519-6612 2/13/2001 50-029-20600-01-00 ' 4a. Location of Well(Governmental Section): 8. Date TD Reached: 16. Well Name and Number: 2/19/2001 PBU G-13A ' Surface: 2224'FNL,2368'FEL,Sec.12,T11N,R13E,UM 9 Ref Elevations' KB 65.97 •• 17. Field/Pool(s): Top of Productive Interval: 1288'FNL,888'FEL,Sec.12,T11N,R13E,UM GL 35.47 • BF 36.29 PRUDHOE BAY,PRUDHOE OIL . Total Depth: 480'FNL,411'FWL,Sec.07,T11N,R14E,UM 10. Plug Back Depth(MD/TVD): 18. Property Designation: Surface/Surface ADL 028280&028304 4b. 4b.Location of Well(State Base Plane Coordinates,NAD 27): 11. Total Depth(MD/TVD): 19. Land Use Permit: Surface:x- 657852• y- 5969417 • Zone - ASP 4 10844'/8990' • 88-002 TPI: x- 659310 y- 5970383 Zone - ASP 4 12. SSSV Depth(MD/TVD): 20 Thickness of Permafrost MD/TVD: Total Depth:x- 660592 y- 5971219 Zone - ASP 4 None 1900'(Approx.) 5. Directional or Inclination Survey: Yes l'(attached)„.14 No 13. Water Depth,if Offshore: 21. Re-drill/Lateral Top Window MD/TVD: Submit electronic and printed information per 20 MC 25.050 N/A (ft MSL) • 9090'/8780' 22. Logs Obtained List all logs run and,pursuant to AS 31.05.030 and 20 MC 25.071,submit all electronic data and printed logs within 90 days of completion, suspension,or abandonment,whichever occurs first.Types of logs to be listed include,but are not limited to:mud log,spontaneous potential,gamma ray,caliper, resistivity,porosity,magnetic resonance,dipmeter,formation tester,temperature,cement evaluation,casing collar locator,j I nd erforation record. Acronyms may be used.Attach a separate page if necessary El E MWD/GR&Mem GR/CNL/TEMP ) JAN 0 4 2017 23. CASING,LINER AND CEMENTING RECORD AOGCC CASING WT.PER GRADE SETTING DEPTH MD SETTING DEPTH ND HOLE SIZE CEMENTING RECORD AMOUNT TOP BOTTOM TOP BOTTOM PULLED 20" 91.5# H-40 Surface 111' Surface 111' 36" 8 cu yds Concrete 13-3/8" 72# L-80 Surface 2674' Surface 2674' 17-1/2" 3441 cu ft Arcticset II 9-5/8" 47# L-80 Surface 8649' Surface 8349' 12-1/4" 1104 cu ft Class'G' 7" 29# L-80 8138' 9090' 7852' 8780' 8-1/2" 336 cu ft Class'G' 2-3/8" 4.6# L-80 8143' 10844' 7856' 8990' 3" 73 cu ft Class'G' 24. Open to production or injection? Yes 0 No a 25. TUBING RECORD If Yes,list each interval open(MDR-VD of Top and Bottom;Perforation GRADE DEPTH SET(MD) PACKER SET(MD/TV Size and Number): 3-1/2"9.2#L-80 1540'/7981'-9090' 8083'/7798' 26. ACID,FRACTURE,CEMENT SQUEEZE,ETC. Was hydraulic fracturing used during completion? Yes 0 No 0 • SCORED � 1 l/ 201:,/, Per 20 AAC 25.283(i)(2)attach electronic and printed MA4, . information DEPTH INTERVAL(MD) AMOUNT AND KIND OF MATERIAL USED See Attached 27. PRODUCTION TEST Date First Production: Not on Production Method of Operation(Flowing,gas lift,etc.):N/A Date of Test: Hours Tested: Production for Oil-Bbl: Gas-MCF: Water-Bbl: Choke Size: Gas-Oil Ratio: Test Period �..1► Flow Tubing Casino Press: Calculated Oil-Bbl: Gas-MCF: Water-Bbl: Oil Gravity-API(cord: Press 24 Hour Rate Form 10-407 Revised 11/2015 CONTINUED ON PAGE 2 Submit ORIGINAL only //� � ,,,,,,S> 3.1`3- /7 J /4 37i /O 1t(r ROOMS LL- JAN 1 9 201 28. CORE DATA • Conventional Core(s) Yes ❑ No 0 • Sidewall Cores Yes ❑ No IZ • If Yes to either question,list formations and intervals cored(MD+TVD of top and bottom of each),and summarize lithology and presence of oil,gas or water (submit separate sheets with this form,if needed).Submit detailed descriptions,core chips,photographs and laboratory analytical results per 20 AAC 25.071. 29. GEOLOGIC MARKERS(List all formations and markers encountered): 1 30. FORMATION TESTS NAME MD TVD Permafrost-Top Well Tested? Yes ❑ No 0 • Permafrost-Base If yes,list intervals and formations tested,briefly summarizing test results.Attach Top of Productive Interval 8806' 8502' separate sheets to this form,if needed,and submit detailed test information per 20 AAC 25.071. Sag River 8689' 8388' Shublik 8728' 8426' SADLEROCHIT 8806' 8502' Zone 1 A • 9404' 9007' Formation at total depth: 31. List of Attachments: Summary of Pre-Rig Work,Summary of Daily Reports,Summary of Post-Rig Work,Pictures,Wellbore Schematic Diagram Information to be attached includes,but is not limited to:summary of daily operations,wellbore schematic,directional or inclination survey,core analysis,paleontological report,production or well test results,per 20 AAC 25.070. 32.I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact: Leemhuis,Jacob Email: Jacob.Leemhuis@bp.com Printed Name: Joe Lastufk Title: Drilling Technologist Signature: Phone: +1 907 564 4091 Date: 1/5/)7 INSTRUCTIONS General:This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska.Submit a well schematic diagram with each 10-407 well completion report and 10-404 well sundry report when the downhole well design is changed. All laboratory analytical reports regarding samples or tests from a well must be submitted to the AOGCC,no matter when the analyses are conducted. Item 1 a. 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 1 b.Well Class Service wells:Gas Injection,Water Injection,Water-Alternating-Gas Injection,Salt Water Disp,Water Supply for Injection,Observation or Other. Item 4b.TPI(Top of Producing Interval). Item 9. The Kelly Bushing and Ground Level elevations in feet above mean sea level.Use same as reference for depth measurements given in other spaces on this form and in any attachments. Item 15.The API number reported to AOGCC must be 14 digits(ex:50-029-20123-00-00). Item 20.Report true vertical thickness of permafrost in Box 20.Provide MD and TVD for the top and base of permafrost in Box 29. Item 22.Review the reporting requirements of 20 AAC 25.071 and,pursuant to AS 31.05.030,submit all electronic data and printed logs within 90 days of completion,suspension,or abandonment,whichever occurs first. Item 23.Attached supplemental records should show the details of any multiple stage cementing and the location of the cementing tool. Item 24.If this well is completed for separate production from more than one interval(multiple completion),so state in item 1,and in item 23 show the producing intervals for only the interval reported in item 26.(Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval). Item 27.Method of Operation:Flowing,Gas Lift,Rod Pump,Hydraulic Pump,Submersible,Water Injection,Gas Injection,Shut-in,or Other(explain). Item 28.Provide a listing of intervals cored and the corresponding formations,and a brief description in this box.Submit detailed description and analytical laboratory information required by 20 AAC 25.071. Item 30.Provide a listing of intervals tested and the corresponding formation,and a brief summary in this box.Submit detailed test and analytical laboratory information required by 20 AAC 25.071. Item 31.Pursuant to 20 AAC 25.070,attach to this form:well schematic diagram,summary of daily well operations,directional or inclination survey,and other tests as required including,but not limited to:core analysis,paleontological report,production or well test results. Form 10-407 Revised 11/2015 Submit ORIGINAL Only 0 • WELL NAME: G-13A 26. Acid, Fracture, Cement Squeeze, Etc. Depth Interval (MD) Amount & Kind of Material Used 7981' Cut and Pull 3-1/2" Tubing 7900' Set EZSV 6248' 120 Bbls Class 'G' 1600' Set EZSV 1580' Cut 9-5/8' Casing 1561' Set EZSV 1561' 125 Bbls Class 'G' Surface 117.2 Bbls Class 'G' • i G-13A Well History (Pre-Rig Suspend) ACTIVITYD _ b MARY, T/I/O=SSV/100/50, Temp=SI. PPPOT-T(PASS), PPPOT-IC (FAIL). Pre P&A. PPPOT-T: Stung into trest port(0+ psi), bled to 0 psi. Monitored for 10 min, no change in pressure. Functioned LDS, all moved freely (2.5"). Pumped through void, good returns. Pressured void to 5000 psi for 30 min test, lost 100 psi in 15 min, lost 0 psi in second 15 min (PASS). Bled void to 0 psi. PPPOT-IC: Stung into trest port(0+ psi), bled to 0 psi. Monitored for 10 min, no change in pressure. Functioned LDS, all were tight but fully functioned (2"). Pumped through void, good returns. Unable to pressure void above 2800 psi. Torqued LDS to 600 lb/ft. Still unable to pressure void above 2800 psi, lost 600 psi in 15 min. Suspect Y seal needs to be re- energized (FAIL). Bled void to 0 psi. 8/8/2016 T/I/O = SSV/80/80. Temp = SI. MIT- C&B lines. No AL. Balance line= 550 psi. Control line = 510 psi. Pumped —1 quart of HYD oil into balance line and locked up at 3000 psi. Pumped —1 quart of HYD oil into control line and locked up. R/U crystal recorder and MIT balance & control line. Balance line lost 17 psi in 15 min. Control line lost 17 psi in 15 min. Final WHPs = SSV/80/80. 8/11/2016 SV, WV, SSV= C. MV= O. IA, OA= OTG. 13:00 T/I/0=73/76/73, Well temp=S/I, CMIT-T/IA/OA***PASSED***to 2100 psi (Plug & Abandon), Pumped 21 bbls diesel down TBG to reach test pressure, IA and OA tracked while pumping down TBG, 1st 15 min TBG/IA/OA lost 37/38/37 psi, 2nd 15 min TBG/IA/OA lost 19/17/17 psi for a total loss of 56/55/54 psi, IA/OA did not track back down with TBG. Rigged up jumper. Bled back 11 bbls to FWHP = 35/51/51. F/L is bled to 0 psi. SV, WV, SSV 8/15/2016 are closed. MV is open. IA and OA are OTG. WFO notifed of well status upon departure. ***WELL S/I UPON ARRIVAL.*** (SLB ELINE - RCT TUBING CUT) INITIAL T/I/O = 10/100/60 PSI RUN 1: RIH W/ HEAD/WB/WB/CCL/2.5" BLIND BOX. TAGGED COLLAPSED TUBING AT 40.1' MD (ZEROED TOP OF TOOLSTRING AT SWAB). FLAG LINE AT CUT DEPTH OF 22' MD. RUN 2: RIH WITH HEAD/WB/JARS/EMA/CCL/RCT TO FLAG. ACCOUNT FOR DEPTH CORRECTION. CUT TUBING AT 22' MD. BEFORE CUT T/I/O = 10/100/60 PSI. AFTER CUT T/I/O = 60/95/50 PSI. OVERPULL 1200#TO SHEAR OFF ANCHORS. FINAL T/I/O = 60/95/50 PSI 8/16/2016 ***JOB COMPLETE. WELL S/I ON DEPARTURE.*** T/I/O = SSV/360/200. Temp = SI. Suspended well inspection (Pre AOGCC). No AL or hydraulics. Inspection completed. 10/6/2016 SV, WV, SSV, MV= C. IA, OA= OTG. 15:10. T/I/O = TWC/240/240. Torque &Test Temp SV x MV. See log for details. ***Job 10/17/2016 Complete*** T/I/O = 263/265/235. Set 6" J TWC#421 . Conducted LTT on TWC (PASS). Removed upper tree and installed DH Temp#62 . Installed IA and OA Piggyback IA Temp#42 , OA Temp 10/17/2016 #18 . Torqued to API specs. RDMO. ***Job Incomplete*** FWHP = TWC/265/235. T/I/O = TWC/170/150. Temp = SI. Bleed WHPs to 0 psi (Pre Rig). IA, OA FL near surface. WH, scaffolding and flowline removed. Bled OAP to BT from 150 psi to 10 psi in 3 hrs (Gas/fluid, —1/2 bbl). During OA bleed, IAP decreased 110 psi. Bled IAP to BT from 60 psi to 0 psi in 2 hrs (Gas). During IA bleed OAP decreased 10 psi. Monitored for 30 min. IAP increased 20 psi. Final WHPs =TWC/20/20. 10/19/2016 SV= C. MV= O. IA, OA= OTG. 16:00. i G-13A Well History (Pre-Rig Suspend) T/I/O = TWC/250/170. Temp = SI. Bleed WHP 's to 0 (pre RIG). No scaffolding or flowline. Second gate valve installed on IA and OA. Bleed WHP's while roads and pads takes lunch. IA& OA FL's near surface. Bled OAP & IAP to BT from 250/170 psi to 170/80 psi in 30 min (gas/fluid 0.5 bbls). Did not monitor. FWHP's =TWC/180/70. SV= ?. MV= O. IA, OA= OTG. 0100. 10/19/2016 T/I/O = TWC/20/20. Temp= SI. Bleed WHPs to 0 psi (Pre Rig). IA, OA FL near surface. WH, scaffolding and flowline removed. Bled IAP/OAP to BT from 20/20 psi to 0+/0+ psi in 1 hr(Gas). Maintained open bleed for additional 3 hrs. Monitored for 30 min. IAP/OAP unchanged. Final WHPs = TWC/0/0. 10/20/2016 SV= ?. MV= O. IA, OA= OTG. 05:00. T/I/0 =TWC/60/50. Temp = SI. Bleed WHPs to 0 psi (Pre Rig). IA& OA have piggy back (2nd gate) valve's rigged up. IA& OA FL near surface. Well is disconnected from the system, well house, scaffolding &flowline removed. Bled IAP to BT from 60 psi 0 psi in 5 min, gas. Bled OAP to BT from 50 psi to 0 psi in 2 min, gas. Monitored for 30 min. During monitor WHPs unchanged. Final WHPs =TWC/0/0. 10/24/2016 SV= ?. MV= O. IA, OA= OTG. 14:45 • • North America-ALASKA-BP Page 1 of 47 Operation Summary Report Common Well Name:G-13 AFE No Event Type:WORKOVER(WO) Start Date:11/3/2016 End Date:11/25/2016 IZ3-001X7-E:(2,630,000.00) Project:Prudhoe Bay Site:PB G Pad Rig Name/No.:PARKER 272 Spud Date/Time:7/13/1981 12:00:00AM Rig Release:11/25/2016 Rig Contractor:PARKER DRILLING CO. UWI:500292060000 Active datum:G-13 OKB @65.97usft(above Mean Sea Level) Date From-To Hrs Task ' Code NPT NPT Depth Phase Description of Operations (hr) (usft) 11/3/2016 06:00 - 13:00 7.00 MOB P PRE BEGIN EVENT WITH PARKER RIG 272 AT 06:00 ON 11/03/16 GENERAL RIG DOWN OPERATIONS ON H-25A -COMPLETE PRE-RIG MOVE CHECKLISTS WITH DERRICK INSPECTION -SECURE TOP DRIVE AND BRIDLE UP RIG DOWN INTERCONNECTS -HOLD PRE-SPUD MEETING WITH ANCHORAGE TEAM 13:00 - 15:30 2.50 MOB P PRE VERIFY WINDS BELOW 35MPH THRESHOLD TO LOWER MAST LOWER PIPE CAT,SKID CATTLE CHUTE AND RIG FLOOR TO RIG MOVE POSITION LOWER MAST 15:30 - 17:00 1.50 MOB P PRE SPLIT MODULES AND FOR MOVE TO G-13A PULL DUMMY WELL HOUSE OFF H-25A 17:00 - 23:00 6.00 MOB P PRE MOVE ALL 3 MODULES FROM H PAD TO G PAD ROUTE OF TRAVEL: -H PAD ACCESS ROAD TO GC-2 ACCESS ROAD -GC-2 ACCESS ROAD TO SPINE ROAD -SPINE ROAD TO K PAD ACCESS ROAD -K PAD ACCESS ROAD TO G PAD ACCESS ROAD 23:00 - 00:00 1.00 MOB P PRE POSITION MUD MODULE ON RIG MATS SPOT DUMMY WELL HOUSE OVER G-13A 11/4/2016 00:00 - 02:00 2.00 MOB P PRE SPOT DRILL MODULE OVER G-13A VERIFY E-STOP WORKS AND TOURPUSHER IN CONTROL OF E-STOP WHEN BACKING OVER WELL 02:00 - 03:00 1.00 MOB P PRE MERRY MUD MODULE TO DRILL MODULE SPOT UTILITY MODULE AND MERRY TO DRILL MODULE 03:00 - 06:30 3.50 RIGU P PRE i SHIM ALL MODULES AND HOOKUP ELECTRICAL CONNECTIONS AND SERVICE LINES BETWEEN MODULES. RIG UP WELL HOUSE.INSTALL ALL WALKWAYS AND FLOOR TRANSISTIONS. PERFORM DERRICK INSPECTION 06:30 - 07:00 0.50 RIGU P PRE RAISE THE MAST;522K LBS COMING OFF THE HEADACHE RACK. 07:00 - 08:00 1.00 RIGU P PRE SKID THE RIG FLOOR TO THE DRILLING POSITION. SKID THE HAUNCH INTO PLACE. RAISE THE PIPECAT RAMP. 08:00 - 10:00 2.00 RIGU P PRE BRIDLE DOWN BLOCKS. RIG UP FORUM CRANE AND PERFORM DERRICK INSPECTION 10:00 - 12:00 2.00 RIGU P PRE RIG UP RIG FLOOR EQUIPMENT HOOK UP STEAM AND AIR LINES MAKE UP HIGH PRESSURE MUD LINE CONNECTIONS BEGIN TAKING ON FLUID TO THE PITS Printed 12/5/2016 8:53:59AM *AII depths reported in Drillers Depths* • North America-ALASKA-BP Page 2 of 47 Operation Summary Report Common Well Name:G-13 AFE No Event Type:WORKOVER(WO) Start Date:11/3/2016 End Date:11/25/2016 Z3-001X7-E:(2,630,000.00) Project:Prudhoe Bay Site:PB G Pad Rig Name/No.:PARKER 272 Spud Date/Time:7/13/1981 12:00:00AM Rig Release:11/25/2016 Rig Contractor:PARKER DRILLING CO. UWI:500292060000 Active datum:G-13 OKB @65.97usft(above Mean Sea Level) Date From-To Hrs Task Code I NPT NPT Depth Phase I Description of Operations (hr) (usft) 12:00 - 13:30 1.50 RIGU P PRE I CONTINUE TO RIG UP RIG FLOOR EQUIPMENT AND INTERCONNECTS INSTALL BLEEDER AND CEMENT LINES INSTALL OFFLINE MOUSE HOLES !ACCEPT RIG AT 12:00 13:30 - 14:00 0.50 RIGU P PRE PERFORM RIG EVACUATION DRILL AND AAR WITH RIG CREW 14:00 - 15:00 1.00 RIGU P PRE MODIFY FLOOR IN DUMMY WELL HOUSE TO ACCOMMODATE 90°SWING FOR ANNULUS RIG UP SECONDARY KILL LINE TO OA 15:00 - 17:00 2.00 WHSUR P DECOMP ATTEMPT TO PRESSURE TEST TWC -PRESSURE TEST TWC FROM BELOW 250/2000 PSI FOR 5 MIN EACH -GOOD TEST -PRESSURE TEST TWC FROM ABOVE 250/3500 PSI FOR 5 MIN EACH -TWC IS LEAKING BY -SUCK OUT TREE AND PREP FOR INSTALLING A NEW TWC. -MONITOR OPEN OA AT TIGER TANK -MONITOR OPEN MAT BLEED TRAILER -SEE ATTACHED CHART 17:00 - 17:30 0.50 RIGU P PRE SERVICE TOP DRIVE AND RIG FLOOR EQUIPMENT 17:30 - 23:30 6.00 WHSUR N HMAN DECOMP INSTALL NEW TWC AND VERIFY PRE-RIG WELLHEAD WORK INSTALL LUBRICATOR ON TREE AND PRESSURE TEST -GOOD TEST -PULL AND INSTALL NEW TWC -DRILL SITE MAINTENANCE REMOVE FLANGE ON IA AND VERIFY VR PLUG IS INSTALLED.TEST TO 250/3500 PSI FOR 5 MIN EACH DRILL SITE MAINTENANCE REMOVE FLANGE ON OA AND VERIFY VR PLUG IS INSTALLED.TEST TO 250/3500 PSI FOR 5 MIN EACH SIMOPS:LOAD 5"DRILL PIPE IN PIPE SHED 23:30 - 00:00 0.50 WHSUR P DECOMP ATTEMPT TO PRESSURE TEST TWC -PRESSURE TEST TWC FROM BELOW -250 PSI LOW FOR 5 MIN-GOOD TEST -3500 PSI HIGH VS PLANNED 2100 PSI TEST -FLUID OBSERVED IN CELLAR BOX,BLED OFF PRESSURE NOTIFIED WOS AND WSUP OF CHANGE IN WELL CONDITIONS -SEE ATTACHED CHART Printed 12/5/2016 8:53:59AM *AII depths reported in Drillers Depths* • • North America-ALASKA-BP Page 3 of 47 Operation Summary Report Common Well Name:G-13 AFE No Event Type:WORKOVER(WO) Start Date:11/3/2016 End Date:11/25/2016 Z3-001X7-E:(2,630,000.00) Project:Prudhoe Bay Site:PB G Pad Rig Name/No.:PARKER 272 Spud Date/Time:7/13/1981 12:00:00AM Rig Release:11/25/2016 Rig Contractor:PARKER DRILLING CO. UWI:500292060000 Active datum:G-13 OKB©65.97usft(above Mean Sea Level) Date From-To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (usft) 11/5/2016 00:00 - 04:00 4.00 WHSUR N SEAL DECOMP TROUBLESHOOT AND ATTEMPT TO DIAGNOSE LEAKS IN WELL ENVELOPE DISCUSS SITUATION AND AGREE ON DIAGNOSTIC PLAN FORWARD WITH ODE, I WSUP,RIG MANAGER AND PARKER AREA SUPERINTENDENT LINE UP ON IAAND ATTEMPT DIAGNOSE THE LEAK PATH IN 500 PSI INCREMENTS AFTER PUMPING 1 BBL TOTAL VOLUME THE AD OBSERVED RETURNS AT THE TIGER TANK • FROM THE OA. ALSO OBSERVED ARCTIC PAK OOZING FROM A FLUTE IN THE 13-3/8"X 20"CONDUCTOR. SHUT DOWN WITH NO PRESSURE ON SYSTEM. PERFORMED A SHORT VERIFICATION TEST ON THE 9-5/8"x 13-3/8"PACK-OFF(250/3300 PSI FOR 2/10 MIN)-GOOD TEST. NOTIFIED ODE AND WSUP OF RESULTS. 04:00 - 05:00 1.00 WHSUR N SFAL DECOMP WAIT FOR ANCHORAGE ENGINEERING TEAM TO DEVELOP A PLAN FORWARD • RIG DOWN LUBRICATOR AND CLEAN AND CLEAR RIG FLOOR TO PERFORM SCHEDULED MAINTENANCE AND INSPECTION ON THE TOP DRIVE. CONTINUOUS MONITORING IN WELL CELLAR, ADJACENT WELL HOUSES AND AROUND PAD. 05:00 - 15:30 10.50 WHSUR N SEAL DECOMP WAIT FOR ANCHORAGE ENGINEERING TEAM TO DEVELOP A PLAN FORWARD PERFORM INSPECTIONS AND PM WORK ON TOP DRIVE,BOP CRANES,PRT CRANES, FORUM CRANE AND MAN RIDERS. CLEAN AND PRESSURE WASH TOP DRIVE !AND DERRICK. CONTINUOUS MONITORING IN WELL CELLAR, IAAND OA, ADJACENT WELL HOUSES AND AROUND PAD. Printed 12/5/2016 8:53:59AM *AII depths reported in Drillers Depths* North America-ALASKA-BP • Page 4 of 47 Operation Summary Report Common Well Name:G-13 AFE No Event Type:WORKOVER(WO) Start Date:11/3/2016 1 End Date:11/25/2016 Z3-001X7-E:(2,630,000.00) Project:Prudhoe Bay Site:PB G Pad Rig Name/No.:PARKER 272 Spud Date/Time:7/13/1981 12:00:00AM Rig Release:11/25/2016 Rig Contractor:PARKER DRILLING CO. UWI:500292060000 Active datum:G-13 OKB©65.97usft(above Mean Sea Level) Date From-To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (usft) 15:30 - 17:00 1.50 WHSUR N SFAL DECOMP CONTINUE TO WAIT FOR AN APPROVED OCN FROM ANCHORAGE ENGINEERING TEAM. SUCK OUT CELLAR BOX WITH CUSCO VAC TRUCK-SNOWMELT FROM DRIFTS IN CELLAR BOX RIG UP CUSCO TO 1"CSH AND SUCK OUT ARCTIC PACK FROM BETWEEN FLUTE ON HANGER IN THE CONDUCTOR x 13-3/8" ANNULUS -ABLE TO WORK 1"CSH DOWN-14'AND SUCK OUT ALL FLUIDS. -MIX AND FLUSH THE CONDUCTOR x 13-3/8" ANNULUS WITH BARACLEAN SOAP PILL IN PREPERATON FOR CEMENT TOP JOB. CONTINUOUS MONITORING IN WELL CELLAR, IAAND OA, ADJACENT WELL HOUSES AND AROUND PAD. SIMOPS:LOAD 5"DRILL PIPE IN PIPE SHED AND BUILD STANDS OF 5"DRILL PIPE OFFLINE. 17:00 - 22:30 5.50 WHSUR N SFAL DECOMP 'CONTINUE TO WAIT FOR AN APPROVED OCN FROM ANCHORAGE ENGINEERING TEAM. CONTINUOUS MONITORING IN WELL CELLAR, IAAND OA, ADJACENT WELL HOUSES AND AROUND PAD. CONTINUE TO LOAD 5"DRILL PIPE IN PIPE SHED AND BUILD STANDS OF 5"DRILL PIPE OFFLINE. SPOT SCHLUMBURGER CEMENT CREWAND 'RIG UP TO PERFORM CEMENT TOP JOB 22:30 - 00:00 1.50 WHSUR N SFAL DECOMP RIG UP AND PERFORM A CEMENT TOP JOB ON THE 20"CONDUCTOR x 13-3/8"ANNULUS -PJSM WITH RIG CREWAND SLB CEMENT CREW -PUMPED 2 BBLS OF 15.7 PPG AS1 CEMENT INTO THE ANNULUS -CEMENT IN PLACE AT 23:10 CONTINUOUS MONITORING IN WELL CELLAR, IAAND OA, ADJACENT WELL HOUSES AND AROUND PAD. 11/6/2016 00:00 - 02:30 3.50 WHSUR N SFAL DECOMP !MONITOR CONDUCTOR x 13-3/8"ANNULUS CEMENT TOP JOB AND ADD CEMENT AS REQUIRED. -ADD 1.5 GAL TO TOP OFF AS CEMENT SETTLED IN FLUTE CLEAN UP LINES AND RIG DOWN SCHLUMBERGER CEMENTERS 1000 PSI COMPRESSIVE STRENGTH REACHED AT 02:16 PERFORM GENERAL RIG MAINTENANCE AND CLEAN AND ORGANIZE RIG. CHANGE OUT SAVER SUB FROM HT-38 TO NC50 CONTINUOUS MONITORING IN WELL CELLAR, IAAND OA, ADJACENT WELL HOUSES AND AROUND PAD. Printed 12/5/2016 8:53:59AM *AII depths reported in Drillers Depths* North America-ALASKA-BP Page 5 of 47 Operation Summary Report Common Well Name:G-13 AFE No Event Type:WORKOVER(WO) Start Date:11/3/2016 End Date:11/25/2016 IZ3-001X7-E:(2,630,000.00) Project:Prudhoe Bay Site:PB G Pad Rig Name/No.:PARKER 272 Spud Date/Time:7/13/1981 12:00:OOAM Rig Release:11/25/2016 Rig Contractor:PARKER DRILLING CO. UWI:500292060000 Active datum:G-13 OKB @65.97usft(above Mean Sea Level) Date From-To Hrs Task Code NPT 1 NPT Depth Phase Description of Operations (hr) (usft) 02:30 - 03:00 0.50 WHSUR N SFAL DECOMP PRESSURE TEST TWC FROM ABOVE 250/3500 PSI FOR 5/5 CHARTED MIN. -GOOD TEST I-BLEED OFF PRESSURE AND BLOW DOWN LINES 103:00 - 05:00 2.00 WHSUR P DECOMP NIPPLE DOWN ADAPTER FLANGE AND TREE -CAMERON WELLHEAD TECH BLEED OFF HANGER VOID CAMERON WELLHEAD TECH FUNCTIONED 1 ALL LOCK DOWN SCREWS LAY DOWN TREE AND ADAPTER FLANGE -INSPECT HANGER THREADS AND MAKE UP XO -HANGER THREADS LOOK GOOD -6 TURNS TO MAKE UP XO SIMOPS:CONTINUE TO BUILD 5"DRILL PIPE STANDS OFFLINE 05:00 - 08:30 3.50 BOPSUR P DECOMP NIPPLE UP BOPE STACK AND HIGH I PRESSURE RISERS I NIPPLE UP AND TORQUE BOLTS ON HIGH PRESSURE RISERS I .-NIPPLE UP BOPE STACK ON HIGH PRESSURE RISER AND TORQUE BOLTS I-INSTALL MOUSE HOLE , RIG UP TURN-BUCKLES ON STACK AND , , INSTALL LOW PRESSURE RISERS INSTALL HOLE FILL AND JET LINES -AIR UP AIR BOOTS ON LOW PRESSURE ' RISERS OBTAIN AND RECORD RKB MEASUREMENTS SIMOPS:CONTINUE TO BUILD 5"DRILL PIPE STANDS OFFLINE 08:30 - 09:30 1.00 BOPSUR P DECOMP ,RIG UP TO TEST BOPE MAKE UP 9-5/8"TEST JOINT AND HANGER , XO -6 TURNS TO MAKE UP ,-FILL ALL LINES AND PURGE AIR FROM SYSTEM -PERFORM SHELL TEST ON BOPE STACK -VERIFY BOTH OAAND IA OPEN AND MONITORED PRIOR TO TESTING 09:30 - 14:30 5.00 BOPSUR P DECOMP TEST BOPE PER AOGCC AND BP !REQUIREMENTS 250 PSI LOW 3500 PSI HIGH FOR 5 CHARTED MINUTES EACH -TEST UPPER RAMS WITH 9-5/8"TEST JOINT -TEST LOWER RAMS WITH 3-1/2"AND 5" TEST JOINT TEST ANNULAR PREVENTER WITH 3-1/2" I TEST JOINT -BLOW DOWN ALL LINES AND TIG DOWN TEST EQUIPMENT AOGCC REPRESENTATIVE CHUCK SHIEVE WAIVED WITNESS ON 11/04/16 AT 06:00 HRS SEE ATTACHED TEST CHARTS AND FORMS. 14:30 - 15:30 1.00 WHSUR P DECOMP PULL AND LAY DOWN TWC WITH VALVE SHOP CREW Printed 12/5/2016 8:53:59AM *AII depths reported in Drillers Depths* North America-ALASKA-BP Page 6 of 47 r Operation Summary Report Common Well Name:G-13 AFE No Event Type:WORKOVER(WO) Start Date:11/3/2016 End Date:11/25/2016 Z3-001X7-E:(2,630,000 00) Project:Prudhoe Bay Site:PB G Pad Rig Name/No.:PARKER 272 Spud Date/Time:7/13/1981 12:00:00AM Rig Release:11/25/2016 Rig Contractor:PARKER DRILLING CO. UWI:500292060000 Active datum:G-13 OKB©65.97usft(above Mean Sea Level) Date From-To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (usft) 15:30 - 16:00 0.50 WHSUR P DECOMP VERIFY CIRCULATION CLOSE BLIND/SHEAR RAMS AND LINE UP TO CIRCULATE DOWN THE TBG AND OUT THE IA TO THE FLOW BACK TANK -PUMP BBLS AT 2 BPM,110 PSI -OBSERVE RETURNS OUT IA AT FLOW BACK TANK NO RETURNS OBSERVED FROM OAAT FLOW BACK TANK -BLOW DOWN ALL LINES 16:00 - 17:00 1.00 WHSUR P DECOMP RIG UP DOYON CASING EQUIPMENT AND SLB SPOOLING UNIT ON RIG FLOOR 17:00 - 17:30 0.50 WHSUR P DECOMP PICKUP LANDING JOINTAND MAKE UP THE XO TO THE HANGER -6 TURNS TO MAKE UP -CAMERON WELLHEAD TECH BACKED OUT LOCK DOWN SCREWS 17:30 - 21:30 4.00 WHSUR P DECOMP ATTEMPT TO PULL HANGER FREE -WORK UP TO 35K LBS OVER(70K)AND HOLD -APPLY STEAM TO WELLHEAD AND MAINTAIN 35K OVER WITH NO SUCCESS -WORK PIPE 40K OVER IN 5K INCREMENTS; NO MOVEMENT NOTED -INCREASE PULL TO 65K OVER IN 5K INCREMENTS AND HOLD FOR SEVERAL MINUTES -NO MOVEMENT NOTED CALL ODE AND WSUP TO DISCUSS PLAN FORWARD 21.30 - 22:30 1.00 WHSUR N SEAL DECOMP MOBILIZE INSIDE CUTTER FROM SCHLUMBERGER FISHING SHOP CAMERON WELLHEAD TECH PULLAND REPLACE EACH LOCK DOWN SCREW,ONE ATA TIME,TO VERIFY NONE ARE SHEARED. ALL LOOK GOOD. 22:30 - 00:00 1.50 WHSUR N SFAL DECOMP LAY DOWN LANDING JOINT AND XO WHILE WAITING FOR EQUIPMENT TO CUT TUBING SLB REDRESSING INSIDE CUTTER WITH KNIVES FOR 4-1/2"TUBING DOYON CASING BRINGING OUT TONGS TO MAKE UP 2-7/8"PAC DRILL PIPE 11/7/2016 00:00 - 01:30 1.50 WHSUR N SFAL DECOMP WAIT FOR EQUIPMENT FROM SLB AND DOYON CASING TO MAKE UP INSIDE CUTTER FOR 4-1/2"TUBING RIG UP TO PICK UP 2-7/8"PAC DRILL PIPE Printed 12/5/2016 8:53.59AM *AII depths reported in Drillers Depths* • North America-ALASKA-BP • Page 7 of 47 Operation Summary Report Common Well Name:G-13 AFE No Event Type:WORKOVER(WO) Start Date:11/3/2016 End Date:11/25/2016 IZ3-001X7-E:(2,630,000.00) Project:Prudhoe Bay Site:PB G Pad Rig Name/No.:PARKER 272 Spud Date/Time:7/13/1981 12:00:00AM Rig Release:11/25/2016 Rig Contractor:PARKER DRILLING CO UWI:500292060000 Active datum:G-13 OKB @65.97usft(above Mean Sea Level) Date From-To I Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (usft) '01:30 - 05:00 3.50 CUT N SFAL DECOMP MAKE UP INSIDE CUTTER FOR 4-1/2"TUBING AND 2-7/8"PAC DRILL PIPE W/XO TO 5"DRILL PIPE 1-RUN IN THE HOLE TO 60'BELOW ROTARY TABLE -ESTABLIS PARAMETERS: -PU/SO 38K LBS;ROT 37.5K LBS;60 RPM; 1K TORQUE -1/2 BPM;209 PSI ATTEMPT TO LOCATE E-LINE RCT CUT WITH INSIDE CUTTER ENGAGE KNIVES W/0 ROTARY AND SLACK !OFF SLACK OFF FROM 60'BELOW ROTARY TABLE TO 82' -NO INDICATION OF CUT PICK UP TO 75'BELOW ROTARY TABLE(-15 ABOVE DEPTH OF ESTIMATED DEPTH OF COLLAPSED TUBING) CUT 4-1/2"TUBING PER SLB FISHING REPRESENTATIVE -1/2 BPM;209 PSI -60 RPM;1K TORQUE FOR 10 MIN '-70 RPM;800-1000 FT-LBS TORQUE FOR 5 MIN STOP ROTARY AND PUMPS.PICK UP 2'.OPEN KNIVES AND LOCATE CUT -1/2 BPM;209 PSI GOOD INDICATION OF CUT AT 75'BELOW ROTARY TABLE. PULL AND LAY DOWN SLB CUTTING TOOL AND 2-7/8"PAC DRILL PIPE. 05:00 - 05:30 0.50 PULL N SFAL DECOMP RIG UP TO PULL TUBING HANGER AND 5-1/2" TUBING WITH CONTROL LINE. 05:30 - 08:30 3.00 PULL N SFAL DECOMP ATTEMPT TO PULL HANGER FREE -MAKE UP LANDING JOINT AND XO TO HANGER -6 TURNS TO MAKE UP ATTEMPT TO PULL HANGER FREE STAGING UP IN 5K INCREMENTS FROM 45K TO 90K -APPLY STEAM TO WELLHEAD AND CONTINUE TO WORK PIPE -BACK OUT LANDING JOINT AND HANGER AND LAY DOWN 08:30 - 10:00 1.50 PULL N SFAL DECOMP PERFORM DERRICK AND TOP DRIVE INSPECTION PRIOR TO JARRING OPERATIONS 10:00 - 11:30 1.50 PULL N SFAL DECOMP SPEAR RUN#1: PICK UP AND MAKE UP SPEAR AND JARRING ASSEMBLY PER SLB FISHING REPRESENTATIVE SPEAR TO CATCH INSIDE 4-1/2"TUBING -XO -BUMPER SUB OIL JAR -1 DRILL COLLAR -ACCELERATOR JARS -_- -5"DRILL PIPE Printed 12/5/2016 8:53:59AM *AII depths reported in Drillers Depths* North America-ALASKA-BP Page 8 of 47 Operation Summary Report Common Well Name:G-13 AFE No Event Type:WORKOVER(WO) Start Date:11/3/2016 End Date:11/25/2016 IZ3-001X7-E:(2,630,000.00) Project:Prudhoe Bay Site:PB G Pad Rig Name/No.:PARKER 272 Spud Date/Time:7/13/1981 12:00:00AM 'Rig Release:11/25/2016 Rig Contractor:PARKER DRILLING CO. UWI:500292060000 Active datum:G-13 OKB©65.97usft(above Mean Sea Level) Date From-To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (usft) 11:30 - 13:30 2.00 PULL N SFAL DECOMP SPEAR RUN#1: SPEAR TUBING BELOW HANGER AND ATTEMPT TO JAR HANGER FREE -SO 20KAND PU 35KAND ATTEMPT TO JAR -JARS COLD AND WON'T FIRE -CONTINUE TO SO 20K AND WORK UP TO 40K -JARS STILL WON'T FIRE 13:30 - 14:30 1.00 PULL N SFAL DECOMP DISENGAGE SPEAR,LAY DOWN JARS AND PICK UP BACK UP JARS FROM PIPE SHED 14:30 - 16:30 2.00 PULL N SFAL DECOMP SPEAR RUN#2: RE-ENGAGE TUBING BELOW HANGER AND ATTEMPT TO JAR HANGER FREE JAR ON HANGER FOR 2 HRS(-50 HITS)WITH NO SUCCESS SET DOWN 20KAND WORK UP IN 5K INCREMENTS FROM 35K TO 50K. 16:30 - 17:30 1.00 PULL N SFAL DECOMP PERFORM POST JARRING DERRICK AND TOP" DRIVE INSPECTION -NO DEFICIENCIES FOUND 17:30 - 19:30 2.00 PULL N SFAL DECOMP CONTINUE TO JAR ON HANGER FOR 2 HRS (-70 HITS)WITH NO SUCCESS SET DOWN 20KAND WORK UP IN 5K INCREMENTS FROM 50K TO 60K. 19:30 - 20:30 1.00 PULL N SFAL DECOMP PERFORM POST JARRING DERRICK AND TOP DRIVE INSPECTION -NO DEFICIENCIES FOUND 20:30 - 21:30 1.00 PULL N SFAL DECOMP CONTINUE TO JAR ON HANGER(-75 HITS) SET DOWN 20KAND WORK UP IN 5K INCREMENTS FROM 50K TO 60K. -FISH PULLED FREE 21:30 - 22:00 0.50 PULL P DECOMP PULL HANGER AND CUT JOINT TO SURFACE AND LAY DOWN SPEAR ASSEMBLY AND FISH -LENGTH OF CUT=29.10'FROM TOP OF HANGER TO CUT(72'BELOW ROTARY TABLE) -CUT IS FROM PRE-RIG RCT CUT -APPEARS RCT CUT WAS ONLY A PARTIAL CUT. 22:00 - 22:30 0.50 PULL N SFAL DECOMP PERFORM POST JARRING INSPECTION ON TOP DRIVE AND DERRICK -NO DEFICIENCIES FOUND -MONITOR WELL-STATIC 22:30 - 23:00 0.50 PULL P DECOMP SERVICE TOP DRIVE,BLOCKS AND CROWN. REPAIR LEAKING HYDRAULIC HOSE ON ST-80. 23:00 - 00:00 1.00 PULL P DECOMP OVERSHOT RUN#1: PICKUP AND MAKE UP OVERSHOT BHA TO ENGAGE TUBING STUB 11/8/2016 00:00 - 01:00 1.00 PULL P DECOMP OVERSHOT RUN#1: ENGAGE 4-1/2"TUBING STUB AT 75'MD WITH OVERSHOT ASSEMBLY AND PERFORM BLIND BACK OFF -PU TO 109K(CALCULATED BUOYED WEIGHT TO ABOVE PACKER) -WORK LEFT-HAND TORQUE DOWN STRING -1-5K TORQUE -80-109K UP WEIGHT -TUBING BACKED OFF;PU 38K -RECOVERED 16'OF 4-1/2"TUBING AND SOME CONTROL LINE -BACKED OUT AT CONNECTION AT ESTIMATED COLLAPSE POINT Printed 12/5/2016 8:53:59AM *All depths reported in Drillers Depths* North America-ALASKA-BP Page 9 of 47 Operation Summary Report Common Well Name.G-13 AFE No Event Type:WORKOVER(WO) Start Date:11/3/2016 End Date:11/25/2016 Z3-001X7-E:(2,630,000.00) Project:Prudhoe Bay Site:PB G Pad Rig Name/No.:PARKER 272 Spud Date/Time:7/13/1981 12:00:00AM Rig Release:11/25/2016 Rig Contractor:PARKER DRILLING CO. UWI:500292060000 Active datum:G-13 OKB©65.97usft(above Mean Sea Level) Date From-To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (usft) 01:00 - 02:00 1.00 PULL P DECOMP DISENGAGE FISH FROM OVERSHOT AND LAY DOWN TO PIPE SHED 02:00 - 03:30 1.50 PULL N DPRB 91.00 DECOMP RE-DRESS OVERSHOT TO CATCH 4-1/2" TUBING COLLAR BASED ON FISH RECOVERED 03:30 - 04:00 0.50 PULL N DPRB 91.00 DECOMP OVERSHOT RUN#2: RUN IN THE HOLE WITH OVERSHOT ASSEMBLY AND ATTEMPT TO ENGAGE FISH PER SLB FISHING REPRESENTATIVE. PULL OVERSHOT TO RIG FLOOR AFTER SEVERAL ATTEMPTS TO ROTATE DOWN OVER FISH SIGNIFICANT SCARRING AND GUIDE LIP ON OVERSHOT IS SWEDGED IN SLIGHTLY FROM COLLAPSED 9-5/8"CASING. 04:00 - 05:00 1.00 PULL N DPRB 91.00 DECOMP LAY DOWN OVERSHOT ASSEMBLY AND CLEAR RIG FLOOR 05:00 - 07:30 2.50 PULL N DPRB 91.00 DECOMP PERFORM GENERAL RIG MAINTENANCE WHILE WAITING FOR FISHING PLAN FORWARD 07:30 - 08:30 1.00 PULL N DPRB 91.00 DECOMP SLIP AND CUT DRILLING LINE WHILE WAITING ON ORDERS.CALIBRATE BLOCKS AND AMPHION SYSTEM. 08:30 - 09:30 1.00 FISH N DPRB 91.00 DECOMP FISHING TROUBLESHOOTING RUN: LEAD IMPRESSION BLOCK RUN#1: -PU AND MU IMPRESSION BLOCK PER SLB REP -RIH AND SET DOWN 15K ON OBSTRUCTION AT 95'MD -POH AND LD IMPRESSION BLOCK:NO SIGNIFICANT SCARRING ON BOTTOM OF BLOCK,2 AREAS OF SCRAPED PAINT ON SIDES 180°TO EACH OTHER.SEE ATTACHED PICTURES. -CLEAN AND CLEAR RIG FLOOR 09:30 - 15:30 6.00 FISH N DPRB 91.00 DECOMP MAKE UP 1 JOINT OF 2-7/8"PAC TO 5"DRILL PIPE -RIH TO OBSTRUCTION TO DETERMINE ACCESSIBILITY INTO 4-1/2"TUBING -TAG OBSTRUCTION AT 95'MD -CIRCULATE AT 0.5 BPM,40 PSI ALLOWING SEAWATER TO SWAP WITH FREEZE PROTECT IN ATTEMPT TO CLEAN UP WELLBORE WAIT ON WASH PIPE AND BURN SHOE FROM SLB FISHING. 15:30 - 16:30 1.00 FISH N DPRB 91.00 DECOMP RACK BACK STAND OF 5"DRILL PIPE AND LD 2-7/8"PAC.BREAK DOWN COLLAR STAND. 16:30 - 17:00 0.50 FISH P 91.00 DECOMP GREASE BLOCKS AND WASHPIPE.CHECK OIL LEVELS IN TOP DRIVE. 17:00 - 18:00 1.00 FISH N DPRB 91.00 DECOMP LOAD WASH OVER MILLING BHA INTO PIPE SHED AND ONTO RIG FLOOR.MEASURE ID, OD AND STRAP. Printed 12/5/2016 8:53:59AM •AII depths reported in Drillers Depths* • North America-ALASKA-BP Page 10 of 47 Operation Summary Report Common Well Name:G-13 AFE No Event Type:WORKOVER(WO) Start Date:11/3/2016 End Date:11/25/2016 IZ3-001X7-E:(2,630,000.00) Project:Prudhoe Bay Site:PB G Pad Rig Name/No.:PARKER 272 Spud Date/Time:7/13/1981 12:0O:OOAM Rig Release:11/25/2016 Rig Contractor:PARKER DRILLING CO. UWI:500292060000 Active datum:G-13 OKB @65.97usft(above Mean Sea Level) Date From-To Hrs Task Code NPT NPT Depth 1 Phase Description of Operations (hr) (usft) 18:00 - 00.00 } 6.00 FISH N DPRB 91.00 DECOMP WASHOVER MILLASSEMBLY RUNS: 1 MILL RUN#1: MAKEUP AND RUN IN HOLE WITH SLB 8-3/8"WASHOVER MILLING ASSEMBLY FROM SURFACE TO 89'MD. INITIAL TAG AT 89'MD. WORK MILLS FAIRLY EASILY TO 95'MD. MILL OBSTRUCTION IN CASING WITH WASHOVER MILL ASSEMBLY FROM 95'TO 95.9'MD. NO PROGRESS AT 95.9'MD. -DISPLACE TO NEW MILLING FLUID AT 18:00 -213 GPM,30 PSI,90 RPM,1-3 KFT-LBS TRQ ON BOTTOM -PU/SO WEIGHTS=41 KLBS MW IN/OUT-8.5 PPG VISCOSIFIED I SEAWATER CONTMINATED WITH DIESEL AND ARCTIC PACK. -NO PRESSURE ON IA/OA/OOA MILL RUN#1: FLOWCHECK WELL FOR 10 MIN ' 1 I(STATIC)AND POOH FROM 95.9'MD TO INSPECT MILLS. 1 I-OBSERVE SIGNIFICANT WEAR ON MILL SHOE. BOTTOM"WAVE"PATTERN GROUND 1 I NEARLY FLAT. MILL OD IS 1/16" UNDERGAUGE. ELECT TO NOT RERUN. MILL RUN#2: MAKEUP AND RUN IN HOLE WITH SLB 8-3/8"FISHING ASSEMBLY FROM SURFACE TO 94'MD(2'HIGH COMPARED TO PREVIOUS DEPTH). WORK MILLS EASILY FROM 94'MD 95'MD. UNSUCCESSFULLY I ATTEMPT TO MILL AHEAD FROM 95'MD. NO PROGRESS MADE AFTER 40 MIN. (1HR15MIN MILLING TIME) -213 GPM,30 PSI,90 RPM,1-3 KFT-LBS TRQ 1I ON BOTTOM +-NO METAL SHAVINGS IN RETURNS. Printed 12/5/2016 8:53:59AM *AII depths reported in Drillers Depths* • North America-ALASKA-BP Page 11 of 47 Operation Summary Report Common Well Name:G-13 AFE No Event Type:WORKOVER(WO) Start Date:11/3/2016 End Date:11/25/20161Z3-001X7-E:(2,630,000.00) Project:Prudhoe Bay Site:PB G Pad Rig Name/No.:PARKER 272 i Spud Date/Time:7/13/1981 12:00:00AM Rig Release:11/25/2016 Rig Contractor:PARKER DRILLING CO. UWI:500292060000 Active datum:G-13 OKB @65.97usft(above Mean Sea Level) Date From-To Hrs Task Code NPT NPT Depth Phase 1 Description of Operations (hr) (usft) 11/9/2016 00:00 - 05:00 5.00 FISH N DPRB 95.00 DECOMP WASHOVER MILLASSEMBLY RUNS CONTINUED: MILL RUN#2 CONTINUED: IN RESPONSE TO 1 NO PROGRESS AFTER 40 MIN,INCREASE WOB TO 4 KLBS AND OBSERVE IMMEDIATE WOB DROP OFF TO 0 KLBS. STALL PIPE WITH 7 KFT-LBS MAX TRQ AT 95'MD. STAGE UP OVERPULLS AND WORK PIPE FREE WITH 55 KLBS STRAIGHT OVERPULL(95 KLBS HOOKLOAD). MILL RUN#2: POOH FROM 95'MD TO SURFACE TO INSPECT MILL SHOE. -MILL SHOWS MINOR WEAR BUT NO SIGNIFICANT ISSUES. ELECT TO RERUN SAME MILL. -INSPECT TOP DRIVE ON SURFACE AFTER WORKING PIPE FREE MILL RUN#3: FLOWCHECK WELL FOR 10 MIN (STATIC). MAKEUP AND RIH WITH 8-3/8" WASHOVER MILLASSY FROM SURFACE TO 95'MD HARD TAG. UNSUCCESSFULLY ATTEMPT TO MILL AHEAD FROM 95'MD WITH NO PROGRESS(1HR15MIN MILLING TIME) -213 GPM,30 PSI,60 RPM,2-3/1 KFT-LBS TRQ 'ON/OFF BTM -NO METAL SHAVINGS IN RETURNS. -NO PRESSURE ON IA/OA/OOA MILL RUN#3: FLOWCHECK WELL FOR 10 MIN (STATIC). POOH FROM 95'AND CHECK MILL SHOE. I-NO SIGNIFICANT WEAR OBSERVED ON MILL 11 SHOE. ELECT TO RERUN. MILL RUN#4: FLOWCHECK WELL FOR 10 MIN (STATIC). MAKEUP AND RIH WITH 8-3/8" WASHOVER MILLASSY FROM SURFACE TO 95'MD HARD TAG. UNSUCCESSFULLY ATTEMPT TO MILL AHEAD FROM 95'MD WITH NO PROGRESS(1 HOUR MILLING TIME) -213 GPM,30 PSI,60 RPM,2-3/1 KFT-LBS TRQ ON/OFF BTM -NO METAL SHAVINGS IN RETURNS. NO PRESSURE ON IA/OA/OOA MILL RUN#4: FLOWCHECK WELL FOR 10 MIN (STATIC). POOH FROM 95'AND CHECK MILL SHOE. NO SIGNIFICANT WEAR OBSERVED ON MILL SHOE. ELECT TO RERUN. Printed 12/5/2016 8.53:59AM *All depths reported in Drillers Depths* • • North America-ALASKA-BP Page 12 of 47 Operation Summary Report Common Well Name:G-13 AFE No Event Type:WORKOVER(WO) Start Date:11/3/2016 End Date:11/25/2016 IZ3-001X7-E:(2,630,000.00) Project:Prudhoe Bay Site:PB G Pad Rig Name/No.:PARKER 272 I Spud Date/Time:7/13/1981 12:00:00AM !Rig Release:11/25/2016 Rig Contractor:PARKER DRILLING CO. UWI:500292060000 Active datum:G-13 OKB @65.97usft(above Mean Sea Level) Date From-To Hrs Task Code NPT ' NPT Depth Phase Description of Operations (hr) (usft) N DPRB 05:00 06:00 1.00 FISH ! 95.00 DECOMP FISHING TROUBLESHOOTING RUN: LEAD IMPRESSION BLOCK RUN#1: MAKEUP ! AND RIH WITH 8-1/4"LEAD IMPRESSION BLOCK FROM SURFACE TO HARD TAG AT 91' MD. SET DOWN WITH 17 KLBS. POOH AND INSPECT LIB(SIGNIFCANT MARKINGS !POSSIBLY SHOWING FOLDED OVER PIECE OF PIPE DOWNHOLE). SEE ATTACHED PHOTOS. 06:00 - 08:30 2.50 FISH � N i DPRB 95.00 DECOMP WAIT ON ORDERS '-GENERAL HOUSEKEEPING AND CLEANING Printed 12/5/2016 8.53.59AM *All depths reported in Drillers Depths* • • North America-ALASKA-BP Page 13 of 47 Operation Summary Report Common Well Name:G-13 AFE No Event Type:WORKOVER(WO) Start Date:11/3/2016 End Date:11/25/2016 Z3-001X7-E:(2,630,000.00) Project:Prudhoe Bay Site:PB G Pad Rig Name/No.:PARKER 272 Spud Date/Time:7/13/1981 12:00:00AM Rig Release:11/25/2016 Rig Contractor:PARKER DRILLING CO. UWI:500292060000 Active datum:G-13 OKB @65.97usft(above Mean Sea Level) Date From-To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (usft) 08:30 - 18:30 10.00 FISH N DPRB 95.00 DECOMP WASHOVER MILL ASSEMBLY RUNS: MILL RUN#5: MAKEUP AND RUN IN HOLE WITH SLB 8-3/8"WASHOVER MILL ASSEMBLY FROM SURFACE TO 95'MD. MILL FROM 95' MD TO 96.9'MD(3.5 HOURS ACTUAL MILLING TIME) -512 GPM,130 PSI,90 RPM,3.5/1-2 KFT-LBS TRQ ON/OFF BTM, -PU/SO/ROT=41 KLBS -MW IN/OUT=8.5 PPG VISCOSIFIED SEAWATER CONTAMINATED WITH DIESEL AND ARCTIC PACK -DISPLACE WELL TO NEW MILLING FLUID AT 8:30 30 PSI ON IA/OAAND NO FLOW FROM OOA MILL RUN#5: FLOWCHECK WELL FOR 10 MIN (STATIC)AND PULL OUT OF HOLE AT 96.9'MD TO CHECK MILLS. -ELECT TO CHANGEOUT MILL SHOW DUE TO WEAR. MILL RUN#6: MAKEUP AND RUN IN HOLE WITH SLB 8-3/8"WASHOVER MILL ASSEMBLY FROM SURFACE TO 97'MD. MILL FROM 96.9' MD TO 97.2'MD(2 HOURS ACTUAL MILLING TIME). STALL PIPE WITH 7 KFT-LBS MAX TRQ AT 97.2'MD. RELEASE TORQUE AND WORK PIPE FREE WITH 20 KLBS OVERPULL. -512 GPM,130 PSI,90 RPM,3.5/1-2 KFT-LBS TRQ ON/OFF BTM, -PU/SO/ROT=42 KLBS -MW IN/OUT=8.5 PPG VISCOSIFIED SEAWATER CONTAMINATED WITH DIESEL AND ARCTIC PACK -DISPLACE WELL TO NEW MILLING FLUID AT 14:30 I-30 PSI ON IA/OA AND NO FLOW FROM OOA MILL RUN#6: PULL OUT OF HOLE AT 97.2'MD TO CHECK MILLS. OBSERVE 6 KLBS CONSTANT OVERPULL FROM BOTTOMS AT 97.2'MD TO WELLHEAD AT 46'MD. RECOVER 9'LONG 5"WIDE SECTION OF 9-5/8"CASING(SEE PHOTOS). TOP BENT OVER SECTION MATCHES EARLIER LIB 1 IMPRINT. -MILL SHOE IS SLIGHTLY OUT OF ROUND AND HAS EXTERNAL SCARRING. UNABLE TO RERUN. Printed 12/5/2016 8:53:59AM *AII depths reported in Drillers Depths* • North America-ALASKA-BP • Page 14 of 47 Operation Summary Report Common Well Name:G-13 AFE No Event Type:WORKOVER(WO) Start Date:11/3/2016 End Date:11/25/2016 Z3-001X7-E:(2,630,000.00) Project:Prudhoe Bay Site:PB G Pad Rig Name/No.:PARKER 272 Spud Date/Time:7/13/1981 12:00:00AM Rig Release:11/25/2016 Rig Contractor:PARKER DRILLING CO. UWI:500292060000 Active datum:G-13 OKB @65.97usft(above Mean Sea Level) Date From-To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (usft) 118:30 - 21:00 , 2.50 FISH N DPRB 95.00 DECOMP FISHING TROUBLESHOOTING RUNS: -LEAD IMPRESSION BLOCK RUN#2: RIH WITH 6-318"LIB AND TAG IN WELLHEAD AT 45' MD. WEIGHT DROPS OFF QUICKLY. POOH AND INSPECT LIB(SLANTED IMPRESSION ON SIDE EDGE OF BLOCK) -LEAD IMPRESSION BLOCK RUN#3: RIH WITH 6-3/8"LIB FROM SURFACE TO 90'MD. I NO ISSUES THROUGH WELLHEAD. TAG AT 90'MD AND SET DOWN ADDITIONAL 5 KLBS. POOH AND INSPECT LIB(INCONCLUSIVE DENT IN LIB) ' -MAGNET RUN#1: RIH WITH 8"MAGNET AND TAG AT 89'MD. SET DOWN ADDITIONAL 5 „KLBS. POOH AND INSPECT MAGNET. ONLY r SMALL SHAVINGS RECOVERED. 21:00 - 00:00 3.00 FISH N DPRB 95.00 DECOMP WASHOVER MILL ASSEMBLY RUN: ! MILL RUN#7: MAKEUP AND RUN IN HOLE WITH NEW SLB 8-3/8"WASHOVER MILL ASSEMBLY FROM SURFACE TO 97'MD. MILL TO 101'MD AT MIDNIGHT(2 HOURS ACTUAL MILLING TIME) I -FLOWCHECK WELL FOR 10 MIN PRIOR TO , RUNNING IN HOLE(STATIC) „ -512 GPM,105 PSI,90 RPM,5/1 KFT-LBS TRQ I ON/OFF BTM -PU/SO/ROT=41 KLBS -MW IN/OUT=8.5 PPG VISCOSIFIED ,SEAWATER CONTAIMINATED WITH DIESEL AND ARCTIC PACK. I-30 PSI ON IA/OA. NO FLOW OUT 13-3/8"X I CONDUCTOR ANNULUS -PICKUP EVERY-1'MILLED TO CONFIRM — r PIPE FREE Printed 12/5/2016 8:53:59AM `AII depths reported in Drillers Depths* North America-ALASKA-BP Page 15 of 47 Operation Summary Report Common Well Name:G-13 AFE No Event Type:WORKOVER(WO) Start Date:11/3/2016 End Date:11/25/2016 Z3-001X7-E:(2,630,000.00) Project:Prudhoe Bay I Site:PB G Pad Rig Name/No.:PARKER 272 ' Spud Date/Time:7/13/1981 12:00:00AM Rig Release:11/25/2016 Rig Contractor:PARKER DRILLING CO. UWI:500292060000 Active datum:G-13 OKB @65.97usft(above Mean Sea Level) Date From-To Hrs Task 1 Code ' NPT NPT Depth I Phase Description of Operations (hr) — (usft) 11/10/2016 00:00 - 07:00 7.00 FISH N DPRB 95.00 DECOMP WASHOVER MILLASSEMBLY RUNS ' CONTINUED: MILL RUN#7 CONTINUED: MILL AHEAD WITH , 8-3/8"WASHOVER MILL FROM 101'MD AT MIDNIGHT TO 104'MD(-1.5 FPH,1:20 TOTAL MILLING TIME)WHEN WOB SUDDENLY FALLS ! 'OFF TO 0 KLBS. -512 GPM,105 PSI,90 RPM,5/1 KFT-LBS TRQ I I ON/OFF BTM MW IN/OUT=8.5 PPG SEAWATER CONTAIMINATED WITH DIESELAND ARCTIC I PACK. -30 PSI ON IA/OA. NO FLOW OUT 13-3/8"X CONDUCTOR ANNULUS , ' PICKUP EVERY-1'MILLED TO CONFIRM PIPE FREE MILL RUN#7: EASILY RUN IN HOLE WITH i WASHOVER MILL FROM 104'MD TO 108'MD. HARD TAG AT 108'MD WITH NO ROTATION. � I !MILL RUN#7: FLOWCHECK WELL FOR 10 MIN I(STATIC)AND PULL OUT OF HOLE WITH 'MILLS FROM 108'MD TO INSPECT. -NO FISH RECOVERED AT SURFACE OR NOTICEABLE WEAR ON MILL SHOE. ELECT TO RERUN. MILL RUN#8: MAKEUP AND RUN IN HOLE WITH 8-3/8"WASHOVER MILL ASSY FROM SURFACE TO HARD TAG AT 98'MD. WORK I MILLS DOWN EASILY FROM 98'TO 121'MD WITH OCCASIONAL MINOR TORQUE STALLS. DECISION TO STOP AND CHECK MILLED AREA. , -510 GPM,130 PSI,60 RPM,1-3 KFT-LBS TRQ ON BOTTOM,0 KLBS WOB , -OBSERVE SIGNS OF CONTROL LINE AND BANDS BACK AT SURFACE. -UNSUCCESSFULLY ATTEMPT TO DRIFT , MILLED AREA WITHOUT ROTATION OR ,PUMPS. UNABLE TO TRAVEL FREELY WITHOUT REGULARLY TAKING WEIGHT. -DISPLACE WELL TO NEW MILLING FLUID AT 06:00 I MILL RUN#8: FLOWCHECK WELL FOR 10 MIN (STATIC)AND PULL OUT OF HOLE WITH WASHOVER MILLASSY FROM 121'MD TO SURFACE. -MINOR WEAR ON MILL SHOE Printed 12/5/2016 8:53:59AM *All depths reported in Drillers Depths* • • North America-ALASKA-BP Page 16 of 47 Operation Summary Report Common Well Name:G-13 AFE No Event Type:WORKOVER(WO) Start Date:11/3/2016 End Date:11/25/2016 i1Z3-001X7-E:(2,630,000.00) 1 Project:Prudhoe Bay Site:PB G Pad Rig Name/No.:PARKER 272 Spud Date/Time:7/13/1981 12:00:00AM Rig Release:11/25/2016 Rig Contractor:PARKER DRILLING CO. UWI:500292060000 Active datum:G-13 OKB @65.97usft(above Mean Sea Level) Date From-To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (usft) '07:00 - 10:00 3.00 FISH N DPRB 95.00 DECOMP FISHING ASSEMBLY RUNS: -OVERSHOT RUN#3: MAKEUP AND RIH WITH 5-1/4"OVERSHOT ASSEMBLY FROM !SURFACE TO HARD TAG AT 101'MD. SET ,DOWN 15 KLBS AND ATTEMPT TO WORK OVER. ROTATE ON OBSTRUCTION WITH 5 KFT-LBS TORQUE AT 10 RPM. PU WITH 5 KLBS OVERPULL. OVERPULLAND TORQUE FALL OFF. REPEAT STEPS AND PULL OUT OF i HOLE TO CHECK OVERSHOT. NO FISH IRECOVERY. I-OVERSHOT RUN#4: MAKEUP AND RIH WITH 4-1/2"OVERSHOT ASSEMBLY FROM SURFACE TO HARD TAG AT SAME 101'MD. i MAKE SAME ATTEMPTS TO ENGAGE FISH. POOH TO CHECK OVERSHOT. NO FISH 1 RECOVERY. r 110:00 21:00 11.00 FISH N DPRB 95.00 DECOMP I WASHOVER MILLASSEMBLY RUNS: MILL RUN#9: FLOWCHECK WELL FOR 10 MIN PRIOR TO RIH(STATIC). MAKEUP AND RUN IN HOLE WITH 8-3/8"WASHOVER MILL ASSEMBLY FROM SURFACE TO 95'MD. WORK MILLS DOWN TO 125'MD TAKING i OCCASIONAL LIGHT WEIGHT(2.5 HOURS ON , BOTTOM MILLING TIME) 508 GPM,115 PSI,80 RPM,3-5 KFT-LBS TRQ ' ON BTM,3-5 KLBS WOB I -PU/SO/ROT WEIGHTS=41 KLBS 1 MILL RUN#9: POOH WITH MILL ASSEMBLY. -NO FISH INSIDE MILL SHOE NOR SIGNS OF ! SIGNIFICANT WEAR. ELECT TO RERUN MILL. MILL RUN#10: MAKEUP AND RUN IN HOLE I WITH 8-3/8"OD X 5-3/8"ID WASHOVER MILL ASSEMBLY FROM SURFACE TO TAG AT 101' MD. MILL FROM 101'MD TO 132'MD(-4' SHALLOW OF FULL MILL SHOE SWALLOW). ATTEMPT TO RESEAT MILLS SEVERAL TIMES. UNABLE TO MAKE NEW PROGRESS(6 HOURS TOTAL ON BOTTOM MILL TIME). -512 GPM,130 PSI,80 RPM,3-5 KFT-LBS TRQ ON BTM,3-5 KLBS WOB -PU/SO/ROT WEIGHTS=41 KLBS MW IN/OUT=8.5 PPG SEAWATER ICONTAIMINATED WITH DIESEL AND ARCTIC I PACK. -30 PSI ON IA/OA. NO FLOW OUT 13-3/8"X CONDUCTOR ANNULUS I MILL RUN#10: FLOWCHECK WELL FOR 10 MIN(STATIC). POOH FROM 132'MD TO INSPECT MILLS. -22'SECTION OF FLATTENED 4-1/2"TUBING RECOVERED INSIDE MILL SHOE(SEE PHOTOS). ID OF MILL WORN DOWN FROM 5-3/8"TO 15-3/4". ELECT TO RERUN. 21:00 - 22:00 1.00 FISH N DPRB 95.00 DECOMP RIG SERVICE,DERRICK INSPECTION AND —_ SWAP OUT OIL JARS. Printed 12/5/2016 8:53:59AM *All depths reported in Drillers Depths* North America-ALASKA-BP Page 17 of 47 Operation Summary Report Common Well Name:G-13 1AFE No Event Type:WORKOVER(WO) Start Date:11/3/2016 End Date:11/25/2016 „Z3-001X7-E:(2,630,000.00) Project:Prudhoe Bay Site:PB G Pad Rig Name/No.:PARKER 272 Spud Date/Time:7/13/1981 12:00:OOAM Rig Release:11/25/2016 Rig Contractor:PARKER DRILLING CO. I UWI:500292060000 Active datum:G-13 OKB @65.97usft(above Mean Sea Level) Date 1 From-To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (usft) 22:00 - 00:00 2.00 FISH N DPRB 95.00 DECOMP WASHOVER MILLASSEMBLY RUN: MILL RUN#11: FLOWCHECK WELL FOR 10 MIN(STATIC). MAKEUP AND RUN IN HOLE WITH 8-3/8"OD X 5-3/4"ID WASHOVER MILL ASSEMBLY FROM SURFACE TO TAG AT 132' MD. MILL FROM 132'MD TO 137'MD UNTIL UNABLE TO MAKE ADDITIONAL PROGRESS. ;UNSUCCESSFULLY ATTEMPT TO REGAIN ROP BY REPEATEDLY RESEATING MILL. -508 GPM,110 PSI,80 RPM,5 KFT-LBS TRQ ON BTM,3-5 KLBS WOB MILL RUN#11: FLOWCHECK WELL FOR 10 MIN(STATIC). PULL OUT OF HOLE TO INSPECT MILLS AND CHECK FOR FISH. 1-NO FISH RECOVERED I-ID OF MILL FOUND TO BE 100%GROUND DOWN 11/11/2016 00:00 - 01:00 1.00 FISH N 1 DPRB 95.00 DECOMP WASHOVER MILL ASSEMBLY RUN COMPLETION: I 1 -LAYDOWN 8-3/8"OD X 5-3/4"WASHOVER MILL ASSEMBLY. COMMENTS IN PREVIOUS TIME SUMMARY ENTRY. Printed 12/5/2016 8:53:59AM `All depths reported in Drillers Depths* North America-ALASKA-BP Page 18 of 47 Operation Summary Report Common Well Name:G-13 AFE No Event Type:WORKOVER(WO) Start Date:11/3/2016 End Date:11/25/2016 Z3-001X7-E:(2,630,000.00) Project:Prudhoe Bay Site:PB G Pad Rig Name/No.:PARKER 272 Spud Date/Time:7/13/1981 12:00:00AM Rig Release:11/25/2016 Rig Contractor:PARKER DRILLING CO. UWI:500292060000 Active datum:G-13 OKB @65.97usft(above Mean Sea Level) Date From-To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (usft) 01:00 - 07:00 6.00 FISH N DPRB 95.00 DECOMP FISHING RUNS: OVERSHOT RUN#3: MAKEUP AND RUN IN HOLE WITH 5-3/4"OVERSHOT ASSEMBLY TO I TAG AT 131'MD. WORK OVERSHOT DOWN TO 133'MD AND ENGAGE FISH. CONFIRM WITH 55 KLBS OVERPULL. ROTATE 8 WRAPS TO LEFT AND OBSERVE BACKOFF AT 6KFT-LBS TRQ. COMPLETE BACKOUT OF JOINT WITH 12 FULL TURNS TO LEFT AT 2 KFT-LBS. NEW PICKUP WEIGHT=103 KLBS. I ATTEMPT TO POOH WITH FISH,BUT OBSERVE WEIGHT DROP OFF TO 42 KLBS , AFTER 3'UPWARD MOVEMENT. POOH TO INSPECT GRAPPLE. ESTIMATE BACKOFF POINT AT 6500'MD. NO FISH RECOVERED AT SURFACE,NO SIGNIFICANT MARKINGS ON OVERSHOT. OVERSHOT RUN#4: MAKEUP AND RUN IN I 'HOLE WITH 5-3/4"OVERSHOT ASSEMBLY TO TAG AT 131'MD. WORK DOWN TO 133'MD. ' UNSUCCESSFULLY ATTEMPT TO ENGAGE FISH WITH REPEATED 20 KLBS SET DOWN I WEIGHTS AND ROTATION. POOH TO I I INSPECT GRAPPLE(NO FISH). I OVERSHOT RUN#5: ADD OVERSHOT j I EXTENSION TO FISHING ASSEMBLY. . MAKEUP AND RUN IN HOLE WITH 5-3/4" OVERSHOT ASSEMBLY TO TAG AT 133'MD. I UNSUCCESSFULLY ATTEMPT TO ENGAGE I FISH WITH REPEATED 20 KLBS SET DOWN WEIGHTS AND ROTATION. POOH TO , INSPECT GRAPPLE(NO FISH). OVERSHOT RUN#6: CHANGEOUT TO SMALLER GRAPPLE. MAKEUP AND RUN IN HOLE WITH 5-1/2"OVERSHOT ASSEMBLY TO TAG AT 133'MD. LATCH UP FISH WITH 15 KLBS DOWN. NEW UP WEIGHT WITH FISH= 103 KLBS. -FLOWCHECK WELL FOR 10 MIN(STATIC). PULL UP 7'AT 2 FPM AND BEGIN TO OBSERVE FLOW FROM WELL. RIG GAS ALARMS ACTIVATE IN SHAKER ROOM. -WELL INTEGRITY OPERATIONS IN NEXT TIME SUMMARY ENTRIES. Printed 12/5/2016 8:53:59AM *AII depths reported in Drillers Depths* • North America-ALASKA-BP • Page 19 of 47 Operation Summary Report Common Well Name:G-13 AFE No Event Type:WORKOVER(WO) Start Date:11/3/2016 End Date:11/25/2016 Z3-001X7-E:(2,630,000.00) Project:Prudhoe Bay Site:PB G Pad Rig Name/No.:PARKER 272 Spud Date/Time:7/13/1981 12:00:00AM Rig Release:11/25/2016 Rig Contractor:PARKER DRILLING CO. UWI.500292060000 Active datum:G-13 OKB @65.97usft(above Mean Sea Level) Date 1 From-To Hrs Task Code NPT NPT Depth Phase 1 Description of Operations (hr) (usft) 07:00 - 00:00 17.00 FISH N DPRB 95.00 DECOMP WELL INTEGRITY OPERATIONS: 1)NON-ESSENTIAL PERSONNEL EVACUATED FROM RIG AND LEVEL 1/TIER 3 NOTIFICATIONS MADE. 2)RIG CREW SECURES WELL WITH ANNULAR PREVENTER ON 6" 1 I NON-SHEARABLE SPIRAL DRILL COLLAR. INITIAL SIDP=240 PSI,SICP=120 PSI(BOTH ' CLIMBING). 3)PER WELL-SPECIFIC STANDING ORDERS*, I IMMEDIATELY BEGIN TO DIVERT FLOW THROUGH CHOKE TO MGS TO ALLEVIATE I ' I PRESSURE BUILDING UP ON WELL. 4)OPEN IA AND OA LINES TO FLOWBACK I TANKS. SHUT-IN SUPERCHOKE TO DIVERT ALL FLOW OUTSIDE RIG. , 5)FLOWBACK(CONTROLLED)TOTAL ' "PITGAIN"OF 75 BBLS OVER 1 HOUR UNTIL WELL PRESSURE BLEEDS TO 0 PSI. DECLINING FLOWBACK TREND RECORDED 'AFTER INITIAL FLOWBACK RATE OF 8 BPM. 6)SHUT IN WELLAND MONITOR FOR PRESSURE BUILD UP. FLOWCHECKAND PRESSURE CHECK WELL FOR 3 HOURS WITH NO FLOW OR PRESSURE BUILDUP. -(*)NOTE: WELL-SPECIFIC STANDING I ORDERS TO DIVERT FLOW UPON SHUT-IN , ARE IN PLACE BECAUSE OF DOWNHOLE INEGRITY ISSUES. COMMUNICATION EXISTS I BETWEEN THE TBG,IA,OA AND CONDUCTOR. THERE IS LOW CONFIDENCE I IN THE ABILITY OF THE UNTESTED CEMENT I TOP JOB IN 13-3/8"X 20"ANNULUS TO HOLD PRESSURE. ISOLATION TO THE RESERVOIR !HAS BEEN ESTABLISHED. SOURCE OF GAS IS BELIEVED TO BE ENTRAINED GAS DISSOLVING OUT OF CRUDE OIL SOLUTION ,AS HYDROSTATIC PRESSURE IS REDUCED DURING NATURAL FLUID SWAPPING IN WELL WHILE 8.5PPG SEAWATER IS CONTINUOUSLY ADDED OVER THE TOP. DISPLACE CRUDE OIL AND EVACUATE FREE I GAS FROM WELL WITH 8.5 PPG SEAWATER AS FOLLOWS(PER AGREED PLAN WITH ANCHORAGE TEAM): -14:30-16:30: FILL WELL WITH 80 BBLS 8.5 PPG SEAWATER DOWN OVERSHOT ASSEMBLY(RETURNS OUT IA)AT 5 BPM,50 PSI(ATTEMPTED TO FILLAT 1/2 BPM,BUT , CHARGE PUMP OUTRAN MUD PUMP). SHUT DOWN AND MONITOR WELL. PRESSURE ON DP/IA/OA BEGIN TO CLIMB QUICKLY TO 150 PSI IN 10 MIN. BLEED PRESSURE THROUGH IA/OA/CHOKE TO 0 PSI OVER 1 HR 15 MIN. BLEED BACK TOTAL OF 80 BBLS. -17:00-2100: FILL WELL WITH 97 BBLS 8.5 PPG SEAWATER DOWN OVERSHOT ASSEMBLY(RETURNS OUT IA)AT 1/2 BPM,30 PSI IN 10 BBL INCREMENTS SEPARATED BY 5 1 MIN MONITORING PERIODS. NO SIGNS OF Printed 12/5/2016 8:53:59AM `AII depths reported in Drillers Depths' 11111 • North America-ALASKA-BP Page 20 of 47 Operation Summary Report Common Well Name:G-13 I AFE No Event Type:WORKOVER(WO) Start Date:11/3/2016 End Date:11/25/2016 Z3-001X7-E:(2,630,000.00) Project:Prudhoe Bay Site:PB G Pad Rig Name/No.:PARKER 272 Spud Date/Time:7/13/1981 12:00:00AM 1 Rig Release:11/25/2016 Rig Contractor:PARKER DRILLING CO. UWI:500292060000 Active datum:G-13 OKB @65.97usft(above Mean Sea Level) Date From To Hrs I Task Code I NPT NPT Depth Phase Description of Operations (hr) (usft) WELL PRESSURE WHEN HOLE FULL BUT AFTER PUMPING ADDITIONAL 13 BBLS FOR TOTAL OF 113 BBLS IN INTERVAL WELL PRESSURE QUICKLY BUILDS TO 115 PSI IN 3 MIN. BLEED PRESSURE THROUGH I IA/OA/CHOKE TO 0 PSI OVER 25 MIN. BLEED I BACK TOTAL OF 40 BBLS OF 7.3 PPG CRUDE OIL. -21:30-22:30: FILL WELL WITH 45 BBLS 8.5 PPG SEWATER DOWN OVERSHOT ASSEMBLY I I(RETURNS OUT IA)AT 2.5 BPM,30 PSI. NO WELL PRESSURE INITIALLY WHEN HOLE FULL,BUT PRESSURE BUILDS TO 70 PSI IN 1 , MIN AFTER MONITORING STATIC WELL FOR , 15 MIN. BLEED PRESSURE THROUGH IA& CHOKE TO 0 PSI OVER 15 MIN. BLEED BACK TOTAL OF35 BBLS OF 7.4 PPG CRUDE OIL. -22:30-23:00: FILL WELL WITH 23 BBLS 8.5 PPG SEAWATER DOWN OVERSHOT , ASSEMBLY(RETURNS OUT IA)AT 2.5 BPM,30 PSI. PRESSURE IMMEDIATELY BUILDS TO 40 PSI AFTER PUMPS OFF. BLEED PRESSURE 1 I THROUGH IA&CHOKE TO 0 PSI OVER 5 MIN. BLEED BACK TOTAL OF17 BBLS OF I SEAWATER CRUDE MIX. 1 I-23:00-00:00: MONITOR WELLAND OBSERVE NO FLUID SWAPPING IN WELL. ONE 'ATTEMPT TO FILL WELL ONLY REQUIRES 1 BBL. ,-NOTE: TOTAL VOLUME OF FLUID IN WELL REPLACED BY SEAWATER DURING TIME INTERVAL=246 BBLS(43%OF 571 BBL CALCULATED HOLE VOLUME IN TUBING AND IA) 1-DRILLING TROUBLE TIME TR@CTION IR#: 12016-IR-5371152. SUBMIT BOPE USAGE FORM TO AOGCC Printed 12/5/2016 8:53:59AM "All depths reported in Drillers Depths* North America-ALASKA-BP Page 21 of 47 Operation Summary Report Common Well Name:G-13 AFE No Event Type:WORKOVER(WO) 11 Start Date:11/3/2016 End Date:11/25/2016 Z3-001X7-E:(2,630,000.00) Project:Prudhoe Bay Site:PB G Pad Rig Name/No.:PARKER 272 Spud Date/Time:7/13/1981 12:00:00AM Rig Release:11/25/2016 Rig Contractor:PARKER DRILLING CO. UWI:500292060000 Active datum:G-13 OKB @65.97usft(above Mean Sea Level) Date From-To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (usft) 11/12/2016 00:00 - 00:00 1 24.00 FISH N DPRB 95.00 DECOMP r WELL INTEGRITY OPERATIONS CONTINUED: 'WITH WELL SHUT IN,ESTALISH STABLE FLUID COLUMN IN WELL BY DISPLACING CRUDE AND GAS FROM WELL WITH NEW 8.5 I PPG SEAWATER. ALTERNATE SEQUENCES OF ADDING NEW SEAWATER AND MONITORING CRUDE FLOWBACK WITH GAS BLEED OFF(SIMILAR TO LUBE AND BLEED). I SEQUENCE SUMMARY AS FOLLOWS: -00:00-03:00: MONITOR WELL AT FLOWBACK TANK AND MGS FOR FLOW(NO FLOW) -03:00-11:00: CIRCULATE WELL DOWN I OVERSHOT ASSEMBLY(RETURNS OUT CHOKE THROUGH MGS)BBL FOR BBL WITH ' '8.5 PPG SEAWATER AT 2 BPM,30 PSI FOR 1 . HOUR.,THEN MONITOR WELL FOR 1 HOUR. -SOME MONITORING INTERVALS CONSIST OF STATIC FLOWCHECK WHILE OTHERS INCLUDE CRUDE FLOWBACK WITH GAS DISOLVING OUT OF SOLUTION. -OBSERVE MINOR SIGNS OF ABILITY TO 1 PUSH FLUID DOWN TUBING(BASED ON I •SEEING TUBING PRESSURE BUILD DURING ' I MONITORING PERIOD WITH NO CORRESPONDING INCREASES ON IA/OA). 11:00-18:00: CIRCULATE WELL DOWN 'OVERSHOT ASSEMBLY(RETURNS OUT ' CHOKE THROUGH MGS)BBL FOR BBL WITH , 8.5 PPG SEAWATER AT 2-5 BPM,30-75 PSI (INCREASING 0.5 BPM EVERY INTERVAL)FOR 30 MIN INTERVALS,FOLLOWED BY 30 MIN , MONITORING PERIODS. ELECT TO I DISCONTINUE PUMPING AT RATES>2.5 BPM BECAUSE OF EXTRA PRESSURE APPLIED TO WELLBORE. , -3-7 BBLS TO FILL WELL EACH TIME STARTING UP PUMPS SEE REGULAR SIGNS OF FLUID SWAPPING DURING MONITOR PERIODS , (DRILLPIPE PRESSURE BUILDUP, CRUDE/GAS FLOW SURGES THROUGH MGS, , ETC) I -PERFORM ONE(1/2)HOUR MONITOR ' WITH WELL SHUT-IN. IA PRESSURE BUILDS 5 PSI. WELL FLOWS BACK UPON OPENING CHOKE AT END OF MONITOR. 18.00-00:00: CIRCULATE WELL DOWN OVERSHOT ASSEMBLY(RETURNS OUT CHOKE THROUGH MGS)BBL FOR BBL WITH 8.4 PPG SEAWATER AT 2.5 BPM,30 PSI FOR I 30 MIN INTERVALS,FOLLOWED BY 30 MIN MONITORING PERIODS. -3-8 BBLS TO FILL WELL EACH TIME STARTING UP PUMPS SEE REGULAR SIGNS OF FLUID SWAPPING DURING MONITOR PERIODS (DRILLPIPE PRESSURE BUILDUP, CRUDE/GAS FLOW SURGES THROUGH MGS, ETC). MAX FLOWBACK=3 BBLS FOR I SURGES. Printed 12/5/2016 8:53:59AM 'AII depths reported in Drillers Depths* North America-ALASKA-BP page 22 of 47 Operation Summary Report Common Wet Name:G-13 1AFE No Event Type:WORKOVER(WO) Start Date:11/3/2016 End Date:11/25/2016 'Z3-001X7-E:(2,630,000.00) Project:Prudhoe Bay 1 Site:PB G Pad Rig Name/No.:PARKER 272 Spud Date/Time:7/13/1981 12:00:OOAM Rig Release:11/25/2016 Rig Contractor:PARKER DRILLING CO. UWI:500292060000 Active datum:G-13 OKB©65.97usft(above Mean Sea Level) Date From-To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (usft) -IA/OA PRESSURES=30/40 PSI -PERFORM ONE(1)HOUR MONITOR WITH WELL SHUT-IN. IA PRESSURE BUILDS 10 PSI. I WELL FLOWS BACK UPON OPENING CHOKE AT END OF MONITOR. 11 1 PLANS DEVELOPED DURING THE DAY WITH 1 ANCHORAGE TEAM INCLUDE: 1)STABLE WELL CRITERIA AND PLAN FOR RE-OPENING WELL(ATTACHED) I2)PLAN FORWARD FOR HANDLING AND I I LAYING DOWN COLLAPSED TUBING(CALL I OUT BOOTS AND COOTS FROM HOUSTON) 3)DISCUSS BOPE TESTING PLANS (ORIGINALY DUE 11/13)AND RECEIVE !AUTHORIZATION FROM AOGCC INSPECTIONS SUPERVISOR JIM REGG FOR DELAYED SCHEDULED/USAGE TEST UNTIL RIG IS IN A +—_ BETTER POSITION. 11/13/2016 00:00 - 12:00 1 12.00 1 FISH N DPRB ' 95.00 DECOMP WELL INTEGRITY OPERATIONS CONTINUED: WITH WELL SHUT IN,ESTALISH STABLE ' 1FLUID COLUMN IN WELL BY DISPLACING 1 „ 1 „ . 1 1CRUDE AND GAS FROM WELL WITH NEW 8.5 PPG SEAWATER. ALTERNATE SEQUENCES 1I OF ADDING NEW SEAWATER AND MONITORING CRUDE FLOWBACK WITH GAS BLEED OFF(SIMILAR TO LUBE AND BLEED). ' 1 SEQUENCE SUMMARY AS FOLLOWS: I 1 I -00:00-10:00: CIRCULATE WELL DOWN OVERSHOT ASSEMBLY(RETURNS OUT CHOKE THROUGH MGS)BBL FOR BBL WITH I 8.4 PPG SEAWATER AT 2.5 BPM,30 PSI FOR 130 MIN INTERVALS,FOLLOWED BY 30 MIN MONITORING PERIODS. -1-3 BBLS TO FILL WELL EACH TIME STARTING UP PUMPS 1 -SEE REGULAR SIGNS OF FLUID SWAPPING DURING MONITOR PERIODS (DRILLPIPE PRESSURE BUILDUP, 1 CRUDE/GAS FLOW SURGES THROUGH MGS, ETC). MAX FLOWBACK=3 BBLS FOR SURGES. -IA/OA PRESSURES=30/40 PSI -PERFORM ONE(1)HOUR MONITOR WITH WELL SHUT-IN. IA PRESSURE BUILDS 10 PSI AND TUBING PRESSURE BUILDS 40 PSI DURING MONITOR. WELL FLOWS BACK UPON OPENING CHOKE AT END OF MONITOR. -10:00-11:00: SHUT IN WELL FOR ONE HOUR AND MONITOR FOR PRESSURE BUILDUP. DRILLPIPE BUILDS UP 40 PSI TO 70 PSI. IA/OA PRESSURES REMAIN CONSTANT. -11:00-12:00: OPEN CHOKE AND MONITOR WELL FOR ONE HOUR. NO FLOW. Printed 12/5/2016 8:53:59AM *All depths reported in Drillers Depths* • North America-ALASKA-BP • Page 23 of 47 Operation Summary Report Common Well Name:G-13 AFE No Event Type:WORKOVER(WO) Start Date:11/3/2016 End Date:11/25/2016 !Z3-001X7-E:(2,630,000.00) Project:Prudhoe Bay Site:PB G Pad Rig Name/No.:PARKER 272 Spud Date/Time:7/13/1981 12:00:00AM 'Rig Release:11/25/2016 Rig Contractor:PARKER DRILLING CO. UWI:500292060000 Active datum:G-13 OKB©65.97usft(above Mean Sea Level) Date From-To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (usft) 12:00 - 14:00 2.00 FISH N DPRB 95.00 DECOMP WELL INTEGRITY OPERATIONS CONTINUED: AS PREPARATION FOR OPENING WELL, CHECK FOR GAS BUILDUP BETWEEN ANNULAR AND MUD CROSS BY SLOWLY BACKING OFF ANNULAR CLOSING PRESSURE FROM 1500 PSI TO 150 PSI AND MONITORING FOR FLOW BY ELEMENT WITH BORESCOPE CAMERA PLACED ON TOP OF ELEMENT. NO SIGNS OF GAS. 14:00 - 16:00 2.00 FISH N DPRB 95.00 DECOMP WELL INTEGRITY OPERATIONS CONTINUED: OPEN ANNULAR PREVENTER AND FLOWCHECK WELL(FLUID LEVEL SLIGHTLY DROPPING WITH MINOR GAS BUBBLES BREAKING OUT) -RECEIVE AUTHORIZATION TO OPEN WELL FROM WIG WELL OPERATIONS MANAGER (WOM) 16:00 - 17:30 1.50 FISH P DECOMP COMPLETION OF OVERSHOT RUN#6: LAYDOWN OVERSHOT FISHING ASSEMBLY INCLUDING COLLARS,BUMPER SUB,JARS, AND EMPTY BOOT BASKETS.MAKEUP SAFETY JOINT WITH CROSSOVER TO TOP OF TAPERED TUBING STRING. RUN IN HOLE TO PLACE SHEARABLE DRILLPIPE JOINT ACROSS BOP STACK. -RECEIVE AUTHORIZATION FROM WOM PRIOR TO BREAKING OFF TOP DAMAGED TUBING JOINT AND LAYING DOWN OVERSHOT ASSEMBLY. --14'PIECE OF COLLAPSED TUBING RECOVERED ON TOP OF FULL GOOD JOINT. (1 TOTAL JOINT OF 40'TUBING WAS FOUND TO BE COLLAPSED IN WELL) -DUAL CONTROL LINES FOUND TO BE WRAPPED AROUND BASE OF COLLAPSED JOINT. BALL OF CONTROL LINE CUT OFF AT SURFACE. REMAINDER OF CONTROL APPEARS TO BE IN GOOD CONDITION BELOW COLLAPSE AREA. 17:30 - 23:00 5.50 PULL N DPRB 95.00 DECOMP WELL INTEGRITY OPERATIONS CONTINUED: CIRCULATE 40 BBL BARACLEAN PILL SURFACE TO SURFACE. -2 BPM,T/I/O 75/40/60 PSI -PUMP ONE TUBING VOLUME PRIOR TO SENDING SOAP PILL -DISPLACE FIRST BOTTOMS UP WITH LARGE 'PERCENTAGE OF CRUDE OUT TO FLOWBACK TANK(STILL MONITORING BBL IN/OUT) 23:00 - 00:00 1.00 PULL P DECOMP STAGE UP PUMPS AND CIRCULATE 40 BBL BARACLEAN SOAP PILL SURFACE TO SURFACE. -7 BPM,T/I/O 386/20/30 PSI. -CLEAN 8.5 PPG SEAWATER THROUGHOUT CIRCULATION. Printed 12/5/2016 8:53:59AM *All depths reported in Drillers Depths* • North America-ALASKA-BP Page 24 of 47 Operation Summary Report Common Well Name:G-13 AFE No Event Type:WORKOVER(WO) Start Date:11/3/2016 End Date:11/25/2016 Z3-001X7-E:(2,630,000.00) Project:Prudhoe Bay Site:PB G Pad Rig Name/No.:PARKER 272 Spud Date/Time:7/13/1981 12:00:00AM Rig Release:11/25/2016 Rig Contractor:PARKER DRILLING CO. UWI:500292060000 Active datum:G-13 OKB©65.97usft(above Mean Sea Level) Date From-To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (usft) 11/14/2016 00:00 - 01:00 1.00 PULL P DECOMP COMPLETE CIRCULATING WELL CLEAN WITH SOAP PILL SURFACE TO SURFACE -DETAILS OF CIRCULATING IN PREVIOUS TIME ENTRY. FLOWCHECK WELL FOR 15 MIN AFTER SHUTTING DOWN PUMPS(STATIC) 01:00 - 02:00 1.00 PULL P DECOMP RIG UP TO PULLAND LAYDOWN TAPERED TUBING STRING WITH CONTROL LINES. HOLD PJSM WITH RIG TEAM. -DOYON DOUBLE STACK TONGS,SLB CONTROL LINE SPOOLER 02:00 - 03:00 1.00 PULL P DECOMP LAYDOWN 4-1/2"X 3-1/2"TAPERED TUBING STRING FROM BACKOFF POINT(ESTIMATED AT-6500'MD). -INITIAL PICKUP WEIGHT=92 KLBS -MONITOR WELL ON TRIP TANK WITH CONTINOUS FILL(STATIC) -AFTER JOINT-12,CONTROL LINE STOPS PULLING OUT OF HOLE WITH TUBING. 03:00 - 13:00 10.00 PULL N DPRB DECOMP UNSUCCESSFULLY ATTEMPT TO PULLAND LAYDOWN 4-1/2"X 3-1/2"TAPERED TUBING STRING FROM BLIND BACKOFF POINT. CONTROL LINES NOT PULLING OUT OF HOLE WHEN PULLING ON TUBING. -ATTEMPT RUNNING BACK IN HOLE SEVERAL STANDS AND PULLING BACK OUT -ATTEMPT PULLING CONTROL LINES WITH TUGGERS AND STRAPS -ATTEMPT PULLING CONTROL LINES WITH "CABLE PULLERS"FROM POWER INDUSTRY -DUAL CONTROL LINES PART(3/8"CABLE STILL INTACT). DRAIN STACK AND CONFIRM LINE NOT STICKING UP THROUGH BOP STACK. -DECISION TO STOP PULLING CONTROL LINE AND TEST BOPE WHILE DEVELOPING PLAN FORWARD WITH ANCHORAGE TEAM. 13:00 - 14:30 1.50 PULL N DPRB DECOMP RIG DOWN TUBING PULLING EQUIPMENT (DOYON CASING TOOLS AND SLB CONTROL LINE SPOOLER). 14:30 - 17:30 3.00 BOPSUR N DPRB 44.00 DECOMP UNSUCCESSFULLY ATTEMPT TO SET TEST PLUG(WITH TUBING STRING HANGING BELOW)FOR BOPE TESTING. -ENCOUNTER TRASH IN HOLE/BOP STACK DURING SEVERAL ATTEMPTS. -CONTROL LINE PIECES AND BREAD LOAF SIZE OF MILLED/MANGLED PIECE OF 9-5/8" CASING RECOVERED FROM BOP CAVITIES. -REPLACE RUBBER SEALS ON TEST PLUG AFTER SEVERAL UNSUCCESSFUL RUNS. -RUN WATERMELON MILL ON ASSEMBLY THROUGH WELLHEAD TO ENSURE AREA IS --._ CLEAR. Printed 12/5/2016 8:53:59AM *All depths reported in Drillers Depths* • • North America-ALASKA-BP Page 25 of 47 Operation Summary Report Common Well Name:G-13 AFE No Event Type:WORKOVER(WO) Start Date:11/3/2016 End Date:11/25/2016 'Z3-001X7-E:(2,630,000.00) Project:Prudhoe Bay Site:PB G Pad Rig Name/No.:PARKER 272 Spud Date/Time:7/13/1981 12:00:OOAM Rig Release:11/25/2016 Rig Contractor:PARKER DRILLING CO. UWI:500292060000 Active datum:G-13 OKB @65.97usft(above Mean Sea Level) Date From-To I Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (usft) 17:30 - 18:00 0.50 BOPSUR P DECOMP SET TEST PLUG FOR BOPE TESTING. -PORTED SUB,WATERMELON MILLAND DRILLPIPE JOINT WITH XO MADE UP TO TOP OF TUBING STRING HANGING FROM TEST PLUG. -CAMERON REP ON LOCATION TO RUN IN 'FOUR LOCKDOWN SCREWS ON PLUG. -PICKUP/SLACKOFF WEIGHTS OF FULL TUBING STRING BELOW TEST PLUG=85/82 KLBS 18:00 - 19:30 1.50 BOPSUR P DECOMP FLUSH STACK AND FUNCTION ALL STACK COMPONENTS(FOLLOWING EXTENSIVE i MILLING AND FISHING OEPRATIONS). 1-RUN MAGNET DOWN TO TEST PLUG AND PULL BACK TO SURFACE(NO SIGNIFCANT METAL COLLECTED) -FLUSH TOP OF TEST PLUG TO ENSURE .ABILITY TO SCREW IN WITH TEST JOINTS 19:30 - 20:30 1.00 BOPSUR P DECOMP RIG UP TO TEST BOPE. -RUN IN HOLE WITH 9-5/8"TEST JOINTS FOR FIRST TEST. MAKEUP FLOOR VALVE ASSEMBLY ON RIG FLOOR. -HOLD PJSM FOR TESTING AND COMPLETE PRESSURE CROSSCHECK -FILL LINES AND COMPLETE SHELL TEST. 20:30 - 00:00 3.50 BOPSUR P ' DECOMP PRESSURE TEST BOPE PER BP PRACTICES AND AOGCC REGULATIONS TO 250 PSI LOW AND 3500 PSI HIGH FOR FIVE MIN EACH. -STATE'S RIGHT TO WITNESS WAIVED BY AOGCC REP BRIAN BIXBY -TEST UPPER 9-5/8"RAMS WITH 9-5/8"TEST JOINT -TEST LOWER 2-7/8"X 5"VBRS WITH 3-1/2" AND 5"TEST JOINTS -TEST ANNULAR PREVENTER WITH 3-1/2" TEST JOINT -MAINTAIN OPEN IA VALVE BELOW TEST PLUG TO MONITOR LEAK PATH -NO FAILURES(SEE ATTACHED DOCUMENTATION) -TEST COMPLETED AT 01:30 ON 11/15/16 11/15/2016 00:00 - 01:30 1.50 BOPSUR P DECOMP COMPLETE BOPE TESTING -FULL DETAILS OF TEST IN PREVIOUS TIME SUMMARY ENTRY ON 11/14/16. 01:30 - 02:30 1.00 BOPSUR P DECOMP RIG DOWN AFTER TESTING&LOAD TOOLS TO RIG FLOOR FOR NEXT FISHING RUNS 02:30 - 04:00 1.50 BOPSUR P DECOMP BACKOUT LOCKDOWN SCREWS AND PULL TEST PLUG WITH TUBING STRING TO RIG FLOOR. BREAKOFF AND LAYDOWN TEST PLUG,PORTED SUB,WATER MELON MILL AND DRILLPIPE JOINT WITH CROSSOVER FROM TOP OF TUBING. -PICKUP WEIGHT=87 KLBS. Printed 12/5/2016 8:53:59AM *All depths reported in Drillers Depths* • • North America-ALASKA-BP Page 26 of 47 Operation Summary Report Common Well Name:G-13 AFE No Event Type:WORKOVER(WO) Start Date:11/3/2016 End Date:11/25/2016 Z3-001X7-E:(2,630,000.00) Project:Prudhoe Bay Site:PB G Pad Rig Name/No.:PARKER 272 Spud Date/Time:7/13/1981 12:00:00AM Rig Release:11/25/2016 Rig Contractor:PARKER DRILLING CO. UWI:500292060000 Active datum:G-13 OKB @65.97usft(above Mean Sea Level) Date From-To Hrs Task Code NPT NPT Depth Phase I Description of Operations (hr) (usft) 04:00 - 08:30 4.50 FISH N DPRB 95.00 DECOMP FISHING OPERATIONS: SPEAR RUN#3: MAKEUP SLB 4-1/2"SPEAR ASSEMBLY AND ENGAGE TOP OF TUBING AT RIG FLOOR. -SPEAR,OIL&BUMPER JARS,(2)DRILL COLLARS,ACCELERATOR VISIBLE CONTROL LINES ARE BANDED TO TOP OF TUBING SPEAR RUN#3: RUN IN HOLE WITH TAPERED TUBING STRING ON SPEAR ASSEMBLY FROM SURFACE TO HARD TAG AT 606'MD(-100'BELOW EXPECTED TAG DEPTH BASED ON TUBING LAID DOWN). FLOWCHECK WELL FOR 10 MIN PRIOR TO RIH(STATIC) 20-40 FPM CAUTIOUS RUNNING SPEED IN HOLE. MINOR 5-8 KLBS TAGS AT 95'MD(MIDDLE OF 9-5/8"HOLE),108'MD,AND 137'MD(END OF WASHOVER MILLING). NO ISSUES I BELOW 137'MD(SPEAR DEPTHS). -INITIAL SLACKOFF WEIGHT=92 KLBS. FINAL AT 600'MD=102 KLBS. SPEAR RUN#3: RELEASE SPEAR FROM TUBING AND POOH. LAYDOWN SPEAR ASSEMBLY. -PICKUP WEIGHT WITHOUT TUBING STRING =52 KLBS,NO OVERPULLS ON TRIP OUT. -1 CLAMP AND MINOR CONTROL LINE PIECES FOUND ON BUMPER SUB CYLINDER 08:30 - 09:00 0.50 WHSUR N DPRB 95.00 DECOMP INSTALL WEAR RING,(8-7/8"ID) Printed 12/5/2016 8.53.59AM •AII depths reported in Drillers Depths* • • North America-ALASKA-BP Page 27 of 47 Operation Summary Report Common Well Name:G-13 AFE No Event Type:WORKOVER(WO) Start Date:11/3/2016 End Date:11/25/2016 Z3-001X7-E:(2,630,000.00) Project:Prudhoe Bay Site:PB G Pad I Rig Name/No.:PARKER 272 Spud Date/Time:7/13/1981 12:00:OOAM Rig Release:11/25/2016 Rig Contractor:PARKER DRILLING CO. UWI:500292060000 Active datum:G-13 OKB @65.97usft(above Mean Sea Level) Date ' From-To Hrs Task ! Code NPT NPT Depth Phase Description of Operations (hr) (usft) 09:00 - 00:00 15.00 FISH N DPRB 95.00 DECOMP MILLING OPERATIONS: MILL RUN#12: MAKEUP AND RUN IN HOLE WITH 8-3/8"TAPERED MILL ASSEMBLY WITH 8-1/2"WATERMELON MILL(14'BACK)FROM SURFACE TO TAG AT 89'MD. MILL FROM 89' MD TO 102'MD. UNSUCCESSFULLY ATTEMPT ! I TO WIPE AREA(UNABLE TO PASS THROUGH CLEAN). POOH AND LAYDOWN TAPERED , ! MILL. -256 GPM,40 PSI,80 RPM,2-6/1 KFT-LBS TRQ ON/OFF BTM,2-3 KLBS WOB -MW IN/OUT=8.5 PPG VISCOSIFIED SEAWATER -PICKUP/SLACKOFF/ROTATING=42 KLBS -OBSERVE BREACH TO SURFACE IN 13-3/8"X ' 20"CONDUCTOR ANNULUS WHILE MILLING (BREAKDOWN OF TOP JOB POSSIBLY DUE TO VIBRATION). A MINOR AMOUNT OF FLUID !TRICKLES OUT OF ANNULUS WHEN PUMPS ' ARE ON(<1 VIS CUP PER HOUR). DISCUSS WITH ANCHORAGE TEAM I-TAPERED MILL SHOWS SIGNIFICANT WEAR ON LEADING EDGES OF TAPER MILL RUN#13: MAKEUP AND RUN IN HOLE WITH 6-1/2"MULE SHOE ASSEMBLY WITH !8-1/2"WATERMELON MILL(39'BACK)FROM SURFACE TO TAG AT 91'MD(MILL DEPTH). , NO ATTEMPT AT MILLING. POOH AND LAYDOWN MULE SHOE. MILL RUN#14: MAKEUP AND RUN IN HOLE !WITH 6-3/8"TAPERED MILL ASSEMBLY WITH I 18-1/2"WATERMELON MILL PER OCN#8 FROM , � SURFACE TO TAG AT 103'MD. UNABLE TO ' EASILY WORK MILLS DOWN FURTHER AND SUSPECT THAT TAPERED MILL IS EXITING 9-5/8"CASING. POOH AND LAYDOWN TAPERED MILL. PRIOR TO TAGGING WITH MILLS,STAGE UP PUMPS TO ESTIMATE EFFECT OF HIGHER PUMP RATES ON FLOW FROM 13-3/8"X 20" CONDUCTOR ANNULUS. NO DIFFERENCE I !BETWEEN 1 BPM AND 6 BPM OR WITH IA/OA OPEN VS CLOSED. A TRICKLE OF FLUID IS CONSTANTLY FLOWING OUT OF ANNULUS. DISCUSS WITH ANCHORAGE TEAM. MILL RUN#15: MAKEUP AND RUN IN HOLE , !WITH 6-1/2"MULE SHOE WITH 8-1/2" WATERMELON MILL(39'BACK)PER OCN#9 FROM SURFACE TO TAG AT 91'MD(MILL DEPTH). MILL TO 98'MD AT MIDNIGHT. I '-265 GPM,35 PSI,50 RPM,2-5/1 KFT-LBS TRQ ON/OFF BTM,2-3 KLBS WOB. MW IN/OUT=8.5 PPG VISCOSIFIED SEAWATER i -PICKUP.SLACKOFF WEIGHTS=42 KLBS Printed 12/5/2016 8:53:59AM `All depths reported in Drillers Depths* North America-ALASKA-BP Page 28 of 47 Operation Summary Report Common Well Name:G-13 'AFE No Event Type:WORKOVER(WO) Start Date:11/3/2016 End Date:11/25/2016 Z3-001X7-E:(2,630,000.00) Project:Prudhoe Bay Site:PB G Pad Rig Name/No.:PARKER 272 Spud Date/Time:7/13/1981 12:00:00AM !Rig Release:11/25/2016 Rig Contractor:PARKER DRILLING CO. ,UWI:500292060000 Active datum:G-13 OKB @65.97usft(above Mean Sea Level) Date 1 From-To 1 Hrs 1 Task Code NPT NPT Depth Phase Description of Operations I' (hr) (usft) 11/16/2016 '00:00 - 04:00 4.00 FISH N DPRB 95.00 DECOMP MILLING OPERATIONS CONTINUED: MILL RUN#15 CONTINUED: EASILY REAM DOWN WITH MULE SHOE AND WATERMELON 1 MILLASSEMBLY FROM 98'MD AT MIDNIGHT 1 TO 105'MD(MILL DEPTHS). MAKE SEVERAL REAMING PASSES UP AND DOWN PRIOR TO DRIFTING AREA WITH NO ROTATION AND NO ISSUES. POOH,LAYDOWN MULE SHOE AND MILL. -PICKUP/SLACKOFF AT 600'MD ABOVE TOP 10F TUBING=52 KLBS ' -TRIP IN HOLE WITH ASSEMBLY TO TAG TOP OF TUBING FISH AT 606'MD(AS PLANNED). CONFIRM TAG WITH 5 KLBS DOWN 1 1-FLOWCHECK WELL ON BOTTOM AND PRIOR 'TO BHA(STATIC) NO HOLE ISSUES BEYOND LAST TROUBLE SPOT AT 98'(MILL DEPTH) , I -NO WEAR OBSERVED ON WATERMELON ' MILL 04:00 - 07:30 3.50 WHSUR N DPRB 95.00 DECOMP PULL WEAR RING l-DIFFICULTY PULLING OUT OF WELLHEAD (POSSIBLY DUE TO METAL BUILDUP FROM MILLING BASED ON OVERPULLAND SCARRING). PULL WITH TOP DRIVE WITH RIGHT HAND TORQUE AND 35 KLBS - , ,OVERPULL Printed 12/5/2016 8:53:59AM *AII depths reported in Drillers Depths* • North America- 411 ALASKA-BP Page 29 of 47 Operation Summary Report Common Well Name:G-13 AFE No Event Type:WORKOVER(WO) Start Date:11/3/2016 End Date:11/25/2016 Z3-001X7-E:(2,630,000.00) Project:Prudhoe Bay Site:PB G Pad Rig Name/No.:PARKER 272 Spud Date/Time:7/13/1981 12:00:00AM Rig Release:11/25/2016 Rig Contractor:PARKER DRILLING CO. UWI:500292060000 Active datum:G-13 OKB @65.97usft(above Mean Sea Level) Date From-To I Hrs Task ' Code NPT NPT Depth Phase Description of Operations (hr) (usft) 07:30 - 00:00 16.50 FISH N DPRB 95.00 DECOMP FISHING OPERATIONS: OVERSHOT RUN#7: MAKEUP AND RUN IN HOLE WITH 8-1/8"OVERSHOT ASSEMBLY WITH 5-1/4"GRAPPLE FROM SURFACE TO I TAG AT 103'MD. UNABLE TO WORK PAST. , POOH AND INSPECT OVERSHOT. SIGNS OF WEAR INSIDE OVERSHOT,MINOR FLARE ON CUT LIP GUIDE. OVERSHOT RUN#8: MAKEUP AND RUN IN I HOLE WITH 6-3/8"OD X 5-1/4"ID OVERSHOT ASSEMBLY PER OCN#10 FROM SURFACE TO TAG TUBING STUB AT 606'MD. UNABLE TO I LATCH FISH. POOH AND INSPECT OVERSHOT(NO SIGNS OF WEAR). -ATTEMPT TO SET DOWN WITH INCREASING I WEIGHTS,VARYING ROTATION AND VARYING PUMP RATES. I OVERSHOT RUN#9: MAKEUP AND RUN IN I !HOLE WITH 6-3/8"OD X 5"ID OVERSHOT ASSEMBLY FROM SURFACE TO TAG TUBING j 1 STUB AT 606'MD. UNABLE TO LATCH FISH. , POOH AND INSPECT OVERSHOT(NO SIGNS OF WEAR). -ATTEMPT TO SET DOWN WITH INCREASING 1 WEIGHTS,VARYING ROTATION AND VARYING I PUMP RATES. SPEAR RUN#4: MAKEUP AND RUN IN HOLE WITH 4-1/2"SPEAR FROM SURFACE TO TAG TUBING STUB AT 606'MD. UNABLE TO I ENGAGE FISH. ATTEMPT TO SET DOWN WITH INCREASING ' WEIGHTS AND VARYING ROTATION. OBSERVE SIGNS OF PACKING OFF WHILE PUMPING AND INCREASING WEIGHT ON FISH ' (INDICATING TRASH ON TOP OF TUBING STUB. MILL RUN#16: MAKEUP AND RUN IN HOLE I WITH 8-1/2"OD X 5-3/8"ID WASHOVER MILL ASSEMBLY PER OCN#11 FROM SURFACE TO I TAG TOP OF TUBING STUB AT 606'MD(MINOR I BOBBLE PASSING THROUGH 105'MD). DRESSOFF TOP OF TUBING STUB AND CONFIRM ABILITY TO REPEATEDLY SWALLOW TOP 4'OF TUBING. POOH AND , LAYDOWN WASHOVER MILL. , -CONTROL LINE HOUSING RUBBER OBSERVED BACK AT SHAKERS DURING DRESSOFF. FLOWCHECK FOR 10 MIN PRIOR TO PULLING OFF BOTTOM(STATIC) -6 FT MANGLED PIECE OF 9-5/8"CASING RECOVERED IN SHOE AT SURFACE OVERSHOT RUN#10: MAKEUP AND RUN IN HOLE WITH 6-3/8"OD X 5-1/4"ID OVERSHOT FROM SURFACE TO TOP OF TUBING AT 606' MD. -CONTINUED ON 11/17/16 Printed 12/5/2016 8:53:59AM *AII depths reported in Drillers Depths* North America-ALASKA-BP Page 30 of 47 Operation Summary Report Common Well Name:G-13 AFE No Event Type:WORKOVER(WO) Start Date:11/3/2016 End Date:11/25/2016 Z3-001X7-E:(2,630,000.00) Project:Prudhoe Bay Site:PB G Pad Rig Name/No.:PARKER 272 Spud Date/Time:7/13/1981 12:00:00AM !Rig Release:11/25/2016 Rig Contractor:PARKER DRILLING CO. UWI:500292060000 Active datum:G-13 OKB @65.97usft(above Mean Sea Level) Date From-To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (usft) 11/17/2016 00:00 - 02:00 2.00 FISH N DPRB 95.00 DECOMP OVERSHOT RUN#10 CONTINUED: ENGAGE TAPERED TUBING STRING FISH AT 610'MD (TOP OF TUBING)WITH 5 KLBS DOWN. CONFIRM WITH 102 KLBS PICKUP WEIGHT. PULL OUT OF HOLE WITH 5-1/4"OVERSHOT ASSEMBLY FROM 610 MD TO SURFACE (OVERSHOT DEPTHS).DISENGAGE SPEAR AND LAY DOWN. -FLOWCHECK WELL FOR 10 MIN ON BOTTOM AND AT BHA(STATIC) NO ISSUES PULLING THROUGH DAMAGED 9-5/8"CASING AREA WITH OVERSHOT AND TOP OF TUBING. WEAR ON COLLAR INDICATES IT WAS WASHED OVER.SIGNIFICANT AMOUNT OF MATERIAL INSIDE TOP OF 4-1/2"TUBING. 02:00 - 02:30 0.50 PULL P DECOMP RIG UP TO LAY DOWN TUBING -SLB SPOOLER FOR CONTROL LINES -DOYON CASING 5-1/2"DOUBLE STACK TONGS -SETUP WELL CONTROL EQUIPMENT AND HOLD PJSM Printed 12/5/2016 8:53:59AM *All depths reported in Drillers Depths* • North America-ALASKA-BP • Page 31 of 47 Operation Summary Report Common Well Name:G-13 AFE No Event Type:WORKOVER(WO) Start Date:11/3/2016 End Date:11/25/2016 Z3-001X7-E:(2,630,000.00) Project:Prudhoe Bay Site:PB G Pad Rig Name/No.:PARKER 272 Spud Date/Time:7/13/1981 12:00:00AM Rig Release:11/25/2016 Rig Contractor:PARKER DRILLING CO. UWI:500292060000 Active datum:G-13 OKB©65.97usft(above Mean Sea Level) Date From-To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (usft) 02:30 - 13:00 10.50 PULL P DECOMP PULL OUT OF HOLE AND LAYDOWN 4-1/2"X 3-1/2"TAPERED TUBING STRING FROM 6405' MD(BLIND BACKOFF POINT)TO SURFACE INITIAL PICKUP WEIGHT=85 KLBS(P272 BLOCKS+TD=35 KLBS) -NO CONTROL LINES,3/8"CABLE OR CLAMPS FOR FIRST 15 JOINTS(615')OUT OF THE HOLE ON THIS LAYDOWN EVENT (ACTUAL JOINT NUMBER 12-27 IN ORIGINAL STRING). CONTROL LINES HAD BEEN BANDED TO PIPE PRIOR TO LEAVING STRING ON BOTTOM FOR BOPE TEST,BUT LINES WERE NO LONGER PRESENT UPON RETREIVAL. -ALL CONTROL LINE EQUIPMENT WITH RUBBER ENCAPSULATION BEGINS TO PULL WITH TUBING AT JOINT#27,-1100'OUT OF THE HOLE. -OBSERVE-10K OVERPULL EVERY 40', QUARTER TURNS TO LEFT OR RIGHT ALLOW STRING TO PULL FREE RACK BACK 24 STANDS OF 3-1/2"TUBING (31'JOINTS,2255'TOTAL LENGTH)FOR USE AS KILL STRING AT END OF WELL -TOTAL EQUIPMENT RECOVERED FROM WELL: (1)TBG HGR ASSY,(1)4-1/2"SSSV NIPPLE ASSY,(51)FULLJOINTS4-1/2",12.6#, L-80,TDS TUBING,(1)COLLAPSED JT 4-1/2" TUBING,(1)4-1/2"X 3-1/2"XO ASSY,(135) TOTAL JOINTS 3-1/2",9.2#,L-80,TDS TUBING, (2)3-1/2"GLM ASSYS,19 RUBBER CLAMPS -TOTAL EQUIPMENT UNINTENTIONALLY LEFT IN WELL: APPROX 500'-1000'OF CONTROL LINES,APPROX 500'3/8'CABLE,LARGE AMOUNT OF RUBBER CONTROL LINE ENCAPSULATION MATERIAL,APPROX.7 RUBBER CLAMPS -INSPECT ALL EQUIPMENT FOR NORM PRIOR TO LEAVING LOCATION(NEGATIVE) -TOP OF TUBING STUB IS 1677'ABOVE PROD PACKER AT 8083'MD,488'BELOW ESTIMATED TOC IN 9-5/8"ANNULUS AT 5917'MD 13:00 - 14:00 1.00 PULL P DECOMP RIG DOWN AFTER LAYING DOWN TUBING 14:00 - 14:30 0.50 PULL P DECOMP SERVICE AND LUBRICATE RIG 14:30 - 15:00 0.50 WHSUR N DFAL 6,424.00 DECOMP UNSUCCESSFULLY ATTEMPT TO SET 9-1/6"ID WEAR RING. HANG UP IN THE STACK WHILE TRYING TO RUN IN HOLE WITH WEAR RING. DECISION TO NOT INSTALL. RETRIEVE SIGNIFICANT BALL OF CONTROL CONTROL LINES&3/8"CABLE FROM BOP STACK AND WELLHEAD(SEE ATTACHED PHOTO) Printed 12/5/2016 8:53:59AM *AII depths reported in Drillers Depths* • • North America-ALASKA-BP Page 32 of 47 Operation Summary Report Common Well Name:G-13 AFE No Event Type:WORKOVER(WO) Start Date:11/3/2016 End Date:11/25/2016 Z3-001X7-E:(2,630,000.00) Project:Prudhoe Bay Site:PB G Pad Rig Name/No.:PARKER 272 Spud Date/Time:7/13/1981 12:00:00AM Rig Release:11/25/2016 Rig Contractor:PARKER DRILLING CO. I UWI:500292060000 Active datum:G-13 OKB @65.97usft(above Mean Sea Level) Date From-To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (usft) 15:00 - 00:00 9.00 CLEAN N DFAL 6,424.00 DECOMP WELLBORE CLEANOUT(UNPLANNED) OPERATIONS: MILL RUN#17: MAKEUP AND RUN IN HOLE WITH 8-1/8"OD X 7-5/16"ID WASHOVER MILL ASSEMBLY PER LEVEL 1 OCN#12 FROM SURFACE TO TAG AT 73'MD. MILL DOWN TO 88'MD,THEN POOH TO INSPECT MILLS (SIGNIFICANT BUNDLE OF CONTROL LINES CAUGHT INSIDE MILL SHOE). I '-2 BPM,50-70 PSI,20 RPM,1-3 KFT-LBS TRQ ON BTM,2-15 KLBS WOB -MW IN/OUT=8.5 PPG VISCOSIFIED SEAWATER MILL RUN#18: MAKEUP AND RUN IN HOLE :WITH 8-1/8"OD X 7-5/16"ID WASHOVER MILL ASSEMBLY PER LEVEL 1 OCN#12 FROM SURFACE TO TAG AT 78'MD. MILL TO 109' MD. POOH TO INSPECT MILL(WASHPIPE 'PLUGGED WITH COMMINGLED BALL OF JUNK 1 'INCLUDING CONTROL LINES,CABLE, RUBBER AND MILLED TBG) , -2 BPM,50 PSI,50 RPM,1-5 KFT-LBS TRQ ON BTM MILL RUN#19: MAKEUP AND RUN IN HOLE WITH 8-1/8"OD X 7-5/16"ID WASHOVER MILL i ASSEMBLY PER LEVEL 1 OCN#12 FROM ' SURFACE TO TAG AT 101'MD.MILL TO 120' I MD. EASILY REAM IN HOLE WITH WASHOVER MILL ASSEMBLY FROM 120'MD TO 140'MD. EASILY RUN IN HOLE FROM 140' I MD TO 150'MD. PULL UP HOLE TO 85'MD WITH NO ISSUES. ATTEMPT TO WASH IN HOLE TO HARD TAG AT 110'MD. ATTEMPT TO MILLAHEAD FOR 30 MIN WITH NO PROGRESS -2 BPM,35-70 PSI,50 RPM,3-5 KFT-LBS TRQ ON BTM -CONTINUE ON 11/18/16 Printed 12/5/2016 8:53:59AM *All depths reported in Drillers Depths* North America-ALASKA-BP Page 33 of 47 Operation Summary Report Common Well Name:G-13 AFE No Event Type:WORKOVER(WO) Start Date:11/3/2016 End Date:11/25/2016 Z3-001X7-E:(2,630,000.00) Project:Prudhoe Bay Site:PB G Pad Rig Name/No.:PARKER 272 Spud Date/Time:7/13/1981 12:00:00AM Rig Release:11/25/2016 Rig Contractor:PARKER DRILLING CO. UWI:500292060000 Active datum:G-13 OKB @65.97usft(above Mean Sea Level) Date From-To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (usft) 11/18/2016 00:00 - 10:00 10.00 FISH N DFAL 6,424.00 DECOMP WELLBORE CLEANOUT OPERATIONS CONTINUED: MILL RUN#19 CONTINUED: PULL OUT OF HOLE FROM 150'MD WITH WASHOVER MILL ASSEMBLY(NO JUNK OR FISH RECOVERED). -CARBIDE ON BOTTOM EDGE OF WASHOVER MILL SHOE 100%WORN OFF. MILL RUN#20: MAKEUP AND RUN IN HOLE WITH MULE SHOE AND 8-1/2"WATERMELON MILLASSEMBLY PER OCN#14 FROM SURFACE TO TAG AT 93'MD(MILL DEPTH). EASILY REAM DOWN TO 119'MD(MILL DEPTH). MAKE 7 PASSES ACROSS DAMAGED AREA OF 9-5/8"CASING WITH AND WITHOUT PUMPS AND ROTATION. RUN IN HOLE ADDITIONAL 95'TO 214'MD(MILL DEPTH) WITH NO ISSUES. POOH AND INSPECT MILL (1/32"UNDER GAUGE,MINOR WEAR) -STAGE UP PUMPS TO 10 BPM,70 PSI,50 RPM,1 KFT-LBS TRQ ON/OFF BTM,0-1 KLBS WOB,IA/OA=20 PSI SIGNIFICANT AMOUNT OF RUBBER IN RETURNS AT SHAKERS DURING REAMING -MW IN/OUT=8.5 PPG VISCOSIFIED SEAWATER -FLOWCHECK WELL FOR 10 MIN PRIOR TO PULLING OFF BTM(STATIC) MILL RUN#21: MAKEUP AND RUN IN HOLE WITH MULE SHOE AND TANDEM 8-1/2" WATERMELON MILLASSEMBLY PER OCN#14 FROM SURFACE TO TAG AT 93'MD(LEADING MILL DEPTH). EASILY MILL FROM 93'MD TO 120'MD.ABLE TO WIPE THROUGH TIGHT SPOT WITH AND WITHOUT ROTATION. -STAGE UP PUMPS TO 10 BPM,70 PSI,50 RPM,0.5-3K TRQ,IA/OA=20 PSI -MW IN/OUT=8.5 PPG VISCOSIFIED SEAWATER -FLOW CHECK WELL FOR 10 MIN PRIOR TO PULLING OFF BTM(STATIC) MILL RUN#22:MAKEUP AND RUN IN HOLE WITH 8-3/8"WASHOVER MILL ASSEMBLY WITH 8-1/8"WASHPIPE PER OCN#12 FROM SURFACE TO TAG AT 110'MD WITH 5K DOWN. MILLED FROM 110'-112'MD.PULL OUT OF HOLE FROM 112'MD AND LAY DOWN WASHOVER MILL ASSEMBLY. -STAGE UP PUMPS TO 4 BPM,35 PSI,10-15 RPM,2-5 KFT-LBS TRQ,2-3 KLBS WOB,IA/OA =20 PSI -UNABLE TO WORK DOWN PAST 112'MD -MW IN/OUT=8.5 PPG VISCOSIFIED SEAWATER -FLOW CHECK WELL FOR 10 MIN PRIOR TO PULLING OFF BTM(STATIC) Printed 12/5/2016 8:53:59AM *AII depths reported in Drillers Depths* • North America-ALASKA-BP Page 34 of 47 Operation Summary Report Common Well Name:G-13 AFE No Event Type:WORKOVER(WO) Start Date:11/3/2016 End Date:11/25/2016 Z3-001X7-E:(2,630,000.00) Project:Prudhoe Bay Site:PB G Pad Rig Name/No.:PARKER 272 Spud Date/Time:7/13/1981 12:00:00AM Rig Release:11/25/2016 Rig Contractor:PARKER DRILLING CO. UWI:500292060000 Active datum:G-13 OKB @65.97usft(above Mean Sea Level) Date From-To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (usft) 10:00 - 11:30 1.50 CLEAN N DPRB 6,424.00 DECOMP SAFETY STAND DOWN TO REVIEW FIRST AID INCIDENT WHILE CHANGING OUT BHA. -MINOR CUT RESULTED FROM CONTACT MADE BETWEEN BHA COMPONENTS AND FACE ON RIG FLOOR -TR@CTION#2016-IR-535097 11:30 - 12:00 0.50 CLEAN N DFAL 6,424.00 DECOMP MILL RUN#23(WELLBORE CLEANOUT): MAKEUP AND RUN IN HOLE WITH 8-1/2" CONCAVE JUNK MILL WITH 8-1/2" I WATERMELON MILL ASSEMBLY PER OCN#15 FROM SURFACE TO 135'MD. -FLOWCHECK WELL FOR 10 MIN PRIOR TO RIH(STATIC) -NO ISSUES PASSING DAMAGED 9-5/8" CASING AT 110'MD 12:00 - 17:30 5.50 CLEAN N DFAL 6,424.00 DECOMP MILL RUN#23(WELLBORE CLEANOUT): TRIP IN HOLE WITH 8-1/2"CONCAVE MILL ASSEMBLY FROM BHAAT 135'MD TO TAG TUBING STUB AT 6424'MD(19'DEEPER THAN CALCULATED OFF OF PIPE RECOVERED VS ORIGINAL PIPE TALLY). -NO ISSUES TRIPPING THROUGH 9-5/8" CASING �-OBSERVED 5K DRAG FROM 2,610'MD TO BOTTOM -CONFIRM TAG WITH 15 KLBS DOWN. 17:30 - 19:30 2.00 CLEAN N DFAL 6,424.00 DECOMP MILL RUN#23(WELLBORE CLEANOUT): CIRCULATE HOLE CLEAN WITH HI-VIS SWEEP SURFACE TO SURFACE OVER 2 TOTALS BOTTOMS UP -420 GPM,550 PSI,NO ROTATION, RECIPROCATE 20'STROKES AT 10 FPM -LARGE VOLUME OF RUBBER IN RETURNS DURING FIRST BOTTOMS UP 19:30 - 22:00 2.50 CLEAN N DFAL 6,424.00 DECOMP MILL RUN#23(WELLBORE CLEANOUT): PULL OUT OF THE HOLE WITH 8-1/2"CONCAVE MILLASSEMBLY FROM TUBING STUB AT 6424' MD TO BHA AT 135'MD. -PULLING SPEED=150 FPM -FLOWCHECK WELL FOR 10 MIN PRIOR TO PULLING OFF BOTTOM AND AT BHA(STATIC) 22:00 - 23:00 1.00 CLEAN N DFAL 6,424.00 DECOMP MILL RUN#23(WELLBORE CLEANOUT): LAYDOWN 8-1/2"CONCAVE MILL TOOLS i FROM 135'MD TO SURFACE. -HOLD STOP THE JOB DRILL WITH AAR AND DISCUSSION ABOUT RECENT FIRST AID INCIDENT. 23:00 - 00:00 1.00 CLEAN N DFAL 6,424.00 DECOMP CLEAN AND CLEAR RIG FLOOR -GREASE AND INSPECT TOP DRIVE,GREASE BLOCKS PULL MASTER BUSHINGS,CLEAN RUBBER AND METAL OUT OF THE FLOW BOX -BEGIN TO MU WASHOVER ASSEMBLY,PICK I UP BOOT BASKET AND INSTALL FLOAT IN FLOAT SUB Printed 12/5/2016 8:53:59AM *All depths reported in Drillers Depths* • • North America-ALASKA-BP Page 35 of 47 Operation Summary Report Common Well Name:G-13 1 AFE No Event Type:WORKOVER(WO) Start Date:11/3/2016 End Date:11/25/2016 Z3-001X7-E:(2,630,000.00) Project:Prudhoe Bay I, Site:PB G Pad Rig Name/No.:PARKER 272 Spud Date/Time:7/13/1981 12:00:00AM Rig Release:11/25/2016 Rig Contractor:PARKER DRILLING CO. UWI:500292060000 Active datum:G-13 OKB @65.97usft(above Mean Sea Level) Date From To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (usft) 11/19/2016 00:00 - 02:00 2.00 FISH N DFAL 6,424.00 DECOMP CONDUCT KICK WHILE OUT OF HOLE DRILL: HIGH LEVEL H2S RIG EVACUATION AND MAN DOWN DRILL -HOLD AAR AFTER DRILL WITH DISCUSSION 1 AROUND ROSTER ACCOUNTABILITY WHEN � SITE CONTROL IS THE MAN DOWN -WELLBORE MONITORED CONTINUOUSLY THROUGHOUT THE DRILL(STATIC) 02:00 - 05:00 3.00 FISH N DFAL 6,424.00 DECOMP WELLBORE CLEANOUT(UNPLANNED) Ili OPERATIONS: MILL RUN#24 CONTINUED:MAKE UP AND I RUN IN HOLE WITH 8-3/8"OD X 7-1/8"ID WASHOVER MILLASSEMBLY(4'SHOE+6' EXTENSION)PER OCN#16 FROM SURFACE , TO TAG AT 111'MD.UNABLE TO PASS 111'MD. 1 POOH AND INSPECT SHOE,OBSERVE MINOR I WEAR ON LEADING EDGE. ' -UNABLE TO WORK PAST 111'MD WITH ' ORIENTATION TURNS AND CONSTANT 20 RPM I -MW IN/OUT=8.5 PPG VISCOSIFIED SEAWATER MILL RUN#25:MAKE UP AND RUN IN HOLE !WITH FLEXIBLE 8-3/8"OD X 7-1/8"ID I WASHOVER MILLASSEMBLY(4'SHOE+6' !EXTENSION+STAND OF 5"DRILLPIPE ABOVE ' WASHPIPE)FROM SURFACE TO TAG AT 111' MD.POOH AND INSPECT MILL SHOE, OBSERVE WEAR ON LEADING EDGE. -UNABLE TO WORK PAST 111'MD WITH 50 RPM,1-2 KFT-LBS TRQ 1 '-MW IN/OUT=8.5 PPG VISCOSIFIED SEAWATER MILL RUN#26:MAKE UP AND RIN IN HOLE WITH FLEXIBLE SHORT 8-3/8"OD X 7-1/8"ID WASHOVER MILL ASSEMBLY(4'SHOE+(2) STANDS OF 5"DP ABOVE SHOE)FROM SURFACE TO TAG AT 104'MD.ABLE TO WORK THROUGH WITH ORIENTATION TURNS AND 50 RPM.TOTAL BHA LENGTH 338'. PAINTED INSIDE OF WASHOVER SHOE AS I TATTLE-TALE TO MONITOR FOR JUNK I ENTERING INSIDE OF SHOE WHILE MILLING. -ATTEMPT TO WORK PAST 101'MD WITH I ORIENTATION TURNS,50 RPM,1-2 KFT-LBS I TRQ. 105:00 - 09:00 4.00 FISH N DFAL , 6,424.00 DECOMP MILL RUN#26(CONTINUED):TRIP IN HOLE WITH FLEXIBLE SHORT 8-3/8"OD WASHOVER MILLASSEMBLY ON ELEVATORS TO TOP OF 1 3-1/2"TUBING STUB AT 100 FPM. Printed 12/5/2016 8:53:59AM *AII depths reported in Drillers Depths* • North America-ALASKA-BP • Page 36 of 47 Operation Summary Report Common Well Name:G-13 AFE No Event Type:WORKOVER(WO) Start Date:11/3/2016 End Date:11/25/2016 Z3-001X7-E:(2,630,000.00) Project:Prudhoe Bay Site:PB G Pad Rig Name/No.:PARKER 272 Spud Date/Time:7/13/1981 12:00:00AM Rig Release:11/25/2016 Rig Contractor:PARKER DRILLING CO. UWI:500292060000 Active datum:G-13 OKB©65.97usft(above Mean Sea Level) Date From-To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (usft) 09:00 - 11:00 2.00 FISH N DFAL 6,424.00 DECOMP MILL RUN#26(WELLBORE CLEANOUT) CONTINUED: CLEAN UP TOP OF TUBING STUB. TAG ON DEPTH AT 6424'MD. MILL DOWN TO 6428'MD(4'WASHOVER MILL SWALLOW) -250 GPM,220 PSI,50 RPM,3-6 KFT-LBS TRQ ON BOTTOM,2-6 KLBS WOB MW IN/OUT=8.5 PPG SEAWATER -CIRCULATE AROUND HI-VIS SWEEP FROM SURFACE TO SURFACE AT END OF MILLING WITH NO SIGNIFICANT INCREASE IN RETURNS. 11:00 - 13:30 2.50 FISH N DFAL 6,424.00 DECOMP MILL RUN#26(WELLBORE CLEANOUT) CONTINUED: PULL OUT OF THE HOLE WITH 8-3/8"WASHOVER FROM 6428'MD TO BHA AT 338'MD. -PULLING SPEED=150 FPM -FLOWCHECK WELL FOR 10 MIN PRIOR TO PULLING OFF BOTTOM AND AT BHA(STATIC) 13:30 - 14:00 0.50 FISH N DFAL 6,424.00 DECOMP MILL RUN#26(WELLBORE CLEANOUT) CONTINUED: LAYDOWN 8-3/8"OD WASHOVER MILL ASSEMBLY FROM 338'MD TO SURFACE OBSERVE WEAR INSIDE MILL INDICATING FULL SWALLOW OF MILLACHEIVED ON TUBING STUMP 14:00 - 14:30 0.50 FISH N DFAL 6,424.00 DECOMP SERVICE AND LUBRICATE RIG 14:30 - 16:00 1.50 FISH -- N DFAL 6,424.00 DECOMP OVERSHOT RUN#11(FISH 3-1/2"TUBING): MAKEUP AND RUN IN HOLE WITH 6-3/8"OD X 3-1/2"GRAPPLE OVERSHOT ASSEMBLY WITH EXTENSION AND PACKOFF FROM SURFACE TO 124'MD. -FLOWCHECK WELL FOR 10 MIN PRIOR TO RIH(STATIC) 16:00 - 17:30 1.50 FISH N DFAL 6,424.00 DECOMP OVERSHOT RUN#11 (FISH 3-1/2"TUBING) CONTINUED: RUN IN HOLE WITH 6-3/8" OVERSHOT ASSEMBLY FROM BHA AT 124'TO 3100'MD 17:30 - 18:00 0.50 FISH N DFAL 6,424.00 DECOMP KICK WHILE TRIPPING DRILL WITH MAN DOWN COMPLICATION+AAR WITH RIG TEAM Printed 12/5/2016 8.53.59AM *AII depths reported in Drillers Depths* • North America-ALASKA-BP •• Page 37 of 47 Operation Summary Report Common Well Name:G-13 AFE No Event Type:WORKOVER(WO) Start Date:11/3/2016 End Date:11/25/2016 Z3-001X7-E:(2,630,000.00) Project:Prudhoe Bay Site:PB G Pad Rig Name/No.:PARKER 272 Spud Date/Time:7/13/1981 12:00:00AM Rig Release:11/25/2016 Rig Contractor:PARKER DRILLING CO. UWI:500292060000 Active datum:G-13 OKB©65.97usft(above Mean Sea Level) Date From-To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (usft) 18:00 - 20:30 2.50 FISH N DFAL 6,424.00 DECOMP OVERSHOT RUN#11(FISH 3-1/2"TUBING) CONTINUED: RUN IN HOLE WITH 6-3/8" OVERSHOT ASSEMBLY FROM 3100'MD TO TAG TUBING STUMP AT 6429'MD. UNABLE TO INITIALLY LATCH UP STUMP. WASH AREA WITH 10 BPM AND THEN ABLE TO WASH OVER TUBING STUMP TO 6435'MD. --CONFIRM LATCH WITH OVERPULL. UNABLE TO CONFIRM LATCH WITH PUMP PRESSURE (PACKOFF NOT HOLDING). -PU/SO WEIGHTS=178/167 KLBS COMPLETE BLIND BACKOFF: -TARGET DEPTH=PROD PACKER AT 8083' MD(1660'OF 3-1/2",9.2#,-13 KLBS BOUYANT WEIGHT) -WORK PIPE BETWEEN 195 KLBS AND 210 KLBS WHILE APPLYING LEFT HAND TORQUE IN 1/2-1 WRAP INCREMENTS. -OBSERVE TORQUE DROPOFF WITH 3 WRAPS AND 4 KFT-LBS SURFACE TORQUE. -BACKOUT WITH 9 ADDITIONAL WRAPS WHILE CONTINUING TO WORK STRING -BETWEEN 195 KLBS AN 210 KLBS NEW PU WEIGHT=181 KLBS(INDICATING ONLY-375'OF PIPE RECOVERED VS GOAL OF 1660') 20:30 - 00:00 3.50 FISH N DFAL 6,424.00 DECOMP OVERSHOT RUN#11(FISH 3-1/2"TUBING) CONTINUED: PULL OUT OF HOLE WITH 6-3/8" OVERSHOT ASSEMBLY FROM 6435'MD TO 600'AT MIDNIGHT(OVERSHOT DEPTHS). -PULLING SPEED=150 FPM -FLOWCHECK WELL FOR 10 MIN PRIOR TO PULLING OFF BOTTOM AND AT BHA(STATIC) 11/20/2016 00:00 - 00:30 0.50 FISH N DPRB 6,424.00 DECOMP OVERSHOT RUN#11(FISH 3-1/2"TUBING) CONTINUED: PULL OUT OF HOLE WITH 6-3/8" OVERSHOT ASSEMBLY FROM 600'MD AT MIDNIGHT TO BHAAT 124'MD. 00:30 - 01:30 1.00 FISH N DPRB 6,424.00 DECOMP OVERSHOT RUN#11 (FISH 3-1/2"TUBING): LAYDOWN 6-3/8"OVERSHOT ASSEMBLY FROM 124'MD TO SURFACE(OVERSHOT DEPTHS). DISENGAGE OVERSHOT FROM TOP OF TUBING STUMP(TOP OF 3-1/2"TBG STUB PINCHED IN TO 2-3/8"ID VS ORIGINAL 2.992",LIKELY FROM WASHOVER MILL,SEE ATTACHED PHOTO). 01:30 - 02:00 0.50 FISH N DPRB 6,424.00 DECOMP RIG UP TUBING HANDLING EQUIPMENT -VERIFIED ID OF HANDING EQUIPMENT FOR TUBULAR OD CLEARANCE _ 02:00 - 02:30 0.50 FISH N DPRB 6,424.00 DECOMP LAY DOWN 3-1/2",9.2#,L-80,TDS PRODUCTION TUBING(434') -11 FULL JOINTS,1 30'GLM ASSEMBLY,&2 FULL JOINTS BELOW GLM RECOVERED -NEW BACK OFF POINT AT 6,865'MD -FINAL JOINT HAS GOOD CONDITION PIN POINTING DOWN LEAVING TUBING STUB DOWNHOLE WITH BOX FACING UP. -FLOWCHECK WELL FOR 10 MIN(STATIC) 02:30 - 03:00 0.50 FISH N DPRB 6,424.00 DECOMP RIG DOWN TUBING HANDLING EQUIPMENT AND REDRESS Printed 12/5/2016 8.53:59AM "All depths reported in Drillers Depths* • North America-ALASKA-BP • Page 38 of 47 Operation Summary Report Common Well Name:G-13 'AFE No Event Type:WORKOVER(WO) Start Date:11/3/2016 End Date:11/25/2016 Z3-001X7-E:(2,630,000.00) Project:Prudhoe Bay Site:PB G Pad Rig Name/No.:PARKER 272 Spud Date/Time:7/13/1981 12:00:00AM Rig Release:11/25/2016 Rig Contractor:PARKER DRILLING CO. UWI:500292060000 Active datum:G-13 OKB©65.97usft(above Mean Sea Level) Date From-To I Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (usft) 03:00 - 06:30 3.50 PULL P DECOMP OVERSHOT RUN#12(FISH 3-1/2"TUBING): MAKEUP AND RUN IN HOLE WITH 6-3/8"OD GRAPPLE OVERSHOT ASSEMBLY FROM SURFACE TO 6,863'MD. OVERSHOT AND GRAPPLE MADE UP TO 1 STAND OF 5"DP -NO DRILL COLLARS OR JARS TO ALLOW CLEARANCE FOR E-LINE TOOLS TO PASS THROUGH — — -MINIMUM ID RESTRICTION=2-11/16" 06:30 - 08:00 1.50 PULL P DECOMP OVERSHOT RUN#12(FISH 3-1/2"TUBING): TAG TUBING STUB AT 6863'MD AND WASH DOWN THROUGH 2'OF DEBRIS ON TOP OF FISH TO 6,865'MD.INITIALLY UNABLE TO LATCH UP TO TUBING STUB. WASHED OVER AREA AT 5-10 BPM WITH 1/4 1 TURN ORIENTATION TURNS. -ENGAGED GRAPPLE WITH 10K DOWN. CONFIRM LATCH WITH 5K OVERPULL. 08:00 - 10:00 2.00 PULL P DECOMP RIG UP ELINE: -PRE JOB SAFETY MEETING PRIOR TO RIG UP E-LINE -RIG UP SHEAVE TO ELEVATORS AND WIRELINE BEAM,RUN CABLE THROUGH SHEAVES AND RAISE TOP DRIVE -MU 2-1/2"ELINE WEIGHTED DRIFT I TOOLSTRING WITH CCL FOR ELINE RUN#1 10:00 - 13:00 3.00 PULL P DECOMP ELINE RUN#1:RIH WITH 2-1/2"DRIFT TOOLSTRING WITH CCL THROUGH 5"DP DRIFT UNABLE TO PASS THROUGH 6,864' ELMD(TOP OF 3-1/2"TUBING STUB) -ATTEMPT TO PASS THROUGH RESTRICTION 'WITH VARIABLE SPEEDS.DRIFT TAGGED UP HARD,WITH NO STICKING ON THE UPSTROKE -PULL 2-1/2"DRIFT CCL TOOLSTRING TO SURFACE AND LD 113:00 - 16:00 3.00 PULL N DPRB 6,865.00 DECOMP 1ELINE RUN#2:RIH WITH 2-1/8"DRIFT TOOLSTRING WITH CCL THROUGH 5"DP TO 8,037'MD '-ABLE TO PASS THROUGH 6,864'MD WITH NO ISSUE -TAG AT 8,037'ELMD(TOP OF GLM#1), UNABLE TO PASS THROUGH -POOH WITH 2-1/8"OD DRIFT CCL TOOLSTRING AND LD 16:00 - 18:30 2.50 PULL N WAIT 6,865.00 DECOMP WAIT FOR APPROVAL OF PLAN FORWARD AND FOR DELIVERY OF STRING SHOT EQUIPMENT Printed 12/5/2016 8:53:59AM *All depths reported in Drillers Depths* • North America-ALASKA-BP Page 39 of 47 Operation Summary Report Common Well Name:G-13 AFE No Event Type:WORKOVER(WO) Start Date:11/3/2016 End Date:11/25/2016 Z3-001X7-E:(2,630,000.00) Project:Prudhoe Bay Site:PB G Pad Rig Name/No.:PARKER 272 Spud Date/Time:7/13/1981 12:00:00AM Rig Release:11/25/2016 Rig Contractor:PARKER DRILLING CO. UWI:500292060000 Active datum:G-13 OKB©65.97usft(above Mean Sea Level) Date From-To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (usft) 18:30 - 19:30 1.00 PULL P DECOMP MAKE UP TOP DRIVE AND BEGIN TARGETED BACK OFF OPERATIONS: -HOLD PJSM PRIOR TO JOB -TARGET DEPTH=7,981'MD(2 JOINTS ABOVE GLM#1),1,120'OF 3-1/2",9.2#TBG, 9 KLBS BUOYANT WEIGHT -WORK PIPE UP AND DOWN SEVERAL TIMES TO ENSURE STRING IS FREE OF ALL TORQUE -APPLY 1.5 ROUNDS OF LEFT HAND TURN IN 1/4 TO 1/2 TURN INCREMENTS AND WORK DOWN THE STRING -DID NOT EXCEED 3.5 KFT-LBS TORQUE AT SURFACE -WORK PIPE BETWEEN 191 KLBS AND 197 KLBS(9-15KLBS OVERPULL) -LOCKED ROTARY TABLE AND SET SLIPS WITH PIPE IN TENSION 191'KLBS AND 3 KFT-LBS LEFT HAND TORQUE IN PREPERATION FOR STRING SHOT 19:30 - 23:30 4.00 PULL P DECOMP ELINE RUN#3:MAKE UP TOOLSTRING WITH STRING SHOT(3 STRINGS),ARM AND RIH. LOCATE COLLAR WITH CCL AT 7,984'ELMD. PU 11'TO PLACE MIDDLE OF STRING SHOT AT 7,984'ELMD.DETONATE STRING SHOT. POOH WITH ELINE TOOLSTRING. 23:30 - 00:00 0.50 PULL P DECOMP COMPLETE TARGETED BACK OFF OF 3-1/2" TUBING: -MAKE UP TOP DRIVE AND OBSERVE 0 KFT-LBS TORQUE -BACK OUT 3-1/2"TUBING PER SLB FISHING REP WITH 10 TOTAL WRAPS WHILE CONTINUING TO WORK STRING BETWEEN 197 KLBS AND 185 KLBS. -WORK TORQUE DOWN 3K ATA TIME -NEW PU WT=191 KLBS(INDICATING 1,120' OF PIPE RECOVERED) -FLOW CHECK WELL FOR 10 MIN PRIOR TO PULLING OFF BOTTOM(STATIC) 11/21/2016 00:00 - 01:00 1.00 PULL P DECOMP WHILE LATCHED ONTO-1,100'TUBING FISH WITH OVERSHOT CIRCULATE BOTTOMS-UP 1.5 TIMES -420 GPM,380 PSI -PUMPED 30 BBL HI-VIS SWEEP WITH NO SIGNIFICANT INCREASE IN RETURNS _-RDMO SLB E-LINE UNIT 01:00 - 04:00 3.00 PULL P DECOMP POOH ON ELEVATORS WITH OVERSHOT ASSEMBLY FROM TOP OF 3-1/2"TUBING FISH AT 6,865'MD TO SURFACE(1,100'MD 3-1/2" TUBING NEXT TO LAY DOWN) -MONITOR WELL FOR 10 MINUTES(STATIC). PUMP DRY JOB. -PU 191 K,SO 180KAT 6,865'MD(OVERSHOT DEPTH) -150 FPM PULLING SPEED 04:00 - 04:30 0.50 PULL P DECOMP DISENGAGE SLB OVERSHOT AND LAY DOWN FISHING TOOLS.RIG UP DOYON CASING TONGS AND SWAP HANDLING/WELL CONTROL EQUIPMENT. -3/8"CABLE AND CONTROL LINE JUNK JAMMED INSIDE OF OVERSHOT Printed 12/5/2016 8:53:59AM *All depths reported in Drillers Depths* • North America-ALASKA-BP Page 40 of 47 Operation Summary Report Common Well Name:G-13 AFE No Event Type:WORKOVER(WO) Start Date:11/3/2016 End Date:11/25/2016 Z3-001X7-E:(2,630,000.00) Project:Prudhoe Bay Site:PB G Pad Rig Name/No.:PARKER 272 Spud Date/Time:7/13/1981 12:00:00AM Rig Release:11/25/2016 Rig Contractor:PARKER DRILLING CO. UWI:500292060000 Active datum:G-13 OKB @65.97usft(above Mean Sea Level) Date From-To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (usft) 04:30 - 05:30 1.00 PULL P DECOMP MAKE UP MILLING ASSEMBLY OFFLINE WHILE WAITING ON DOYON CASING TO LAY 3-1/2"TUBING PICK UP AND MAKE UP FLAT BOTTOM MILL, XO,5'PUP JT,WATERMELON MILLAND LAY DOWN IN PIPE SHED 05:30 - 07:30 2.00 PULL P DECOMP LAY DOWN 3-1/2",9.2#,L-80,TDS TUBING FROM STRING SHOT BACKOFF POINT TO SURFACE -35 FULL JOINTS RECOVERED,MATCHING TARGET BACKOFF POINT,NO VISIBLE DAMAGE ON BACKED OFF PIN FROM STRING SHOT -1 30'GLM ASSEMBLY -NEW TOP OF TUBING STUB AT 7,981'MD WITH BOX END FACING UP. 07:30 - 08:00 0.50 PULL P DECOMP CLEAN AND CLEAR RIG FLOOR.RIG DOWN POWER TONGS AND ELEVATORS. 08:00 - 08:30 I 0.50 CLEAN P DECOMP MILL RUN#27:MAKE UP AND RIH WITH 8-1/2" CONCAVE JUNK MILL ASSEMBLY WITH 8-1/2" WATERMELON MILL TO 134'MD. -TOOK WEIGHT AT-111'MD.ABLE TO WORK THROUGH WITH ORIENTATION. 08:30 - 12:30 4.00 CLEAN P DECOMP TRIP IN HOLE WITH 8-1/2"JUNK MILL ASSEMBLY FROM BHAAT 134'MD TO 7,922' MD.STRING MILL DEPTH AT 7,900'MD -RUNNING SPEED=150 FPM TOOK 10-15K WEIGHT AT 2,600'MD.WEIGHT FELL OFF AND ABLE TO WORK UP AND DOWN THROUGH SPOT WITH NO ISSUES. -PU/SO=220K/195KLBS @ 7,900'MD 12:30 - 14:00 1.50 CLEAN P DECOMP CIRCULATE HI-VIS SWEEP SURFACE TO SURFACE -415 GPM,800 PSI -50 RPM,5 KFT-LBS TORQUE -NO SIGNIFICANT CHANGE IN RETURNS 14:00 - 17:00 3.00 CLEAN P DECOMP POOH ON ELEVATORS FROM 7,922'MD TO 134'MD -MONITOR WELL FOR 10 MINUTES PRIOR TO PULLING OFF BOTTOM AND PULLING NONSHEARABLES INTO THE STACK(STATIC) -MONITOR WELL VIA TRIP TANK(GOOD DISPLACEMENT) 17:00 - 18:30 1.50 CLEAN P DECOMP LAY DOWN COLLARS AND BHA AS PER SLB FISHING FROM 134'MD TO SURFACE -NO JUNK OR DEBRIS FOUND IN BOOT 'BASKETS CLEAN AND CLEAR RIG FLOOR. 18:30 - 19:00 0.50 CLEAN P DECOMP GREASE TOP DRIVE,BLOCKS AND WASHPIPE,INSPECT TOP DRIVE AND DERRICK. 19:00 - 23:00 4.00 PXA P DECOMP MAKE UP EZSV RUNNING TOOL ON DP AS PER HALLIBURTON REP AND MAKE A DRIFT RUN THROUGH THE STACK AND WELLHEAD. PULL BACK TO SURFACE AND INSTALL EZSV PER HES REP.RIH FROM SURFACE TO 7,900' MD AT 90 FPM. -PU/SO=212K/188 KLBS AT 7,830'MD -MONITOR WELL VIA TRIP TANK=GOOD DISPLACEMENT Printed 12/5/2016 8:53:59AM *AII depths reported in Drillers Depths* • • North America-ALASKA-BP Page 41 of 47 Operation Summary Report Common Well Name:G-13 AFE No Event Type:WORKOVER(WO) I Start Date:11/3/2016 End Date:11/25/2016 Z3-001X7-E:(2,630,000.00) Project:Prudhoe Bay Site:PB G Pad Rig Name/No.:PARKER 272 Spud Date/Time:7/13/1981 12:00:OOAM Rig Release:11/25/2016 Rig Contractor:PARKER DRILLING CO. UWI:500292060000 Active datum:G-13 OKB @65.97usft(above Mean Sea Level) Date From-To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (usft) 23:00 - 00:00 1.00 PXA P DECOMP SET EZSV AT 7,900'MD(TOP OF PLUG)PER HES REP WITH 35 TURNS TO THE RIGHT AND 45 KLBS OVERPULL.OBSERVE GOOD SET. -PU/SO=212K/188 KLBS -WEIGHT TEST WITH 15KLBS DOWN,SLACK OFF TO 173 KLBS FROM 188 KLBS ORIGINAL 11/22/2016 00:00 - 01:30 1.50 PXA P DECOMP HANG OFF DRILL STRING ON HES 9-5/8" RTTS. -RACK BACK 2 STANDS FROM TOP OF EZSV -MU RTTS WITH PORTED SUB AND DRILLPIPE SCREEN -RIH WITH RTTS AND SET AT 60'MD -RACK BACK 1 STAND AND LAY DOWN RUNNING TOOL 01:30 - 02:00 0.50 BOPSUR P DECOMP FLUSH STACK AND FUNCTION RAMS FOLLOWING MILLING OPERATIONS -FUNCTION ALL RAMS AND ANNULAR ABOVE TEST PLUG TO ENSURE NO DEBRIS IN STACK 02:00 - 03:30 1.50 BOPSUR P DECOMP CHANGE UPPER RAMS FROM 9-5/8"FIXED RAMS TO 2-7/8"X 5"VBR'S -PRE JOB FOR CHANGING UPPER RAMS -CLOSE BLIND SHEARS AND LINE UP TO MUD GAS SEPARATOR.MONITOR WELL VIA CHARGE PUMP. -RIG UP FOR BOPE TESTING -BLOW AIR THROUGH CEMENT LINE FOR UPCOMING CEMENT JOB 03:30 - 05:00 1.50 BOPSUR P DECOMP INSTALL TEST PLUG,RIG UP TEST HOSES AND FILL ALL LINES. -PERFORM SHELL TEST 05:00 - 09:00 4.00 BOPSUR P DECOMP TEST BOPE TO 250 PSI LOW,3,500 PSI HIGH FOR 5 MINUTES EACH AS PER AOGCC AND BP REQUIREMENTS -TEST WITH 3-1/2"AND 5"TEST JOINTS -TEST ALARMS,PVT AND FLOW SHOW. -TEST WITNESS WAIVED BY AOGCC REPRESENTATIVE JEFF JONES 09:00 - 09:30 0.50 PXA P DECOMP PULL HES RTTS TO RIG FLOOR PER HES AND LAY DOWN -RIH TO PICK UP RTTS WITH RUNNING TOOL AND 1 STAND '09:30 - 10:00 0.50 PXA P DECOMP RIH AND TAG TOP OF EZSV AT 7,900'MD WITH 15 KLBS DOWN -RIG UP FOSV WITH HEAD PIN -RIG UP CEMENT LINE,SWING AND LOW TORQUE VALVE 10:00 - 14:00 4.00 PXA P DECOMP CIRCULATE AND CONDITION FLUID WHILE RIGGING UP FOR CEMENT JOB AND WAITING ON CH2 WATER TRUCK 360 GPM,400 PSI Printed 12/5/2016 8:53:59AM "All depths reported in Drillers Depths* • • North America-ALASKA-BP Page 42 of 47 Operation Summary Report Common Well Name:G-13 AFE No Event Type:WORKOVER(WO) Start Date:11/3/2016 End Date:11/25/2016 Z3-001X7-E:(2,630,000.00) Project:Prudhoe Bay I Site:PB G Pad Rig Name/No.:PARKER 272 Spud Date/Time:7/13/1981 12:00:00AM Rig Release:11/25/2016 Rig Contractor:PARKER DRILLING CO. UWI:500292060000 Active datum:G-13 OKB @65.97usft(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 PXA P DECOMP PUMP BALANCED CEMENT PLUG -FILL LINES WITH WATER AND PRESSURE TEST TO 250 PSI LOW/3,500 PSI HIGH FOR 5 MINUTES EACH -PUMP 120 BBLS OF 15.8 PPG CEMENT FOLLOWED BY 5 BBLS WATER AT 5 BPM,220 PSI -DISPLACE WITH RIG PUMPS WITH 88 BBLS 8.5 PPG SEAWATER ! 1-580 SACKS,1.16 CUFT/SACK -ESTIMATED TOC AT 6,260'MD -CEMENT IN PLACE AT 16:00 -11 HOURS TO 500 PSI COMPRESSIVE STRENGTH AT 0300 HRS 16:00 - 17:00 1.00 PXA P DECOMP PULL OUT OF CEMENT ON ELEVATORS AT 60 FT/MIN FROM 7,990'MD TO 5,793'MD(23 STANDS) -PU=220 KLBS @ 7,990'MD MONITOR WELL VIA TRIP TANK(GOOD ' I DISPLACEMENT) 17:00 - 18:00 ' 1.00 PXA P DECOMP PUMP DRILL PIPE WIPER BALLAND NUT PLUG SWEEP TO CLEAN CEMENT !CONTAMINATED 5"DRILL PIPE '-415 GPM,285 PSI 18:00 - 18:30 0.50 PXA P r DECOMP PULL OUT OF HOLE ON ELEVATORS FROM 5,793'MD TO 3,614'MD -PU/SO=147K/138KAT 5,793'MD -MONITOR WELL VIA TRIP TANK(GOOD 1 DISPLACEMENT) 18:30 - 19:30 1.00 PXA P DECOMP RUN IN HOLE WITH CEMENT CONTAMINATED PIPE FROM 3,614'MD TO 5,698'MD -PU/SO=118K/115KLBS AT 3,614'MD -MONITOR WELL VIA TRIP TANK(GOOD DISPLACEMENT) 19:30 - 21:00 1.50 PXA P DECOMP PUMP NUT PLUG SWEEP SURFACE TO SURFACE TO CLEAN CEMENT CONTAMINATED 5"DRILL PIPE I 415 GPM,285 PSI 21:00 - 00:00 I 3.00 PXA 1 P DECOMP I PULL OUT OF HOLE ON ELEVATORS FROM 5,698'MD TO SURFACE AND LAY DOWN EZSV RUNNING TOOL -PU/SO=147K/138KLBS AT 5,698'MD -MONITOR WELL VIA TRIP TANK(GOOD ,' } DISPLACEMENT) 11/23/2016 00:00 - 03:30 3.50 PXA P 1 DECOMP RUN IN HOLE ON ELEVATORS TO 5760'MD ' AND PREPARE TO TAG TOP OF CEMENT PLUG ROLLERCONE BIT,BIT SUB,FLOAT SUB, STABALIZER(-10') -MW IN/OUT=8.5 PPG f -MONITOR WELL VIA TRIP TANK(GOOD DISPLACEMENT) 03:30 - 04:30 1.00 PXA P DECOMP ATTEMPT TO WASH DOWN AND TAG TOP OF I CEMENT PLUG -EXPECTED TOP OF CEMENT AT 6,260'MD -PU/SO=170K/160KLBS,2 BPM,80PSI -ENCOUNTER SOFT CEMENT AT 6,230'MD WITH 7-10K DRAG,110 PSI PUMP PRESSURE ' -CONTINUE TO 6,247'MD WITHOUT HARD TAG,PU 20'AND CIRCULATE BOTTOMS UP Printed 12/5/2016 8:53:59AM *AII depths reported in Drillers Depths* • North America-ALASKA-BP r Page 43 of 47 Operation Summary Report Common Well Name:G-13 AFE No Event Type:WORKOVER(WO) I Start Date:11/3/2016 End Date:11/25/2016 Z3-001X7-E:(2,630,000.00) Project:Prudhoe Bay Site:PB G Pad Rig Name/No.:PARKER 272 I Spud Date/Time:7/13/1981 12:00:00AM Rig Release:11/25/2016 Rig Contractor:PARKER DRILLING CO. UWI:500292060000 Active datum:G-13 OKB©65.97usft(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 PXA P DECOMP CIRCULATE BOTTOMS UP AT 6,230'MD, AFTER BU PICK UP TO 6,040'MD AND CONTINUE TO CIRCULATE -9 BPM,384 PSI OBSERVE GREEN CEMENT AND NUT PLUG RETURNS OVER SHAKERS 06:00 - 06:30 0.50 PXA P DECOMP WASH DOWN FROM 6,040'MD TO TOP OF CEMENT AT 6,248'MD AND TAG WITH 15 KLBS DOWN -2 BPM,80 PSI 06:30 - 07:30 1.00 PXA P DECOMP CIRCULATE BOTTOMS UP AT 6,248'MD -8.5 BPM,330 PSI '-30 RPM,2 KFT-LBS TORQUE -RECIPROCATE 25 FT DURING CIRCULATION 07:30 - 09:00 1.50 PXA P DECOMP WAIT ON STATE REPRESENTATIVE FOR WITNESS OF CEMENT TAG 09:00 - 17:00 8.00 PXA P DECOMP PULL OUT OF HOLE ON ELEVATORS FROM 6,248'MD TO SURFACE -MONITOR WELL FOR 10 MINUTES(STATIC) -PU/SO=1361Q134KLBS AT 5,057'MD 17:00 - 18:30 1.50 PXA P DECOMP RUN IN HOLE AND INSTALL CIBP PER HALLIBURTON REP AT 1,600'(TOP OF PLUG) AND VERIFY WITH 10KLBS DOWN -PICK UP RUNNING TOOL AND MAKE UP TO DRILL STRING -RIH AT 90 FT/MIN TO 1,603'MD -PU/SO=68K/72KLBS -MONITOR WELL VIA TRIP TANK(GOOD 'DISPLACEMENT) -SET CIBP AS PER HES REP,35 RIGHT HAND TURNS,PICK UP IN 10KLBS INCREMENTS UNTIL SHEAR AT 50 KLBS OVER -SET DOWN 10K TO VERIFY SET 18:30 - 19:00 0.50 PXA P DECOMP DISPLACE WELL FROM 8.5 PPG SEAWATER TO 9.8 PPG BRINE -300 GPM,80 PSI 19:00 - 20:00 1.00 PXA P DECOMP PULL OUT OF HOLE FROM 1,600'MD TO SURFACE AND LAY DOWN RUNNING TOOL -PU/SO=68K/72KLBS AT 1,600'MD -MONITOR WELL VIA TRIP TANK(GOOD DISPLACEMENT) 20:00 - 23:30 3.50 PXA P DECOMP RUN IN HOLE WITH CASING CUTTER AND CUT 9-5/8"CASING AT 1,580'MD PER SLB FISHING REPRESENTATIVE -WASH DOWN AT 2 BPM,385 PSI -LOCATE COLLAR WITH KNIVES AT 1,567'MD -PU/SO=68K/71 KLBS -80 RPM,0-5K TORQUE,125 GPM,300-775 PSI -CLEAR INDICATION OF CASING CUT, PRESSURE DROP FROM 775 PSI TO 80 PSI -CONFIRMED GOOD CUT BY HOLDING KNIVES IN OPEN POSITION AND PU WITH 10KLBS OVERPULL 20 MINUTES INTO CUTTING OPERATIONS, BEGIN TO OBSERVE SMALL VOLUMES OF ARCTIC PACK IN THE POSSUM BELLY.BEGIN TO DUMP ARCTIC PACK RETURNS DIRECTLY INTO CUTTINGS BOX.CONTINUE WITH CUTTING OPERATIONS. Printed 12/5/2016 8:53:59AM *AII depths reported in Drillers Depths* North America-ALASKA-BP • Page 44 of 47 Operation Summary Report Common Well Name:G-13 1AFE No Event Type:WORKOVER(WO) Start Date:11/3/2016 End Date:11/25/2016 Z3-001X7-E:(2,630,000.00) Project:Prudhoe Bay Site:PB G Pad Rig Name/No.:PARKER 272 Spud Date/Time:7/13/1981 12:00:00AM Rig Release:11/25/2016 Rig Contractor:PARKER DRILLING CO. UWI:500292060000 Active datum:datum:G-13 OKB©65.97usft(above Mean Sea Level) Date From-To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (usft) 23:30 - 00:00 0.50 PXA P DECOMP LUBRICATE RIG,GREASE TOP DRIVE AND BLOCKS -BUILD 70 BBLS OF 9.8 BRINE IN THE PILL PITS 11/24/2016 00:00 - 02:30 2.50 PXA P DECOMP BUILDING AND WAITING ON FLUIDS FROM 1 BAROID MUD PLANT TO CIRCULATE OUT ARCTIC PACK 1 -ARCTIC PACK U-TUBED INTO IA FROM HOLE IN 9-5/8"AT 110' '-ADDITIONAL FLUID REQUIRED TO FULLY DISPLACE ARCTIC PACK PRIOR TO PULLING OUT OF THE HOLE 02:30 - 03:30 1.00 PXA P DECOMP CIRCULATE OUT ARCTIC PACK -2 BPM,380 PSI,SHUT OFF PUMPS ONCE RETURNS WERE CLEAN -FLOW CHECK WELL FOR 10 MINUTES, OBSERVED ARCTIC PACK SWAPPING WITH BRINE IN STACK 03:30 - 05:00 1.50 PXA P DECOMP PULL OUT OF HOLE ON ELEVATORS FROM 1,600'MD TO SURFACE -FLOW CHECK WELL FOR 10 MINUTES PRIOR TO PULLING OFF BOTTOM(STATIC) 05:00 - 08:00 3.00 PXA P DECOMP .MAKE UP EZSV RUNNING TOOL ON DP AS PER HALLIBURTON REP AND RUN IN HOLE. UNABLE TO PASS THROUGH 98'MD. -ATTEMPT TO WORK THROUGH WITH ORIENTATION TURNS AND 10 KLBS DOWN, UNABLE TO PASS THROUGH 98'MD. -PICK UP STABALIZER AND RUN IN HOLE WITHOUT EZSV AS A DRIFT RUN,ABLE TO PASS THROUGH WITHOUT ISSUE TO 130'MD -PICK UP EZSV AGAIN TO ATTEMPT TO RUN THROUGH,STILL UNABLE TO PASS 98'MD 08:00 - 08:30 0.50 PXA N DPRB 1,580.00 DECOMP WAIT ON ORDERS AND PLAN FORWARD FROM TOWN. 08:30 - 12:00 3.50 FISH N DPRB 1,580.00 DECOMP MILL RUN#28:8-1/2"FLAT BOTTOM MILL,XO, 5'PUP AND(2)8-1/2"WATERMELON MILLS, TOTAL BHA LENGTH=23'.MILL FROM 91'MD TO 115'MD. -MAKE UP AND RUN IN HOLE,TAG UP AT 91' MD -BEGIN TO MILL DOWN AT 6 BPM,145 PSI,60 RPM,0.5 KFT-LBS TORQUE OFF BTTM -OBSERVED ERRATIC TORQUE FROM 91'TO 96' 1-5 KFT-LBS.AFTER WORKING DOWN, TORQUE AND WOB DROPPED OFF. -OBSERVED TORQUE AND WEIGHT AGAIN AT 104'MD,MILLED DOWN TO 115'MD WITH 2-3 1 KFT-LBS TORQUE AND 3 KLBS WEIGHT ON BIT. -ABLE TO PASS THROUGH SECTION WITH NO ROTATION AND PUMPS OFF WITH NO ISSUES. Printed 12/5/2016 8:53:59AM *AII depths reported in Drillers Depths* • North America-ALASKA-BP • Page 45 of 47 Operation Summary Report Common Well Name:G-13 AFE No Event Type:WORKOVER(WO) Start Date:11/3/2016 End Date:11/25/2016 Z3-001X7-E:(2,630,000.00) Project:Prudhoe Bay Site:PB G Pad Rig Name/No.:PARKER 272 Spud Date/Time:7/13/1981 12:00:00AM I Rig Release:11/25/2016 Rig Contractor:PARKER DRILLING CO. I UWI:500292060000 ..-__--.---_ Active datum:G-13 OKB @65.97usft(above Mean Sea Level) Date From-To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (usft) 12:00 - 13:30 1.50 PXA P DECOMP MAKE UP EZSV ON DP PER HALLIBURTON REP,RUN IN HOLE AND SET AT 1,561'MD. ABLE TO PASS THROUGH TROUBLE AREA WITH NO ISSUE.STING INTO EZSV WITH 5" DP. -SET EZSV AT 1,561'MD.APPLY 35 ROUNDS OF RIGHT HAND ROTATION.PICK UP TO SHEAR OFF IN 10 KLB INCREMENTS. OBSERVE SHEAR AT 43 KLBS OVERPULL. -PICKUP 5'AND APPLY 25 RIGHT HAND TURNS TO EXTEND STINGER AND STING INTO EZSV WITH 25 KLBS DOWN. 13:30 - 15:30 2.00 PXA P DECOMP CIRCULATE SURFACE TO SURFACE THROUGH CUT IN 9-5/8"CASING AT 1,580'MD. PUMP SOAP PILL TO ENSURE NO RESIDUAL ARCTIC PACK IN THE OA. -3-5 BPM,80-130 PSI 1 15:30 - 18:00 2.50 PXA P DECOMP CEMENT 9-5/8"X 13-3/8"ANNULUS WITH 125 BBLS 15.8 PPG CEMENT FROM 1,580'MD TO SURFACE FILL LINES WITH WATER AND PRESSURE TEST 250 PSI/LOW,3,000 PSI/HIGH FOR 5 MINUTES EACH PUMP 125 BBLS OF 15.8 PPG CEMENT AT 4 BPM,220 PSI -TAKE RETURNS TO THE PITS UNTIL CEMENT REACHES SURFACE.BEGIN TO DIVERT RETURN FLOW OUT OF IA/OA INTO THE CELLAR BOX -605 SACKS,1.16 CUFT/SACK -TOC AT 110'MD -CEMENT IN PLACE AT 17:00 -4:05 HR:MM THICKENING TIME 18:00 - 18:30 0.50 PXA P DECOMP PULL OUT OF HOLE ON ELEVATORS FROM 1,560'MD TO SURFACE AND LAY DOWN STINGER -MONITOR WELL FOR 10 MINUTES(STATIC) -PU/SO=67K/70KLBS AT 1,560'MD 18:30 - 19:00 0.50 PXA P DECOMP LUBRICATE RIG,GREASE AND INSPECT TOP DRIVE,CHECK OIL LEVELS. 19:00 - 19:30 0.50 PXA P DECOMP RIG UP DOYON CASING EQUIPMENT AND SLIP TYPE ELEVATORS 19:30 - 23:00 3.50 PXA P DECOMP MAKE UP HANGER AND LANDING JOINT.RUN IN HOLE WITH 16 STANDS OF 3-1/2"TUBING TO 1,541'MD AND LAND IN TUBING SPOOL. -MONITOR WELL VIA TRIP TANK(GOOD DISPLACEMENT) 23:00 - 00:00 1.00 PXA N SFAL 1,561 00 DECOMP UNABLE TO RUN IN LOCK DOWN SCREWS. PULL HANGER BACK TO SURFACE AND TAP LOCK DOWNS.CEMENT CREW HOURED OUT, RELEASE SCHLUMBERGER CEMENTERS WHILE CONDUCTING WELLHEAD WORK. CONTINUED ON 11/25/2016. Printed 12/5/2016 8:53:59AM *All depths reported in Drillers Depths* North America-ALASKA-BP Page 46 of 47 Operation Summary Report Common Well Name:G-13 No ',Z3-0 Event Type:WORKOVER(WO) Start Date:11/3/2016 End Date:11/25/2016 3-0 01X7-E:(2,630,000.00) Project:Prudhoe Bay Site:PB G Pad Rig Name/No.:PARKER 272 Spud Date/Time:7/13/1981 12:00:00AM Rig Release:11/25/2016 Rig Contractor:PARKER DRILLING CO. UWI:500292060000 Active datum:G-13 OKB©65.97usft(above Mean Sea Level) Date From-To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (usft) 11/25/2016 00:00 - 03:00 3.00 PXA N SFAL 1,561.00 DECOMP CONTINUED FROM 11/24/2016:TAP LOCK DOWN SCREWS PER CAMERON REP. REMOVE METAL SHAVINGS AND DEBRIS FROM LOCK DOWNS AND TAP THREADS. -CLEAR RIG FLOOR -RIG DOWN RIG TONGS,SUCK OUT DRIP PANS ON RIG FLOOR -LAY DOWN 16 STANDS OF 5"DRILL PIPE OFFLINE -CLEAN PITS AND PREPARE MUD MOD FOR RIG MOVE 03:00 - 04:00 1.00 PXA P DECOMP RE-LAND TUBING HANGER AND RUN IN LOCK DOWN SCREWS PER CAMERON REP WITH NO ISSUE. 04:00 - 09:30 5.50 RIGD P POST CONTINUE TO PREPARE FOR RIG MOVE WHILE WAITING ON SCHLUMBERGER CEMENTERS,EXPECTED TO RETURN AT 0900 HRS. -CLEAN PITS AND SUCK OUT DRIP PANS ON RIG FLOOR -REMOVE OFFLINE AND ROTARY MOUSEHOLES -BLOW DOWN CHOKE,KILLAND HOLE FILL LINES !-CHANGE SAVER SUB TO 4"HT-38 FOR UPCOMING WELLS -REMOVE TURN BUCKLES AND HOLE FILL LINE FROM STACK -PREP ROOF TOP TO SKID RIG FLOOR -RIG DOWN INNER-CONNECTS 09:30 11:30 2.00 PXA P DECOMP CEMENT TUBING/IA/OA TO SURFACE -SCHLUMBERGER CEMENTERS BACK ON j LOCATION AT 09:00 AND VERIFY RIG UP -FLUID PACK LINES AND VERIFY CIRCULATION THROUGH IA AND OA -BREAK CIRCULATION THROUGH IAAND OA TO CONFIRM ABILITY TO CIRCULATE -PUMP 28 BBLS OF 10 PPG MUDPUSH II SPACER AT 3 BPM(130 PSI)FOLLOWED BY 110 BBLS OF 15.8 PPG CEMENT DOWN TUBING AND OUT IA UNTIL CLEAN RETURNS OBSERVED IN THE CELLAR. -CLOSE IA VALVES AND OPEN OA,PUMP 7 BBLS OF CEMENT UNTIL CLEAN RETURNS OBSERVED IN CELLAR. -ATTEMPT TO SQUEEZE CEMENT INTO OOA, NO CEMENT RETURNS OBSERVED IN THE CELLAR. -FLUSH 5 BBLS OF WATER WITH OPEN IA VALVE -TOTAL OF 117.2 BBLS OF 15.8 PPG CEMENT PUMPED AT 4 BPM(250 PSI),1.16 CUFT/SACK, 567 SACKS. 11:30 - 12:00 0.50 PXA P DECOMP RIG UP CEMENT LINE TO BLEEDER AND PUMP 15 BBLS OF WATER TO CUTTINGS BOX TO FLUSH LINE -FLUSH SECONDARY VALVES ON WELLHEAD 12:00 - 13:00 1.00 RIGD P POST PERFORM DERRICK AND TOP DRIVE INSPECTION,BREAK BOLTS ON STACK AND RISER. Printed 12/5/2016 8.53:59AM *AII depths reported in Drillers Depths* • North America-ALASKA-BP Page 47 of 47 Operation Summary Report Common Well Name:G-13 AFE No Event Type:WORKOVER(WO) Start Date:11/3/2016 End Date:11/25/2016 Z3-001X7-E:(2,630,000.00) Project:Prudhoe Bay Site:PB G Pad Rig Name/No.:PARKER 272 Spud Date/Time:7/13/1981 12:00:00AM Rig Release:11/25/2016 Rig Contractor:PARKER DRILLING CO. I UWI:500292060000 Active datum:G-13 OKB @65.97usft(above Mean Sea Level) Date From-To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (usft) 13:00 - 15:00 2.00 RIGD P POST NIPPLE DOWN BOPE,PULL BELL NIPPLE, REMOVE TURN BUCKLES AND RACK STACK BACK ON STUMP.REMOVE RISER AND LAY DOWN IN PIPE SHED. 15:00 - 16:30 1.50 RIGD P POST CLEAN OUT HANGER PROFILE AND RING GROOVES,MIX AND POUR 2 BAGS OF DRY CEMENT INTO TUBING AND CELLAR BOX, NIPPLE UP DRY HOLE TREE AS PER CAMERON REP. -SIMOPS:SECURE TOP DRIVE AND UNPIN BLOCKS,LAY DOWN PIPE CAT,REMOVE ROOF TOP WALKWAYS 16:30 - 18:00 1.50 RIGD P POST BRIDAL DOWN,UNHOOK RIG FLOOR INTERCONNECT LINES,PIN BRIDAL LINES TO BLOCKS AND HOIST TO POSITION.SECURE FORUM CRANE AND SERVICE LOOPS. END G-13A PM EVENT.RIG RELEASE 11/25/16 AT 18:00.BEGIN C-36A EVENT. Printed 12/5/2016 8:53:59AM *All depths reported in Drillers Depths* • G-13A (Post-Rig Suspend) GTI:' !ATE,._,! " ''1►4 1 P T/I/O = SV/0/0. Temp = SI. Measure cellar box. (Pre- P &A). Cellar box is 11' X 9'8". Cellar is -2' deep from top of flooring. Wellhead is centered 2'10" from the left(9:00 position) and 4'10" from the front of the box (6:00 position). Double casing valves on the IA & OA extend from the well head on the right side (3:00 position). SSV, flow cross, flow line, well head scaffolding, flow line &well house are all removed. 11/26/2016 SV= C. MV= O. IA, OA= OTG. 02:55 T/I/O = ?/0/0. Temp = SI. Cellar prep (Pre P&A). No wellhouse, flowline or scaffolding. Dry hole tree installed. Cellar has a cement bottom with a small amount of oily fluid around casing. Removed wellhouse flooring and installed a high temp visqueen covering with a heater. Thawed cellar for 40 minutes and confirmed a cement bottom. Heater left installed. Barriers left around cellar. 11/27/2016 SV, MV= ?. IA, OA= OTG. 1130 hrs. T/I/O = 0/0/0. Temp = SI. Excavate cellar(P&A). Wellhouse, wellhouse floor, flowline & well scaffold removed. 2nd CV installed on IA& OA. Water washed &jack hammered cement from cellar. Unable to remove cement from cellar w/Super Sucker due to the hose getting clogged &signs of hydro carbons beneath cement. Stopped job to reassess future job scope path. 11/28/2016 SV, MV= C. SSV= NA. IA, OA= OTG. 15:30 T/I/O= 0/0/0. Removed 3" IA TEMP#42 and 3" OA TEMP#18 . Installed integral flanges and block valves. Torqued to API specs. RDMO***Job Complete*** SEE LOG FOR 11/30/2016 DETAILS. Final T/1/0= 0/0/0. well scaffold removed. Dry hole tree installed. Block Valves installed on IA& OA. Excavate cellar with mini excavater to a depth of 48" removing -10 yards of gravel and cement. SV, MV= C. IA, OA= OTG. 14:00 12/1/2016 T/I/O = 0/0/0. Temp = SI. Strap TOC (P&A). Wellhouse, wellhouse floor, flowline &well scaffold removed. Dry hole tree installed. Block Valves installed on IA& OA. Tag TOC in Tbg = 55" and it's dry, IA= 54" and dry, OA= 8" and dry. SV, MV= C. IA, OA= OTG. 15:00 12/2/2016 T/I/O = 0/0/0. Temp = SI. Remove wellhead (P&A). Wellhouse, wellhouse floor, flowline & well scaffold removed. Dry hole tree installed. Block Valves installed on IA& OA. Rig up Wachs saw . SV, MV= C. IA, OA= OTG. ...Job suspended for night continue on 12/04/2016 WSR... 12/3/2016 T/I/O= 0/0/0 Job Scope: Rig Up Crane and Wach's Golliath Guillotine Saw 1' below wellhead componants. Cut through 30"x 20" sealed conductor, 13 3/8" surface CSG, 9 5/8" intermediate CSG and 3 1/2" kill string. Remove wellhead &tree from P&A'd wellbore. Had issues with saw binding up. Had to release blade and attempted to get out with no luck. Repositioned saw lower on conductor for second cut and same issue occured. Able to work saw blade back out untill teeth jammed at starting point of cut. Stopped at that point and will round up wedges binders to help hold up sealed conductor while cutting.. ...Job 12/4/2016 suspended for night... • • G-13A (Post-Rig Suspend) T/I/O= 0/0/0 Job Scope: Remove wellhead &tree from P&A'd wellbore. Rig Up Crane and Wach's Golliath Guillotine Saw 1' below wellhead componants. Cut through 30"x 20" sealed conductor, 13 3/8" surface CSG, 9 5/8" intermediate CSG and 3 1/2" kill string. Tree removed with crane and sent to valve shop. Need to dress top of stub and give AOGCC 48 12/5/2016 hrs notice for inspecton. ...Suspend Permit for night... 12/6/2016 Job Scope: Prep well stub for AOGCC inspection. Visuil inspection of tree stub, dress off cement and take pictures. Heater and parachute left 12/8/2016 on cellar. • • :. OF +>C 411N', '. 4, X7:6 4 4 r g RWk i yg f F a ' 4 ,,,,,, ,,,,.,,,,' ,;'-':::',7-**,,,,,. .ti fix+ �3 4i � ,,,:,..,4,,, . r s Y ' 2 1 Fp a 4 At', . e • ' E x+" , e �y *y ., �,. . .r r n -1 c � if 3 .1 +f # 't ' r, • � _. r 1. gym., f x a G« „, F sr 4 -000 ... .. ,.. { . ...,„ . / ,.. ... .. ...„, ..,„,... s t }h� Y".y 4 4 ( / ! , 1. r p t 4. 1 , w 1 1 t ;., _ i A.,,..,s, . ., . ,..„ ,, ,,...„,, ,.,. _.... ,.. ., ' a .f,Erv9°'', 'A , 0 • Ci. 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E N. co a E ,..?,- o N- a) _1 > um >, 1 E a) Fp o N. < -a CCC) = CFCC -c. -0-c 0 co co co = •••• E co ..4- CLZ• 0- a- 6 6 th 'n g18 61) (3';(3 G g C°- ,— E a. 7; co (6 Z- ii '9 E < -0 C) C .. os 4-, `6 C a 0 •0, CD 5 _c (N 0 0 o, `s. ,- TREE= MCEVOY ` WELLHEAD= MCEVOY P&A • _ silly NOTES: ACTUATOR= AXLESON I /OA1TBG CMT I 3A KB.aEV= 65.97' TO SURFACE BF.ELEV= 37.52' c•: ♦♦ ••••O• ••• 'XI, 1540' 3-1/2' L STRING,9.2#L-80,3200' 11125116 O ♦•r►♦••• ••i••♦•i• •X♦+, .0087bpf„D=2.992' Max Angle= 96°@ 10090' ••••:•••••► ♦••••••••t•i,V•♦• J 1 110' ♦4.♦_♦.♦_•_♦•4't l 1661• H 9-5/8"FES EZSV(11/24/16) Datum MD= 9179' 20"COND • Datum TVD= 8800'SS •4 . ....♦i' ♦♦ •♦•♦� { 1600' H9-5/8"FES EZSV(11/23/16) HOLE N 13-3/8'X 9-5/8"(11/23/16) H 95' -110' I13-3/8"X 9-5/8"CMT PLUG(11/23/16) -{-110 -1580' 2689' I 9-5/8"DV FKR 1,9-5/8"CSG CUT(11123/16)- 1580' 13-3/8"CSG,72#,L-80 MRS, -I 2672' D=12.347" Minimum ID = 1.90" @ 8150' - -6248'I- {CMT PLUG(11/22/16) TIW XO -TOP OF 2-3/8" LN R iii•••••••••:i••••••4• ►•••••••••••••••• 7900' I—{95/8"FES tZSV(11/21116) -oval 8079'1H3-112"XO TO 4-1/2",ID=3.95" TOP OF 3-1/2 TBG STIR(11/21/16) 7981' ._,1—[� j _ _ l r 8083' H9-5/8"TW FBBP R(R,D=4.00" TOP OF 7"LNR -{ 8137' 1 II ® 8093' -14-112'XO T O 3-1/2",D=3.958" TOP OF 2-3/8"LNR -J 8143' 8143' _ 2-3/8"TIWDEPLOY SLV,D=2.25" s 1w/3-1/2"BAITED BULLDOG SPEAR ,8116'SLM i i 8150' 1-I TIW CROSSOVER RN,D=1.90' j $ 4 1 i 4 9-5/8"LNR 47#,L-80 BTRS,D=8.681" H 8665' 1_41 i i , $ 4 $ 8773' —1 JET CUT TBG(04/06/08) TOP OF CEMENT(08/03/08) 8790' All.•i ,4���! 8810' —2-3/8'WFD CEP(04/05/08) 3-1/2"TBG,9.2#L-80 IDS,0087 bpf,D=2.992" —{ 9090' ►0 'M _ ................ PERFORATION SURMARY 1 0 j 3-1/2'&7"!&LOUT VVNDOW(G-13A)9090'-9094' REF LOG: SVVS CNL 2/21/01 •$.0 :• ANGLE AT TOP PERF: 48°@ 9263' %4ii•••,.I. • Note:Refer to Production DB for historical pert data 'ti• •SIZE SPF I TERVAL Opn/Sgz DATE �� •• 1-11/16" 4 9263-9278 C 08/02/03 .• ••4►4 ` 1-9/16" 6 9317-9337 C 05/06/01 .t....►♦ ` 1-9/16" 6 9345-9365 C 05/06/01 4♦•♦•♦4►•. a'••••••••••4►' 1-11/16" 6 9445-9555 C 02/22/01 , 1-11!16" 6 9624-9940 C 02/22/01 �♦�►.••••••••♦�►♦♦ ` ,I 1i $1•••4 ►♦ 1-11/16" 6 10000-10160 C 02/22/01 t.^••••• ►• 1-11/16" 6 10185-10260 C 02/22/01 44 ••••401 ►♦ ` 1-11/16" 6 10330-10460 C 02/22/01 • • ♦♦•♦♦•♦♦4 1-11/16" 6 10480 10600 C 02/22/01 ._•,..._•••••_•., 1-11/16" 6 10610-10690 C 02/22/01t 1M-FSTOCK �. PBTD a 10779' 1-11/16" 7 10611-10690 C 02/23/01 (01/07/01) �... .Al, 1-11/16" 8 10612-10690 C 02/24/01 •, 2-3/8'LNR,4.6#,L-80 STL, 0039 bpf,ID-1 995' 10844' 7"LW,29/1,L-80 BTRS,.0371 bpf,D=6.184" -I 9483' DATE REV BY COMVENTS DATE REV BY COMMENTS PRUDHOE BAY UNT ORIGINAL COMPLETION WELL: G-13A 1990 RWO _ fT No:"2001630 02/22/01 CTD SIDTRACK(G-13A) _ API No: 50-029-20600-01 11/25/16 P-272 P&A SEC 12,T1114,R13E,2224'NSL&2368'VVEL 11/28/16 JIVE) DRLG HO CORRECTIONS BP Exploration(Alaska) MEMORANDU State offIaska Alaska Oil and Gas Conservation Commission (l)Z-51)(‘) TO: Jim Regg �e� DATE: November 23, 2016 P. I. Supervisor FROM: Lou Grimaldi SUBJECT: Wellbore Plug Verification Petroleum Inspector BP Exploration PBU G-13A, PTD 2001630 Prudhoe Bay Field Wednesday, November 23, 2016: I witnessed the verification of plug placement by drill pipe tag for abandonment of BP Exploration's well G-13A in the Prudhoe Bay field. I arrived Nabors Drilling rig #272 to find the rig ready to tag. They had already washed down and tagged firm cement earlier this morning and had placed a chalk mark approximately 14 feet out on the stand in the hole. I obtained a copy of the rig's pipe tally with the BHA length applied, this is attached. I asked that they break circulation at 2 barrels per minute and wash down to tag. This was accomplished and a firm tag with 15,000 to 20,000 pounds set down on the plug with the 8 1A-inch bit. I observed a good solid plug with no weight let-off or sticking when they picked up off bottom. The rig tagged the plug at the same depth determined prior to my arrival — at the chalk mark on stand #66 (198 joints of drill pipe) plus a 9.5-foot bottomhole assembly (BHA). Referring to the pipe talley, and subtracting 14 feet (from stand #66) put this plug depth at approximately 6248 ft RKB. Attachments: Page 2 Rig-272 Pipe Tally 11-23-16 LG.pdf Non-Confidential SCANNED APR 0 7 2011 2016-1123_Plug_Verification_PBU_G-13A_Ig.docx 1 of 1 > 2c' 4 -1--4, cc SrecA6-t ol )( z-5j 14- - Lu2ti c Pt Ueh J '( Date: 11 2018 Pipe Description: r WWI Name: 0.1 • BHA Length: 9.78 •1 CE STD JT# Length Std Lng DP ONLY DP+BHA STD JT# Length Std Lng DP ONLY DP+BHA • 2/3 101 31.53 3188.95 3198.73 1/3 151 31.75 4768.05 4777.83 >' 34 102 31.88 94.68 3220.63 3230.31 25 152 31.51 4799.56 4809.34 . 1/3 103 31.51 3252.04 3261.82 51 183 31.60 94.88 4831.18 4840.94 ( 2/3 104 31.54 3283.58 3293.36 1r3 154 31.59 4862.75 4872.53 35 106 31.63 94.68 3316.21 3324.99 213 155 31.53 4894.28 4904.06 R 1/3 106 31.57 3346.78 3356.66 52 156 31.64 94.88 4925.82 4935.60 2/3 107 31.58 3378.34 3388.12 vs 157 31.53 4957.35 4967.13 38 108 31.72 94.85 3410.06 3419.84 2/3 158 31.58 4988.93 4998.71 1r3 109 31.55 - 3441.61 3451.39 53 169 31.61 94.82 5020.44 5030.22 213 110 31.56 3473.17 3482.95 1/3 160 31,48 5051.90 5061.68 37` 111 31.57 94.68 3804.74 3514.52 2/3 181 31.76 5083.68 5093.44 1n 112 31.60 3538.34 3546.12 54 162 31.48 94.70 6115.14 , 6124.92 2r3 113 31.58 3567.92 3577.70 113 163 31.57 5146.71 5156.49 38 114 31.54 94.72 3599.48 3609.24 2/3 184 31.58 5178.29 5188.07 1/3 115 31.60 3631.06 3640.84 55 185 31.55 94.70 5209.84 6219.82 2r3 116 31.41 3662.47 3872.25 1/3 188 31.52 5241.36 5251.14 39 117 31.88 94.89 3894.15 3703.93 2r3 187 31.57 5272.93 5282.71 1r3 118 31.52 3725.87 3735.46 56 188 31.49 94.58 5304.42 5314.20 2r3 119 31.51 3767.18 3786.98 113 169 31,62 5338.04 5345.82 40 120 31.54 94.87 3788.72 3798.60 2r3 170 31.60 5387.64 5377.42 1r3 121 31.55 3820.27 3830.05 57 171 31.59 94.81 5398.23 5409.01 213 122 31.73 3852.00 3861.78 15 172 31.58 5430.81 5440.59 41 123 31.48 94.78 3883.48 3893.26 213 173 31.67 5482.38 5472.16 1r3 124 31.45 3914.93 3924.71 58 174 31.85 94.70 6483.93 6803.71 2/3 126 31.73 3946.66 3956.44 • 1/3 175 31.60 5525.53 5535.31 42 128 31.57 94.75 3978.23 3988.01 2r3 176 31.61 5557.14 5588.92 1r3 127 31.58 4009.81 4019.59 59 177 31.67 94.78 6588.71 5598.49 2/3 128 31.52 4041.33 4051.11 1r3 178 31.66 6620.37 5630.15 43 129 31.67 94.77 4073.00 4082.78 213 179 31.58 5651.95 5861.73 1r3 130 31.54 4104.54 4114.32 60 180 91.80 94.84 6683.65 5893.33 2/3 131 31.71 4136.25 4146.03 1/3 181 31.67 5715.22 5725.00 44 132 31.61 94.78 4187.78 4177.54 2r3 182 31.69 5746.91 5758.89 113 133 31.30 4199.06 4208.84 61 183 31.68 95.04 5778.69 5788.37 " 2/3 134 31.84 4230.70 4240.48 1/3 184 31.55 5810.14 5819.92 45 136 31,58 94.60 4282.28 4272.04 2/3 185 31.76 5841.90 5851.68 1/3 138 31.57 4293.83 4303.61 62 188 3f.89 95.00 5873.69 5883.37- n 137 31.51 4325.34 4335.12 1r3 187 31.65 5905.24 5915.02 46 138 31.70 94.78 4357.04 4388.82 era 188 31.57 5936.81 5948.59 1/3 139 31.74 4388.78 4398.56 63 189 31.72 94.94 5988.53 5978.31 2/3 140 31.54 4420.32 4430.10 1r3 190 31.47 6000.00 6009.78 47 141 31.87 94.95 4451.99 4481.77 2r3 191 31.82 8031.62 8041.40 1/3 142 31.73 4483.72 4493.50 64 192 31.73 94.82 8063.36 8073.13 2/3 143 31.59 4515.31 4525.09 1E3 193 31.58 6094.93 6104.71 48 144 31.80 94.92 4546.91 4658.89 213 194 31.57 6128.50 8136.28 15 145 31.59 4578.50 4588.28 65 195 31.49 94.84 6157.99 6187.77 2/3 148 31.57 4610.07 4619.85 1/3 198 31.47 6189.48 6199.24 49 147 31.68 94.74 4841.65 4851.43 213 197 31.48 6220.94 6230.72 15 148 31.60 4673.25 4683.03 66 198 31.81 94.58 8252.55 8282.33 2/3 149 31.53 4704.78 4714.56 1)3 199 31.47 6284.02 6293.80 50 150 31.52 94.66 4738.90 4748.08 2/3 200 31.55 6315.57 6325.35 jr?‹.___ OP 1 • • Quick, Michael J (DOA) From: Quick, Michael.' (DOA) Sent: Monday, November 21, 2016 2:15 PM To: 'Browning,Zachary H' Cc: Egbejimba, Uchenna J; Daniel, Ryan Subject: RE: G-13A P&A request to approved program_Sundry 316-575 PTD 200-163 Zach— FCC) 20 ' \b� Thank you for the additional information. The Change to Sundry 316-575 for the PTD 200-163 as you outlined in this email is APPROVED. I will attach your updated procedure to the AOGCC well file. Michael Quick Sr. Petroleum Engineer Alaska Oil and Gas Conservation Commission 333 West Avenue Anchorage,tAK 99501 SCANNED JUN20 / (907)793-1231(phone) (907)276-7542(fax) mike.quickPalaska.gov 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 Mike Quick at 907-793-1231 or mike.auick@alaska.gov. From: Browning, Zachary H [mailto:Zachary.Browning@bp.com] Sent: Monday, November 21, 2016 2:10 PM To:Quick, Michael J (DOA)<michael.quick@alaska.gov> Cc: Egbejimba, Uchenna J<John.Egbejimba@uk.bp.com>; Daniel, Ryan <Ryan.Daniel@bp.com> Subject: RE: G-13A P&A request to approved program_Sundry 316-575 Michael, As discussed on the phone see my responses in blue below. Thanks, Zach From: Quick, Michael J (DOA) [mailto:michael.quick@alaska.gov] Sent: Monday, November 21, 2016 1:57 PM To: Browning, Zachary H Cc: Egbejimba, Uchenna 3; Daniel, Ryan Subject: RE: G-13A P&A request to approved program_Sundry 316-575 Zach— 1 • • How damaged/collapsed is the 9-5/8" casing? Do you have a ID? We believe we have cut-9' holes on each side of the casing during the initial wash over/milling operation performed to gain access to pull the tubing. However,we have been able to run 8.5" mills through that section without significant issue. Concern is how will you get a CIBP and Cement Retainer ran through the collapsed area? There is less of a concern for the CIBP since it's OD is-7.75"vs the 8.5" mills that have passed through that section.The bigger risk specific with the USIT is the chance that it could get fall into the openings or get pinched while pulling through and get stuck. Also, do you have indications that you will be able to circulate through the collapsed area in the 9-5/8"x 13-3/8" annulus to be able to get the cement in this annulus? We do not have certainty that we will be able to circulate. However the annulus should be clear of cement and we believe the collapse/damage to the 13-3/8"to be limited and not to the extent that circulation is significantly restricted. Michael Quick Sr. Petroleum Engineer Alaska Oil and Gas Conservation Commission 333 West 7th Avenue Anchorage,AK 99501 (907)793-1231(phone) (907)276-7542(fax) mike.quickPalaska.gov 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 Mike Quick at 907-793-1231 or mike.quick@alaska.gov. From: Browning,Zachary H [mailto:Zacharv.Browning@bp.com] Sent: Monday, November 21, 2016 1:14 PM To: Quick, Michael J (DOA)<michael.quick@alaska.gov> Cc: Egbejimba, Uchenna J<John.Egbeiimba@uk.bp.com>; Daniel, Ryan <Rvan.Daniel@bp.com> Subject:G-13A P&A request to approved program_Sundry 316-575 Michael, As you know,the G-13A P&A has been challenging.The rig is on day 19 and we have just finished pulling tubing and are currently preparing for the lower P&A.The lower P&A should be completed to plan. However,we would like approval for an alternative upper P&A plan. The original upper P&A plan was to cut and pull the 9-5/8" prior to pumping cement in the 13-3/8" casing. Given the collapsed 9-5/8" casing and high probability of damaged 13-3/8" surface casing at-100' we would like to cement with the 9-5/8" production casing in place.This would eliminate the risk of: • Sticking the USIT logging tool in the highly damaged section of the 9-5/8" casing at"'100' and complicate wellbore re-entry.The USIT is required to locate the top of cement in the 13-3/8"x 9-5/8" annulus prior to cutting and pulling the 9-5/8" casing. • Sticking the collapsed 9-5/8" casing while pulling through the likely damaged 13-3/8" casing. Alternatively,we would prefer to: 2 • • 1. Set a CIBP in the 9-5/8" production casing at—1600'above the likely top of cement in the 13-3/8"x 9-5/8" annulus. 2. Punch holes in the 9-5/8" casing above the CIBP at—1580'. 3. Run a cement retainer with 3-1/2" killstring and set at 1560'above the punched hole in the 9-5/8" casing. 4. Circulate out Artic Pack 5. Fully cement the 13-3/8"x 9-5/8" annulus through the cement retainer(min 96 bbls, 15.8 ppg class G). 6. Unsting from cement retainer and land the tubing hanger. 7. Cement the 3-1/2"tubing string and 9-5/8"x 3-1/2" annulus to surface (min 110 bbls, 15.8 ppg class G) . 8. ND/NU Updated Proposed Schematic attached. Please let us know if the State agrees with the above change of plans. -r-D �"° Regards, r Zach Zach Browning II CTD&RWO Engineer BP Alaska 0:(907)564-5220 C:(907)351-7941 Zachary.browning@bp.com 3 STATE OF ALASKA LASKA OIL AND GAS CONSERVATION COMMIS. REPORT OF SUNDRY WELL OPERATIONS , 1. Operations Performed Abandon 0 Plug Perforations ❑ Fracture Stimulate 0 Pull Tubing 0 Operations shutdown ❑ Suspend 0 Perforate 0 Other Stimulate 0 Alter Casing 0 Change Approved Program 0 Plug for Redrill 0 Perforate New Pool 0 Repair Well 0 Re-enter Susp Well 0 Other:Sus Well Inspection Rpt Q 2. Operator Name: BP Exploration(Alaska),Inc 4. Well Class Before Work 5. Permit to Drill Number: 200-163 3. Address: P.O.Box 196612 Anchorage, Development Q Exploratory 0 AK 99519-6612 Stratigraphic ❑ Service ❑ 6. API Number: 50-029-20600-01-00 7. Property Designation(Lease Number): ADL 0028304 8. Well Name and Number: PBU G-13A 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 10844 feet Plugs measured 8790/8810 t .... . _ D true vertical 8990 feet Junk measured feet A'o 01C Effective Depth: measured 8790 feet Packer measured 8083 feet N U true vertical 8486 feet Packer true vertical 7798 feet Casing: Length: Size: MD: TVD: Burst: Collapse: Structural Conductor 80 20"91.5#H-40 31-111 31 -111 1490 470 Surface 2644 13-3/8"72#L-80 30-2674 30-2674 4930 2670 Intermediate 8621 9-5/8"47#L-80 28-8649 28-8349 6870 4760 Production Liner 2701 2-3/8"4.6#L-80 8143-10844 7856-8990 11200 11780 Perforation Depth: Measured depth: 9263 9278 feet feet 9317-9337 feet 9345-9365 feet 9445-9555 feet 9624-9940 feet 10000-10160 feet 10185-10260 feet 10330-10460 feet 10480-10600 feet 10610-10690 feet True vertical depth: 8933-8942 feet feet 8964-8976 feet 8980-8991 feet 9015-9021 feet 9022-9012 feet 9011-9001 feet 9000-8996 feet 8996-8993 feet 8992-8991 feet 8990-8989 feet Tubing(size,grade,measured and true vertical depth) See Attachment See Attachment See Attachment Packers and SSSV(type,measured and 4-1/2"TIW HBBP Packer 8083 7798 true vertical depth) 12.Stimulation or cement squeeze summary: Intervals treated(measured): "f Treatment descriptions including volumes used and final pressure: SCANNED MAR 40 2;.1 d, 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation: 281 22036 0 0 878 Subsequent to operation: Shut-In 14.Attachments:(required per 20 AAC 25.070.25.071,&25.283) 15.Well Class after work: Daily Report of Well Operations Q Exploratory ❑ Development Q Service ❑ Stratigraphic 0 Copies of Logs and Surveys Run 0 16.Well Status after work: Oil 0 Gas 0 WDSPL 0 Printed and Electronic Fracture Stimulation Data ❑ GSTOR 0 WINJ 0 WAG ❑ GINJ 0 SUSP Q SPLUG 0 17.I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O.Exempt: N/A Contact Catron,Garry R(Wipro) Email Garry.Catron@bp.com Printed Name Catron,Garry R(Wipro) Title PDC Principal Engineer Signature I/,A.°1 �— Phone +1 907 564 4424 Date 11/14/16 Form 10-404 Revised 5/2015 VTL 2 /GHy— R D 1137 i+v7 NOV 1 6 201 Submit Original Only /6/1/7 1Y1 • • Suspended Well Site Inspection Form Initial Inspection Notify AOGCC Inspectors at least 10 days prior to inspection to allow witness Well Name: Drill Pad G No 13A Field/Pool: Prudhoe Bay Field/Prudhoe Bay Pool Permit#(PTD): 2001630 API Number: 50029206001 Operator: BP EXPLORATION (ALASKA) INC Date Suspended: 10/6/2008 Surface Location: Section: 12 Twsp: 11N Range: 13E Nearest active pad or road: Prudhoe Bay Unit G-Pad Take to Location Digital camera Map showing well location/Aerial photos Brief well history Wellbore diagram showing downhole condition Latest Sundry or Completion report Past Site Visit documentation Site clearance documentation Pressure gauges, fittings, tools Sample containers for fluids on or near pad Condition of Surface Location AOGCC requires: 1)a description of the condition of the surface location, including discoloration, fluids or sheens visible on the ground or in any nearby water, 2) photographs showing the condition of the location surrounding the well General location condition: Clean Good Condition Pad or location surface: Level Gravel Pad Location cleanup needed: None Pits condition: Good-frozen water, no hydrocarbons, no sheen Surrounding area condition: Good, Clean Water/fluids on pad: Frozen Puddles Discoloration, Sheens on pad, pits or water: None Samples taken: None Access road condition: Good gravel road Photographs taken(#and description): 1 Photo-Wellhouse with sign Condition of Wellhead AOGCC requires: 1) a description of the condition of the wellhead,2)well pressure readings,where practicable, 3) photographs showing the wellhead condition Wellhead/tree/valve description, condition: Good -some corrosion, slight leak on inner casing test port. Production tree, wing closed, flowline connected. Cellar description, condition, fluids: Gravel cellar, no visible hydrocarbons Rat Hole: N/A Wellhouse or protective barriers: Wellhouse-good condition Well identification sign: Yes Tubing Pressure(or casing if no tubing): SSV Closed no panel Annulus pressures: IA=250psi, OA=200psi Wellhead Photos taken (#and description): 1 Photo-Wellhead/Tree Work Required: Repair leaking casing test port, Operator Rep(name and signature): Joshua Stephens �. AOGCC Inspector: Jeff Jones Other Observers: Inspection Date: 10/10/2016 AOGCC Notice Date: (70/9/2016 Time of arrival: 11:40am Time of Departure: 11:50am Site access method: Pickup Truck • • 0.1 0.05 0 0.1 Miles 0 P <3i_32 „E-37PBI '`E 5 v E E-25APB1 E-75A Legend E-37AL' Pipelines(General) 1A 'G-13 31APB 1 I3' Pipelines(Detailed) TCG-02 Otis XE-2 IA /G-25A MI PB2 —WAG —Water —Relief _ G36A -"Selected Pipeline, -911kbt Nib G-03 '.. J 777" 'G o rr fit) \ l :G 23A \,� Author: y 1 \. ~ \Go6 ` 14 November,2016 BP1\catrgl ©BP Explorat on(Alaska)Inc.All rights reserved.This map is mrormanouai in nature and is presented without representations or Product of BPXA Atlas Enterprise GIS. alaska- is.b web.b .com warranties as to accuracy,completeness o use for any purpose P 9 P P I14±= MCEVOY • WELL!-EAD= MCEVOYSA NOTES: ACTUATOR= AXLESON G"'"1 3A _ KB.ELEV= 65.97' -47'SLMD -4-1/2"TBG COLLAPSED CONFRNED BY LIB BF.a.EV= 37.52RCT �, .. 4 (05/31/09) KOP= 3200' Max Angle= 96° 10090 '•016/16) 2097° -!4.5"OTLS SSSV,ID=3.813" Datum AC= 9179' �...._____--- 2115' H 4-1/2"X 3-112"XO,D=2.992' Datum ND= 8800"SS 2589' H-194.--51:28: 9-518"DV PKR 20"CUPDUCTOR 110' GAS LFT MANDRELS 4.5"12.6#L-80 TDS, H 2115' , ST MD ND DEV TYPE VLV LATCH PORT DATE .0152 bpf,ID=3.958' 5 3067 3067 1 MERLA DMI' RM 0 07/18/07 4 5165 5064 22 IVE A DMY RM 0 07/18/07 13-3/8"CSG,72#,L-80 BTRS, -+ 2672' 3 6759 6541 22 MERLA DMY RA 0 03/02/01 D=12.347" 2 7631 7364 16 MERLA DMY RA 0 03/02/01 1 8036 7753 17 MERLA DMI' RA 0 03/02/01 Minimum ID = 1.90" @ 8150' ( 8066' -3-1/2"PARKER SWSNIP TIW XO -TOP OF 2-3/8" LNR _ MILL®Toz.80"oNo2roslol 8079' 13-1/2"XO TO 4-1/2",D=3.95" '= 8083' --19-5/8"TIW HBBP PKR,D=4.00" 8093' -14-1/2"XO T O 3-1/2",D=3.958" TOP OF 7"LNR -{ 8137' TOP OF 2-3/8"LNR -{ 8143' 8143' -2-3/8"TM,DEPLOY SLY,D=2.25" I w/3-1/2"BATTED BULLDOG SPEAR(8116'SLM ! ' f 8150' -1-11-W CROSSOVER PN,D=1.90" 4 • • I9-518-LNR,47#,L-80 BTRS,D=8.681" H 8666' 1-411 0 0 , iiiii• 8773' HJET CUT TBG(04/06/08) TOP OF CEMENT(08/03/08) H 8790' I i i ip4��pi 8810' H 2-3/8"WFD CEP(04/05/08) 3-1/2"TBG,9.2#L-80 TDS,0087 bpf,D=2.992" -1 9090' i 0 PERFORATION SUIMARYREF L SVVS CM_2121!01 °4 3-1/2"&7"MELOUT WINDOW(G-13A)9090'-9094' �4j /\ ANGLE AT TOP" PERF: 48°Q 9263' •�.4• Note:Refer to Production DB for historical pert data �� Q.• SEE SPF INTERVAL Opn/Sgz DATE i� �. 1-11/16" 4 9263-9278 C 08/02/03 .• , 4►• ` 1-9116" 6 9317 9337 C 05/06/01 •••••• \%%% 1-9/16" 6 9345-9365 C 05/06/01 .•••••►•. 1 11116" 6 9445 9555 C 02/22/01 ��,••• ♦....•• 1-11/16" 6 9624-9940 C 02!22!01 0•►*.❖.4►•41-11/16" 6 10000-10160 C 02/22/01 P� ••••• ►•• 0•,••❖•►. ." ..•1-11116" 6 10185-10260 G 02/22/01 )•�••• ►. 1-11/16" 6 10330-10460 C 02/22/01 =• -•••••••••-1-11116' 6 10480-10600 C 02/22/01 ����• ` 1-11/16" 6 10610-10690 C 02/22/01 PBTD 10779' 3-1/2"WHIPSTOCK --L 9090' ` — 1-11/16" 7 10611-10690 C 02/23/01 0444 1-11/16" 8 10612-10690 C 02/24/01 (02/07/01) 4�14,0` 2-3/8"LNR,4.6#,L-80 STL,.0039 bpf,D.1.995" - 10844' 7"LNR,29#,L-80 BTRS,.0371 bpf,D=6.184" H 9483' DATE REV BY CONVENTS DATE REV BY COMMENTS PRUDHOE BAY UNE ORIGINAL COMPLETION 10/25/08 PJC DRAWNG CORRECTIONS WELL: G-13A 02/22/01 CTD SIDTRACK(G-13A) 11/23/15 RHVJMD 1BG COLLAPSE(05/31/09) TEAK No:' 001630 04/17/04 TWGKAK CORRECTIONS 08/22/16 MRD/JMD RCT CUT TBG(08/16/16) API No 50-029-20600-01 07/21/07 KSB/PJC GLV CIO(07/18/07) SEC 12,T11N,R13E,2224'NSL&2368'WEL 04/15/08 RRD/TLH TBG CUT&CUP SET(04/06/08) 10/16/08 GJF/PJC BAI I hi)SPEAR(09/25/08) BP Exploration(Alaska) • • m o O O a O o 0 0 N- Ln LO C U y 0 0 0 00 0 O) CO I. 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"-"-' , ;#X,'''''., '. ''''.,..'. ., ' . . • • ?9a.0-134- Regg, James B (DOA) ZoOr3p From: Regg,James B (DOA) Sent: Saturday, November 12, 2016 3:18 PM "I1l Ili, To: Daniel, Ryan; Noble, Robert C (DOA) 11 I Cc: Quick, Michael J (DOA); DOA AOGCC Prudhoe Bay; Sarber, Greg J; Leemhuis, Jacob Subject: RE: Parker 272 BOP Usage form for well G-13 Thank you,Ryan. Good luck with ops. Sent from my Samsung Galaxy smartphone. SUMS JU/N Original message From: "Daniel, Ryan" <Ryan.Daniel@bp.corn> Date: 11/12/2016 3:14 PM (GMT-09:00) To: "Noble, Robert C (DOA)" <bob.noble@alaska.gov> Cc: "Regg, James B (DOA)" <jim.regg@alaska.gov>, "Quick, Michael J (DOA)" <michael.quick@alaska.gov>, DOA AOGCC Prudhoe Bay <doa.aogcc.prudhoe.bay@alaska.gov>, "Sarber, Greg J" <SarberJG@BP.com>, "Leemhuis, Jacob" <Jacob.Leemhuis@bp.com> Subject: Re: Parker 272 BOP Usage form for well G-13 Hello Bob, Spoke with Jim earlier this afternoon. We will provide a daily well status update until we are in a position to resume normal operations/ scheduled testing along with any components used during the shut-in and divert yesterday. u BOPE testing is on hold until normal operations can be established. -1r`' 14�i� We will copy the inspectors email and michael quick on the daily well status update. Thanks Ryan Sent from my iPhone On Nov 12, 2016, at 13:20, Noble, Robert C (DOA) <bob.noble@alaska.gov>wrote: Hello Has Jim gotten back with you? I've been trying to call the rig and gotten no answer. 299-1362 Bob Noble AOGCC 333 W. 7th Ave. Ste. 100 1 • • Anch AK, 99501 Cell 907-2994362 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 Bob Noble at 907-299-1362 or bob.noble@alaska.gov From: Daniel, Ryan [mailto:Ryan.Daniel@bD.com] Sent: Saturday, November 12, 2016 10:39 AM To: Regg, James B (DOA); Quick, Michael J (DOA); DOA AOGCC Prudhoe Bay Cc: Sarber, Greg J; Leemhuis, Jacob Subject: Fwd: Parker 272 BOP Usage form for well G-13 Good morning Jim, Michael, P272 has a scheduled BOP test coming due tomorrow which we will need to defer for operational reasons. I have attached a copy of the BOP usage report from yesterday morning. The rig team are currently developing a plan forward in consultation with the town well engineering team. Jacob can supply more details when available but at this stage I would not anticipate having either 1) tubing fish out of hole, or 2) overshot disconnected for a number of days. The primary well objective now is safely stabilizing the annulariluid column with sea water (swapping out slowly with completion fluid) and to the extent we can circ through tubing to the backoff point (circulating through non sealed overshot and collapsed pipe). If you recall this well had communication across the tubing and annular strings to atmosphere (prior to 13 3/8" by 20" top cement job last week) so the BOP stack and annular is acting as a diverter only, and we are minimizing back pressure accordingly. Planning and hot tap equipment to safely handle and break down collapsed tubing joints with potential trapped HC/pressure is underway. 2 We may be circulating slowly for at least another 24hrs and monitoring until we are ready to safely move forward and work the string, open annular divert etc If one of you could reply to Greg, Jacob on this request that would be much appreciated. Any questions on current operations and the plan forward, well status etc can be directed to Jacob with copy to me please. Thanks Ryan Sent from my iPhone Begin forwarded message: 3 i 196c,c C-I3A- Prb zeoa6 Regg, James B (DOA) From: Sarber, Greg J <SarberJG@BP.com> Sent: Friday, November 11, 2016 10:40 PM To: DOA AOGCC Prudhoe Bay Cc: Romo, Louis A; Kilfoyle,Jeffery A; Hunt,Terry; Daniel, Ryan; Egbejimba, Uchenna J; Cismoski, Doug A; Isaacson, William S; Serpa, Lina M Subject: Parker 272 BOP Usage form for well G-13 Attachments: Parker 272.BOP Usage Form.Well G-13.11-11-2016.doc All, Parker 272 used the BOPE to prevent flow while performing a work over on well G-13. The attached reporting form contains the full details of the incident. Please contact me if you need additional information. Cheers, Greg "The single biggest problem in communication is the illusion that it has taken place." George Bernard Shaw Greg Sarber North Slope - Drilling Well Operations Specialist +1 (907)659-4618(Office-slope) +1 (907)242-8000(Cell Phone) Harmony 2156 Alternate: Jay Murphy %CANNE) JUN 1 G201 1 • • AOGCC BOPE USAGE REPORT FORM (Well Control event only) Field Superintendent Name: Greg Sarber Wellsite Leader Name: Keith Conatser Contact Number: 907-659-4618 Contact Number: 907-685-4802 BP Traction Number: 2016-IR-5371152 Rig Name &Well Pad or Drill Site &Well Name: Parker 272,G-13A Permit To Drill (PTD) Number: 200-163 Date and Time of Incident: 11-11-16, 06:56 AM Original Scope of Work: Plug and abandon well. Pull collapsed tubing from blind backoff at^'5100' MD. Operational Description Leading up to Well Control Event: The rig was performing a P&A operation on well G-13. The production perforations had been previously isolated with a cast bridge plug and cement cap. Pre-rig it was found that the 4-1/2" production tubing and 9-5/8"casing had collapsed. Annulur communication existed from TxlAxOAx20"conductor. The rig restored partial mechanical integrity by performing a cement top job on the 20" Conductor by 13-3/8"casin• annulus. The rig milled open the collapse in the 9-5/8"casing and attempted to fish the collapsed 4-1/2"tubing by performing a blind backoff. String weight of 105 klb Hook load, indicated a possible successful blind backoff of the production tubing at an estimated 5100' MD. Shortly after backing off and picking up the production tubing,the rig team observed flow coming across the shakers. The low LEL alarms sounded and non-essential personnel evacuated from the rig. The well was secured by closing the annular_preventer and diverting flow to two, 500 bbl flowback tanks until the gas bubble was dispersed. Approximately 70 bbls of fluid was bled back into the flowback tanks before the flow halted and WHP bled to 0 psi. Maximum WHP observed was 154 psi,which was minimized to prevent broaching or damage to the cement top job on the 20" Conductorxl3-3/8" annulus. The suspected cause of the observed flow and gas is possible breakout of gas entrained in the crude oil that had been used as a packer fluid. The rig is currently conducting lubricate and bleed opeations to remove the crude oil that was used as packer fluid from the well. This will continue until the entire wellbore down to the top of the production packer at 8083'and the cement plug at 8790' is displaced to seawater. Those efforts are ongoing at the present time. BOPE Used and Reason: Well shut in with annular preventer after flow was observed and high LEL alarms sounded. Current BOPE test time/date Last BOPE test 11-6-16. Next scheduled BOPE test 11-13-16. Is a BOPE re-test required after use: Yes/No and reason Yes. BOPE used for well control. -- Annular preventer will be tested when the well is displaced to seawater and the fish layed down. This is estimated tl Be performed on 11-12/13-2016. Plan Forward: Displace the crude oil from the tubing and IA using the lubricate and bleed technique. Lay down the fish and test BOP's. • S Additional Comments: ACTIONS REQUIRED: 1) Well Site Leader: Timely email notification of BOPE re-test time estimate to AOGCC North Slope Inspectors is required following any WC incident to allow the State to witness re-test as required. (This is a judgment call given WC is an unplanned event during rig operations and factors such as wellbore condition and trip timing will influence timing of any retest) 2) Superintendents: Email the completed BOPE Usage Report form to AOGCC North Slope Inspectors within 24 hours of a WC incident: doa.aogcc.prudhoe.bay@alaska.gov 3) Well Site Leader: Complete AOGCC BOPE Test report form 10-424 and send to three AOGCC addresses (noted in form) within 5 days following the test/retest. This is applicable to Well Control events Only. SOF Tji • • ,,I yyy�6. THE STATE Alaska Oil and Gas of1L1c K1 Conservation Commission L'It i-£i__ = 333 West Seventh Avenue GOVERNOR BILL WALKER VirrM Anchorage, Alaska 99501-3572 Main: 907.279.1433 SFA :S ` Fax: 907.276.7542 www.aogcc.alaska.gov John Egbejimba "KED W\R 2 12f 9 , Drilling Supervisor SCS BP Exploration(Alaska), Inc. P.O. Box 196612 Anchorage,AK 99519-6612 Re: Prudhoe Bay Field,Prudhoe Bay Oil Pool, PBU G-13A Permit to Drill Number: 200-163 Sundry Number: 316-575 Dear Mr. Egbejimba: 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. Sincerely, Al° Daniel . Seamount,Jr. k Commissioner DATED this Pr day of November, 2016. RBDMS NOV 1 6 2016 STATE OF ALASKA • ALASKA OIL AND GAS CONSERVATION COM N APPLICATION FOR SUNDRY APPRO LS 20 AAC 25.280 1. Type of Request: Abandon 0 Plug Perforations 0 Fracture Stimulate 0 Repair Well 0 Operations shutdown❑ Suspend 0 Perforate 0 Other Stimulate 0 Pull Tubing 0 Change Approved Program m • Plug for Redrill 0 Perforate New Pool 0 Re-enter Susp Well 0 Alter Casing 0 Other 0 2. Operator Name: BP Exploration(Alaska),Inc 4. Current Well Class: 5. Permit to Drill Number: 200-163. 3, Address: P.O.Box 196612 Anchorage,AK Exploratory 0 Development !. 99519-6612 Stratigraphic 0 Service 0 6. API Number: 50-029-20600-01-00 • 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 0 No m PBU G-13A • RECEIVED 9. Property Designation(Lease Number): 10. Field/Pools: ADL 028280&028304 ' PRUDHOE BAY,PRUDHOE OIL• N O V 0 7 2016 11. PRESENT WELL CONDITION SUMMARY Total Depth MD(ft): Total Depth TVD(ft): Effective Depth MD: Effective Depth TVD: MPSP(psi): Plugs(MD): AO GCC ' 8990 • 8790 8486 2020 8790'(TOC).8810' ®VV None Casing Length Size MD TVD Burst Collapse Structural Conductor 80 20" 31 -111 31 -111 1490 470 Surface 2644 13-3/8" 30-2674 30-2674 4930 2670 Intermediate 8621 9-5/8" 28-8649 28-8349 6870 4760 Liner 952 7" 8138-9090 7852-8780 8160 7020 Liner 2701 2-3/8" 8143-10844 I 7856-8990 11200 11780 Perforation Depth MD(ft): Perforation Depth TVD(ft): Tubing Size: Tubing Grade: Tubing MD(ft): None 4-1/2",12.6#x 3-1/2",9.2# L-80 26-9090 Packers and SSSV Type: 4-1/2"TIW HBBP Packer Packers and SSSV MD(ft)and TVD(ft): 8083/7798 No SSSV Installed No SSSV Installed 12.Attachments: Proposal Summary RI Wellbore Schematic H 13.Well Class after proposed work: Detailed Operations Program 0 BOP Sketch ® Exploratory 0 Stratigraphic 0 Development ® Service 0 14.Estimated Date for Commencing Operations: November 5,2016 15. Well Status after proposed work: Oil 0 WINJ ❑ WDSPL 0 Suspended 16.Verbal Approval: Date: 11/5/2016 GAS 0 WAG 0 GSTOR 0 SPLUG 0 Commission Representative: Michael Quick GINJ 0 Op Shutdown 0 Abandoned 0 17.I hereby certify that the foregoing is true and the procedure approved herein will not Contact Leemhuis,Jacob be deviated from without prior written approval. Email Jacob.Leemhuis@bp.com Printed Name John Egbejimba Title Drilling Supervisor Signature -.'"d'e/./C.• .• Phone +1 907 564 4139 IO/PeDate It 1—) 20/COMMISSION USE ONLY Conditions of approval:Notify Commission so that a representative may witness Sundry Number: r^' / 3\ -3Z..-- 6-74- Plug Integrity 0 BOP Test12 Mechanical Integrity Test 0 Location Clearance 0 Other: ->< ?:),OV LTj"G. ..t,p '- 10 t› -t Si '141 Is tk" Post Initial Injection MIT Req'd? Yes 0 No ❑ Spacing Exception R-quired? Yes 0 No 13/ Subsequent Form Required: n40---1APPROVED BYTHE 9 Approved by: '� COMMISSIONER COMMISSION Date: /f/i /i,‘ ORIGINAL RBDMS ( NOV 1 6 2016 1t lq libSubmit Form and Form 10-403 Revised 11/2015 Approved application is valid for 12 months from the date of approval. � �J l r' Attachments in Duplicate —a i,'.c7. • • , Lastufka, Joseph N From: Leemhuis,Jacob Sent: Monday, November 07, 2016 7:57 AM To: Lastufka,Joseph N Subject: FW:G-13A P&A Sundry#316-282 Categories: CAUTION:Contains external email - increased risk of phishing external-email: -1 Just a heads up. We need to submit an updated sundry. Thanks, Jacob C. Leemhuis From: Quick, Michael J (DOA) [mailto:michael.quick@alaska.gov] Sent: Saturday, November 05, 2016 6:55 PM To: Leemhuis, Jacob Cc: Daniel, Ryan; Regg, James B (DOA); Schwartz, Guy L(DOA) Subject: Re: G-13A P&A Sundry #316-282 Jacob You have verbal approval to continue operations per your revised plan below. As we discussed on the phone,you will need to submit the updated procedure and schematic to the AOGCC on Monday. Please let me know if the top job does not give you the isolation planned. Mike On Nov 5, 2016,at 5:47 PM, Leemhuis,Jacob<Jacob.Leemhuis@bp.com>wrote: Mike, The approved sundry plan was as follows: 1. MIRU. ND tree. NU and test BOPE with four preventers configured top down a. Annular b. 9-5/8" Fixed c. Blind Shears d. Mud Cross e. 2-7/8" x 5-1/2"VBR's 2. Pull 4-1/2" L-80 tubing from"22' MD(control line will be parted).Save old hanger for surface cement work. 3. Recover collapsed 4-1/2"tubing(straight pull, back off, wash over and outside cut) 4. Rig up E-line. RIH and perform a tubing punch in the 3-1/2"tubing below the packer(8,100' MD). 5. Use E-line to jet cut 3-1/2"tubing above packer. 1 6. Recover 4-1/2" x 32"tubing (and parted control line). Save 2' 00' of tubing for surface cement work. 7. Set cement retainer above top of production packer. Weight test EZSV. Sting back into EZSV and establish injectivity to reservoir(not expected due cemented liner and CIBP w/cement cap). If injectivity established squeeze cement. Lay 25 bbls (-328') of cement above EZSV. 8. Set CIBP at' 2,250'. 9. Cut 9-5/8" casing at 2,200' MD. Circulate out Artic Pac. LD cutter. 10. Pull 9-5/8" casing. 11. Run 4-1/2" x 3-1/2" kill string and land hanger. ND BOPE and NU dry hole tree. 12. Pump cement surface to surface (^'400 bbls). 13. RDMO. The updated plan that I am requesting approval is as follows: 1. Perform a top job through the 13%" fluted hanger using 1" CSH a. TOC to Landing ring is 14'TVD 2. Perform BOPE test while waiting for cement to gain compressive strength 3. Pump down the tubing, taking returns out to flowback tank for the IA and OA. Monitor cellar for flow 4. Pull tubing hanger from pre-rig RCT cut at 22' MD 5. RIH with overshot and engage collapse tubing and pull. 6. Once all collapsed tubing is out of the wellbore, RIH with overshot on 5" drill pipe and engage tubing. 7. Rig up E-line and RIH with jet cutter 8. Cut 3%" tubing above production packer 9. Pull out of hole and rig down E-line 10. Circulate 8.6 ppg seawater into tubing and IA/OA. 11. Pull 4%" x 3%2"tubing a. Visually inspect all 3%"tubing as we will rerun for kill string 12. Rig up E-line and RIH with USIT and log 9%" casing from 2,600'to surface 13. Lay down USIT and RIH with EZSV drift on E-Line. 14. Pull out of hole, lay down drift, and rig down E-Line. 15. Set cement retainer above top of production packer. Weight test EZSV to 15K. Lay 110 bbls (-1,500') of cement above EZSV. 5+ .Acc ✓ 16. Set CIBP at '2,250' (-50' below top of cement from USIT). 17. Cut 9-5/8" casing at 2,200' MD. Circulate out Artic Pac. LD cutter.' 18. Pull 9-5/8" casing. 19. Run 4-1/2" x 3-1/2" kill string and land hanger. Pump 100' diesel cap in Tubing and annulus. ND BOPE and NU dry hole tree. 20. RDMO. 21. (Fullbore will come in post rig and cement the kill string surface to surface ("'350 bbls)). Notable changes: • Perform a top job in the 13%" Surface Casing to regain 13%" integrity, as required to circulate the well and maintain a hydrostatic column in the riser. By performing a circulation test (down the tubing, up the IA and OA, which are hardlined to a flowback tank) we will demonstrate the cement integrity is adequate to meet the above objectives. The cellar will be monitored by a rig personnel during this step to ensure there isn't flow. 2 • We are requester to eliminate punching the tubing belova'"the production packer as we currently have isolation to the reservoir and would prefer not to potentially introduce packer gas into our system. • It was previously stated that we would weight test and pressure test our EZSV to 1,500 psi. According to 20 AAC 25.112 (g), which states, "Except for surface plugs, the operator shall record the actual location and integrity of cement plugs, cement retainers, or bridge plugs required by this section, using one of the following methods, which in the case of a cement retainer or bridge plug may be performed before cement is placed on top of the plug: (1) placing sufficient weight on the plug to confirm its location and to confirm that the plug has set and a competent plug is in place; (2) testing the plug to hold a surface pressure of 1,500 psig or 0.25 psi/ft multiplied by the true vertical depth of the casing shoe, whichever is greater, and tagging the plug to confirm location; however, surface pressure may not subject the casing to a hoop stress that will exceed 70 percent of the minimum yield strength of the casing." We would prefer to only weight test to 15K so we don't inadvertently put pressure on the 13%" x 20" annulus that was cemented via a top job. This would still meet the State Regulations. Please let me know if you would like to discuss more. Thanks, Jacob C. Leemhuis GWO I BP Alaska I Drilling Engineer—CTD & RWO I Mobile: +1 (907)223-6792 I Office : +1 (907)564-4989 I Lync: +1 (832)787-3231 I Office 755B <G-13A- P&A-JCL Update 5.pdf 3 TREE= MCEVOY • G -13 A NOTES: WEiLHEAD= MCEVOY ACTUATOR= AXLESON KB.E LEV= 65.97' Proposed P&A BF. —;-- ------- s7-52' .. `s< ` : '„ Fullycemented to surface (350 KO_P=_ 3200' : ::.,:.;.� l bbls) N6x Angle= 96°@ 10090' Datum MD= _9179' ; .. PARKER 272 BOP STACK RAM TYPE BOP: SHAFFER LXT DOUBLE BOP 13 5/8°-5M DUTCH LOCK DOWN FLANGE 13 5/8"-5M STUDDED TOP 13 5/8"-5M FLANGED BOTTOM W/(2) 14" UL2 OPERATOR, UPPER CAVITY ° ° ANNFULARR LBOP: ND (2CRAVITY SLK W/BSTR OPERATOR, °ii i° ^"� 13A5/8" 5MTSTUDDED TOP 0 13-5/8" 5M FLANGED BOTTOM 0 I I DRILLING CROSS: I I 13 5/8"-5M FLANGED TOP :I I I .-% 13 5/8"-5M FLANGED BOTTOM o°0,6) le - _ W (2) 3 1/8"-5M SIDE OUTLETS 1 • '42_5,:, . f _ II °, ° 11 II �or� 0 0 �' _ "- 0 f u T112 IE _Ai I - KILL LINE: -WW1 r • 2-1/16" 5M FLEX HOSE ,�I���r ■I-(■�1 `I A 32-1/16"-1/8' 5M BD.S.A.' 5M FLANGEDMANUALGATE VALVE Ci 3-1/8" 5M FLANGED HYDRAULIC GATE VALVE E 1147 ler ......, 00 00 �$� •..,E - Dl II 0 00 I 1 I CHOKE LINE: RAM TYPE BOP: 3-1/8" 5M FLANGED MANUAL GATE VALVE SHAFFER LXT SINGLE 13 5/8" 5M 3-1/8" 5M FLANGED HYDRAULIC GATE VALVE 13 5/8"-5M STUDDED TOP 13 5/8"- 5M FLANGED BOTTOM 3-1/8" 5M FLEX HOSE w/(2) 14" UL2 OPERATOR • Quick, Michael J (DOA) From: Quick, Michael J (DOA) Sent: Saturday, November 05, 2016 6:55 PM To: Leemhuis,Jacob Cc: Daniel, Ryan; Regg,James B (DOA); Schwartz, Guy L(DOA) Subject: Re: G-13A P&A Sundry#316-282 Jacob You have verbal approval to continue operations per your revised plan below. As we discussed on the phone,you will need to submit the updated procedure and schematic to the AOGCC on Monday. Please let me know if the top job does not give you the isolation planned. Mike SCANNED JUN 2 8 2017 On Nov 5,2016, at 5:47 PM, Leemhuis,Jacob<Jacob.Leemhuis@bp.com>wrote: Mike, The approved sundry plan was as follows: 1. MIRU. ND tree. NU and test BOPE with four preventers configured top down a. Annular b. 9-5/8" Fixed c. Blind Shears d. Mud Cross e. 2-7/8"x 5-1/2"VBR's 2. Pull 4-1/2" L-80 tubing from —22' MD(control line will be parted).Save old hanger for surface cement work. 3. Recover collapsed 4-1/2"tubing(straight pull, back off, wash over and outside cut) 4. Rig up E-line. RIH and perform a tubing punch in the 3-1/2"tubing below the packer(-8,100' MD). 5. Use E-line to jet cut 3-1/2"tubing above packer. 6. Recover 4-1/2"x 3-1/2"tubing(and parted control line). Save 2,500'of tubing for surface cement work. 7. Set cement retainer above top of production packer. Weight test EZSV. Sting back into EZSV and establish injectivity to reservoir(not expected due cemented liner and CIBP w/cement cap). If injectivity established squeeze cement. Lay 25 bbls(^'328')of cement above EZSV. 8. Set CIBP at^'2,250'. 9. Cut 9-5/8" casing at 2,200' MD. Circulate out Artic Pac. LD cutter. 10. Pull 9-5/8" casing. 11. Run 4-1/2"x 3-1/2" kill string and land hanger. ND BOPE and NU dry hole tree. 12. Pump cement surface to surface ("'400 bbls). 13. RDMO. The updated plan that I am requesting approval is as follows: 1. Perform a top job through the 13%"fluted hanger using 1" CSH 1 • a. TOC to Landing ring is 14'TVD 2. Perform BOPE test while waiting for cement to gain compressive strength 3. Pump down the tubing,taking returns out to flowback tank for the IA and OA. Monitor cellar for flow 4. Pull tubing hanger from pre-rig RCT cut at 22' MD 5. RIH with overshot and engage collapse tubing and pull. 6. Once all collapsed tubing is out of the wellbore, RIH with overshot on 5" drill pipe and engage tubing. 7. Rig up E-line and RIH with jet cutter 8. Cut 31/2"tubing above production packer 9. Pull out of hole and rig down E-line 10. Circulate 8.6 ppg seawater into tubing and IA/OA. 11. Pull 4W'x 3W'tubing a. Visually inspect all 31/2"tubing as we will rerun for kill string 12. Rig up E-line and RIH with USIT and log 9%" casing from 2,600'to surface 13. Lay down USIT and RIH with EZSV drift on E-Line. 14. Pull out of hole, lay down drift, and rig down E-Line. 15. Set cement retainer above top of production packer. Weight test EZSV to 15K. Lay 110 bbls (^'1,500')of cement above EZSV. 16. Set CIBP at—2,250' ("'50' below top of cement from USIT). 17. Cut 9-5/8" casing at 2,200' MD. Circulate out Artic Pac. LD cutter. 18. Pull 9-5/8" casing. 19. Run 4-1/2"x 3-1/2" kill string and land hanger. Pump 100' diesel cap in Tubing and annulus. ND BOPE and NU dry hole tree. 20. RDMO. 21. (Fullbore will come in post rig and cement the kill string surface to surface (^'350 bbls)). Notable changes: • Perform a top job in the 13%"Surface Casing to regain 13%' integrity,as required to circulate the well and maintain a hydrostatic column in the riser. By performing a circulation test (down the tubing,up the IA and OA,which are hardlined to a flowback tank)we will demonstrate the cement integrity is adequate to meet the above objectives. The cellar will be monitored by a rig personnel during this step to ensure there isn't flow. • We are requesting to eliminate punching the tubing below the production packer as we currently have isolation to the reservoir and would prefer not to potentially introduce packer gas into our system. • It was previously stated that we would weight test and pressure test our EZSV to 1,500 psi. According to 20 AAC 25.112 (g), which states, "Except for surface plugs, the operator shall record the actual location and integrity of cement plugs, cement retainers, or bridge plugs required by this section, using one of the following methods, which in the case of a cement retainer or bridge plug may be performed before cement is placed on top of the plug: (1) placing sufficient weight on the plug to confirm its location and to confirm that the plug has set and a competent plug is in place; (2) testing the plug to hold a surface pressure of 1,500 psig or 0.25 psi/ft multiplied by the true vertical depth of the casing shoe, whichever is greater, and tagging the plug to confirm location; however, surface pressure may not subject the casing to a hoop stress that will exceed 70 percent of the minimum yield strength of the casing."We would prefer 2 • • to only weight test to 15K so we don't inadvertently put pressure on the 13%"x 20" annulus that was cemented via a top job. This would still meet the State Regulations. Please let me know if you would like to discuss more. Thanks, ;--�-� _' �S Jacob C. Leemhuis 1 1/ 20D GWO I BP Alaska I Drilling Engineer—CTD & RWO I Mobile:+1 (907)223-6792 I Office :+1 (907)564-4989 I Lync: +1 (832)787-3231 I Office 755B <G-13A - P&A - JCL Update 5.pdf 3 • • STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION Suspended Well Inspection Report Date Inspected: 10/10/16 Inspector: Jeff Jones Operator: BPXA Well Name: PBU G-13A • Oper.Rep: J.Stephens PTD No.: 2001630 Oper. Phone: 659-5766 Location Verified? Yes Oper.Email: .com If Verified,How? Other(specify in comments) Onshore/Offshore: Onshore Suspension Date: 10/06/08 Date AOGCC Notified: 10/09/16 Sundry No.: Well Completion Report Type of Inspection: Subsequent Wellbore Diagram Avail.? Yes Well Pressures(psi): Tubing N/A Photos Taken? Yes IA 200 OA 200 Condition of Wellhead: Wing valve,master valve&SSV closed&hydraulics disconnected.Wellhead in good condition with some corrosion.Slight hydraulic fluid leak @ casing hanger test port. Condition of Surrounding Surface Clean level gravel pad in good condition with some frozen puddles and road access.No hydrocarbon residue visible.Well house in Location: good condition. Follow Up Actions Needed: Repair hydralic leak @ well head test port. Comments: Well identified by pad map and well sign permanently attached to the well house.Mr.Stephens took photos at my direction and they are attached to his report. SCANNED UN 0 20 �. Attachments: none REVIEWED BY' Insp.Supry %gt0116 Comm PLB 12/2015 2016-1010_Suspend_PBU_G-13Ajj.xlsx Pra lob — / 3 S Loepp, Victoria T (DOA) From: Loepp,Victoria T(DOA) Sent: Friday,August 26, 2016 2:09 PM To: 'Leemhuis,Jacob' Cc: Lastufka,Joseph N Subject: RE:G-13A P&A(PTD 200-163, Sundry#316-282) Follow Up Flag: Follow up Flag Status: Flagged Jacob, Approval is granted for the modifications listed below with the addition of the plug test to 1500 psig. The remainder of the approved sundry outlined in the post-rig work remains unchanged. Please include this approval with the approved sundry. Thanx, Victoria Victoria Loepp Senior Petroleum Engineer State of Alaska SC ►NNEO FES 15 2017, Oil&Gas Conservation Commission 333 W.7th Ave Anchorage,AK 99501 Work: (907)793-1247 Victoria.LoeoPa.alaska.gov 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 Loepp at(907)793-1247 or Victoria.loeoo@alaska.gov From: Leemhuis,Jacob [mailto:Jacob.Leemhuis@bp.com] Sent: Friday,August 26, 2016 10:30 AM To: Loepp, Victoria T(DOA) Cc: Lastufka,Joseph N Subject: RE: G-13A P&A(PTD 200-163, Sundry #316-282) Victoria, Thanks for the quick response. Yes,we will test the plug to 1,500 psi. As far as the USIT,we are not planning on it as the state records (with 40%washout) indicate a cement top of—5,917' MD. My schematic incorrectly had 7,781' listed as TOC for 9-5/8". Thanks, Jacob C. Leemhuis 1 • • From: Loepp, Victoria T(DOA) [mailto:victoria.loepp@alaska.gov] Sent: Friday, August 26, 2016 9:59 AM To: Leemhuis,Jacob Subject: RE: G-13A P&A(PTD 200-163, Sundry#316-282) Jacob, Will you be running a USIT to determine TOC?Will you PT the PC to 1500 psi? Thanx, Victoria From: Leemhuis, Jacob [mailto:Jacob.Leemhuisftbp.com] Sent: Friday,August 26, 2016 9:10 AM To: Loepp,Victoria T(DOA) Cc: Lastufka, Joseph N Subject: G-13A P&A- Sundry #316-282 Victoria, There is an opportunity to reduce complexity and risk on the G-13A P&A by leaving the production packer in place. The 3-1/2"tubing can be punched below the packer so injectivity in the 7"x 3-1/2"annulus can be established The outcome of the P&A will be exactly the same as before just without the issue of recovering and anchor,milling packer, then fishing packer. Below is an operation summary. I have also attached 2 schematics,the first being our original plan and the second being the proposed updated plan. Proposed Updated RWO Procedure: • MIRU. ND tree. NU and test BOPE with four preventers configured top down • Annular • 9-5/8" Fixed • Blind Shears • Mud Cross • 2-7/8"x 5-1/2"VBR's • Pull 4-1/2" L-80 tubing from "22' MD(control line will be parted).Save old hanger for surface cement work. • Recover collapsed 4-1/2"tubing(straight pull, back off,wash over and outside cut) • Rig up E-line. RIH and perform a tubing punch in the 3-1/2"tubing below the packer(^'8,100' MD). • Use E-line to jet cut 3-1/2"tubing above packer. • Recover 4-1/2"x 3-1/2"tubing(and parted control line). Save 2,500'of tubing for surface cement work. • Set cement retainer above top of production packer. Weight test EZSV. Sting back into EZSV and establish injectivity to reservoir(not expected due cemented liner and CIBP w/cement cap). If injectivity established squeeze cement. Lay 25 bbls(-328')of cement above EZSV. • Set CIBP at 2,250'. • Cut 9-5/8"casing at 2,200' MD. Circulate out Artic Pac. LD cutter. • Pull 9-5/8"casing. • Run 4-1/2"x 3-1/2" kill string and land hanger. ND BOPE and NU dry hole tree. • Pump cement surface to surface(^'400 bbls). • RDMO. Since this work varies slightly from the approved Sundry, I am seeking approval to change from the original Sundry plan. Thanks, Jacob C.Leemhuis 2 • • GWO I BP Alaska I Drilling Engineer— Mobile:+1 (907)223-6792 I Office:+1 (907)564-4989 I Lync:+1 (832)787-3231 I Office 755B 3 TREE= AICEVOY NVELLFEAD= MCEVOY • G—1 3A so.NOTES: ACTUATOR= AXLESON KB.REV= 65.97' BF.ELEV= 37.52 KOp= 32 00, i fa Fully cem ented to surce (400 bbls) Max Angle= 96°@ 10090' Datum MD= 9179' Datum TVD= 8800'SS 3-1/2"kill stchg tD 2190 ' BPRE 1992' 20"CONDUCTOR H 110' ? 9-5/8" bi- -tub at' 00' ..:4 ,s___...--12589' —9-5/8"DV PKR DP Z #1 • 13-3/8"CSG,72#,L-80 BTRS, H 2672' 11;1 ♦ ` 9 5/8"E Z S V at 2 2 5 0' D= 12.347 CM 3 6367' E st TOC -7781'assum lig 30% / '•- — .'ti'ti.r.� 328'm alin um cem entp1iq (25 bbls m ii) • r.r•r•r•1 washout.Log forconfrm atnn. I 8079' H3-1/2"XO TO 4-1/2",13=3.95" Perorate casbg ifnecessaLy. =, ,�, 8083' —19-518"TIW FEBP PKR,D=4.00" Tubing Punch H —8100 4 TOP OF T LNR 8137' ' 8093' 4-12"XO T O 3-1/2",D=3.958"_ TOP OF 2-318"LNR H 8143' 8143' 12-3/8"TM/DEPLOY SLV,D=225" i $ w13-1/7"11A11111 F3UI.1 flOC SPEAR @ 8116'SI M i 1 _' '. . 8150' —I TNV CROSSOVER PN,D=1.90" 01 4 i i 9-5/8"LNR 47#,L-80 BTRS,D=8.681" —i 8655' ; T S G R 8689' •4 L maid< 8773' -HET CUT TBG(04/06/08) TOP OF CEMENT(08/03!08) —I 8790' I SIFT 0.. 0 8810' —12-3/8"WFD CEP(04/05/08) .3-1/2"TBG,92#L-80 IDS,0087 bpf,D=2992" —I 9090' 0 PERFORATION SUMMARY i 4 REF LOG: SWS CNL 2!21!01 ;4 0 ANGLE AT TOP PERE: 48°@ 9263' 0 0 3-1/2"&7"M&LOUT WINDOW(G-13A)9090'-9094' •.►4 _� Note:Refer to Roduction DB for historical pert data i SIZE SPF NTB2VAL Opn/Sgz DATE • ♦ 1-11/16" 4 9263-9278 C 08/02/03 of •1-9/16" 6 9317-9337 C 05/06/01 ♦4 �%•i••„„• ` 1-9/16" 6 9345-9365 C 05/06/01 t �►,44, ♦ 1-11116" 6 9445-9555 C 02/22/01 ♦; , •:•;•; ` ►d •••• DPZ #2 1-11/16" 6 9624-9940 C 02/22/01 'yi'444 1 ` 1-11/16" 6 10000-10160 C 02/22/01 •o•++••�►k4 1-11/16" 6 10185-10260 C 02/22/01 i ,V4,1 I IV ` i�•i•i-►i 1-11!16" 6 10330-10460 C 0222/01 • -•••4 • , 1-11/16" 6 10480-10600 C 0222/01 ':••'•'•`i!• B S A D 9342' •-•-•-•-•♦ 1-11/16" 6 10610-10690 C 02/22/01 !•••••„„!.!�! 1-11/16” 7 10611-10690 C 02/23/01 FBTD H 10779' 1-11/16" 8 10612-10690 C 02/24/01 (1/2"WFPSTOCK —I 9090` ,..'' ,♦', 02/07/01 2-3/8"LNR,4.6#,L-80 SIL, .0039 bpf,D=1.995" 10844' 7"LNR,29#,L-80 BTRS,.0371 bpf,D=6.184" —1 9483' DATE REV BY CONVENTS DATE REV BY CONVENTS PRUDHOE BAY MT ORIGINAL COMPLETION 07/21/07 KSB!PJC GLV CYO(07/18/07) WELL: G-13A 02/22/01 CTD SIDTRACK(G-13A) 04/15/08 RRIYILH TBG CUT&CEP SET(04/06/08) PERMT No: 2001630 03/10/01 C1-VKAK FNAL 10/16/08 GJF/PJC BATTED SPEAR(09/25/08) API No: 50-029-20600-01 05/12/01 JLJ/TLH ADD PERFS 10/25/08 PJC DRAWING CORRECTIONS SEC 12,T11 N,R13E,2224'NSL&2368'WEL 08/02/03 BJMc/TLH ADD PERFS 11/23/15 RWJMD TBG COLLAPSE(05/31/09) 04/17/04 TW YKAK CORRECTIONS BP Exploration(Alaska) • TREE WELL MC:EV OY • G-13A S1 (NOTES: kVIELLI-EAD= MC�IJOY ACTUATOR= AXLESON KB.REV= 65.97' BF.ELEV= 37.52' —Fully cern ented to surface (400 bbls) KOP= 3200' Max Angle= 96° r, 10090' I 1/2"kill stchg to 2190' BPRF 1992' Datum MD= 9179' Datum WD= 8800'SS •• • 9 5i8"tubing stub at2200' DP #1. 20"CONDUCTOR 110' .4 2588' 9-5/8"DV PKR �� 9 5/8"EZSV at2250' 13-3/8"CSG,72#,L-80 BTRS, —I 2672' 13= 12.347 CM3 6367' Minimum ID = 1.90" @ 8150' TAN XO-TOP OF 2-3/8" LNR E st TO C 7781' ' .:`f�;.�r•j:;:••;___— 328'm izin um cem entplig (25 bbls m in) `. 1.1.1. •..•..1. assum na 30° washout '•?:1.r_ll;t;J .' ' —EZSV -8130' TOP OF 7"LNR H 8137' . TOP OF 2-3/8"LNR —i 8143' 8143' 12-3/8'71W CEPLOY SLV,13=225' �I I HV/t 1 t'/'11A 1T D BULLDOG DEAR @ 8116'SLIM 11 8150' —1 TM/CROSSOVER F14,13=1.90" 0 1 ►t 9-5/8"LM ,47#,L-80 BTRS,D=8.681" --I 8655' „1-411. 7 , TSGR 8689 ' 8773' —f JET CUT TBG(04/06/08) TOP OF CUENT(08/03/08) 8790' TT, ( . 0 • 8810' —12-3/8”WFD CEP(04/05/08) 3-1/2"TBG,9.2#L-80 IDS,0087 bpf,D=2.992" H 9090' 0 . PERFORATION SUMvfARY 'i IRE=LOG: SWS CNL 2/21/01 1 1 ANGLE AT TOP PERF: 48°@ 9263' : $ �� �----TO C @ 8995 Note:Fbfer to Roduction DB for historical perf data .!'i� ,s SIZE SPF NTERVAL Opn/Sgz DATE •: •j •• 3-1/2"&7"MLLOUT WNDOW(G-13A)9090'-9094' 1-11/16" 4 9263-9278 i. 08/02/03 .i •. 1-9/16" 6 9317-9337 C 05/06/01 •i•• L.7••••�i ` 1-9/16" 6 9345-9365 C 05/06/01 • 44,,41' • ♦.••►4\%%%1-11/16' 6 9445-9555 C 02/22/01 `� i!••••••.•, ♦..• .1-11/16" 6 9624-9940 C 02(22101 ' ••••••• DP Z #3 1-11/16" 6 10000-10160 C 02/22/01 • • „•••••❖i•••„♦1-11/16" 6 10185-10260 C 02/22/01 ••i !••• ►• .,...•►1-11/16" 6 10330-10460 C 02/22./01 i•••4 ►• ••` •! ••••• ►• 1-11/16" 6 10480-10600 C 02/22/01 ••...•.• 1-11/16" 6 10610-10690 C 02/22/01 , •❖:❖:❖i ` B S A D 9342' 1-11/16" 7 10611-10690 C 02/23/01 FBTD H 10779' 1-11/16" 8 10612-10690 C 02/24/01 3-1/2"WHPSTOCKH (%()(' ' ,,� ''., (02/07/01) �A 2-3/8"LNR,4.6#,L-80 SIL, .0039 bpf,D=1.995" 10844' 7"LM,29#,L-80 BTRS,.0371 bpf,D=6.184" --I 9483' DATE REV BY C.OKSENTS DATE REV BY CONSENTS PRUDHDE BAY UNIT ORIGINAL COMPLETION 07/21/07 KSB/PJC GLV CYO(07/18/07) WE.L: G-13A 02/22/01 CTD SIDTRACK(G-13A) 04/15/08 RERI TLH TBG CUT&CEP SET(04/06/08) PERMT Na: 2001630 03/10/01 CWKAK FINAL 10/16/08 GJF/PJC BAIT®SPEAR(09/25/08) API Na: 50-029-20600-01 05/12/01 JLJ/'R.H ADD PERFS 10/25/08 PJC DRAWING CORRECTIONS SEC 12,T11 N,R13E,2224'NSL&2368'WE_ 08/02/03 BJMo/TLH ADD ARES 11/23/15 RHIJMD TBG COLLAPSE(05/31/09) 04/17/04 TWC/KAK CORRECTIONS BP Exploration(Alaska) TREE= MCEV OY WELLHEAD= MCEV OY ! G-1 ' A S/ Y NOTES: ACTUATOR= AXLESON KB.ELEV= 65.97' —4T SLMD 4-1/2"TBG COLLAPSED(UNARMED BY LB BF.ELEV= 37.52' 1 (05/31/09) KOP= 3200' Max Angle= 96°@ 10090' 2097' --E-4.5"0715 SSSV,D=3.813"1 Datum MD 9179' O I 2115' -I4-1/2"X 3-1/2"XO,ID=2.992" Datum TVD= 8800'SS • 20"CONDUCTOR 110' 2589' �g.G�DV 1NANDRELS 4.5"12.6#L-80-MS, J 2115' ST MD TVD DEV TYPE VLV LATCH FORT DATE I 5 3067 3067 1 MERLA DMY RM 0 07/18/07 .0152 bpf,ID=3.958" .4 5165 5064 22 MERLA DMY RM 0 07/18/07 13-3/8'CSG,72#,L-80 BTRS, —I 2672' MD 3 6759 6541 22 MERLA DM' RA 0 03/02/01 D= 12.347 2 7631 7364 16 MERLA DMY RA 0 03/02/01 1 8036 7753 17 MERLA DMY RA 0 03/02/01 Minimum ID = 1.90" @ 8150' I 8066' —3-1/2"PARKER SWS NIP MLLED TO 2.80"ON 02/09/01 TIW XO -TOP OF 2-3/8" LN R 8079' —13-1/2"XO TO 4-1/2",U=3.95" • 2 ):Z' 8083' —I 9-5/8"TNV I-UBP PKR,D=4.00" TOP OF 7"LNR — 8137' 80 — 93' 1 4-f f2"XO TO 3-1/2",D=3.958" TOP OF 2-3/8"LNR H 8143' 8143' H2-3/8"TIW DEPLOY SLV,D=2.25' : w/3-1/2"BAITED BULLDOG SPEAR @ 8116'SLM 1 ;1 i [ 8150' —I TIW CROSSOVER PN,D=1.90" 4 i 9-5/8"LNR,47#,L-80 BTRS,0=8.681" H 8655' —' ►4 '4 ' 41 t EM ► 8773' —I JET CUT TBG(04/06/08) TOP OF CENT(08/03/08) ---1 8790' I TT' o -4,- , 8810' —{2-3/8-WFD CUP(04/05/08) 3-1/2"TBG,9.2#L-80 TDS,0087 bpf,D=2.992" H 9090' 0 PERFORATION SUMARY ►i i REF LOG: SWS CNL 2/21/01 �4 4 ANGLE AT TOP P RF: 48°@ 9263' ►� 3-1/2'&7"FALLOUT VVNDOW(G-13A)9090'-9094' •�►, ,4� Note:Refer to Production DB for historical perf data •� .•• SQE SPF INTERVAL Opn/Sqz DATE �i �i 1-11/16" 4 9263-9278 C 08/02/03 •••���• 1-9/16" 6 9317-9337 C 05/06/01 V �`?�• 1-9/16" 6 9345-9365 C 05/06/01 •� e N ♦;....W,..,41 1-11/16" 6 9445-9555 c 02/22/01 �! 1-11/16" 6 9624-9940 C 02/22/01 :1:::::::►i 1-11/16" 6 10000-10160 c 02/22/01 .•►*•••a• 1-11/16" 6 10185-10260 C 02/22/01 •i ••••4 i 1-11116" 6 10330-10460 C 02/22/01 4i ,•i�i� ►i ` 1-11/16" 6 10480-10600 C 02/22/01 t.•••..-iii i 1-11/16" 6 10610-10690 C 02/22/01 !•••••-•!•!•! 1-11/16" 7 10611-10690 C 02/23/01 PBTD --I 10779' I 1-11/16" 8 10612-10690 C 02/24/01 3-1/2"WHPSTOCK —I 9090' ,��1 (02/07/01) 41‘•..•4.1 2-3/8"LNR 4.6#,L-80 STL, .0039 bpf,D=1.995" — 10844' 7"LNR,29#,L-80 BTRS,.0371 bpf,D=6.184" —I 9483' DATE REV BY COMMENTS DATE REV BY COMMENTS PRUDHOE BAY UNIT ORIGINAL COMPLETION 07/21/07 KSB/PJC GLV GO(07/18/07) WELL: G-13A 02/22/01 CTD SIDTRACK(G-13A) 04/15/08 RRDr1LH TBG CUT&COP SET(04/06/08) PERMIT No:`2001630 03/10/01 G-VKAK FINAL 10/16/08 GJF/PJC BAITED SPEAR(09/25/08) API No: 50-029-20600-01 05/12/01 JLJ/TLH ADD PERFS 10/25/08 PJC DRAWING CORRECTIONS SEC 12,T11 N,R13E,2224'NSL 8 2368'WE 08/02/03 BJINcITLH ADD PERFS 11/23/15 RFYJMD TBG COLLAPSE(05/31/09) 04/17/04 TWGKAK CORRECTIONS BP Exploration(Alaska) • OF T • • x-m THE STATE Alaska Oil and Gas ti -- A1, p f /\ T 1SKA Conservation Commission - -= nL -if£_ _ 333 West Seventh Avenue �' ' GOVERNOR BILL WALKER Anchorage, Alaska 99501-3572 *+' �. . Main: 907.279.1433 OFALAS 1Fax: 907.276.7542 www.aogcc.alaska.gov Sean McLaughlin Drilling Supervisor SCANNED JAN 1 7 2017 BP Exploration (Alaska), Inc. P.O. Box 196612 Anchorage, AK 99519-6612 Re: Prudhoe Bay Field, Prudhoe Bay Oil Pool, PBU G-13A Permit to Drill Number: 200-163 Sundry Number: 316-282 Dear Mr. McLaughlin: 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. Sincerely, ./1(4Pis Cathy . Foerster Chair llA- DATED this l v day of August, 2016. RBDMS jt-Aliii 1 2 2016 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMM.N • APPLICATION FOR SUNDRY APPRO S 20 AAC 25.280 1. Type of Request: Abandon 0 Plug Perforations ❑ Fracture Stimulate 0 Repair Well 0 Operations shutdown 0 Suspend 0 Perforate 0 Other Stimulate ❑ Pull Tubing 0 Change Approved Program 0 Plug for Redrill 0 Perforate New Pool 0 Re-enter Susp Well ❑ Alter Casing 0 Other Additional Suspend Q . 2. Operator Name: BP Exploration(Alaska),Inc 4. Current Well Class: 5. Permit to Drill Number: 200-163 3. Address: P.O.Box 196612 Anchorage,AK Exploratory 0 Development RI 99519-66126. API Number: 50-029-20600-01-00 - Stratigraphic 0 Service ❑ 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 0 No Q PBU G-13A ' RECE®p 9. Property Designation(Lease Number): 10. Field/Pools: ADL 028280&028304 • PRUDHOE BAY,PRUDHOE OIL ' 0—C.S 3 2 O �� 11. PRESENT WELL CONDITION SUMMARY AY 2+ 2O1 Total Depth MD(ft): Total Depth TVD(ft): Effective Depth MD: Effective Depth ND: MPSP(psi): / Plugs(MD): i. Lrl C 10844 . 8990 • 8790 8486 2020 8790'(TOC),8810' `one Casing Length Size MD TVD Burst Collapse Structural Conductor 80 20" 31-111 31 -111 1490 470 Surface 2644 13-3/8" 30-2674 30-2674 4930 2670 Intermediate 8621 9-5/8" 28-8649 28-8349 6870 4760 Production Liner 2701 2-3/8" 8143-10844 7856-8990 11200 11780 Perforation Depth MD(ft): Perforation Depth TVD(ft): Tubing Size: Tubing Grade: Tubing MD(ft): None 4-1/2",12.6#x 3-1/2",9.2# L-80 26-9090 Packers and SSSV Type: 4-1/2"TIW HBBP Packer Packers and SSSV MD(ft)and TVD(ft): 8083/7798 No SSSV Installed No SSSV Installed 12.Attachments: Proposal Summary RI Wellbore Schematic Q 13.Well Class after proposed work: Detailed Operations Program 0 BOP Sketch Q Exploratory 0 Stratigraphic 0 Development Q Service 0 14.Estimated Date for Commencing Operations: October 15,2016 15. Well Status after proposed work: Oil 0 WINJ 0 WDSPL 0 Suspended Q 16.Verbal Approval: Date: GAS 0 WAG 0 GSTOR 0 SPLUG 0 Commission Representative: GINJ 0 Op Shutdown 0 Abandoned 0 17.I hereby certify that the foregoing is true and the procedure approved herein will not Contact Leemhuis,Jacob be deviated from without prior written approval. Email Jacob.Leemhuis@bp.com Printed Name Sean McLaughlin Title Drilling Supervior Signature / v ` — --:. Phone +1 907 564 4387 Date V2,0/ 16 COMMISSION USE ONLY Conditions of approval:Notify Commission so that a representative may witness Sundry Number: 2_.. 2_ ��/" \u, - Plug Integrity 0 BOP Test M Mechanical Integrity Test ❑ Location Clearance 0 Other: B op 7L to.5 1 to 33,0 0 0 p5. A r--,ri. La t-p r r L rC Y- L1 f to Z 5-D 0 p5-) , c � / � 1 J Post Initial Injection MIT Req'd? Yes 0 No l� , Spacing Exception Required? Yes 0 No C Subsequent Form Required: /O 4-O -----' " // �f—� APPROVED BYTHE / Approved by COMMISSIONER COMMISSION Date: 8-(0 111 ten 7/201/1, ORIGINAL RBDMS L`'Alin 1 2 2016 Submit-Form and Form 10-403 Revised 11/2015 Approved application is valid for 12 months from the date of approval. ,213 Attachments in Duplicate • bp Sundry Request for Plug &Suspend Well: G-13A Date: 05/20/2016 Engineer: Jacob Leemhuis MASP: 2020 psi Well Type: Producer Estimated Start date: October 15, 2016 History: In 1991, G-13 was drilled in Northeastern G-Pad targeting both Zone 2 and Upper Zone 1 sands. G-13A CTD sidetrack was drilled due to a combination of marginal GOR and a packer leak. G-13A was sidetracked with tiny tools in February 2001 as a horizontal Zone 1A Producer. Poor rock quality and substantially low reservoir pressure (2,593 psi) led to lower-than-expected production. Subsequent Zone 1B perforations were added which brought in more gas than oil. The well was shut-in in mid-2002 when the gas rate quickly jumped above 20 MMSCFD resulting in 50,000+ GOR. It was tested only a few times over the next year, and each time the oil, gas, and GOR came back unchanged. Zone 2A add perfs were shot August 2, 2003. The well stayed online for nearly 4 months before hitting marginal. In 2009, the well was screened for another tiny tools CTD sidetrack. E-Line jet cut the 2-3/8" liner then service coil attempted to pull the liner to no avail. Subsequently, slickline was unable to drift passed 47' SLM after tagging with a 2.0" LIB; the imprint indicated collapsed tubing and the sidetrack was cancelled. The Well was deemed to have no future utility by the Reservoir Development Team and placed on the AOGCC list of suspended wells in April 2008. AOGCC required that the well be P&A'd bar the end of 2016. Scope of Work: The primary objective of the rest of this RWO is plugging well G-13, achieving zonal isolation for all DPZs and allowing for the permanent abandonment of the well 3' below the original tundra level. Pre Rig Work E 1 Jet cut tubing above collapse—40' F 2 Bleed wellhead pressure to zero ✓ 3 Set TWC Proposed RWO Procedure: • MIRU. ND tree. NU and test BOPE with four preventers configured top down (annular, 9-5/8" fixed, blind shears, mud cross and 2-7/8"x 5-1/2"VBR's). • Pull 4-W L-80 tubing from —40' MD (control line will be parted). Save old hanger for surface cement work. • Recover collapsed 4-1/2"tubing (straight pull, back off, wash over and outside cut) • Rig up eline to cut 3-1/2" tubing above and below the production packer. • Recover 4-1/2" x 3-1/2"tubing (and parted control line). Save 2500' of tubing for surface cement work. • Pick up DP, Recover TIW latch from above packer • Mill Packer • Recover packer • Rig up Eline and run USIT 7000'—8140' (tubing stub) and 2700'—surface. • Contingency plan if 100' of annular cement not present above 7"TOL—Run big hole charges to perforate 100' of 9-5/8"casing. • Set cement retainer above top of 7" liner. Establish injectivity to reservoir(not expected due • . • cemented liner and CIBP w/cement cap). If injectivity established squeeze cement. Lay 15 bbls (-200') of cement above EZSV. -rot R /! • Test production casing to 1,500 psi. DDP to 2500'. J • Set CIBP at 2500'. • Cut 9-5/9" casing at 2450'. Circulate out Attic Pac. LD cutter. • Pull 9-5/8"casing. • Run 4-1/2" x 3-1/2" kill string and land hanger. ND BOPE and NU dry hole tree. • Pump cement surface to surface. • RDMO. Post Rig Work O 1 Excavate around the wellhead. O 2 Cut off and remove the casing and wellhead 1 ft below pad level or deep enough to cut-off the ✓ wellhead in entirety, whichever is deeper. o wr S S h' dio O 3 Fill all unfilled annuli to surface with cement. <— no h i�&-CC i# pectin * 1�J Notify Inspector of opportunity to witness cut off prior to elding plate. 2-`- k. no IC e Take picture once the wellhead is cut off. O 4 Place an abandonment plate on top of the cut off casing with the following information: BP Exploration Alaska, Inc. G-13A A 0b C C 1,/'`t-✓4,C 55 PTD#2001630 API No. 50-029-20600-01 O 5 Remove cellar/shoring box. Backfill with gravel over the tack-welded marker plate/well to pad level. O 6 Obtain Site Clearance Approval from AOGCC. • • • • Loepp, Victoria T (DOA) From: Leemhuis,Jacob <Jacob.Leemhuis@bp.com> Sent: Thursday,July 28, 2016 10:35 AM To: Loepp,Victoria T(DOA) Subject: RE: PBU G-13A P&A(PTD 200-163, Sundry 316-282) Victoria, The CIBP was set,tagged, and then had 10' of cement placed on top of it. The MIT failed as expected from poor tubing. We don't believe we are in communication with the reservoir. There wouldn't be a way to pressure test prior to setting EZSV since there is a jet cut directly above the cement. After we set the EZSV we will try to obtain injectivity below the EZSV and if possible we will squeeze cement below. Thanks, Jacob C. Leemhuis From: Loepp,Victoria T(DOA) [mailto:victoria.loepp(a)alaska.gov} Sent:Thursday,July 28, 2016 10:16 AM To: Leemhuis,Jacob Subject: PBU G-13A P&A(PTD 200-163, Sundry 316-282) Jacob, Was the TOC at 8790' MD tagged or pressure tested?Is there an opportunity to PT prior to setting EZSV? Thanx, Victoria Victoria Loepp Senior Petroleum Engineer State of Alaska Oil&Gas Conservation Commission 333 W.7th Ave Anchorage,AK 99501 Work: (907)793-1247 Victoria.Loepp a(�alaska.ciov 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 Loepp at(907)793-1247 or Victorialoem@alaska.gov 1 TREE= MCEV OY • V1tQLFiEAb= MCEVOY GOSA1lfY NOTES: ACTUATOR= AXLESON KB.ELEV= 65.97' -47'SLM D—4-1/2"TBG COLLAPSED CONFIRMED BY LB BF ELEV= 37.52' I (05/31/09) KOP= 3200' ( R_ Max Angle= 96°@ 10090' 1 ._ 2097' 1—4.5"OT1S SSSV,ID=3.813" 1 Datum MD= 9179' II2115' H4-1/2"X 3-112"XO,D=2.992" Datum TVD= 8800'SS 20"CONDUCTOR 110' 2589' —9-GAS PKRMANDREL.S ST MD ND DEV TYPE VLV LATCH PORT DATE 4.5"12.6#L-80 TDS, H 2115' 5 3067 3067 1 MERLA DMO' RM 0 07/18/07 .0152 bpf,D=3.958" 4 5165 5064 22 MERLA DMY RM 0 07/18/07 13-3/8"CSG,72#,L-80 B t Hs, — 2672' I 3 6759 6541 22 MERL A DMY RA 0 03/02/01 D= 12.347 2 7631 7364 16 KERLA DMY RA 0 03/02/01 1 8036 7753 17 IVER A DMY RA 0 03/02/01 8066' —3-1/2"PARKER SWS NIP Minimum ID = 1.90" @ 8150' MILLED TO 2,80"ON 02ro9/01 T1W XO -TOP OF 2-3/8" LNR 8079' H3-1/2"XOTO 4-1/2",D=3.95" - 8083' H 9-5/8"TWV I-BBP PKR,D=4.00" TOP OF 7"LNR 8137' 8093' —{4-1/2"XO T O 3-112",D=3.958' TOP OF 2-3/8"LNR H 8143' le 8143' —2-3/8"TAN DEPLOY SLV,D=2.25' iIS w/3-1/2"BAIE)BULLDOG SPEAR @ 8116'SLM 4 • 8150' —TIW CROSSOVER PN,D=1.9044 9-5/8"LNR,47#,L-80 B1 ,D=8.681" —{ 44 4 8773' HJET CUT TBG(04/06/08) TOP OF CEMENT(08/03/08) — 8790' j P 0,,t,i� 8810' --12-3/8-VVFD CBP(04/05/08) 3-1/2"TBG,9.2#L-80 TDS,0087 bpf,D=2.992" H 9090' 0 PERFORATION SUMMARY 1 4 4 REF LOG: SWS C14._2/21/01 �4 4 ANGLE AT TOP FERE: 48°@ 9263' 4 3-1/2'&7"MELOUT WNDOW(G-13A)9090'-9094' 70 Abte:Refer to Pbduction DB for historical perf data $..4.1. i%. I i • SIZE SPF INTERVAL Opn/Sqz DATE i! ,•i 1-11/16" 4 9263-9278 C 08/02/03 �! .i 1-9/16" 6 9317-9337 C 05/06101 .. `N•A� ` 1-9/16" 6 9345-9365 C 05/06/01 .4 !►�� ♦••••♦ 1-11!16" 6 9445-9555 C 02/22/01 •• 1,• •• •• • ►4 1-11/16' 6 9624-9940 C 02/22101 �����•�4 1-11/16' 6 10000-10160 C 02/22/01 1-11116" 6 10185-10260 C 02/22/01 i;cl'llI 1-11/16" 6 10330-10460 C 02/22/011-11/16" 6 10480-10600 C 02/22/01 ♦i••••♦ 1-11/16" 6 10610-10690 C 02/22/01 ••••••4 1-11/16" 7 10611-10690 C 02/23/01 3-1/2"WHPSTOCK 9090' PBTD (-- 10779' l 1-11/16" 8 10612-10690 C 02/24/01 �1� (02107/01) .141.�g�,. 4.2-3/8"LNR,4.6#,L-80 STL, .0039 bpf,D=1.995" — 10844' 7"LNR,29#,L-80 B i RS,.0371 bpf,D=6184" — 9483' DATE REV BY COMMENTS DATE REV BY ODMVE iTS F'RI.AHOE BAY UNIT ORIGINAL COMPLETION 07/21/07 KSB/PJC GLV 00(07/18/07) WELL: G-13A 02/22/01 'CTD SIDTRACK(G-13A) — 04/15/08 RRIY l -1 TBG CUT&CBP SET(04/06/08) PERMT Na:"1001630 03/10/01 CWKAK MAL 10116/08 GJF/PJC BAIIEU SPEAR(09/25/08) AFI Na: 50-029-20600-01 05/12/01 JLJ/TLN ADD PERES 10/25/08 PJC DRAVVNG CORRECTIONS SEC 12,T11N,R13E,2224'NSL&2368'WEL 08/02/03 BJMc/T LH ADD PBZFS 11/23/15 R-VJMD TBG COLLAPSE(05/31/09) 04/17/04 TRIC/KAK CORRECTIONS BP Exploration(Alaska) TREE= MCEVOY • WELLHEAb= MCEVOY G-1 3A SA NOTES: ACTUATOR= AXLES_ON -KB-ELEV= -�-v 6 6- 5 BF-ELEV= 37.52' :, :;f{::1:-: – Fully cemented to surface (400 bbls) KO_P= 3200' • .Vis.': .:..�.;.c ..,#fi Max Angle= 96° 10090' .r :::••••:•,-,,W.0:::•04'� : ^s � 'r;> �•r..��.{.� ��: x<�: � 3-1/2 kill string to 2440' BPRF 1992' oaci;mluD= sips ▪ •:..,::x;,�_.;,. :-. Y Datum ND= —8800 SS .z • ` '' : ` 9-5/8" + ;ng 450' h,a,• DPZ#1 20"CONDUCTOR 110' '' 2589' H9-5/8"DV PKR ' ;� 9-5/8" EZSV at 2500 13-3/8"CSG,72#,L-80 BTRS, H 2672' D= 12.347 CM3 6367' Minimum ID = 1.90" @ 8150' TIW XO -TOP OF 2-3/8" LN R Est. TOC –7781' assuming 30% _ washout. Log for confirmation. q�'":'':'y"~'p''~ 200' minimum cement plug (15 bbls min) Perforate casing if necessary .t; ` -� — EZSV –8130' TOP OF 7"LNR H 8137' x TOP OF 2-3/8"LNR — 8143' 8143" —2-3/8"TW DEPLOY SLV,D=2.25" Ill w/3-1/2"BATTED BULLDOG SPEAR @ 8116'SLM ▪ 1 ▪ i 0 8160" —ITIW CROSSOVER PIN,D=1.90" 4 0 $ 4 4 .y 9-5/8"LNR,47#,L-80 BTPS,D=8.681" — 8655' 4 4 TSGR 8689' 8773' H JET CUT TBG(04/06/08) 1011 TOP OF CEMENT(08/03/08) 8790' 1L q j 404 ' 8810' H2-3/8"WFDCEP(04/05/08) 3-1/2"TBG,92#L-80 TDS,0087 bpf,D=2.992" H 9090" 0 - PERFORATION SUMMARY REF LOG: SOS CNL 2/21/014 ANGLE AT TOP PERF: 48°@9263' ♦" °I ��TOC 8995 Nate:Refer to Production DB for historical perf data ,•.♦4'i SIZE SPF INTERVAL Opn/Sqz DATE •:.:�� ♦� 3-1/2"&7"MLLOUT WBNDOW(G-13A)9090'-9094' 1-11/16" 4 9263-9278 08/02/03 • G 1-9/16" 6 9317-9337 C 05/06/01 •:':.4•` �♦��V {2 43 . ♦ 40. •; ♦t r•♦•♦ 1-9/16" 6 9345-9365 C 05/06/01 ';t' ♦• 4 • V ,1-11/16" 6 9445-9555 C 02/22/01 ▪ ♦t♦♦4 �♦ DPZ#2 1-11/16" 6 9624-9940 C 02/22/01 t: -� �� ` 1-11/16" 6 10000-10160 C 02/22/01 ::**(We ♦( $♦S 1-11/16" 6 10185-10260 C 02/22/01 ♦ ♦♦ 1-11/16" 6 10330-10460 C 02/22/01 ••144.4A♦. 1-11/16" 6 10480-10600 C 02/22/01 X1'1♦�♦•♦�♦•t ` V •♦�♦•••••♦•♦• ` BSAD 9342 1-11/16" 6 10610-10690 C 02/22/01 ••t••�� 1-11/16" 7 10611-10690 C 02/23/01 PBTD —I 1077W 3-1/2"WHPSTOCK —{ 9090'1-11/16" 8 10612-10690 C 02/24/01 ,'4 (02/07/01) 4.�4�*•` J 2-3/8"LNR,4.6#,L-80 STL, _0039 bpf,ID=1.995" — 10844' 7"LNR,29#,L-80 BTRS,.0371 bpf,ID=6.184" —I 9483' DATE REV BY COIvW'ITS DATE REV BY COMMENTS PRUDHOE BAY UNIT ORIGINAL COMPLETION 07/21/07 KSB/PJC GLV CIO(07/18/07) WELL: G-13A 02/22101 CTD SIDTRACK(G-13A) 04/15/08 RRD!Tt.H TBG CUT&CIBP SET(04/06/08) PERMT No:'`2001630 03/10/01 CI-VKAK FINAL 10/16/08 GJF/PJC BAITED SPEAR(09/25/08) AR No: 50-029-20600-01 05/12/01 JLJ/TLH ADD PE ES 10/25/08 PJC DRAWING CORRECTIONS SEC 12,T11 N,R13E,2224'NSL&2368'WEL 08/02/03 BJMc/TLH ADD P RES 11/23/15 RWJMD TBG COLLAPSE(05/31/09) 04/17/04 TWCJKAK CORRECTIONS BP Exploration(Alaska) 0- ID PARKER 272 BOP STACK RAM TYPE BOP: DUTCH LOCK DOWN FLANGE SHAFFER LXT DOUBLE BOP 13 5/8"-5M 13 5/8"-5M STUDDED TOP 13 5/8"-5M FLANGED BOTTOM W/(2) 14" UL2 OPERATOR, UPPER CAVITY ° \°) ANNULAR BOP: AND (2) 14" PSLK W/BSTR OPERATOR, Ei ft f rni r riF SHAFFER LXT 13 5/8"-5M LOWER CAVITY 13-5/8" 5M STUDDED TOP 0 13-5/8" 5M FLANGED BOTTOM 0 I I DRILLING CROSS: 13 5/8"-5M FLANGED TOP CI I 0 I �1 13 5/8"-5M FLANGED BOTTOM _ �0.31 ��,O co_ W (2) 3 1/8"-5M SIDE OUTLETS �� - __-1 7 e e, e II _LI ii DI II 1 •• - �•• r II 1 I KILL LINE: f r nn .A. 2-1/16" 5M FLEX HOSE 'fk�0°�01- • 1 V �� 3-1/86"5MMFLANGED MANUAL B" 5M SGATE VALVE - O 3-1/8" 5M FLANGED HYDRAULIC GATE VALVE ,d)i E . .• • o e Ello 00 I 1 I CHOKE LINE: RAM TYPE BOP: 3-1/8" 5M FLANGED MANUAL GATE VALVE SHAFFER LXT SINGLE 13 5/8" 5M 3-1/8" 5M FLANGED HYDRAULIC GATE VALVE 13 5/8"-5M STUDDED TOP 8" 5M FLEX HOSE 13 5/8"- 5M FLANGED BOTTOM 3-1/8" W/(2) 14" UL2 OPERATOR ti of 1J • �wP��\I%%i s THE • STATE Alaska Oil and Gas ofA LA s KA Canservati®n Commission r _=® . 333 West Seventh Avenue GOVERNOR BILL WALKER Anchorage, Alaska 99501-3572 Main: 907.279.1433 ALASY'� Fax: 907.276.7542 www.aogcc.alaska.gov Ryan Daniel ; CANNE? N V6, Alaska Wells Integrity& Compliance Team Leader I 2015 BP Exploration(Alaska), Inc. P.O. Box 196612 r ,3 Anchorage,AK 99519-6612 Re: Prudhoe Bay Field, Prudhoe Bay Oil Pool,PBU G-13A Sundry Number: 315-584 Dear Mr. Daniel: 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. Approval is granted contingent on development of a P&A plan for suspended wells with no future utility which brings these wells closer to abandonment prior to pad decommissioning. This plan must be developed and approved through the Commission by 12-31-2016. Failure to comply with this requirement will invalidate this sundry. 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, Cathy . Foerster Chair ,4011A— DATED this day of October,2015 Encl. 3C/ RBDMS Nn' 0 2 2015 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COM ON APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 1. Type of Request: Abandon 0 Plug Perforations o Fracture Stimulate 0 Pull Tubing 0 Operations shutdown 0 Suspend El Perforate 0 Other Stimulate 0 Alter Casing 0 Change Approved Program 0 Plug for Redrill 0 Perforate New Pool 0 Repair Well 0 Re-enter Susp Well 0 Other wS /t 5l EV- rtnZ L✓2 / ' a✓r'L- 2. Operator Name: BP Exploration(Alaska),Inc 4. Current Well Class: 5. Permit to Drill Number: 200-163 3. Address: P.O.Box 196612 Anchorage,AK Exploratory 0 Development 0 99519-6612 Stratigraphic 0 Service ❑ 6. API Number: 50-029-20600-01-00 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 0 Nom PBU G-13A RECEIVED Property 9. ADL 0028304 DesignationPRUDHOE(Lease Number): I10� Field/Pools.BAY,PRUDHOE OIL ' SEP 2 1 2015 11. PRESENT WELL CONDITION SUMMARY A7S ' lb Ls Total Depth MD(ft): Total Depth TVD(ft): Effective Depth MD(ft): Effective Depth TVD(ft): Plugs(measured): JAG + d 10844 • 8990 • 8121 7835 8121/8810 Casing Length Size MD TVD Burst Collapse Structural Conductor 80 20"91.5#H-40 31 -111 31-111 1490 470 Surface 2644 13-3/8"72#L-80 30-2674 30-2674 4930 2670 Intermediate 8621 9-5/8"47#L-80 28-8649 28-8349 6870 4760 Production Liner 2701 2-3/8"4.6#L-80 8143-10844 7856-8990 11200 11780 Perforation Depth MD(ft): Perforation Depth TVD(ft): Tubing Size: Tubing Grade: Tubing MD(ft): See Attachment See Attachment See Attachment See Attachment See Attachment Packers and SSSV Type: 4-1/2"TIW HBBP Packer Packers and SSSV MD(ft)and TVD(ft): 8083, 7798 No SSSV Installed No SSSV Installed 12.Attachments: Description Summary of Proposal 0 13.Well Class after proposed work: BOP Sketch 0 Detailed Operations Program 0 Exploratory 0 Stratigraphic 0 Development H ' Service 0 14.Estimated Date for Commencing Operations: 15. Well Status after proposed work: Oil 0 Gas 0 WDSPL 0 Suspended Ed • 16.Verbal Approval: Date: WINJ 0 GINJ ❑ WAG 0 Abandoned ❑ Commission Representative: Op Shutdown 0 GSTOR 0 SPLUG 0 17.I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Daniel,Ryan Email Ryan.Daniel@bp.com Printed Name Daniel,Ryan Title Alaska Wells Integrity&Compliance Team Leader Signature ilk Phone +1 907 564 5430 Date Jeep Ail 7D tr COMMISSION USE ONLY Conditions of approval:Notify Commission so that a representative may witness Sundry Number: 3 . 154;3 Plug Integrity 0 BOP Test 0 Mechanical Integrity Test 0 Location Clearance 0 Other: App/-vv t I /15 9rc„-, tej cop-,t,'r c"4- o,-, dcvc1e'Prvltr,t )f P.4/9.pllh r° i ' SvSpe•,-,c -c w'c//5 tnr,th PI FvFv lJfi1"1'f-y which, kjv,'r, thzsc ftrells (,lLt3Ser o c, 1�uhc!cry,i-t�ttht r,c to Iczcl clec'akr},-,-„ 5Siavifv, P4-4 pig h Ti b,e cJz!vr1opea a/--icl G..�7� rcvto/ f'hrcv5 t, 1hz eoV rn SGL/IvrG fa aa�l/�l�y 14 I', ,n5 y,i q7-4_v,l gh-Zc, i- buil/ 1n✓ot.1,d .i_ehi� /ZJ�{`/� Spacing Exception Required? 'Yes No Cly ubse uent"Form Required:riot-r/20 �C �T,IS ju,^ r"X Q`% l"_`_1'T(.,/y.. APPROVED BYTHE Approved by: ..j !” 1" ..--. COMMISSIONER COMMISSION Date:Date /0-21_/,.. "—� � 1/7- Go/z6!/5" ORIGINAL RBDM ii022015 A/OA6/1 Submit Form and Form 10-403 Revised 5/2015 Approved application is valid for 12 months from the date of approval. Attachme is in Duplicate :U- .ice'' • • a) co m m mLoNrmmm Tr Cp 0) . 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CO t O -4' N O CO CO O C CO CD CD N- O O O J N CD N N O W corY 0 . W NCJ0 UDiQLDTh ZZZ ZaW W OOmm00 O D H Z J D D D TREE= MCEVOY • _ —SOP( NOTES:WELLHEAD= MCEVOY ACTUATOR= AXLESON G-1 3A KB.ELEV = 65.97' BF.ELEV= 37.52' I I KOP= 3200' 209T —14.5"OTIS SSSV. ID=3.813" Max Angle= 96° @ 10090' 0 2589' —19-5/8"DV PKR Datum MD= 9179' 2115' —14-1/2"X 3-1/2"XO, ID=2.992" Datum TVD= 8800'SS 111 20"CONDUCTOR 110' GAS LIFT MANDRELS 4.5" 12.6#L-80 TDS, --I 2115' ST MD TVD DEV TYPE VLV LATCH PORT DATE .0152 bpf, ID=3.958" 5 3067 3067 1 MERLA DMY RM 0 07/18/07 4 13-3/8"CSG,72#.L-80 BTRS, —1 2672' 5165 5064 22 MERLA DMY RM 0 07/18/07 3 6759 6541 22 MERLA DMY RA 0 03/02/01 ID= 12.347 2 7631 7364 16 MERLA DMY RA 0 03/02/01 1 8036 7753 17 MERLA DMY RA 0 03/02/01 8066' 3-1/2"PARKER SWS NIP Minimum ID = 1.90" @ 8150' MILLED TO 2.80"ON 02/09/01 TIW XO -TOP OF 2-3/8" LNR 8079' 1-13-1/2"XO TO 4-1/2", ID=3.95" 8083' —19-5/8"TIW HBBP PKR.ID=4.00" 2 0 8093' —14-1/2"XO T 0 3-1/2", ID=3.958" TOP OF 7"LNR —1 8137' - . 1 TOP OF 2-3/8"LNR — 8143' 8143' 2-3/8"'OW DEPLOY SLV, ID=2.25" 1w/3-1/2"BAITED BULLDOG SPEAR @ 8116'SLM II' 4 ' 4 '4 1 8150' —I TIW CROSSOVER PIN, ID=1.90" 4: 9-5/8"LNR.47#, L-80 BTRS. ID=8.681" —I 8655' I--4 : .$ 44 8773' —I JET CUT TBG(04/06/08) 41114 TOP OF CEMENT(08/03/08) —I 8790' I ' 4 8810' —2-3/8WED CIBP(04/05/08) 3-1/2"TBG,9.24 L-80 TDS,0087 bpf, ID=2.992" —I 9090' 1 : . i 4 PERFORATION SUMMARY ! k ;': .: 3-1/2"&7"MILLOUT WINDOW(G-13A)9090'-9094' REF LOG: SWS CNL 2/21/01 W70 .4• ANGLE AT TOP PERF: 48° @ 9263' ,•4 • . ,•.;..:* Note: Refer to Production DB for historical perf data •,a.,,..,•• '•.,W..• SIZE SPF INTERVAL Opn/Sqz DATE V4W,V4S 0.....".• 1-11/16" 4 9263-9278 C 08/02/03 •..0••• .• .-•••••• • ,*•••4 1-9/16" 6 9317-9337 C 05/06/01 %\% %% ,•1PV,..• •..••• % 1-9/16" 6 9345-9365 C 05/06/01 ,••••.• *-40••• 4 •••4, 1-11/16" 6 9445-9555 C 02/22/01 0:_••••••L N WS*.•• 1-11/16" 6 9624-9940 C 02/22/01 •41•••+ ••••••‘• 1-11/16" 6 10000- 10160 C 02/22/01 •I ••4 • ••• • •4.•••+ 0•^•• • 1-11/16" 6 10185- 10260 C 02/22/01 •• ••4 ••• • % •..•••., 1-11/16" 6 10330- 10460 C 02/22/01 .,•-•-•..•,•_• ,v•-•••••••••• 1-11/16" 6 10480- 10600 C 02/22/01 ••••••• %.•-•-•-•-•-•. % 1-11/16" 6 10610- 10690 C 02/22/01 , PBTD — 10779' 3-1/2"WHIPSTOCK 1-11/16" 7 10611 - 10690 C 02/23/01 H 9090' 1-11/16" 8 10612- 10690 C 02/24/01 (02/07/01) 2-3/8"LNR,4.64,L-80 STL, .0039 bpf.ID= 1.995" 10844' 7"LNR, 294, L-80 BTRS, .0371 bpf, ID=6.184" 9483' DATE REV BY COMMENTS DATE REV BY COMMENTS PRUDHOE BAY UNIT ORIGINAL COMPLETION 07/21/07 KSB/PJC GLV C/O(07/18/07) WELL: G-13A 02/22/01 CTD SIDTRACK(G-13A) 104/15/08 RRD/TLH TBG CUT&CIBP SET(04/06/08) PERMIT No:'2001630 03/10/01 CH/KAK FINAL 10/16/08 GJF/PJC BAITED SPEAR(09/25/08) API No: 50-029-20600-01 05/12/01 JLJ/TLH ADD PERFS 10/25/08 PJC DRAWING CORRECTIONS SEC 12,T11N. R13E,2224'NSL&2368'WEL 08/02/03 BJMc/TLH ADD PERFS 04/17/04 TWC/KAK CORRECTIONS BP Exploration (Alaska) ___ • • bp BP Exploration(Alaska) Inc. Douglas A. Cismoski, P.E., BPXA Wells Intervention Manager Post Office Box 196612 Anchorage,Alaska 99519-6612 August 27, 2015 Ms. Cathy P. Foerster Alaska Oil and Gas Conservation Commission 333 West 7th Avenue Anchorage, Alaska 99501 Subject: Prudhoe Bay Well G-13A (PTD # 2001630) Application for Renewal of Existing Suspension (10-403) Dear Ms. Foerster, BP Exploration (Alaska) Inc. completed an AOGCC witnessed suspended well inspection of Prudhoe Bay Unit well G-13A on 06/07/2014 (20 AAC 25.110 (h). This recently submitted suspended well inspection reflects the current condition of the well (reference 20 AAC 25.110 (f)) and supports the request for renewal of suspension. Recent events from this well indicate that this well is mechanically sound. Specific attachments include: • Wellbore diagram illustrating the current configuration of the well • Suspended Well Site Inspection form documenting the pressures and site condition • Pad map and aerial photo showing well location and other wells within one- quarter mile radius of the surface location. Prudhoe Bay Unit well G-13A was suspended on 10/06/2008. It is located on a pad with active wells and/or service wells. The strata through which the well was drilled is neither abnormally geopressured or depleted. The well is secured with a cement capped mechanical plug in the liner above the perforations. The well is mechanically ' sound as proven by a pressure test after the cement was placed. Based on these conditions and the inspection on 06/07/2014 Prudhoe Bay Unit well G-13A meets the provisions required in 20 AAC 25.110 (a)(1). Based on this information, BPXA requests approval for renewal of the existing suspension status for this well. Attached is an Application for Sundry Approval (10-403) with a technical justification summarizing the information on the current status and condition of the well (reference 20 AAC 25.110 (a), (b), (e), (h) and (i)). In summary, BPXA believes Prudhoe Bay well G-13A is mechanically sound and secure and meets the requirements for renewal of suspended status. If you have any questions, please call me at 564-4303 or Whitney Pettus/ Kevin Parks at 659-5102. • Sincerely, ,_12e7/g Douglas A. Cismoski, P.E. BPXA Wells Intervention Manager Attachments Technical Justification 2014 Suspended Well Site Inspection form Wellbore Schematic Well location plat and aerial photo Cc: Doug Cismoski Pettus/ Parks Ryan Daniel • 1� Prudhoe Bay Well G-13A (PTD 2001630) Technical Justification for Renewal of Suspended Status August 27, 2015 Well History and Status Prudhoe Bay Unit well G-13A (PTD 2001630) was suspended effective 10/06/2008. In preparation for a sidetrack a CIBP was set in the 2-3/8" liner, the liner was cut and cement was dumped on the plug. Several attempts were made to retrieve the section of liner above the cut at 8773', but they were unsuccessful. Because the liner could not be pulled the only remaining option was a rotary sidetrack which has not been pursued. The well is secured with a CIBP at 8810' capped with -20' of cement. In the current state the well will not allow the migration of fluids, will not damage freshwater or producing or potentially producing formations, will not impair the recovery of oil or gas, is secure, safe and not a threat to public health The strata through which the well was drilled is neither abnormally geo-pressured or depleted. Condition of Wellhead and Surface Location Prudhoe Bay Unit well G-13A is located on an active, well maintained pad with clean gravel. The surrounding area is in good condition and there is no discoloration and no sheen on the pad, pits or in nearby water. The well pressure readings are T/I/O= 144/147/147 psi recorded on 6/13/2014 and are stable. Request BPXA requests approval for renewal of the existing suspension status for G-13A. A variance to the provisions of 20 AAC 25.110 (c) (2) is also requested under 20 AAC 25.112 (i) to allow the well to remain as suspended in its current condition. All hydrocarbon intervals are isolated and there are no underground sources of fresh water in this area. 4111 Suspended Well Site Inspection Form Notify AOCCC Inspectors at least 10 days prior to inspection to allow witness Well Narrie, Prudhoe Bay Unit G-13A Field/Pool: Prudhoe Bay Field!Prudhoe Bay pool__ Permit#(PI 0): 2001630 API Number- 500292060001 Operator: BP EXPLORATION (ALASKA)INC Date Suspended: 1016/2008 Surface Location: Section: 12 Twsp: 11N Range: 13E Nearest active pad or road: Prudhoe bay Unit G,Pad Take to I ocation Digital camera Map showing well location/Aerial photos Brief well history Wellbore diagram showing downhole condition Latest Sundry or Completion report Past Site Visit documentation Site clearance documentation Pressure gauges,fittings,tools Sample containers for fluids on or near pad Condition of SJ,Eface Location AOGCC requires: 1)a description of the condition of the surface location, including discoloration,fluids or sheens visible on the ground or in any nearby water, 2)photographs showing the condition of the location surrounding the well General location condition. Active pad very good shape overall Pad or location surface good graded smooth clean Location cleanup needed: No Pits condition Ice, Snow, and water Surrounding area condition: good Water/fluids on pad No Discoloration,Sheens on pad,pits or water. No sheen Samples taken No Access road condition: Graded good Photographs taken(#and description): no Condition of Wellhead AOGCC requires 1)a description of the condition of the wellhead 2)welt pressure readings,where practicable, 3)photographs showing the wellhead condition Wellhead/tree/valve description,condition: McEvoy wellhead CIW tree good condition Cellar description,condition,fluids: Ice, clean Rat Hole: N/A Wellhouse or protective barriers. Well house Well identification sign. yes Tubing Pressure(or casing if no tubing). SSV is shut(DHD will open SSV and get TBG psi) Annulus pressuresIA=210 psi DA= 160 psi Wellhead Photos taken(#and description) yes,(1)sign(2)tree(1)SSV(1)back side of master valve Work Require? None Operator Rep(name and signature? Laurie Climer AOGCC Inspector Lou Grimaldi Other Observers: Kevin Parks Inspection Date 6/7/2014 AOGCC Notice Date: 6/61201 4 Time of arrival: 2:20 PM Time of Departure: 2:45 T'M Site access method: truck • • TREE= FACE'VOY W EL LNEA D= NCEVOY SAFETYNOTES 7. A CTLA TOR= AXLESON G_-I 3 A KB.BE = 65.S7" BF.EL EV= 37.57 96' 100 90' I KOP= 320D° I 2097' p 4.5'OTIS SSSV,ID=3.8 13" I Max Angie= El 1 _- CI —1 Datum SOD= 91 -- 79' 2115' H 4-12"X 3-1/2"X0,ID=2.992" --- DalumTVD= 880 O''SS 20'CONDUCTOR 10' 111"I 9-518' FKR , 1 2589' H_ Dv GAS LIFT MA PIXELS 4.5"12.6#L-80 TOG, —I 2115 Ii ST ND ND DEV TY FE V LV LA TCFII PORT DATE .0152 bpi',ID=1958' 5 3067 3067 1 AC-RLA OW RAI 0 0718/07 13-10 CSG,72 II,L-80 BTRS, H 2672' I1L1 4 5165 .5064 22 &ERA DAV RAI 0 0718/07 3 6759 654 1 22 AIEFLA OW RA 0 03E2/01 ID= 12347 I 2 7631 7364 16 MF_FLA DAN RA 0 03.02t0 1 IRII 1 8036 7753 17 I.ERLA OW RA 0 03.02101 8066' F 3-1,2"FABLER SWS MP Minimum ID=1.90"@ 8150' TO FALL ED 2.83-ON C2,9901 TIW XO-TOP OF 2-3/8"LNR 8079' H3-1.2"XO TO 4-12",ID=395' I war H9-58'71W FE1BF PIR.ID=4.00' I 8093' H4-1.2"X0 T 0 3-1t7,ID=3.958' I ITOP OF 7'L AR H 8137' . . TOP CF 2-311'LNR 8143' 2-1,8'TIW DEFLOY SLV,ID=2.25' . 'AI w;3-1,2'BATED BLLLDOG S PEA Fl,g;81 16 50.1 1:: 8150' 1-1-nw CROSSOVER FIR 10=1.50' I 4 '4 .." 4 ILP,4 7f,L-80 EfTRS,ID=8.68r H B6ST ha4 '41 41 4 4 4 8773' H.Ei cur MG taocherzA I .TOP OF CElicia(0803.98) H 8790' 40 0 e•i I •N.-! 1 88'W H2-3,1r 4WD CEP 04P0500) I 13-12"TBG,9.2#L-80 IDS,0087 If. 0=2.907 H 9090' • '4 4 4 • 4 4 PERFORATON SLAINARY 4 4 4 i 3-12'&7"NILLOLT188130W(G.I3A)9090-9094 REF LOG. SWS CR_2:21.01 ANGL EAT TOP FERF. 48' @ 3263 Note Hefei to Producbd.n 06 tor Ns Orcal port data SEE SFF INTERVAL CimoSqz DATE it Ilk, •t c to, 1-11116" 4 9263-9778 C COI/02,Q) 1-9116" 6 93 17-9337 C 05/06.91 t:4,., i.4„); •••pes°40 14e16" 6 9345-9365 C 05,106/31 N Vito%N •-"AN No' % 1-11116' 6 9445-955 5 C 02/2291 2••••••••C 1-11016" 6 9624-994 0 C 0222,91 N ViNN N to,,•••••,11 I., 1-11;16' 6 10000-10160 C 02,22.91 44 •••••4 % 1411 1-11,16" 6 10185-10260 C 02,22,91 4.". ••-4 • • .•• • 1-11116" 6 103.30-11)480 C Cf2.22Y31 ti:44Ftle...4i!O, Sill' 4411bt 1-11/16' 6 10480-10600 C 322291 41,•••••• ,..•-•-•-•.....; 1-1106" 6 106 10-10690 C 322201 FBTD 10779' 0'• 1-11;16" 7 10611-10690 c 0721 3-1/2"WHIPSTOCK 9090' 01 444 1-11/18' 11 106 12-106 90 C 022491 ;0207,91) 0.4 0 0' 4,0 12-34r LNR 4.60,L-80 STL, .0039 bpi,ID=1.995' H 10844' IT LNR,29#,L-80 BTRS,.037 1 bur,ID=6.184' H 94137 DATE REV BY COAIMENTS DATE REV BY CCP...EMI-6 PRUDHOE BAY LINT OFIGNAL CON PLETION 07.2107 KS8iPJC CIV CO 107/18/97) WELL:G-134 02122101 GTO SIC/TRACK(6-13A) 0415,38 RR611_I-I TBG CLT&CEP SET(0440898) PENT No:ik0 1630 03/1901 CHI'KA K R)AL 10/1898 (Si FTPJC BARED SFEAR(0925,08) API NZI:504129-20800-01 05(12,401 JUITLH ADD FERFS 10,2508 PJC CRAW NG CORRECTIONS SEC 12,71 04,R13E 2224FCL&2368 WEL 0190203 BJACTU-1 ACC PERS . . 041047. TWCIKAX 03RFECTIONS BP Exploration(Alaska) • 0 Erter Exit �l / 638' _ .r Z ■ i� i : 13. 32 12 21 I < . rr) 11 ow' .' NI 0 a-�� .5 10 . H , 25 T 27 si3 N 52 t• - it CI __ 1 CEI Enter.?Exit " `! 15 ' iip ( I 18 1.0 re. 117 5V t 18 ,. Enter xlt .— til r 1 Enter/6(d ic; I 'WELL PRODUCER •or WELL INJECTOR A DATE '0M6?2009 SCALE: 1" = 300' MAP DATE 2007 PBU - G PAD WELL SLOT'N.CONDUCTO q • • ,y — Pad * �. kqi. • July 25.2010 4 s, Approximate Seale: 1"=340 ., t�. 4/010-19c-6-2' ..'. '''''' ''''' 4* It". '' i''''''' ''''. .' ' . 421 , �� �ti -4 1..1�' 4 . ; s t • • t i n ',n. s 1 a .� _,...---7.7___,----"._" "�' 4-- 104,41, fir. e4. *' ' ' I '; ' " '° , - X 1,7014 * ot' �' t :"A5•x3 t .._ it., a ,., M h t Loepp, Victoria T (DOA) From: Daniel, Ryan <Ryan.Daniel@bp.com> Sent: Thursday, October 22, 2015 9:01 AM To: Loepp, Victoria T (DOA) Cc: Sternicki, Oliver R Subject: FW: PBU Suspension Renewal Wells Good Morning Victoria, Thanks for the conversation this morning. BPXA currently have 59 suspended status wells, of which many would not have *future utility today. My view for the business and from a risk perspective is to leave these wells "as is" until pad level decommissioning.The SU wells on pads with trees are monitored daily and pose minimum risk to our operations. Any wells,that are determined to have a higher risk associated with communication, re-pressurization etc will certainly be given priority for intervention and mitigation. *Additionally, as the business starts to realign from oil to gas over the next 10-15 years we would want to preserve various options(wells and surface locations)for the future. Let me know if you have any other questions Rgds Ryan From: Loepp, Victoria T(DOA) [mailto:victoria.loepp(aalaska.gov] Sent: Wednesday, October 21, 2015 3:56 PM To: Sternicki, Oliver R Subject: RE: PBU Suspension Renewal Wells Oliver, At what point will these wells with no future utility be brought closer to abandonment?Approximately how many suspended wells are in this category? Thanx, Victoria Victoria Loepp Senior Petroleum Engineer State of Alaska Oil&Gas Conservation Commission 333 W.7th Ave Anchorage,AK 99501 Work: (907)793-1247 Victoria.Loeop a alaska.gov 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 Loepp at(907)793-1247 or Victoria.Loepp@alaska.gov 1 • . LoepF, Victoria T (DOA) Subject: From: Daniel, Ryan [ ' o:Ryan.Daniel@bp.com] Sent: Tuesday, October 20, 2015 4:25 PM To: Loepp, Victoria T(DOA); Sternicki, Oliver R Cc: Regg, James B (DOA); Julian, Jennifer Y; Bill, Michael L(ASRC) Subject: RE: PBU Suspension Renewal Wells Hello Victoria, Negative. BP and its working Interest owners are developing some longer term options for"decommissioning" work scope which includes some wells and surface kit.These are screening opportunities only(potential future activities) and still in the very early scoping stage. They are not funded or approved yet, and as such it would be premature for BPXA to comment any further. The Observation well P&A program which I discussed recently with Jim, and the Suspended well renewal applications submitted by Oliver are also separate (discrete and unrelated)activity plans for well stock management and as such have different timelines and rational. We are happy to discuss the Suspended wells further id necessary. If you could use Oliver as the single point of contact for this work that would be much appreciated. Thanks Ryan From: Loepp, Victoria T(DOA) [mailto:victoria.loepp@ alaska.gov] Sent: Tuesday, October 20, 2015 2:16 PM To: Daniel, Ryan Subject: PBU Suspension Renewal Wells Ryan, Do you have any information to share with us on the sustained P&A program and where these suspension renewal wells fit in the program? Thanx, Victoria 1 • • From: Sternicki, Oliver R [mailto:Oliver.SternickiCalbp.com] Sent: Thursday, October 08, 2015 4:03 PM To: Loepp, Victoria T(DOA) Cc: Daniel, Ryan Subject: PBU Suspension Renewal Wells Victoria, This is the response from Base Management for the 9 suspended wells renewals and if the fall under A or B of 20AAC 25.110(a)(2). 20 AAC 25.110(a)(2):the well (A) has future utility as an exploratory, development,or service well; (B) is a viable candidate for redrilling;or (C) is located on a pad or platform with active producing or service wells. WGI-01: no current sidetrack plans 02-30B: no current sidetrack plans G-13A: no current sidetrack plans, but may use surface equipment for another well V-201: no current sidetrack plans S-14A: no current sidetrack plans W-09A: no current sidetrack plans E-18B: evaluating several sidetrack options NK-14A: evaluating a sidetrack option Y-25A: no current sidetrack plans Let me know if you have any other questions. Regards, Oliver Sternicki wo w Well Integrity Engineer BP Exploration Alaska Office: 1 (907) 564 4301 Cell: 1 (907)350 0759 oliver.sternicki(a).bp.com From: Loepp, Victoria T(DOA) [ +iailto:victoria.Ioepp@a>alaska.gov] Sent: Monday, September 28, 2015 3:10 PM To: Sternicki, Oliver R Subject: RE: PBU Suspension Renewal Wells So no well listed below,with the exception of I-100 has future utility as an exploratory,development,or service well and no well listed below is a viable candidate for redrilling? I understand the wells are all located on active pads. Victoria Victoria Loepp Senior Petroleum Engineer 2 • . State of Alaska • Oil&Gas Conservation Commission 333 W.7th Ave Anchorage,AK 99501 Work: (907)793-1247 Victoria.Loeppr7a alaska.Qov 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 Loepp at(907)793-1247 or Victoria.Loeoo@alaska.gov From: Sternicki, Oliver R [ •Oliver.S, rnicki@bp.coml Sent: Monday, September 28, 2015 2:41 PM To: Loepp, Victoria T(DOA) Cc: AK, D&C Well Integrity Coordinator; Daniel, Ryan Subject: RE: PBU Suspension Renewal Wells Victoria, The below wells that you have listed fall under the category; (C) is located on a pad or platform with active producing or service wells. 1-100 which you did not list is the only well that BPXA sent for renewal of suspended status that falls under the category. (A) has future utility as an exploratory, development, or service well; no wells meet the (B)criteria. Regards, Oliver Sternicki VVO p/obd web show Well Integrity Engineer BP Exploration Alaska Office: 1 (907) 564 4301 Cell: 1 (907) 350 0759 oliver.sternicki(c�bp.com From: Daniel, Ryan Sent: Monday, September 28, 2015 9:26 AM To: Sternicki, Oliver R Cc: AK, D&C Well Integrity Coordinator Subject: FW: PBU Suspension Renewal Wells Oliver, Can you please reply to Victoria on this question, Copy me, or come and discuss if we have an issue. Thanks Ryan 3 • • From: Loepp, Victoria T(DOA) [mailto:victoria.loepp@alaska.gov] Sent: Monday, September 28, 2015 9:25 AM To: Daniel, Ryan Subject: PBU Suspension Renewal Wells Ryan, PBU 02-30B 200-126 PBU V-201 201-222 PBU E-18B 204-139 PBU G-13A 200-163 PBU S-14A 204-071 PBU W-09A 204-102 PBU WGI-01 179-031 PBU Y-25A 208-140 PBU NK-14A 206-031 20 AAC 25.110(a)(2):the well (A) has future utility as an exploratory, development,or service well; (B) is a viable candidate for redrilling; or (C) is located on a pad or platform with active producing or service wells. Which wells meet the criteria of(A) and/or(B)? Thanx, Victoria Victoria Loepp Senior Petroleum Engineer State of Alaska Oil&Gas Conservation Commission 333 W.7th Ave Anchorage,AK 99501 Work: (907)793-1247 Victoria.Loepr aC�alaska.Qov 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 Loepp at(907)793-1247 or Victoria.Loeoo@al: a.go\ 4 • • bp BP Exploration (Alaska) Inc. Attn: Well Integrity Coordinator, PAB -20 Post Office Box 196612 Anchorage, Alaska 99519 -6612 May 18, 2012 ED AU G 7 2 5�1% 0' " Mr. Jim Regg / Alaska Oil and Gas Conservation Commission n no - / (p 3 333 West 7 Avenue d' 3 1 Anchorage, Alaska 99501 �� Subject: Corrosion Inhibitor Treatments of GPB G -Pad Dear Mr. Regg, Enclosed please find multiple copies of a spreadsheet with a list of wells from GPB Pad G 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 • • BP Exploration (Alaska) Inc. Surface Casing by Conductor Annulus Cement, Corrosion inhibitor, Sealant Top -off Report of Sundry Operations (10 -404) G-Pad Date: 03/05/2012 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 G-01A 1931710 50029202140100 3.0 NA 3.0 NA 10.2 5/10/2010 G-02B 2081580 50029202170200 0.5 NA 0.5 NA 2.6 5/10/2010 G -03A 1970700 50029202210100 0.7 NA 0.7 NA 6.0 5/27/2010 G-04B 2061400 50029202250200 0.1 NA 0.1 NA 1.7 5/10/2010 G -05 1780970 50029203510000 0.0 NA 0.0 NA 0.0 5/10/2010 G-06A 2060120 50029203580100 0.6 NA 0.6 NA 5.1 5/12/2010 G -07 1790180 50029203590000 0.5 NA 0.5 NA 3.4 5/11/2010 G -08A 2061830 50029205810100 0.1 NA 0.1 NA 0.9 5/27/2010 G -098 2071100 50029205820200 9.0 NA 9.0 NA 69.7 5/20/2010 G -10C 2060090 50029205530300 0.9 NA 0.9 NA 8.5 3/5/2012 G -11B 2080270 50029205830200 0.0 NA 0.0 NA 0.0 5/21/2010 G -12B 2031410 50029205970200 0.5 NA 0.5 NA 2.6 5/13/2010 ._- G -13A 2001630 50029206000100 0.0 NA 0.0 NA Trace 5/12/2010 G -148 2090680 50029206460200 0.7 NA 0.7 NA 5.1 5/22/2010 G -158 2080650 50029206470200 26.0 4.0 0.5 7/16/2011 3.4 7/19/2011 G -16A 2090560 50029206430100 0.0 NA 0.0 NA Trace 5/22/2010 G -17A 2060760 50029206190100 21.4 4.0 0.6 7/16/2011 3.4 7/19/2011 G -18A 1990320 50029206200100 71.7 14.0 1.0 7/16/2011 8.5 7/19/2011 G -198 2071240 50029215990200 0.0 NA 0.0 NA Trace 5/22/2010 G -21 1951540 50029226040000 0.5 NA 0.5 NA 3.4 5/12/2010 G -23B 2091440 50029216800200 0.5 NA 0.5 NA 4.3 5/11/2010 G -24A 2060820 50029216710100 0.1 NA 0.1 NA 0.9 5/11/2010 G -258 2070860 50029216520200 5.3 NA 5.3 NA 23.8 5/28/2010 G -26B 2050480 50029216610200 2.0 NA 2.0 NA 6.8 5/11/2010 G -27A 2070310 50029216460100 0.5 NA 0.5 NA 2.6 5/30/2010 G -29B 2101410 50029216500200 2.8 NA 3.0 NA 17.0 5/13/2010 G -30C 2091510 50029216130300 1.0 NA 1.1 NA 5.1 5/30/2010 G -31B 2090310 50029216160200 0.8 NA 0.8 NA 6.0 5/21/2010 G -32A 1970010 50029216360100 0.8 NA 0.8 NA 3.4 5/21/2010 • STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION Suspended Well Inspection Report Date Inspected: 09/11/10 Inspector: Chuck Scheve Operator: BPX Well Name: PBU G -13A - Oper. Rep: Jack Winslow PTD No.: 2001630 Oper. Phone: 659 -5766 Location Verified? No Oper. Email: If Verified, How? Onshore / Offshore: Onshore Suspension Date: 10/06/08 Date AOGCC Notified: Sundry No.: Well Completion Rpt Type of Inspection: Initial Wellbore Diagram Avail.? Yes Well Pressures (psi): Tubing N/A Photos Taken? Yes IA 360 - by Operator OA 320 Condition of Wellhead: Well house in place, full tree with master valve chained and locked closed. Flow line intact. Condition of OK Surrounding Surface Location: Follow Up Actions none Needed: „ " Ay1a ♦ • Attachments: None REVIEWED BY: pp Insp. Supry :!-7r ,�, - oh, 1( Comm PLB 08/2010 2010- 0911_Suspend_PBU_G- 13A_cs.xls STATE OF ALASKA ALASKAL AND GAS CONSERVATION COMMIS REPORT OF SUNDRY WELL OPERATIONS 1. Operations Abandon ❑ Repair Well ❑ Plug Perforations ❑ Stimulate ❑ Other ❑� Performed: Alter Casing ❑ Pull Tubing El Perforate New Pool ❑ Waiver❑ Time Extension ❑ INSPECT Change Approved Program ❑ Operat. Shutdown ❑ Perforate ❑ Re -enter Suspended Well ❑ WELL 2. Operator BP Exploration (Alaska), Inc. 4. Well Class Before Work: 5. Permit to Drill Number: Name: Development ❑� Exploratory ❑ t 200 -1630 3. Address: P.O. Box 196612 Stratigraphic❑ Service ❑ 6. API Nurpber: Anchorage, AK 99519 -6612 \ 50- 029 - 20600 -01 -00 8. Property Designation (Lease Number) : \1 9. Well Name and Number: ADLO- 028304 PBU G-1 3A 10. Field /Pool(s): PRUDHOE BAY FIELD / PRUDHOE OIL POOL 11. Present Well Condition Summary: Total Depth measured 10844 feet Plugs (measured) 8810' feet true vertical 8989.9 feet Junk (measured) None feet Effective Depth measured 8790 feet Packer (measured) 8092 true vertical 8486. feet (true vertical) 7798 Casing Length Size MD TVD Burst Collapse Structural Conductor 110 20" SURFACE - 110 SURFACE - 110 Surface 2673 13 -3/8" 72# L -80 SURFACE - 2673 SURFACE - 2673 4930 2670 Intermediate 8649 9 -5/8" 47# L -80 SURFACE - 8649 SURFACE - 8349 6870 4760 Production Liner 953 7" 29# L -80 8137 - 9090 7851 - 8780 8160 7020 Liner 2701 2 -3/8" 4.6# L -80 8143 - 10844 7856 - 8990 11200 11780 Perforation depth: Measured depth: SEE ATTACHED - True Vertical depth: Tubing: (size, grade, measured and true vertical depth) 3 -1/2" 9.3# L -80 28-8137 28-7851 Packers and SSSV (type, measured and true vertical depth) Baker S -3 Packer 8092 7798 12. Stimulation or cement squeeze summary: S E P 2 Q 2 01 0 Intervals treated (measured): Treatment descriptions including volumes used and final pressure: M. X 011 (, 13. Representative Daily Average Production or Injection Data Oil -Bbl Gas -Mcf Water -Bbl Casing Pressure Tubing pressure Prior to well operation: SI Subsequent to operation: 14. Attachments: 15. Well Class after work: Copies of Logs and Surveys Run Exploratory ❑\ D lopment� Service El Daily Report of Well Operations X 16. Well Status after we USPENDED Oil Gas WDSPL GSTOR ❑ WAG ❑ GINJ ❑ WINJ❑ SPLUG ❑ 17. 1 hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt: NA Contact Gary Preble Printed Name Gary Preble Title Data Management Enginee Signature Phone 564 -4944 Date ' V HUMS SEP ,# / / / //a G -13A 200 -163 PERF ATTACHMENT Sw Name Operation Date Perf Operation Code Meas Depth Top Meas Depth Base Tvd Depth Top Tvd Depth Base G -13A 2122/01 PER 9,445. 9,555. 9,014.72 9,021.5 G -13A 2/22/01 PER 10,610. 10,690. 8,990.27 8,988.63 G -13A 2/22/01 PER 10,330. 10,460. 8,996.38 8,993.43 G -13A 2/22101 PER 10,480. 10,600. 8,991.6 8,990.69 G -13A 2/22101 PER 10,000. 10,160. 9,010.9 9,001.45 G -13A 2/22/01 PER 9,624. 9,940. 9,021.63 9,011.68 G -13A 2/22/01 PER 10,185. 10,260. 9,000.17 8,996.44 G -13A 5/6/01 APF 9,317. 9,337. 8,964.43 8,975.61 G -13A 5/6101 APF 9,345. 9,365. 8,980.26 8,990.98 G -13A 8/2/03 APF 9,263. 9,278. 8,932.84 8,942.46 G -13A 8/2/08 AB 8,798. 10,690. 8,494.08 8,988.63 AB ABANDONED PER PERF APF ADD PERF RPF REPERF BPP BRIDGE PLUG PULLED SL SLOTTED LINER BPS BRIDGE PLUG SET SPR SAND PLUG REMOVED FCO FILL CLEAN OUT SPS SAND PLUG SET FIL FILL I SQF SQUEEZE FAILED MIR MECHANICAL ISOLATED REMOVED SQZ SQUEEZE MIS MECHANICAL ISOLATED STC STRADDLE PACK, CLOSED MLK MECHANICAL LEAK ISTO ISTRADDLE PACK, OPEN OH OPEN HOLE Prudhoe Bay Unit Well G-1 3A, PTD 2001630 Suspended Well Inspection Report BP Exploration (Alaska) Inc. (BPXA) completed a suspended well inspection of PBU G-1 3A on 9/11/10. The following attachments document the inspection and the current condition of the well (reference 20 AAC 25.110 (e) and (f)). • Suspended Well Site Inspection form documenting the well pressures and site condition. AOGCC inspector Chuck Scheve witnessed the inspection. • Wellbore diagram illustrating the current configuration of the well • Pad map showing the well location and other wells within one - quarter mile radius of the surface location • Photographs showing the condition of the wellhead and the surrounding location Additional pertinent information: • PBU G-1 3A was suspended on 10/06/08 after preparations for a rig sidetrack. • PBU G-1 3A is located on a pad with active producing wells and /or service wells. • The strata through which the well was drilled is neither abnormally geo- pressured or depleted. • The well is secured with a bridge plug at 8810' MD in the liner with cement left on top. • The well is mechanically sound as proven by a pressure test after the plug was set. MLB 09/14/10 Suspended Well Site Inspection Form Notify AOGCC Inspectors at least 10 days prior to inspection to allow witness Well Name: PRUDHOE BAY UNIT G -13A Field /Pool: PRUDHOE BAY / PRUDHOE OIL Permit # (PTD): 2001630 API Number: 50029206000100 Operator: BP EXPLORATION (ALASKA) INC Date Suspended: 10/6/2008 Surface Location: Section: 12 Twsp: 11N Range: 13E Nearest active pad or road: PRUDHOE BAY G-PAD Take to Location Digital camera Map showing well location /Aerial photos Brief well history Wellbore diagram showing downhole condition Latest Sundry or Completion report Past Site Visit documentation Site clearance documentation Pressure gauges, fittings, tools Sample containers for fluids on or near pad Condition of Surface Location AOGCC requires: 1) a description of the condition of the surface location, including discoloration, fluids or sheens visible on the ground or in any nearby water, 2) photographs showing the condition of the location surrounding the well General location condition: Good Pad or location surface: Gravel pad Location cleanup needed: No Pits condition: Good Surrounding area condition: Good Water /fluids on pad: No Discoloration, Sheens on pad, pits or water: No Samples taken: None Access road condition: Good Photographs taken (# and description): (2) wellhouse and sign Condition of Wellhead AOGCC requires: 1) a description of the condition of the wellhead, 2) well pressure readings, where practicable, 3) photographs showing the wellhead condition Wellhead /tree /valve description, condition: McEvoy wellhead; CIW tree - good condition Cellar description, condition, fluids: Gravel dry Rat Hole: None Wellhouse or protective barriers: Wellhouse Well identification sign: Yes Tubing Pressure (or casing if no tubing): Master valve locked out Annulus pressures: IA = 360 psi OA = 320 psi 1A ble '1/1 0 l o - lo.L�•% Wellhead Photos taken (# and description): (2) wellhead and tree Work Required: None Operator Rep (name and signature): Torin Roschinger otZ d AOGCC Inspector: Chuck Scheve Other Observers: Jack Winslow Inspection Date: 9/11/2010 AOGCC Notice Date: 9/8/2010 Time of arrival: 8:50 AM Time of Departure: 9:00 AM Site access method: Truck TREE = MCEV OY WELLHEAD = MCEVOY G �� SAFETY TES: ACTUATOR= AXLESON KB. ELEV = 65.97' BF. R EV = 3 7.52' KOP = 3200' 2097' 4.5" OTIS SSSV, ID = 3.813" Max Angle = 96° @ 10090' Datum MD = 9179' Datum TVD = 8800' SS 20" CONDUCTOR 2589' 4 9-5/8 - - Dv PKR 110' GAS LIFT MANDRELS 1 4.5" 12.6# L - TDS, 2115 ST MD TVD DEV TYPE VLV LATCH PORT DATE . 0 bpf, ID = 3.958" 5 3067 3067 1 MERLA DMY RM 0 07/18/07 4 5165 5064 22 MERLA DMY RM 0 07/18/07 13 -3 /8" CSG, 72 #, L -80 BTRS, 2672' 3 6759 6541 22 MERLA DMY RA 0 03/02/01 ID = 12.347 2 7631 7364 16 MERLA DMY RA 0 03/02/01 1 8036 7753 17 1 MERLA I DMY RA 1 0 03102/01 Minimum ID =1.90" 8150' 8066' 3 -v2" PARKER SWS NIP MILLED TO 2.80' ON 02109/01 TIW XO -TOP OF 2 -3/8" LNR 8079' 3 -1/2" XO TO 4 -1/2 ", ID = 3.95" 8083' 9 -5/8" TMt HBBP PKR, ID = 4.00" TOP OF 7" LNR 8137 8093' 4 -1/2" XO T O 3 -1t2 ", TOP OF 2 -3/8" LNR 8143 8143 2 -3/8" TIN DEPLOY SLV, ID = 2.25" w/3 -1/2" BAITED BU LLD OG SPEAR@ 8116' SLM —F__ TIW CROSSOVER PIN, ID = 1.90" 9 -5/8" LNR, 47 #, L -80 BTRS, ID = 8.681" 8655' $773' JET CUT TBG (04/06/08) TOP OF CEMENT (08/03/08) 8790' 8810' 2 -3/8" WFD CIBP (04/05/08) 1 3-1/2" TBG, 9.2# L - TDS, 0087 bpf, ID = 2.992" 9090' PERFORATION SUMMARY REF LOG: SWS CNL 2/21/01 3-1/2" & 7" N1ILLOUT WINDOW (G-1 3A) 9090'- 9094' ANGLE AT TOP PERF: 48° @ 9263' Note: Refer to Production DB for historical perf data SIZE SPF INTERVAL Opn /Sqz DATE 1- 11/16" 4 9263-9278 C 08/02/03 1- 9/16" 6 9317-9337 C 05106/01 1- 9/16" 6 9345-9365 C 05106/01 1- 11116" 6 9445-9555 C 02/22/01 1- 11/16" 6 9624-9940 C 02/22/01 1- 11/16" 6 10000 - 10160 C 02/22/01 1- 11/16" 6 10185 - 10260 C 02/22/01 1- 11/16" 6 10330 - 10460 C 02/22/01 1- 11/16" 6 10480 - 10600 C 02/22/01 1- 11/16" 6 10610 - 10690 C 02/22/01 PBTD 10779' 1- 11/16" 7 10611 - 10690 C 02/23/01 3-1/2" WHIPSTOCK 9090' 1- 11/16" 8 10612 -10690 C 02/24/01 1 (02/07/01) 9483 2-3/8" LNR, 4.6 #, L -80 STL, .0039 bpf ID = 1.995" 10844' FT��9#, L-80 BTRS, .0371 bpf, ID = 6.184" DATE REV BY COMMENTS DATE REV BY COMMENTS PRUDHOE BAY UNIT ORIGINAL COMPLETION 07/21/07 KSB /PJC GLV C/O (07!18/07) WELL: G -13A 02/22/01 CTD SIDTRACK (G -13A) 04/15/08 RRD /TLH TBG CUT & CIBP SET (04/06/08) PERMIT No: 2001630 03/10/01 CH /KAK FINAL 10/16/08 GJF /PJC BAITED SPEAR (09/25/08) API No: 50- 029 - 20600 -01 05/12/01 JLJ /TLH ADD PERFS 10125108 PJC DRAWING CORRECTIONS SEC 12, T1 1N, R13E, 2224' NSL & 2368' WEL 08/02103 BJMc /TL ADD PERFS 04/17/04 jTWC/KAKj CORRECTIONS 0 1 BP Exploration (Alaska) Enter /Exit 638' 0 Z ■ J 1 �- 2 13 t— L ■3 32 - 12 21 4 53 31 F 11 r 30 ■ 5 i \� 10 i 26 25 29 6 9 24 27 23 $ 7 52 C� 54 Enter /Ex t 14 ~ y 15 ■_ �� i 16 ■ - -- 17 ■ r- r - �18 ■- `* r Enter /Exit T19 — I Enter /Exit WELL PRODUCER ■ or ❑ WELL INJECTOR A DATE : 01/06/2009 SCALE : 1" = 300' MAP DATE : 2007 PBU - G PAD WELL SLOT W /CONDUCTOR 0 bs14495.dgn ``` • rt • G Pad ` a - July 25, 2010 " Approximate Scale: 1 " =300' �} 2010- 19c -6 -28 AV A l � I � t r. N. 4 7 , I 1 +- p s e y 'y� s Aft- tt°" a i • s F s�s . xv a. ` � � ..�.. y . : . . . / : . >¥ � � ., , \ \��s�� .� \ :»� \ \� . wa �° � ,/. � ®�\ : y� �� � � � ?< :2� \ \ »3— . � . . .. . .. w « . ^� � , 2.� ^ � � \� f – � �� � ^ $x, a > : � . . <�— y � � a 22 ». � «��� . . � \2� <� � . � ? � . � :.1. � y ) . . � . / +. \ . .� ^ .} \� / - .�����`.� . � , -��� � � s� „a,.�.�. �. I ; G-1 3A (PTD #2001630) TIO Entry WeN: G -13 4000 3,000 —!— Tbg t IA 2 OA OOA — OOOA ^ On 1A 2�f° 1,000 J ----------- r 07103/10 07/17/10 07/31/10 08/14/10 08/28/10 09/11/10 • L J a L ~ ~- ~~ ~ ~ ~ ~ ~ ~°~ ~ SARAH PAL1N, GOVERNOR L-E e ' ~ ~~ ~~+ ~aT ~r L~Lt~a7~ OIL Al`D V[A5 333 W. 7th AVENUE, SUITE 100 COI~SERQATIOI~T COMrIISSIOI~T ~ ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 Robert Tirpack Engineering Team Leader BP Exploration (Alaska) Inc. P.O. Box 196612 , _.__ Anchorage, Alaska 99519-6612 ~~;~ ...,, Re: Prudhoe Bay Field, Prudhoe Bay Oil Pool, G-13A Well Sundry Number: 309-180 Dear Mr. Tirpack: "~; ~ , ~~~' ~ ~ ~ .) 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. When providing notice for a representative of the Commission to witness any required test, contact the Commission's petroleum field inspector at (907) 659-3607 (pager). As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the Commission grants for good cause shown, a person affected by it may file with the Commission an application for rehearing. A request for rehearing is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. A person may not appeal a Commission decision to Superior Court unless rehearing has been requested. Sincerely, DATED this 2 day of June, 2009 P Cathy P. Foerster Commissioner Encl. -- _ - STATE OF ALASKA ~ r~~ ALA OIL AND GAS CONSERVATION COMMISSION .~l` ~~~~ 6 .Y '~l APPLICATION FOR SUNDRY APPROVAL 20 AAC 25.280 t+/~~t'ar5~ ns: ~~mm~;~ >> 1. Type Of Request: ®Abandon ~ ^ Suspend ^ Operation Shutdown ^ Perforate ^ Time Exte ~7t8t~ ~~ ^ Alter Casing ^ Repair Well ^ Plug Perforations ^ Stimulate ~Re-Ent~nded well ^ Change Approved Program ^ Pull Tubing ^ Perforate New Pool ^ Waiver ^ Other 2. Operator Name: 4. Current Well Class: 5. Permit To Drill Number BP Exploration (Alaska) Inc. ,® Development ^ Exploratory 200-163 - 3. Address: ^ Service ^ Stratigraphic 6. API Number: P.O. Box 196612, Anchorage, Alaska 99519-6612 50-029-20600-01-00 - 7. If perforating, closest approach in pool(s) opened by this operation to nearest 8. Well Name and Number: property line where ownership or landownership changes: PBU G-13A Spacing Exception Required? ^ Yes ®No 9. Property Designation: 10. KB Elevation (ft): 11. Field /Pool(s): ADL 028304 - 66' ~ Prudhoe Bay Field / Prudhoe Bay Oil Pool 12. PRESENT WELL CONDITION SUM MARY Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD (ft): Effective Depth TVD (ft): Plugs (measured): Junk (measured): 10844' ~ 8990'- 8790' 8486' - 8790' None in nth iz MD TV rs II r ral 11 2 11 rf ce 2 73' 13- / " 2 7 ' 73' 493 670 In rm di t 64 ' 9-5/8" 8 49' 70 4760 'n finer 953' 7" 8137' - 090' 7 1' - 8780' 81 7 2 Liner 2701' 2-3/8" 8143' - 1 844' 7856' - 990' 11 0 1178 Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): Below CIBP: 9263' - 10690' 8933' - 8989' 4-1/2", 12.6# x 3-1/2", 9.2# L-80 9090' Packers and SSSV Type: 9-5/8" x 3-1/2" TIW 'HBBP' packer Packers and SSSV MD (ft): 8083' 13. Attachments: 14. Well Class after proposed work: ® Description Summary of Proposal ^ BOP Sketch ' ^ Exploratory ®Development ^ Service ^ Detailed Operations Program 15. Estimated Date for 16. Well Status after proposed work: Commencin O erations: June 15, 2009 ^ Oil ^ Gas ^ Plugged ®Abandoned 17. Verbal Approval: Date: ^ WAG ^ GINJ ^ WINJ ^ WDSPL Commission Representative: 18. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact John Rose, 564-5271 Printed Name Robert Tirpack Title Engineering Team Leader _ Prepared By Name/Number Phone 564-4166 Date ~w77 U Terrie Hubble, 564-4628 Signature ~ ` Commission Use Onl Sundry Number: 3D _ ~~ Conditions of approval: Notify Gommission so that a representative may witness W ~~~ Ste` sl6-o~ ^ Plug Integrity BOP Test ^ Mechanical Integrity Test ^ Location Clearance Other: 35 ~S~ t~.'~~~ ~ a~~ eS ~ T-:.+~. ~ ~.~ +-1Qn~.~ tGr- ~S~ Subsequent Form Required: ~~ APPROVED BY ~ ^~ . ~ A roved B COMMISSIONER THE COMMISSION Date Form 10-403 Revised /2006 ~ „ Submit In Duplicate ,._ ~ ~.~ .l.aN ~ ~ Boas l • • by cr y G-13B Sundry Request Well Type: Producer Current Status: Suspended Request: Plug and abandon wellbore in preparation for Ivishak sidetrack. Well History: The current well is a coil sidetrack (with a 2-3/8" production liner) that was drilled in February 2001 as a horizontal 1A well. The Zone 1A rock quality looked poor. The well did not land deep enough to confirm HOT. After landing, the well inverted in back up to and continued to drill following structure. A total of 991' of initial perfs were shot in Zone 1A only (9445'-9555', 9624'-9940', 10,000'-10,160', 10,185'-10,260', 10,330'- 10,460',10,480'-10,600', and 10,610'-10,690'). A SBHPS was run March 15, 2001 after only a week of production. This test is Zone 1 A only. The pressure was 2593 psi with a temperature of 194°F at 8800' SS. The results show that the well was drilled in the LPA. The well came on line in March 2001 at only 400-500 BOPD at 10,000 GOR. Additional perforation were shot in Z1 B in May 2001 in an attempt to improve rate. The add pert did not pan out as hoped. The oil rate jumped a little to 500-600 BOPD but the GOR doubled to over 20,000. An SCMT was run in June 2003 and showed marginal bond and pretty poor quality cement across the Sag River, which was encouraging because it opened up the possibility of a cut and pull of the upper part of the 2- 7/8" liner to set up the well for another coil sidetrack. In September 2008, the liner was jet cut and 1-3/4" coil was used to try to pull the top of the liner free. The first attempts was unsuccessful but the pulling capability was limited by the 1-3/4" coil, so we decided another attempt would be made when 2-3/8" coil was available. The 2-3/8" attempt occurred in October 2008 and was also unsuccessful. The well now has to be sidetracked with a big rig because the kickoff point will be above the Kingak, which will require an intermediate drilling liner. Other Requests: Given rig floor height limitations, a MASP < 3000 psi, and the fact that the three ram drilling BOP configuration is preferred to a two ram configuration with a spool, BPXA will execute the provisions of 20 AAC 25.285 (f) (1) regarding the initial testing of the BOPE as follows when existing wellhead or testing equipment prevents the testing of the lowest set of pipe rams: That lowest set of rams will be tested at the earliest opportunity during path-forward de-completion work, i.e., after the completion has been pulled from the well. Safety concerns and spacing limitations with the wellhead height and tubing spool preclude us from installing a spacer spool in the three-ram drilling BOP stack. Scope of Work: As the perforations in the existing 2-3/8" production liner have already been isolated on this well with a CIBP set at 8810' MD (set on 4/5/08) with 20' of cement (placed on 8/3/08), the request within this Sundry is to have the current status of this well changed from "Suspended" to "P&A" in preparation for the planned G-13B rotary G-13A Sundry Application 1 5/21/2009 • • sidetrack. (Notes: A successful CMIT-TxIAxOA to 2000 psi on 5/7/09 to confirm integrity of P&A barriers.) With the P&A work already completed, the other pre-rig work scheduled for this well includes at tubing cut at 8041' MD, circulating out the well to clean seawater and diesel freeze protect and testing the tubing and inter-casing pack-offs MASP: 2294 psi Pre-Rig Work: 1. CMIT-TxIAxOA to 2000 psi. - DONE (5!7/09) (NOTE: This CMIT was designed not to exceed the normal 2000 psi pressure test requirement for the OA, however, this test pressure is ~82 psi short of AOGCC P&A test requirements, i.e., .25 psi/ft "8330' TVD = 2082 si. 2. PPPOT-IC to 3500 psi, PPPOT-T to 5000 psi. Cycle all LDS and replace/repair as re uired. 3. Drift tubin to 8050' in re aration for 'et cut. 4. Jet cut tubing at 8041' MD (mid-first full joint of tubing above the HBBP packer at 8082' MD see tubin tall 5. Circulate the well to clean seawater throu h the tubin cut. 6. Freeze rotect T & IA to 2100 MD with diesel. 7. Set BPV in tubin han er and test to 2000 si from below. 8. Remove wellhouse and flow-lines and level ad as re uired. Proposed Drilfing Rig Operations: 1. MI/RU. 2. CMIT-TxIAxOA to 2000 psi. 3. Pull BPV w/tested lubricator and circulate out diesel freeze protection and displace the well to seawater. 4. Set and re-test TWC to 2,000 psi from below and 3500 psi from above for 10 minutes. 5. Nipple down tree. Nipple up and test BOPE to 3500psi. Pull TWC w/tested lubricator. 6. R/U & pull 4-1/2" x 31/z" tubing from the cut depth at 8041' MD. 7. Test lower set of rams if required. 8. PU drillpipe and make bit and scraper run to the top of the tubing stub. 9. RU E-line and RIH w/GR/CCL to top stub and log-out to 6500' MD to find good KOP (a good shale / no -~ . casing collar) in the Colville. ~h~~ ~ 10. RIH with HES EZSV bridge plug on E-line and set at 7000' MD, as required to avoid cutting a casing collar l~~~p~e while milling the window. Test casing to 2000 psi f/30 min and chart. ``^^'~( 11. P/U and RIH with 9 s/a" Baker bottom-trip anchor whip stock assembly. Orient whip stock and set on EZSV bridge plug. Shear off of whip stock. 12. Displace the well to LSND based milling fluid per MI mud program. (End Work Under Sundry Approval #xxx-xxx /Begin Work Under PTD #xxx-xxx) 13. Mill window in 9 5/s" casing at 7000' MD, plus approximately 20' of new hole beyond middle of window and circulate well-bore clean. 14. Pull up into 9 s/8" casing and conduct a FIT. POOH. 15. M/U 8-'/z" Dir/GR/Res/PWD assembly. RIH, kick off and drill the 8-'/2" intermediate section to the top of the Sag River, per the wellplan. Circulate well clean, short trip to window. POOH. 16. Run and cement (1000' tail job) a 7", 26.0#, L-80 intermediate casing string and test to 3500 psi on the bump. 17. Spilt stack and install new tubing spool per Cameron wellhead specialist. 18. M/U and RIH with a 6 1/8" drilling assembly w/motor assembly w/insert bit, Dir/GR + insert bit and drill 20' of new hole and run FIT. 19. Drill ahead per the directional plan and land the well in the Ivishak target. 20. POOH for bit / BHA change. 21. MU and RIH with a 6-1 /8" drilling assembly w/PDC bit, Nue/Density and Impulse as detailed in well plan and mad-pass build section as required by Geologist in real time before drilling lateral. G-13A Sundry Application 2 5/21/2009 22. Drill horizontal section to planned TD, short trip as necessary. 23. Circulate, short trip, spot liner running pill. POOH. 24. Run and cement a 4-~/z", 12.6#, L-80, IBT-M production liner. POOH L/D all drill pipe. 25. R/U and run 4-'h", 12.6#, 13 Cr-80, VamTop completion tubing. Land the tubing RILDS. 26. Reverse circulate inhibited seawater to the production packer depth. 27. Drop ball & rod and set packer and individually test the tubing and annulus to 3,500psi 30 minutes each test. 28. Shear the DCK valve and pump each way to confirm shear. 29. Set a TWC and #est to 1000 psi from above and below. 30. Nipple down the BOPE. Nipple up the tree and test to S,OOOpsi. Pull TWC w/lubricator. 31. Freeze protect the well to 2,200' TVD with diesel. 32. Install BPV and secure the well. 33. Rig down and move off. Post-Rig Operations: (S-Riser Modification will be Required) 1. MI / RU slick line. 2. Pull the ball and rod / RHC plug from landing nipple below the production packer. 3. Install gas lift valves. 4. Install well house and instrumentation. Estimated Pre-rig Start Date: 06/15/2009 Estimated Spud Date: 07/15/2009 Drilling Engineer: John Rose Production Engineer: Chris Zamora Geologist: Kristin Papp ATTACH: Current Well Schematic (907) 564 - 5271 (907) 564 - 4138 (907) 564 - 5256 v,~~ fd,~~~- 30$- cgs ~ Record ~~rv~J~ /~D qo~~i t%'osd ~~y~~'~~s ~~ ~; ~ w ~{c~ s~ may, 6~~~~ G-13A Sundry Application 3 5/21/2009 IIC BitOY OiA7E R6J IY C4~gBifi'9 DATE REU BY ODDYBEttiS O'ltIDINAI COIN PtlTgN DYld1NP kSBJP,~ LV CA F1~A~ 1 L 1 _ 4 PRU DMD E 1AY U NR Nd El L: O-t dP1 PERUII'NO: ~1b~ RPINO: SD~G~D-X800-01 T11M,R13E,22Z~ t~L&Z388 DP ®pwrabon (Aq~ Ne] G-13A Sundry Application 4 5/21/2009 __ _ , ,, TREE- gC610Y M - _ Y t:TLMW R - RXLE90 Ki. BB! - 6697' IOP - 3210 Ndt R I yk - 96• Q 100 D;11~ ~- 9/T 9r Df'1~ ND- 8500' ~ S' 12 biM l~ TDS, 2115' A15Z Opt, ~ - 3.958' 13315 CSG,T21l, L~ ITRS, Z ID- 123tT 3-1F~" Tu~~g Qrt »8041' a Minimum ~ ~ 1.90" ~ 8150' T~ItxO -TOP OF 2-3f8" LNR ~-~ ~~ I Pact C+13x Pre-Sid~traak'Yv'afk I 2AB~l LSO'TISSSSV,B]-3.813 1 ~-1!? X 3111 lQD, m- 2.9921 2~ ~8' OV PIA! GAS LIFT 4k1NDRELS S MD TVD OEJ TYPE VLV lRT1GYf PDRT DATE 1 i SU:S 5061 22 a~lLR DeTY RU D QT118AT 3 6T59 6Sl•1 22 UERLR DU1f RA D 03J32A1 2 7631 T361 16 kR9lLR DeTY RR D 03A2A1 1 8036 TT 5! 1 T eIERLA D 0Y RR D 03A2A 1 3086' 3-111' PARK~SWSNIP A~kl®T10 Z~' ON 02~A7 -1 f~ M1 , 3~- {~6'TW FNIPPWI. D-~ffi i-1 X O 1- 9 81+43' ~ W L v SLV, I - . uF3-il" BAfI'EDBULLDDGSPE0.R~811£SLIJ 81!513' TW GROSSOV@1 PRi, D- 190' ro~1a• LNR, ~7 iM, LSO I TRS, O - 8b81' I LIOP of cEl~ r~J33i08j ~ 312'TIG,928L 1DS,OQSTbp?,D-299d' PERFORATgNSUUUARY REF LOG: SWSp4L221J71 RNGLEATTOP IERF: ~8'~ 9Q63' NDt:RelprloP~nA1c1D~DLlbritbrkUl ff~ta S F RL Op1 1111 ~ C 1J9M'I6' 6 931T -9431 C 03A6~01 1J91f15 6 93iS-3365 C 05A6+1]1 1-11fl5 6 94 L6-9655 C 0222101 1-111'IG 6 962E-919 C 022201 1-11!16' 6 1 OOm - ~ 160 C 0222+01 1-1111 B 6 10185 - X260 C 0222x01 1-111'1 E 6 10330 -10 i60 C Q222A 1 1-11A 6' 6 10L80 - mfiT]0 C 0222101 1-11J1~ 6 10610-~90 C 0222tOi t-111'IE T 10611-~e-o C 02231D7 1-1111 G 8 10612 - X690 C 0221A 1 ~T' LNR. 2911. L-00 lTRS, D371 Opt, D -6.18t' ~a 3-112' & T' NNLLOUT WIDOW (G-TS A )9090' -909' DATE Rear av coleuelTS QATE REN ev CONpIlENTS ORIGINAICORIPLET'IDN OT211D7 K'SMJC LVGO ~t18rOTj !9 A 1 K f L 1 J! 11 1 JL H P 1 PJC IJ A t PRUD11oE eAV uNn- W 8. L: G-13R PERlARNa: ~163fl RPINO: S'6029 X00-01 12, T11N, R13E,222L' NSL&2368' tlR B~OrelfOrl (Ale! NeJ G-13A Sundry Application 5 5/21/2009 • • Page 1 of 3 Maunder, Thomas E (DOA) From: Rose, John G (FAIRWEATHER) [John.G.Rose@bp.com] Sent: Wednesday, May 06, 2009 9:08 AM To: Maunder, Thomas E (DOA) Subject: RE: GPB G-13A (PTD - 200-163) Tom, The Sundry request will detail the work that has been done and the path-forward work on this well. Thanks - jr ian,~ c. n~,s~- BP.A"-Drillinr Consu/tanr Q~/ice J117~519-5271 Cel! 90~ ~ 4Y-5223 j~~ i ~ ,~ r~~} n lrl.\" y(li >(4-4(i411 L~~iY~~111~~~ ~IJZ.. ~ ~! ~.U~~J Home )07'~43-1'81 i From: Maunder, Thomas E (DOA) [mailto:tom.maunder@alaska.gov] Sent: Wednesday, May 06, 2009 9:02 AM To: Rose, John G (FAIRWEATHER) Subject: RE: GPB G-13A (PTD - 200-163) John, Sorry for the delay in replying. From what I can see of the file information, the prior work did effect an adequate plugging of the productive interval in this well. Setting a whipstock and fully cementing the new 7" liner will complete the isolation of the "A" penetration. Please cover these points in the sundry. Call or message with any questions. Tom Maunder, PE AOGCC From: Rose, John G (FAIRWEATHER) [mailto:John.G.Rose@bp.com] Sent: Monday, May 04, 2009 12:18 PM To: Maunder, Thomas E (DOA) Subject: FW: GPB G-13A (PTD - 200-163) Tom, Also, when you have the time, what do you think of the current "suspension" on this well in regards to changing it's status to "abandonment"? Thanks again. - jr John G. Ro.cc liP.1~ - Drilhhg Corrsir/iant Oliice v07'Shd-5'71 Ccll >07:i4~S-i2?i F:1.A" 907:'S<9-4040 Ilome )07%2a3-~'h 13 From: Rose, John G (FAIRWEATHER) Sent: Monday, April 27, 2009 10:27 AM 5/6/2009 ~ • Page 2 of 3 To: 'Maunder, Thomas E (DOA)' Subject: RE: GPB G-13A (PTD - 200-163) Not sure what happened, but, here are the attachments. Sorry. Johir G. Kose l3l'_C - Urilling Cais~dtar~[ OJticc 907-J(4-~271 Cc !1 9/l7,'79R-SZ23 l~a.A~ 907;564-d040 Nomc- 90?'_'~13-8813 From: Maunder, Thomas E (DOA) [mailto:tom.maunder@alaska.gov] Sent: Friday, April 24, 2009 12:35 PM To: Rose, John G (FAIRWEATHER) Cc: Hobbs, Greg S (ANC) Subject: RE: GPB G-13A (PTD - 200-163) John, I can't open the files you sent. I am not even sure what the icons are. Thanks, Tom From: Rose, John G (FAIRWEATHER) [mailto:John.G.Rose@bp.com] Sent: Friday, April 24, 2009 11:48 AM To: Maunder, Thomas E (DOA) Cc: Hobbs, Greg S (ANC) Subject: RE: GPB G-13A (PTD - 200-163) Tom, I have attached a copy of the 407 for your reference and a copy of the 8/3/08 Well Service report where -20' of cement was dump bailed on top of the CIBP at 8810' MD (this cement is also indicated on the schematic which was attached to the original e-mail), therefore, let me know what you think and we'll go from there. Thanks - jr John (:~. Xo.cn BP.A'- Drilting C~on.rrdtc~nt 01J~cc IO?-.i(4-y_%l Ce!! 907-'74b'-5223 F~1.A~ >07;'S14-4040 llonre J!)7-24i-g813 From: Maunder, Thomas E (DOA) [mailto:tom.maunder@alaska.gov] Sent: Friday, April 24, 2009 10:54 AM To: Rose, John G (FAIRWEATHER) Cc: Hobbs, Greg S(ANC); Hubble, Terrie L Subject: RE: GPB G-13A (PTD - 200-163) John, I looked at the file. There is a work summary that I received by email that ends 5/30/08. According to sundry, it was intended to place cement on top of the CT bridge plug. Has that work been accomplished? I also am unable to find a 407 suspending the well. I look forward to your reply. Tom Maunder, PE AOGCC 5/6/2009 ~ • Page 3 of 3 From: Rose, John G (FAIRWEATHER) [mailto:John.G.Rose@bp.com] Sent: Friday, April 24, 2009 9:51 AM To: Maunder, Thomas E (DOA) Cc: Hobbs, Greg S (ANC) Subject: GPB G-13A (PTD - 200-163) Tom, As we are planning to sidetrack the G-13A well in July of this year, is the well's current condition as a Suspended well sufficient to request a permanent Abandonment of the G-13A BHL, i.e., does the current condition of the well meet AOGCC requirements for permanent Abandonment? The base plan for the G-13B Sidetrack is as follows: 1. Move in drilling rig (July - 09). 2. Decompiete well to include a cut and pull the existing completion from -8000' MD. 3. Confirm the integrity of the 9-5/8" production casing. 4. Set a whipstock in the 9-5/8" casing at ~7000' MD (KOP in Colville). 5. Drill 8-1/2" hole into the top of the Sag. 6. Run and fully cement a 7" drilling liner (TOC at TOL - with planned 150' liner lap). 7. Drill production hole. 8. Run and fully cement a 4-1/2" production liner (Ivishak Zone 16 horizontal). 9. Perforate liner. 10. Run 4-1/2" completion. 11. RD/Move off well. I have attached a schematic of the well in it's current condition for your review and if you need any additional information, please advise. Thanks - jr ~~n,~ c. ao~<~ l3P.A~- Drillin~ Consulrant O%/ice 907~564-~271 Cell 907%i 9~S'-5223 FA.A' J07;5(d-4040 llome J07iZ43-8813 5/6/2009 ` WellSarviceReport . • Page i of I WELL SERVICE REPORT ~ ~ b~ - ~~3 WELL JOB SCOPE UNfT G'"13A DRLG CANDI~ATE SCREEN ( MAINT} SWCP 4516 DAT~ DAiLY WORK DAY SUPV 8/3/2008 DUMP BAiL BUE.LOCH COST COC}E PLUS KEY PERSON NIGHT SUPV PBGPDWLI3-M SWCP-HEINZ-BROWN BRACKETT MIN {D DEPTM TTL SiZE 1.9" 8150FT 0" DUMP BAIL CEMENT (2 GAU10') ON CfBP @ 8798' SLM (T07AL CEMENl': 4GAU ~24'~ S~T 3-1/2" REL. SPEAF IN ~1VFi TOP ~ 8121' SLM (2-1/2" "GS" TO PULL} DfiAWING OF REL. SPEAR WI WELLS GROUP *"*WELL 5/I ON 1~EP.. PAD-OP NOTIFIEb O~ ALL CONDITIONS~** LOG ENTRlES I nit T lA OA -> 150 500 4~0 TIME C~MM~NT Q0:01 RIH W/ 20' x 9.75" D.BAILER 7" EXT '~.75" CElVT, B.NOSE .108" S/~, 14' 1.5" STM, ~J, LSS 00:45 S/D ON CIBP ~ 8798' SLM, DUMP CEMENT 2 GAL , POOH 01:15 OOH, BREAK DOWN TOQLS, M/U TUOLSTRING .1 Q$" S/L, 8' 2-1/8" S'CM, OJ LSS 01:45 RIH W/ 2-1/2" GR ST~~I. , 3-1l2" REL. SPEAR 02.00 S/D tN LNR TOP ~ 8121' SLM 5ET' SpEAFi JAFi UP TO ENGAGE SPEAR & SHEAR TOOL, POOH 03:00 OON, C(~NFIRM R/p W/ R~P 03:15 BEGIN R/D 03:59 R/!~ COMPLETE, NOTIFY PAO-OP OF ALL VALVE POSTITIONS & FLAGS, HANG TAG ON WlNG FOR REL. SPEAR ~inal Tb IA OA -~ 150 500 440 JOB COSTS SERVICE COMPAfdY - SERVICE DAILY COST GUMUL TQTA~, CM2MHlLL LABOR $960 $7,580 EQUIP1UtENT FLEET $2,140 $15,825 SCHLUMBERGER $1,43Q $60,$64 SCHLUMBERGER PLUS 15 PERCENT $215 $8,868 BAKER OIE. TDOLS $0 $12,453 ASRG $0 $3 900 H07 WATER FLANT $0 $1,146 OR6lS $0 $9,S5fl CAMEFiON $0 $1,60Q W EATH EFi ~ORD $0 $5,154 WAREHflUSE $0 $6,105 LITTLE RED PLUS 20 PERCENT $0 $2 828 LITf'LE RED $0 $14140 T~TAL FIELD ESTIMATE: $4,7Q5 $150,433 FLUID SUMMARY (~NON~ ,.,..Sy~ , , ~ ,..,. ~/~fn ~ :?''~ 7;! ~ i~..,, 4~4 S .~ 4! G.. 4~..) ,.: C.t ~~~ ~ ~.~ http://apps2-alaska.bpweb,bp.com/awgrs-wellservice~•eport/defau lt.aspx?id=DF654731933... 4/24/2009 TREE = MCEV OY WELLHEAD = MCEVOY ACTUATOR = AXLESON KB. ELEV = . 65.97' BF. ELEV = 37.52' KOP = 3200' Max Angle = 96° @ 10090' Datum MD = 9179' Datum 1V D= 8800' SS i 20" CONDUCTOR 4.5" 12.6# L-80 TDS, .0152 bpf, ID = 3.958" 13-3/8" CSG, 72#, L-80 BTRS, ID= 12.347 ~ G-13A Minimum ID =1.90" @ 8150' TIW XO - TOP OF 2-3/8" LN R ~ TOP OF 7" LNR TOP OF 2-3/8" LNR SA~ NOTES: 2097~ ~5" OTIS SSSV, ID = 3.813" 2115~ 4-1/2" X 3-1/2" XO, ID = 2.992" 2589~ 9-5l8" DV PKR GAS LIFf MANDRELS ST MD ND DEV TYPE VLV LATCH PORT DATE 5 3067 30n7 1 MERLA DMY RM 0 07/18/07 4 5165 5064 22 MERLA DMY RM 0 07l18/07 3 6759 6541 22 MERLA DMY RA 0 03/02/01 2 7631 7364 16 MERLA DMY RA 0 03l02/01 1 8036 7753 17 MERLA DMY RA 0 03/02/01 8066~ 3-1/2" PARKER SWS NIP MILLED TO 2.80" ON 02/09/01 8079~ 3-1/2" XO TO 4-1/2", ID = 3.95" $Q$3' 9-5/8" TNV HBBP PKR, ID = 4.00" 8093~ 4-1/2" XO T O 3-1/2", ID = 3.958" 8143~ 2-3/8" TNV DEPLOY SLV, ID = 2.25" w/3-1/2" BAITED BULLDOG SPEAR @ 8116' SLM 8150~ TNV CROSSOV ER PIN, ID = 1.90" I9-5/8" LNR, 47#, L-80 BTRS, ID = 8.681" I-t TOP OF CEMENT (08/03/08) 3-1/2" TBG, 9.2# L-80 TDS, 0087 bpf, ID = 2.992" PERFORATION SUMMARY REF LOG: SWS CNL 2/21/01 ANGLE AT TOP PERF: 48° @ 9263' Note: Refer to Production DB for historical perf data SIZE SPF INTERVAL Opn/Sqz DATE 1-11/16" 4 9263 - 9278 C 08/02/03 1-9/16" 6 9317 - 9337 C 05/06/01 1-9/16" 6 9345- 9365 C 05/06/01 1-11/16" 6 9445 - 9555 C 02/22/01 1-11/16" 6 9624 - 9940 C 02/22/01 1-11/16" 6 10000 - 10160 C 02/22/01 1-11/16" 6 10185 - 10260 C 02/22/01 1-11/16" 6 10330-10460 C 02/22/01 1-11/16" 6 10480 - 10600 C 02/22/01 1-11/16" 6 10610 - 10690 C 02/22/01 1-11/16" 7 10611 - 10690 C 02/23/01 1-11/16" 8 10612 - 10690 C 02/24/01 7" LNR, 29#, L-80 BTRS, .0371 bpf, ID = 6.184" 8773~ --I JET CUT TBG (04/06/08) I 8810~ 2-3/8" WFD CIBP (04/05/O8) 3-1/2" & 7" MILLOUT WINDOW (G-73A) 9090' - 9094' 3-1/2" WHIPSTOCK (02/07/01) PBTD ~--~ 1 ~ 2-3/8" LNR, 4.6#, L-80 STL, .0039 bpf, ID = 1.995" ~ DATE REV BY COMMENTS DATE REV BY COMMENTS ORIGINAL COMPLETION 07/21/07 KSB/PJC GLV C/O (07/18/07) 02/22/01 CTD SIDTRACK (G-13A) 04/15/08 RRD/TLH TBG CUT & CIBP SET (04/06/08) 03/10/01 CH/KAK FINAL 10/16/08 GJF/PJC BAITED SPEAR (09/25/O8) 05/12/01 JLJ/TLH ADD PERFS 10/25/08 PJC DRAWING CORRECTIONS 08/02/03 BJMc/TL ADD PERFS 04/17/04 TWC/KA CORRECTIONS PFZUDHOE BAY UNff WELL: G-13A PERMff No: ~2001630 A PI No: 50-029-20600-01 SEC 12, T11 N, R13E, 2224' NSL & 2368' WEL BP F~cploration (Alaska) • Page 1 of 1 • Maunder, Thomas E (DOA) From: Maunder, Thomas E (DOA) Sent: Monday, October 20, 2008 2:50 PM To: Hubble, Terrie L Subject: RE: G-13A Abandonment, PTD # 200-163 Terrie, Yes, suspended sounds to be the proper status. Tom From: Hubble, Terrie L [mailto:Terrie.Hubble@bp.com] Sent: Monday, October 20, 2008 2:41 PM TQ: Maunder, Thomas E (DOA) ,r. ~,;~~; Subject: G-13A Abandonment, PTD # 200-163 z ~''' ~ _'~~°` ' ~~' ~_ ~~ ~ ~ '~ ~ ..~;"~. ~F.~..u~ Hi Tom, I am attaching a copy of an approved 10-403 for this well that was submitted upon the request of Production Engineer, Reed Boeger. The idea being that some of the pre-rig work, might "cause damage that would prohibit proper abandonment." That work is now complete and as feared, the well is no longer accessible. The hope was that they would be able to do a coil tubing sidetrack, but now the sidetrack will have to be performed by a rotary rig, which won't happen until 2009. That being the case, should the status of the well be changed on the yet-to-be-submitted 10- 407 to "Suspended" rather than "Abandoned". Please let me know, as I will be working this one up in the next couple of weeks. . Thank you, Terrie 11/10/2008 ~ ~ STATE OF ALASKA ~'~ ALASKA OIL AND GAS CONSERVATION COMMISSIO~ WELL COMPLETION OR RECOMPLETION REPORT AND LOG .~ • ~,.~~ ~ ~~ ~ ~~~ ~ °-~ e`~ ~ ~ ~ 2oa~ 1a. Well Status: ^ Oil ^ Gas ^ Plu ed ^ Abandoned ~ Sus nded 9g ~onnczs.~os ~onaczs.~,o ^ GINJ ^ WINJ ^ WDSPL ^ WAG ^ Other No. of Com letions One 1b. Well C~~i~: ~*_ ~' M:; ~ Development ^ ~acp~qr,~,t~~,i~ ^ Service ^ S~4r'ati° ~a ~ iC 2. Operator Name: BP Ex loration (Alaska) Inc. 5. Date Comp. ~Sus , or Aba 10/6/2008 12. Permit to Drill Number 200-163 30&195 3. Address: P.O. Box 196612, Anchorage, Alaska 99519-6612 6. Date Spudded 02/13/2001 13. API Number 50-029-20600-01-00 ~ 4a. Location of Well (Govemmental Section): Surface: ' ' 7. Date T.D. Reached 02/19/2001 ~4. Well Name and Number: PBU G-13A~ 2224 FNL, 2368 FEL, SEC. 12, T11 N, R13E, UM Top of Productive Horizon: 1283' FNL, 653' FEL, SEC. 12, T11 N, R13E, UM 8• KB (ft above MSL): 66' Ground (ft MSL): 35.47' 15. Field / Pool(s): Prudhoe Bay Field / Prudhoe Bay Total Depth: 481' FNL, 410' FWL, SEC. 07, T11 N, R14E, UM 9. Plug Back Depth (MD+ND) 8790' 8486' Pool 4b. Location of Well (State Base Plane Coordinates, NAD 27): Surface: x- 657852 y- 5969417 Zone- ASP4 10. Total Depth (MD+TVD) 10844' ~ 8990' ~ 16. Property Designation: ADL 028304 TPI: x- 659545 y_ 5970394 Zo~~ ASP4 Total Depth: x- 660592 - 5971218 Zone- ASP4 11. SSSV Depth (MD+ND) 2097~ 2097' 17. Land Use Permit: y 18. Directional Survey ^ Yes ~ No •n ~ • ~ 9• Water depth, if offshore N/A ft MSL 20. Thickness of Permafrost (ND): 1900' (Approx.) 21. Logs Obtained (List all logs here and submit electronic and printed information per 20 AAC 25.071): MWD GR & MEM GR / CNL / Tem Z2. CASING, LINER AND CEMENTING RECORD CASING SETTING DEPTH t~ SETTII~', DEPTH ND HOLE AMOUNT WT. PER FL GRADE TOP BOTfOM TOP BOTfOM SIZE CEMENTINGRECORD PULLED u 4 # - / " -1 I 23. Open to production or inject ion? ^ Yes ~ No 24. T ueirrc RecoRo If Yes, list each i (MD+TVD of Top & Bottom; Pe nterval open rforation Size and Number): S~ Dewn-i Ser nno Pnc~R Ser MD 4-1/2", 12.6#, L-80 x 2115' MD ND MD TVD 3-1/2", 9.2#, L-80 2115' - 9090' 8083' 25. Aci~, FRnc~rur~, CEMENT SQUEEZE, era DEPTH INTERVAL MD AMOUNT & KIND OF MATERIAL USED 8810' Set CIBP 8773' Jet Cut 2-3/8" Liner ~8790' Dump 4 Gallons Cement on top of CIBP 26. PROOUCnoni Tesr Date First Production: Not on Produetion Method of Operation (Flowing, Gas Lift, etc.): wa Date of Test: Hours Tested: PROOUCnor, F~ TEST PERIOD OIL-BBL: GAS-MCF: WATER-BBL: CHOI~ SIZE: GAS-OIL RATIO: Flow Tubing Press. Casing Press: Ca,~cuure~ 24-HouR Rn~.~ OIL-BBL: GAS-MCF: WATER-BBL: OIL GRAVITY-API ~CORR~; 27. CORE DATA Conventional Core(s) Acquired? ^ Yes ~ No Sidewal l Core s A uired? ^ Yes ~ No If Yes to either question, list fortnations and intervals cored (MD+TVD of top and bottom of each), and summarize lithology and presence of oil, gas or water (submit separdte sheets with this fortn, if needed). Submit detailed descriptions, core chips, photographs and laboratory analytical results per 20 AAC 250.071. ,._ ..: , .-..a.':, ~ None ~~-'~-Q~ V~~2~~` Form 10-407 Revised 02/2007 CONTINUED O EVERSE SIDE ~ ~~ . ! . 4 4 . ~ '~~°~ ~~~ ~~. e ~ ~ ,~ ~~. 6 ; b ~`~~fl °„ y G~ 1, ~~ C ~ a Z8. GEOLOGIC MARICERS ~LIST ALL FORMATIONS AND MARKERS ENCOUNTERED~: 29. TION TESTS NAME MD ND Well Tested? ^ Yes ~ No Permafrost Top If yes, list iMervals and formations tested, briefly summarizing test resuRs. Attach separate sheets to this form, if rieeded, and submit Permafrost Base detailed test infortnation per 20 AAC 25.071. Sag River 8689' 8388' None Shublik 8728' 8426' Sadlerochit 8806' 8502' Zone 1A 9404' 9007' Formation at Total Depth (Name): 30. List of Attachments: Summary of Pre-Rig Work, Well Schematic Diagram 31. I hereby certify that the foreg 'ng is tnae and correct to the best of my knowledge. '~/~ t~~ i L~ ~• S Title Drilling Technologist Date gned Terrie Hubble PBU G-13A 200•163 308-195 Prepared BY NameMumber. Terrie Hubb/e, 564-4628 Well Number DrillingEngineer: Reed Boeger, 564-5380 INSTRUCTIONS G~N~u: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. Submit a w~ell sct~matic diagram with each 10-407 well completion report and 10-404 well sundry report when the downhole uvEll design is changed. Ir~ 1a: Classification of Service Wells: Gas Injection, Water Injection, Water-Altemating-Gas Injection, Salt Water Disposal, Water Supply for Injection, Observation, or Other. Mukiple 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. Ir~ 4b: TPI (Top of Producing Interval). Ir~ 8: The Kelly Bushing and Ground Level elevation in feet above mean sea level. Use same as reference for depth measurements given in other spaces on this form and in any attachments. Ir~ 13: Tt~ API number reported to AOGCC mu5t be 14 digits (ex: 50-029-20123-00-00). Ir~ 20: Report true vertical thidcness of pertnafrost in Box 20. Provide MD and TVD for the top and base of pertnafrost in Box 28. Ir~ 22: Attached supplemerital rec:ords for this w+ell should show the details of arry muRiple stage cemeMing and the location of the cemeMing tool. Ir~ 23: 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 irderval). I~ 26: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut-In, or Other (explain). Ir~ 27: Provide a listing of intervals cored and the corresponding fortnations, and a brief description in this box. Submit detailed description and analytical laboratory ir~formation required by 20 AAC 25.071. Ir~r 29: Provide a listing of iMervals tested and the carresponding formation, and a brief summary in this box. Submit detailed test arxi analytical laboratory ir~fortnation required by 20 AAC 25.071. Form 10-407 Revised 02/2007 Submit Original Only ~~ • G-13A, Well History (Suspend, Pre Rig Sidetrack) Date Summary 4/5/2008 T/I/0= 2300/500/20 Assist E-line, Load and Kill. MIT-T FAILED to 3000 psi. (CTD Screen) Pumped 5 bbls neat and 290 bbls crude down Tbg to load. MIT-T FAILED to 3000 psi. on 3 attempts. Pressured Tbg to 3000 psi with 9.2 bbls of crude. Tbg lost 220 psi in the 1 st 15 min and 200 psi in the 2nd 15 min for a total loss of 420 psi. Bled Tbg pressure to 200 psi. FP FL with WOA recipe, pumped 7 bbls neat meoh and 53 bbls crude, rigged down. FWHP=200/500/20 E-Line has control of well upon departure. 4/5/2008 WELL SHUT IN ON ARRIVAL. INITIAL T/I/0= 2300/500/0. LRS LOADED TBG W/ 290 BBLS OF CRUDE. SET WFD 2-3/8" CIBP Q 8810' IN 2-3/8" LINER. 4/6/2008 JET CUT THE 2-3/8" LINER AT 8,773' WITH 1.68 IN SLB POWER CUTTER. WELL LEFT SHUT IN. FINAL T/I/O: 180/500/0. JOB COMPLETE. 5/26/2008 RIH w jars weight bars, 3" GS PlTool. Could not latch. POOH. RIH w jars weight bars, 3" GS Slick Catch. Hit 11 Jar licks.. Unable to stav engaged in fish. POOH. Inspect Tool, looks good. Confer with town. Plan forward is to RDMO. Job incomplete. 5/30/2008 T/I/0=0/500/0 MIT-T PASSED to 3000 psi, MIT IA PASSED to 3000 psi, MIT OA PASSED to 2000 psi (CTD screen) MITT to 3000 psi- Pumped 3.4 bbls crude to to reach test pressure, Tbg lost 180 psi in the ist 15 min and 50 psi in the 2nd 15 min for a total loss of 230 psi in 30 min. MIT-IA to 3000 psi- Pumped 45 bbls crude to reach test pressure, IA lost 70 psi in the ist 15 min and 30 psi in the 2nd 15 min for a total loss of 100 psi in 30 min. MIT-OA to 2000 psi- Pumped 2.4 bbls crude to reach test pressure, OA lost 70 psi in 1 st 15 min and 30 psi in 2nd 15 mins for a total loss of 100 psi in 30 min. Bled whp's. FWHP's=0/540/480 Annulus casing valves tagged & left open 8/2/2008 WELL SHUT IN. DRIFT W/ 20' x 1.75" D. BAILER, K. JAR. ISSUES W/ LNR TOP C~ 8127' SLM. TAG CIBP C«~ 8798' SLM. DRIFT W/ 20' x 1.75" D. BAILER, 1.75" CENT, B. NOSE. STOP 20' ABOVE CIBP (PIN UNTOUCHED). DUMPED 10' (2 GAL) OF CEMENT ON CIPB C~ 8798' SLM. (TOTAL CEMENT: ~~~~ ~ ~~~~ 8/3/2008 SET 3-1/2" REL. SPEAR IN LNR TOP C~3 8121' SLM (2-1/2" "GS" TO PULLZ WELL S/I ON DEPARTURE. PAD-OP NOTIFIED OF ALL CONDITIONS. 9/16/2008 RIH w/ 2" GS pulling tool. Latch spear inside liner Q 8121. Jar up 25 times and stripped inner fish neck in spear, no replacement parts available at this time. Slickline to retrieve spear. Rig down. Job complete. 9/25/2008 WELL S/I ON ARRIVAL. PULL 3 1/2" RELEASEABLE SPEAR FROM TOP OF 2 7/8" LINER Q 8116' SLM, 8143' CORRECTED MD. DRIFT 2 3/8" LINER W/ 1.75" CENT/1.50" S.BAILER, S~D Q 8738' SLM, 8765' MD. RECOVERED GOOD SAMPLE OF CEMENT. SET BULLDOG SPEAR W/ 3.5" BAIT-SUB C 8116' SLM. JARRED ON SPEAR FOR 30 MIN. GOOD SET. LEFT WELL SI, TURNED OVER TO PAD OP. BULLDOG SPEAR =(3 1/2" BAIT SUB O.D.=2.70" W/ 3 1/2 G-FISHNECK, ID OF BAIT SUB - 1.99 ) (20"SPEAR, GRAPPLE O.D.=2.273", NOSE CONE=1.62" O.D ) TOTAL OAL OF BAIT SUB AND SPEAR =33" Page 1 of 1 ~,_ fF. ELEV.= • 37.52' ;OP_ ~ 3200' Aax Angle = 96 @ 10090' I )atum MD = 9179' )atum ND = 8800 SS 20" CONDUCTOR 4.5" 12.6# L-80 TDS, .0152 bpf, ID = 3.958" 13-3/8" CSG, 72#, L-80 BTRS, ID = 12.347 ~ Minimum ID =1.90" @ 8150' TIW XO - START OF 2-3/8" LNR ST MD TVD DEV TYPE VLV LATCH PORT DATE 5 3067 3067 1 MERLA DMY RM 0 07/18/07 4 5164 5063 22 MERLA DMY RM 0 07/1 S/07 3 6758 6540 22 MERLA DMY RA 0 03/02/01 2 7630 7363 16 MERLA DMY RA 0 03/02/01 1 8035 7752 17 MERLA DMY RA 0 03I02/01 8067~ -j ( 3-1/2" PARKERSWS NIP MILLED TO 2.80" ON 02/09/01 8079~ 3-1 /2" XO TO 4-1 /2", ID = 3.95" 8083~ 9-5/8" TNV HBBP PKR, ID = 4.00" TOP OF 7" LNR 8093~ ~-) 4-1/2" XO T O 3-1/2", ID = 3.958" 814~~ 2-3/8" TNV DEPLOY SLV, ID = 2.25" wi3-1/2" BAETEQ BULLDC~G SP~IR ~ 8116' SLP~'i ~9-5/8" LNR, 47#, L-80 BTRS, ID = 8.681" ~ 3-1/2" TBG, 9.2# L-80 TDS, 0087 bpf, ID = 2.992" PERFORATION SUMMARY REF LOG: SWS CNL 2/21/01 A NGLE AT TOP PERF: 57 @ 9317' Note: Refer to Production DB for historical perf data SIZE SPF INTERVAL Opn/Sqz DATE 1-11/16" 4 9263 - 9278 C 08/02/03 1-9/16" 6 9317 - 9337 C 05/06/01 1-9/16" 6 9345 - 9365 C 05/06/01 1-11/16" 6 9445 - 9555 C 02/22/01 1-11/16" 6 9624 - 9940 C 02/22/01 1-11/16" 6 10000 - 10160 C 02/22/01 1-11/16" 6 10185 - 10260 G 02/22/01 1-11/16" 6 10330 - 10460 C 02/22/01 1-11/16" 6 10480 - 10600 C 02/22/01 1-11/16" 6 10610 - 10690 C 02/22/01 1-11/16" 7 10611 - 10690 G 02/23/01 1-11/16" 8 10612 - 10690 C 02/24/01 G 13A SA~NOTES: ~ 2097' -14.5" OTIS SSSV, ID = 3.813" 2115' 4-1 /2" X 3-1 /2" XO, ID = 2.992" 2589' 9-5/8" DV PKR GAS LIFT MANDRELS 7" LNR, 29#, L-80 BTRS, .0371 bpf, ID = 6.184" $15~' TNV CROSSOVER PIN, ID = 1.90" 8773~ JET CUT TBG (04/06/08) 8810' 2-3/8" WFD CIBP (04/05/08) 3-1/2" & 7" MILLOUT WINDOW (G-13A) 9090' - 9094' 9117' TOP OF WHIPSTOCK ~ 9117~ RA TAG 3-1/2" WHIPSTOCK (02/07/01) PBT~ (--I 10779' ~ 2-3/8" LNR, 4.6#, L-80 STL, .0039 bpf, ID = 1.995" ~ DATE REV BY COMMENTS DATE REV BY COMMENTS ORIGINAL COMPLETION 07/21/07 KSB/PJC GLV GO (07/18I07) 02/22/01 CTD SIDTRACK (G-13A) 04/15/08 RRD/TLH TBG CUT & CIBP SET (04/O6/08) U3/10/01 CFVKAK FINAL 10/16/08 GJF/PJC BAffED SPEAR (09/25/08) 05/12/01 JLJ/TLH ADb PERFS 10/16/08 ?/PJC DRAWING CORRECTIONS 08/02/03 BJMc/TL ADD PERFS 04/17/04 TWGKA CORRECTIONS PRUDHOE BAY UNff WELL: G-13A PERMIT No: ~L001630 API No: 50-029-20600-01 SEC 12, T11 N, R13E, 2224' NSL & 2368' WEL BP Exploration (Alaska) Page 1 of 1 • a Maunder, Thomas E (DOA) From: Maunder, Thomas E (DOA) Sent: Monday, October 13, 2008 2:12 PM To: 'Hubble, Terrie L' Cc: Boeger, John Reed Subject: RE: PBU G-13A, PTD # 200-163, Approval # 308-195 .~ Hi Terrie, "Gat me"! Based on the email that Reed and 1 exchanged about the sundry, it appears that the rig scenario is the likely way the redrill happens. Since the redrill is not on the drilling schedule, it is probably best to submit the 407 with the well suspended. Some note stating the well has been plugged but the redrill has not been scheduled should be included. Call or message with any questions. Tom Maunder, PE AOGCC From: Hubble, Terrie L jmailto:Terrie.Hubble@bp.com] Sent: Monday, October 13, 2008 1:59 PM To: Maunder, Thomas E (DOA) Cc: Boeger, John Reed `,~~~,~; ,, - `u~ Subject: PBU G-13A, PTD # 200-163, Approval # 308-195 ~~ ~~ ~ K Hi Tom, A 10-403 was submitted to prep this well for a sidetracking (1 clicked the "Other" box, you changed it to "Abandon"). The following work has been done, as outlined in the Sundry Attachments: Set C I BP, 04/05/08 MIT-T, 04-05/08 Jet Cut Tubing 8773', 04/06/08 Dump 25' Cement on CIBP, 08/02/08 Spear 2-3/8" Liner & Pull, 08/03/08 (several attempts were made on the pull test, with the last one being done on 10/06/08, with no indication of liner movement) How would you like me to proceed reporting wise. The sidetrack is not currently on the Drilling Schedule and the next report required is a 10-407. But since this well is not fully "abandoned" I'm not sure how to proceed. Thanks! Terrie 10/14/2008 • • = SARAH PALIN, GOVERNOR IE AI~T] GA- 7 S ~ A ® L~L[ 333 W 7th AVENUE, SUITE 100 ~t ~ v g~ ~T T ~ ~ T ~ LO"SERQAiiOis I.OSSIOls ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 J Boeger Production Engineer BP Exploration Alaska Inc. PO Box 196612 ~~~~[~ JUN ®3 200$ Anchorage, AK 99519-6612 Re: Pru a oe Bay Field, Prudhoe Bay Oil Pool, PBU G-13A ~ ~ 3 Sun Number: 308-195 ~OD .~ Dear Mr. Boeger: 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. When providing notice for a representative of the Commission to witness any required test, contact the Commission's petroleum field inspector at (90'~ 659-3607 (pager). As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the Commission grants for good cause shown, a person affected by it may file with the Commission an application for rehearing. A request for rehearing is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day >f the 23rd day falls on a holiday or weekend. A person may not appeal a Commission decision to Superior Court unless rehearing has been requested. Sincerely, Daniel T. Seamount, Jr. / Chair DATED this ~ day of June, 2008 Encl. G~ ~ .~~ F~~C~~lV ~ ~ p STATE OF ALASKA xL ~~ ~~~A~ OIL AND GAS CONSERVATION COMM SSION ~"b(3 MAY 3 0 ~~,,~~ ' APPLICATION FOR SUNDRY APPROVA~~ka Oi! & Gas COnS. COfnmTssion ~n/(G/, rpm 20 AAC 25.280 Qnrhn~ano 1. Type of Request: A andon ^ Suspend ^ Operation Shutdown ^ Perforate ^ Time Extension ^ Alter Casing ^ Repair Well ^ Plug Perforations ^ Stimulate ^ Re-Enter Suspended Well ^ Change Approved Program ^ Pull Tubing ^ Perforate New Pool ^ Waiver ®Other Isolate Productive Interval, Pre for SR 2. Operator Name: 4. Current Well Class: 5. Permit To Drill Number BP Exploration (Alaska) Inc. ®Development ^ Exploratory 200-163 - 3. Address: ^ Service ^ Stratigraphic 6. API Number: _ P.O. Box 196612, Anchorage, Alaska 99519-6612 50-029-20600-01-00 7. If perforating, closest approach in pool(s) opened by this operation to nearest 8. Well Name and Number: property line where ownership or landownership changes: PBU G-13A Spacing Exception Required? ^ Yes ®No 9. Property Designation: 10. KB Elevation (ft): 11. Field /Pool(s): ADL 028304 Y 66' , Prudhoe Bay Field / Prudhoe Bay Pool 72. PRESENT WELL CONDITION SUM MARY Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD (ft): Effective Depth TVD (ft): Plugs (measured): Junk (measured): 10844' - 8990' 10779' 8991' 8810' None asin Len h Size MD TVD Burst Colla se Structural on ctor 110' 20" x 30" 110' 110' S rface 2673' 13-3/8" 2673' 2673' 4930 2670 Intermediate 8649' 9-5/8" 8649' 8349' 6870 4760 Pr ion Liner 953' 7" 8137' - 9090' 7851' - 8780' 8160 7020 Liner 2701' 2-3/8" 8143' - 10844' 7856' - 8990' 11200 11780 Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): Below CIBP: 9263' - 10690' 8933' - 8989' 4-1/2", 12.6# x 3-1/2", 9.2# L-80 9090' Packers and SSSV Type: 9-518" x 3-1/2" TIW'HBBP' packer Packers and SSSV MD (ft): 8092' 13. Attachments: 14. Well Class after proposed work: ® Description Summary of Proposal ^ BOP Sketch ^ Exploratory ®Development ^ Service ^ Detailed Operations Program 15. Estimated Date for 16. Well Status after proposed work: Commencin O erations: As Soon As Approved ^ Oil ^ Gas ^ Plugged ®Abandoned 17. Verbal Approval: Date: ^ WAG ^ GINJ ^ WINJ ^ WDSPL Commission Representative: 18. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Reed Boeger, 564-5380 Printed Name J. Reed Boeger Title Production Engineer ,~ Prepared By Name/Number: Signature ~'~~, ~ Phone 564-5380 Date-~. Terrie Hubbte, 564-4628 Commission Use Onl Sundry Number: Conditions of approval: Notify Commission so that a representative may witness ~ ~ 5~f ~ ~ ~~ v"~' i S ^ Plug Integrity ^ BOP Test ^ Mechanical Integrity Test ^ Location Clearance Other: Subsequent Form equired: 1-,~ APPROVED BY A roved B : COMMISSIONER THE COMMISSION Date Form 10-403 Revised 06 Submit In Duplicate ORIGINAL ~~~~-~~s+~~a G-13A -Application for Sundry • We are applying for a Sundry to permanently abandon the G-13A wellbore. We are in the process of planning wellwork that will determine how we sidetrack this well. This wellwork could cause damage that would prohibit proper abandonment. Typically the abandonment sundries and permits to drill are written up concurrently, but in this case we felt it best to do the abandonment now while we still have access to the liner. In April-2008, a CIBP was set in the tubing below the TOC and then the tubing was jet- cut. Afailing MIT-T was done post CIBP setting. Please see the following steps outlining our abandonment for the G-13A wellbore. Unit Job Status E Set CIBP @ 8810' Done F MIT-T to 3000 si Failed E Jet-cut @ 8773' Done S Dum 25' Cmt on CIBP C Sear 2-3/8" liner and ull Please find the current WBS and a proposed WBS attached. Thank you, Reed Boeger G-Pad Engineer BP Exploration (Alaska) TREE = 6" MCEV OY WELLHEAD = MCEVOY ACTUATOR = AXELSON 'KB. ELEV = 65.97 BF. ELEV..- 37.52' KOP = 3200' Max Angle = 96 @ 10090' Datum MD = 9179' Datum TVD = 8800' SS • 4.5" 12.6# L-80 TDS, ID = 3.958", .01522 bpf 13-3/8" CSG, 72#, L-80 BTRS I 2672' Minimum ID =1.90" @ 8150' TIW XO -START OF 2-3/8" LNR 3-1/2" TBG, 9.2# L-80 TDS, .0087 bpf, ID = 2.992" 3.5" PARKER SWS NIP, ID = 2.8" ~-~ 8066' TOP OF 7" LNR, 29#, L-80 BTRS I-I 8137' G -~ ~~ S NOTES: CTD HORIZ SDTRK; 3.5" PARKER SWS NIP @ 8066' MILLED FROM 2.75" TO 2.80 ' 2099' 4.5" OTIS SSSV, ID = 3.813" 2116' 4.5" X 3.5" XO, ID = 2.992" GAS LIFT MANDRELS ST MD TVD DEV TYPE VLV LATCH PORT DATE 5 3067 3067 1 MERLA DMY RM 0 07/18/07 4 5164 5063 22 MERLA DMY RM 0 07/18/07 3 6758 6540 22 MERLA DMY RA 0 03/02/01 2 7630 7363 16 MERLA DMY RA 0 03/02/01 1 8035 7752 17 MERLA DMY RA 0 03/02/01 8092' --~ 9-5/8" TMJ HBBP PKR, ID = 4.00" I 8143' TOP OF 2-3/8" LNR - TM/ DEPLOY SLV, ID = 2.25" ~ 8150' ~--~TM/ XO TO 2-3/8", 4.6# TBG, ID = 1.99" ~LC,OC`~'arS~Fa ~O`1 ~`~ I r3~0~ ~~Ig~ ~~ w c9 S t~c>~ ~ ~ i.\~l Ccc~.cc ~~ v-S ~r 9-5/8" LNR, 47#, L-80 BTRS SHOE I-i $649' PERFORATION SUMMARY REF LOG: SWS CNL 2/21/01 ANGLE AT TOP PERF: 57 @ 9317' Note: Refer to Reduction DB for historical perf data SIZE SPF INTERVAL Opn/Sqz DATE 1-11/16" 4 9263 - 9278 C 08/02/03 1-9/16" 6 9317 - 9337 C 05/06/01 1-9/16" 6 9345-9365 C 05/06/01 1-11/16" 6 9445 - 9555 C 02/22/01 1-11/16" 6 9624 - 9940 C 02/22/01 1-11/16" 6 10000 - 10160 C 02/22/01 1-11/16" 6 10185 - 10260 C 02/22/01 1-11/16" 6 10330 - 10460 C 02/22/01 1-11/16" 6 10480 - 10600 C 02/22/01 1-11/16" 6 10610 - 10690 C 02/22/01 1-11/16" 7 10611 - 10690 C 02/23/01 1-11/16" 8 10612 - 10690 C 02/24/01 7" LNR, 29#, L-80 BTRS 9117' 8773' -JET CUT TBG (04/06/08) 8810' ~3/8" WFD CIBP (04/05/08) MILLOUT WINDOW (G-13A) 9090' 1 TOP OF WHIPSTOCK 17'~ RA TAG PBTD ~-) 10779' 2-3/8" LNR, 4.6#, L-80 ST-L, ID = 1.995" ~--~ 10844' DATE REV BY COMMENTS DATE REV BY COMMENTS ORIGINAL COMPLETION 07/21/07 KSB/PJC GLV C/O (07/18/07) 02/22/01 CTD SIDTRACK {G-13A) 04/15/08 RRD/TLH TBG CUT &CIBP SET (04/06/08) 03/10/01 CH/KAK FINAL 05/12/01 JLJITCH ADD PERFS 08/02/03 BJMcITCH ADD PERFS 04/17/04 TWC/KA CORRECTIONS PRUDHOE BAY UNff WELL: G-13A PERMfr No: 2001630 API No: 50-029-20600-01 SEC 12, T11 N, R13E, 2224' NSL & 2368' WEL BP Exploration (Alaska) REE = 6" MCEV OY VB_LHEAD = ~ MCEVOY ~CTUATOi2 = AXELSON :E~. E~EV = 65.97' 3F. ELEV = 37.52' .OP = 3200' lax...An.9~e..._....... ....a6...@..10090' )atum MD - 9179 ... .......... )atumTVD= ..........................._ 8800' SS ~ G-13A 4.5" 12.6# L-80 TDS, ID = 3.958", .01522 bpf 113-318" CSG, 72#, L-80 BTRS ~~ 2672' Minimum ID =1.90" ~ $150' TIW XO -START ~F 2-318" LN R 3-112" TBG, 9.2# L-80 TDS, .0087 bpf, ID = 2.992" 3.5" PARKER SWS NIP, ID = 2.8" ~--~ 8066' TOP OF 7" LNR, 29#, L-80 BTRS ~-~ 87 37' l_F/G" I f\IR d73! I _S7f1 RTRC CNrIR 1-1 lQGdO' PERFORATION SUMMARY REF LOG: SWS CNL 2121101 ANGLEATTOPPERF: 57 @ 9317' Note: Refer to FYoduction DB for historical pert data SIZE SPF INTBPVAL OpnlSgz DATE 1-11116" 4 9263- 9278 c' 08/02103 1-9116" 6 9317 - 9337 C 05/06/01 1-9116" 6 9345- 9365 C 05/06101 1-11116" 6 9445 - 9555 C 02/22/01 1-11116" 6 9624 - 9940 C 02/22101 1-11!16" 6 10000 - 10160 C. 02/22/01 1-11116" 6 10185 - 10260 C 02/22101 1-11116" 6 10330 - 10460 C. 02/22/01 1-11116" 6 10480 - 10600 C 02/22/01 1-11116" 6 10610 - 10690 C. 02/22/01 1-11116" 7 10611 - 10690 C 02/23/01 1-11116" 8 10612 - 10690 C. 02!24101 7" LNR, 29#, L-80 BTRS ~~ 9777' S NOTES: CTD HORIZ SDTRK; 3.5" PARI¢R SWS NIP ~ 8f]66' MILL®FROM 2.75" TO 2.8 f]" 2099' 4.5" OTIS SSSV, ID = 3.813" 27 76' 4.5" X 3.5" X0, ID = 2.992" GAS LIFT MANDRELS ST MD TVD CEV TYFE VLV LATCH FORT DATE 3067 3067 1 MERLA DMY RM 0 07/18/07 4 5164 5063 22 MEF2LA DMY RM 0 07!18107 3 6758 6540 22 MERLA DMY RA 0 03!02!01 2 7630 7363 16 MERLA DMY RA 0 03/02/01 1 8035 7752 17 MERLA DMY RA 0 03102!01 8092' -~9-518" TIW HBBP PKR, ID = 4.00" 8743' TOP OF 2-318" LNR -TIW DEPLOY SLV, ID = 2.25" 8750' TIW XO TO 2-318", 4.6#TBG, ID = 1.99" 8773' HJET CUT TBG (04106x08} 878x' 25' Cement{Proposed} 887 0' 2-318" WFD GBP (04105108} MILLOUT WINDOW (G-13A] 9090' 9777' TOP OF WHIPSTOCK 9777' RA TAG PBTD ~-j 70779' 2-318" LNR, 4.6#, L-80 ST-L, ID = 1 .995" I--I 70844' DATE REV BY ~MME]VTS DATE REV BY ~MMENTS ORIGINAL COMPLETION 07/21/07 KSBIPJC GLV GO (07118107} 02722101 CTD 51DTRACK [G-13A] 04115108 RRD'TLH TBG CUT & C1BP SEr (04106!08} 03/10101 CHxKAK FINAL JRB Dumlp 25' cmnt orl CIBP(1:~5i29,x0 05/12/01 JLJrTLH ADD PERFS 08/02/03 BJMcIfLH ADD PERFS 04/17/04 TWCIKAK CORRECTIONS PRUDHOEBAY UNIT WELL: G-13A PERMIT No:'1001530 API No: 50-029-20600-01 SEC 12, T11 N, R13E, 2224' NSL & 2368' WEL BP Exploration [Alaska) Page 1 of 2 • • Maunder, Thomas E (DOA) From: Boeger, John Reed [John.Boeger@BP.com] Sent: Tuesday, June 03, 2008 2:28 PM To: Maunder, Thomas E (DOA) Cc: Zamora, Chris A Subject: FW: G-13A (200-163) -AGAIN Attachments: G-13A History 02-26-01 to 05-30-08.pdf Tom, If the liner comes free and we can pull it out of hole, CTD will come in and set their whipstock as usual in the 3- 1/2" liner at ~ 8760' MD. If the liner does not come free, Rotary will come in and set their whipstock as usual at 8050' MD. I checked the Drilling Summary and it stated, like you said, that they pumped 13 bbls cement. The TOC on the backside of the 2-3/8" is 8800° MD (2003 SCMT). From 8800' MD - TOL there appears to be cement stringers, which may hold the pipe in place. The wellwork that could prohibit proper abandonment is the act of jarring on the 2-318" liner. We are in the process of building a releasable spear for the liner because there is not one already. If this releasable spear doesn't work properly, we may be forced to run in with a grapple spear {non-releasable) which would then close off all access to the 2-3/8" liner. FYI, I am going out of town Thursday evening. If you have any further questionslcomments after Thursday, please direct them to Chris Zamora. Thanks, J. Reed Boeger BP Exploration, Alaska G-Pad Engineer Office: 907.564.5380 Mobile: 512.217.1852 ~~¢~~~®JUN ~ 9 2008 From: Hubble, Terrie L Sent: Tuesday, June 03, 2008 11:01 AM To: Boeger, John Reed Subject: FW: G-13A (200-163) -- AGAIN Hi Reed, Tom Maunder didn't have your a-mail address and asked that I forward this request to you. 1 have also forwarded him the attached Well History from AWGRS. Terrie From: Maunder, Thomas E (DOA) [mailto:tom.maunder@alaska.gov] Sent: Tuesday, June 03, 2008 10:16 AM 6/3/2008 • To: Hubble, Terrie L Subject: ~RE: G-13A (200-163) -- AGAIN Terrie, Please forward to Reed as I don't have his eddress. Page 2 of 2 Is there a plan to place a BP or retainer in the 3-1/2" if the 2-3/8" liner portion can be pulled or is there some other additional P&A work planned? According to the 407 from 4/13101, it does not appear that sufficient cement was pumped to cement the liner from TD to the window as planned. The permit stated 31 bbls of cement and only 13 was pumped. What type of wellwork is planned that could "cause damage to prohibit proper abandonment?" Thanks in advance. Tom Maunder, PE AOGCC From: Maunder, Thomas E (DOA) Sent: Tuesday, June 03, 2008 9:55 AM To: 'Hubble, Terrie L' Subject: G-13A (200-163) Terrie, I am reviewing the sundry to P&A the wellbore. Is it possible to send the operations reports for the BP and tubing cut? There isn't much in the file since the original completion report. Thanks, Tom Maunder, PE AOGCC 6/3/2008 Well History • Well Date Summary G-13A 2/26/2001 ATTEMPT TO SET 3 1/2" X-LOCK WrfH OUT KEYS UNABLE TO GET DOWN DUE TO PARAFFIN? PLUG @ 3056' SLM /RAN GAUGE RING 2.75" W/ BRUSH TO CLEAN UP TUBING /SET 3 1/2" SLIP STOP @ 3282' SLM, !PULLED 1 1/2" DGLV RA LATCH REPLACED WITH LNE GLV RA/ CA / TRO1596, PORT 16/64,AT STA#5 TO CIRCULATE BEFORE RUNNING REST OF GL DESIGN , OTHER VALVES @ WOA/W/L BUILDING ( CONTACT DSO TO LEAVE WELL SHUT IN) G-13A 3/2/2001 ASSISTm APC IN PULLING FLOW BACK RISER & FLANGE INSTALLED TREE CAP FLANGE DRIFTED WITH 2.70" CENTRALIZER & SAMPLE BAILER TO LINER TOP @ 8128' WLM. SAMPLE OF DRILLING FLUID/METH GEL. SET 3 1/2" SLIP STOP CATCHER @ 5240' WLM. PULLm 1 1!2" DGLV & RM FROM STA #4 @ 5161' WLM INSTALLED 1 1/2" OGLV & RA (24/64" PORT). IN STA#4. PULLm SLIP STOP. SWAP TREE CAP FOR RISER. RDIV1O. TURN WELL OVER TO APC TEST SEPERATOR RETURNED WELL TO APC BACK FLOW UNfr & NOTIFIED OPER. G-13A 3/15/2001 RAN STATIC BHP SURVEY W/TANDEM PETRADAT GAUGES PRESSURE STILL BUILDING AT 2 PSI PER HR WELL Lff-T SHUT IN G-13A 3/21/2001 WELL SI 3/11/01 @ 01:00 AM. (8800 ND / 2593 PSI / 194 DEG.) WELL BUILDING LESS THEN 1 PSI. PER HR. COMPLETED STATIC SURVEY. --RETURN WELL TO PRODUCTION-- G-13A 5/5/2001 DRIFT W/ 1.65" DG TO 352' WLM,DRIFT W/ 1.75" SAMPLE BAILER TO 132' WLM, OBTAIN SAMPLE OF THICK BLACK SCHMOO,BRUSH & FLUSH TO 2700' WLM W! 1.75 GAAGE RING & 3.5" B-LINE BRUSH. BRUSH & FLUSH TO 2095' WLM W/ 3.25" GAUGE RING & B-LINE BRUSH. DRIFT TO 9380' WLM W/ 1.65" DUMMY GUN (15' RH FOR UPCOMING PERFS), NOTE SEVEF2E DOG LEG @ THE WINDOW (9100' WLM), "*"MAY BE DIFFICULT FOR E-LINE TOOLS TO PASS 9100"""" NOTIFY PAD OPER OF WELL STATUS, LEAVE SHUT IN. CALL FOR FREEZE PROTECT (FLOWLINE). G-13A 5/6/2001 PERFORATm 9345-9365 & 9317-9337 WfTH 1.56" POWERJET 6 SPF, CHARGE DATA: 3.4 GMS, 0.19" EH, 10.70" PEKE. WHP INCREASE FROM 1500 PSI TO 1600 PSI. TAG UP @9396' MD. 't`~'"'***"*"PAD OP TO POP WELL"**""" G-13A 6/8/2003 ~'"` Job in progress "`" Pump for a-line log. Spear in w/ 5 bbls meth followed by 608 bbls water. G-13A 6/10/2003 FOUND WELL S!1 UPON ARRIVAL. RIG UP. RAN 1.75" SAMPLE BAILER. TAG TOP OF DEPLOYMEM SLE)=1/E @ 8120' SLM + 23'= MD-8143'. WORK PAST. TOOLS STOPPED DUE TO HAW @ 9094'SLM+ 23'= 9117' CORR. DEPTH. (PEKES 9317-10690) CONTINUE WSR ON 6/11/03. JOB IN PROGRESS. G-13A 6/11/2003 CONTINUED FROM 6/10/03. RIG DOWN. SECUR® WELL. NOTIFIED DSO OF WELL STATUS. G-13A 6/17/2003 PERFORMED SCMT CBL. LOGGED TWO PASSES FROM 9425' TO LINER TOP @ 1600 FPH WHILE PUMPING 1 % KCL DOWN TUBING @ 1 BPM. WELLBORE FLUID PACKED WITH 130 BBL 1 % KCL PRIOR LOGGING. PROPOSm TOP OF CEMENT @ 8798'. G-13A 6/17/2003 TI0=2150/330/160 Assist SWS (SCMT) Pumped 5 bbls of methanol, 294 bbls of 1 % KCL, 55 bbls of crude, and 10 bbls of diesel. Final TIO=vac/300/160 G-13A 6/17/2003 RAN SCMT LOG FROM 9350' TO 8143'. G-13A 8/2/2003 PERFORATm 9263'-9278' INTff~VAL. GUN WAS 15' LONG, 4 SPF, 1 11/16" HSD. G-13A 2/24/2005 T/VO = 2350/350120. Temp = SI. Monitor WHP (SCP high OAP). ""NOTE*"' Changed out bad OAP gauge reading 120 psi. G-13A 7/16/2007 T/U0=2400/1700/0 Temp=Sl TBG & IA FLs (SL call-in). TBG FL @ 8035' ST#1. IA FL @ 6324'. Print Date: 6/3/2008 Page 1 oft C] Well Date ° Summary G-13A °7/17/2007 *** WELL S/I ONARRNAL *"" DRIFT DEVIATION W/ 1.75" CENT, SAMPLE BAILER, STOP @ 9402' SLM, +18' TO MD (9420') DRIFT W/ 2.7" CENT TO LINER TOP @ 8125' SLM+ 18' TO MD (8143') RUN CALLIPER AS PER PROGRAM, FROM 8122' SLM, + 18' TO MD (8140') TO SURFACE (BAD DATA DUE TO FAULTY MEMORY SUB) RE RUN CALLIPER AS PER PROGRAM, FROM 8122' SLM, + 18' TO MD (8140') TO SURFACE SET 3 1/2" WHIDDON G SUB ON LINER TOP @ 8125' SLM PULLED 1.5" S/O GLV / RA LATCH FROM STA #4 - 5160' SLM, PULLED 1.5" LGLV / RA LATCH FROM STA #5 - 3058' SLM SET 1.5" DUMMY GLV / RM LATCH IN STA #5 - 3058' SLM, LRS TO LOAD IA *"* CONTINUED ON 7!18/07 WSR *"" G-13A 7/17/2007 Assist slickline. Stand by for slickline to set GLV. **** Continued on 7/18/07 WSR*** G-13A 7/18/2007 T/VO = 2550/2420/10 Assist slickline.. Load &Test Mff IA PASSED to 3000 psi., MIT OA PASSED to 2000 psi (CTD Screen) Loaded lA w ith 330 bbls crude. MR-IA w ith 28.4 bbls crude. Va lost 80 psi in 1st 15 min and 40 psi in 2nd 15 min for a total loss of 120 psi in 30 nin test. Bled Va pressure back to 1000 psi. MIT OA w ith 5 bbls of crude. OA lost 60 psi in 1st 15 nin and 30 psi in the 2nd 15 min for a total loss of 90 psi in 30 nin test. Bled back OA to 0 psi FWHPs 2350/ 620/0 G-13A 7/18/2007 *"* CONTINUED FROM 7/17/07 *'* (ctd screening) SET 1.5" DUMMY VALVE W/ RM LATCH IN STA# 4 @ 5160' SLM LRS - NiT-Va TO 3000# (PASS) PULL CATCHER SUB FROM 8125' SLM ''"`WELL NORMALED, PAD OP NOTIFIED*** G-13A 3/6/2008 ""* WELL S/I ON ARRNAL *** (ctd screening) SWAB VALVE REPLACED (stripped gate) DRIFT W/ 1.75 CENT, S-BAILB~ TO 8900'SLM, (NO SAMPLE RECOVERED) ""'LEFT WELL S/I"** G-13A 3/6/2008 (Swab Valve Replacement) SLICK LINE CALL-IN ***JOB COMPLETE''"` Removed Cameron 6 3/8" Model FL w ith Tree Cap, Installed Cameron 6 3/8"with Tree Cap. Tested to 5,000 psi. G-13A 415!2008 T/U0= 2300/500/20 Assist E line, Load and Kill. MIT-T FAILm to 3000 psi. (CTD Screen) Pumped 5 bbls neat and 290 bbls crude dow n Tbg to load. NAT-T FAILED to 3000 psi. on 3 attempts. Pressured Tbg to 3000 psi with 9.2 bbls of crude. Tbg lost 220 psi in the 1st 15 min and 200 psi in the 2nd 15 min for a total loss of 420 psi. Bled Tbg pressure to 200 psi. FP FL w ith WOA recipe, pumped 7 bbls neat meoh and 53 bbls crude, rigged down. FWHP=200/500/20 E Line has control of w ell upon departure. G-13A 4/5/2008 SVC WING & SWAB FOR E-LINE /HOT OIL .WELL IS S/I TUBING-2300 VA-500 UA-0 . G-13A 4/5/2008 "'"`WELL SHUT IN ON ARRIVAL''' INITIAL T/V~ 2300/500/0 LRS LOAD® TBG W/ 290 BBLS OF CRUDE SET WFD 2-3/8" CIBP @ 8810' IN 2-3/8" LINER. ***JOB CONTINUED ON 6-APRIL-2008'"' G-13A 4/6/2008 ****JOB CONTINUED FROM 05-APRIL-2008'"`""` PLUG SET ON 05-APRIL-08. SEE AWGRS FOR MORE DETAIL. JET CUT THE 2-3/8" LINER AT 8,773 FT. WITH 1.68 IN SLB POWER CUTTER. *''WELL LEFT SHUT IN. FINAL T/VO: 180/500/0.'`' '""JOB COMPLETE'** G-13A 5/26!2008 CTU #9 Pull test liner. Move from K-20 to G-13 extremely rough roads. '"'**" Interact Publishing *****RIH w jars w eight bars 3"GS P/Tool Could not latch. POOH RIH w jars weight bars 3"GS Slick Catch Fit 11 Jar licks. Unable to stay engauged in fish. POOH Inspect Tool Looks good. Confer w ith town. Ran forward is to RDMO. Wait on info from TNV. *"**'Job incomplete''"'" G-13A 5/26/2008 CTU #9 Pull test liner. Move from K-20 to G-13 extremey rough roads. RIH w jars w eight bars 3"GS spear. """"""""'Job in progress" """' G-13A 5/30/2008 T/V0=0/500/0 MTT-T PASSm to 3000 psi, MrT IA PASSED to 3000 psi, Mff OA PASSED to 2000 psi (CTD screen) MfTT to 3000 psi- Pumped 3.4 bbls crude to to reach test pressure, Tbg lost 180 psi in the 1st 15 min and 50 psi in the 2nd 15 min for a total loss of 230 psi in 30 min. MrT-IA to 3000 psi- Pumped 45 bbls crude to reach test pressure, IA lost 70 psi in the 1st 15 min and 30 psi in the 2nd 15 nin for a total loss of 100 psi in 30 rrin. MIT-OA to 2000 psi- Pumped 2.4 bbls crude to reach test pressure, OA lost 70 psi in 1st 15 min and 30 psi in 2nd 15 nins for a total loss of 100 psi in 30 min. Bled whp's. FWHPs=0/540!480 Annulus casing valves tagged & left open Print Date: 6/3/2008 Page 2 of 2 Schlumberger Alaska Data & Consulting Services 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2838 ATTN: Beth Well Job # Log Description Date BL 02-30B 10980587 RST 07/17/05 1 PSI-07 10674389 RST 10/27/03 1 PSI-07 10679045 RST 12/26/03 1 L3-02 11072860 RST 06/13/05 1 X-16A 10980531 RST 03/01/05 1 F-30 10987523 RST 06/22/05 1 W-31 10913021 RST 06/30/05 1 Z-15 10980580 RST 07/10/05 1 C-30 10980583 RST 07/13/05 1 W-39A 10928650 MCNL 10/16/05 1 18-31A 10942210 MCNL 04/28/05 1 H-02A 10928622 MCNL 04/05/05 1 05-24A 10928609 MCNL *(PRINT SENT 1/24/05) * 12/22/04 K·06A 11075903 MCNL 07/30/05 1 L-03 10913041 OH LDWG EDIT FOR WIRELlNE DATA 08101/05 2 B-02A 10889169 SCMT 09/22/04 H-05 10674407 CBL 01/21/04 G-13A d DO - flJ,,3 10563175 SCMT 06/17/03 E-06A 11051045 SCMT 05/19/05 W-20 10672389 USIT 06/03/04 MPF-87 A 10708043 USIT 01/08/04 MPA-03 11058243 US IT 09/07/05 MPF-89 11051088 USIT 08/17105 BP Exploration (Alaska) Inc. Petrotechnical Data Center LR2-1 900 E. Benson Blvd. Anchorage, Alaska 99508 ~C;ANNED NOV 2 9 2005 Date Delivered: \ ',<",Þ',\' \.-t if V\'\ 11\" C':C;~ ~'" \" . ~~. , t \...L\ t d U 11/17/05 NO. 3602 Company: State of Alaska Alaska Oil & Gas Cons Comm Attn: Helen Warman 333 West 7th Ave, Suite 100 Anchorage, AK 99501 - . / "'3 Field: Prudhoe Bay, Milne Pt. J.- 00 . I IV Color CD 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 -' 1 1 1 1 1 1 1 1 1 -..-" Alaska Data & Consulting Services 2525 Gambell Street. Suite 400 Anchorage, AK 99503-2838 ATTN: Beth /' r- Received by C~~ Œ ~~." .r.' . '. - ... "...\~. "t "~ ".'¡,~ MICROFILMED 04/01/05 DO NOT PLACE ANY NEW MATERIAL UNDER THIS PAGE F:\LaserFiche\CvrPgs _ Inserts\Microfilm _ Marker. doc . (STATE OF ALASKA ( ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations Performed: AbandonD SuspendD Operation Shutdown 0 Perforate ŒJ VarianceD Annular DisposalD Alter CasingD Repair WellD Plug PerforationsO Stimulate D Time ExtensionD OtherD Change Approved ProgramD Pull TubingD Perforate New Pool 0 Re-enter Suspended WellD 2. Operator 4. Current Well Class: 5. Permit to Drill Number: Name: BP Exploration (Alaska), Inc. 200-1630 Development IX] ExploratoryD 3. Address: P.O. Box 196612 6. API Number Anchorage, Ak 99519-6612 Stratigraphic 0 ServiceD 50-029-20600-01-00 7. KB Elevation (ft): 9. Well Name and Number: ~OO ~~ 8. Property Designation: 10. Field/Pool(s): ADL-0028304 Prudhoe Bay Field / Prudhoe Oil Pool 11. Present Well Condition Summary: Total Depth measured 10840 feet true vertical 8990.4 feet Plugs (measured) None Effective Depth measured 10779 feet Junk (measured) None true vertical 8990.9 feet Casing Length Size MD TVD Burst Collapse Conductor 80 20" 94# H-40 30 - 110 30.0 - 110.0 1490 470 Liner 953 7" 29# L-80 8137 - 9090 7850.7 - 8780.5 8160 7020 Liner 2694 2-3/8" 4.7# L-80 8150 - 10844 7863.3 - 8990.4 11200 11780 Production 8619 9-5/8" 47# L-80 30 - 8649 30.0 - 8348.6 6870 4760 Surface 2642 13-3/8" 72# L-80 30 - 2672 30.0 - 2671.8 4930 2670 Perforation depth: Measured depth: 9263 - 9278,9317 - 9337,9345 - 9365,9445 - 9555,9624 - 9940,10000 -10160 10185-10260,10330 -10460,10480 -10600,10610 -10690 True vertical depth: 8932.99 - 8942.63,8964.64 - 8975.8,8980.45 - 8991.21,9015.12 - 9021.94,9022.1 - 9012.14,9011.37 - 9001.93 9000.66 - 8996.91,8996.84 - 8993.93,8992.11 - 8991.17,8990.75 - 8989.09 Tubing ( size. grade, and measured depth): 3-112" 9.3# L-80 @ 30 - 8137 R E eEl VE D Packers & SSSV (type & measured depth): Baker S-3 Packer @ 8092 JAN 0 6 Otis SSSVN @ 2099 2004 12. Stimulation or cement squeeze summary: S 008. Commission Intervals treated (measured): Anchorage Treatment descriptions including volumes used and final pressure: 13 ReDresentative Dailv Averaae Production or Iniection Data Oil-Bbl Gas-Met Water-Bbl Casinq Pressure Tubing Pressure Prior to well operation: 411 21086 3 330 850 Subsequent to operation: 831 13775 43 150 733 14. Attachments: 15. Well Class after proposed work: 8)MS Bfl JAN 0 7 20~ ExploratoryD Development~ ServiceD Copies of Logs and Surveys run - 16. Well Status after proposed work: Operational Shutdown 0 OillXl GasD WAGD GINJD WINJD WDSPLD Prepared by Sharmaine Copeland (907) 564-4424. Sundry Number or N/A if C.O. Exempt: Title Technical Assistant Signatu Phone 564-4424 Date 12/30/03 Form 10-404 Revised 2/2003 \;"'~GA[~tl\l !Ë[' JAN 2 @ 2004 \' ( ( G-13A DESCRIPTION OF WORK COMPLETED NRWO OPERATIONS EVENT SUMMARY 08/02/03 Perforated 9263'-9278' 4 SPF, Gun 15' long, 111/16" HSD FLUIDS PUMPED BBLS 0 TOTAL Page 1 Permit to Drill 2001630 MD 10844 -~ 'rVD DATA SUBMITTAL COMPLIANCE REPORT 41112003 Well Name/No. PRUDHOE BAY UNIT G-J3A Operator BP EXPLORATION (ALASKA) INC · 8990 ,'"' Completion Dat 2122/2001 ·~ Completion Statu 1-OIL Current Status 1-OIL APl No. 50-029-20600-01-00 UIC N REQUIRED INFORMATION Mud Log N._~o Sample N._.~o Directional Survey ~-!~o--..~.~/--~-, DATA INFORMATION Types Electric or Other Logs Run: Well Log Information: Log/ Data Digital Digital Type Media Fret Log Log Run Name Scale Media No Interval Start Stop (data taken from Logs Portion of Master Well Data Maint) OH I Dataset CH Received Number Comments (,~fl%ctional Survey FINAL ~rrectional Survey FINAL /~CNL/GR/CCL~"~- 2 FINAL 1 oee'4~-- FINAL ,.~D Survey FINAL · -~rectional Survey FINAL 10306 FINAL · ~D Gr 2/5 FINAL c~DGR 2/5 FINAL LIS Verification FINAL 8028 9082 8028 8028 9082 9090 9090 10779 10840 10779 10779 10840 10840 10840 Case Open oh ch OH OH OH OH OH OH 3123/2001 10004 8028-10779 9/20/2001 10306 9082-10840 4113/2001 Directional Survey Digital Data 4/13/2001 Directional Survey Paper Copy 3/23/2001 8028-10779 BL, Sepia 3/23/2001 10004 8028-10779 Digital Data 7/612001 MWD Survey, Digital Data 7/612001 Directional Survey, Paper Copy 9/20/2001 10306 9082-10840 Digital Data 9/20/2001 9090-10840 BL, Sepia 9/20/2001 9090-10840 BL, Sepia 9/20/2001 LIS Verification Well Cores/Samples Information: Name Interval Start Stop Sent Received Dataset Number Comments ADDITIONAL INFORMATION Permit to Drill 2001630 DATA SUBMITTAL COMPLIANCE REPORT 41112003 Well Name/No. PRUDHOE BAY UNIT G-13A Operator BP EXPLORATION (ALASKA) INC MD 10844 TVD 8990 Well Cored? Y ~ Chips Received? ~ Analysis ~ Received? Completion Dat 2/22/2001 Completion Statu 1-OIL Current Status 1-OIL Daily History Received? ~____~N Formation Tops (~/ N APl No. $0-029-20600-01-00 UlC N Comments: Compliance Reviewed By: Date: Transmittal Form HUGHES Baker Atlas Canada GEOSciences Centre To: State of Alaska, Alaska Oil & Gas Conservation Commission 333 West 7th Avenue, Suite 100 Anchorage, AK 99501 Attention: Lisa Weepie Reference: Prudhoe Bay Unit G-13A Comains the following':. ..' . i.. '" .. . 1 LAS Format disk..'" ..' '...'..'." ..'..".:'.'::.:" .... " 1 Film Set .._........:: .' :. ...:...'.'..:.:....:/:,'i:.....:":.::.i.::.i. :...:..: 1 Measured Depth GR:..print':.:..:' .... ~'.::'::.": .' ~".':,"..'"" ',' !''':''''',.''.''' ': "?'' ::~.'..' 1 TVD-GR print .... :'"': ...... . '.': .' "": '"'""':" '"." !. ,'"';' :.:,..',.,i!!..," ::", :' '/J ",-. "i:~":. :'",.."::,Z':". ;i:.i..! !i ' . :'"ii: .i; ' ~enee~N~ber~:.:. 1.~5..~.5: LAC Rede ........... , ..i.: ........ ,.,,:.~,: ..!...... ,...:..........:,....,....:.:.:..:..:..i............i:...i.: :.. . : : . : ' '' ' ." : ...... . ' '": . '...; ' ' ::: .::' '.' .' .'".'. '.' ..',, :':":::'.: S,.r ~;'.. ::.:..: ;'.'. :;' ':.?. '~.,.~...'. ;. :...' ....... '"'. ::.. :.'.'... :~ ~.~.'. "!!~'. :'.':.. ::.~".::....i~...:: ,_ "~': :'.'?:::. :~':; ~, ::r. '.:':~~ Sent By: Josef Be~r,rg PLEASE ACKNOWLEDGE RECEIPT BY SIGNING & RETURNING A BP EXPLORATION (ALASKA) PETROCHEMICAL DATA CENTER 900 E. BENSON BLVD. ANCHORAGE, ALASKA 99508 Baker Atlas #1300, 401-9th Ave. S.W. Calgary, Albert a, Canada T2P 3C5 Direct: (403) 537-3752 FAX: (403) 537-3767 Date: Sept 17, 2001 _ _: ,t.~,.q,T.,.?~, : .. ~ ,,~.,,,,~,:,~,.,~.:, :. - : ======================= = : . :,.~ ~: ,. ~.,.,..... ,, .,_ ~: -'!?"":; ........... ........ ? ....... ? ........... .4:h..,.:.4.: .......... .... i,'..,:. , :,,., ,;,, ,. ' - 2"..L:.%.;:.::2"." -- ..,~ . .;--j: ..... : ...... ~ ~ ....... ..... ~ ..... r ~-~ - ~, ..- ; ....... ~ ..... :~ :_--~ .....,,,, : ~ ,.,. .~ - ~. ....~,~,~ :-~ --:-Y ': X.t:.'. % ?' ...... :', ,:::-, ........ -~',?,', STATE OF ALASKA (' . . ALASKA OIL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1. Status of well Classification of Service Well OIL r~ GAS r~ SUSPENDED r-~ ABANDONED D SERVICE D 2. Name of Operator ~ t.[,,K.;~la.,~l~ 7. Permit Number BP Exploration (Alaska), Inc. I ¥~ 200-163 3. Address P. O. Box 196612 Anchorage, AK 99519-6612 8. APl Number 4. Location of well at surface ; ' ~-"" ' ' 9. Unit or Lease Name 2221' FNL, 2365' FEL, Sec. 12, T11N, R13E, UM (asp's 657852, 5969417),~'~.. ~ ..." .. ". :. Prudhoe Bay Unit 1283' FNL, 653' FEL, SEC 12, T11N, R13E, UM (asp's 659545, 5970394)~ ~ '. '" :' '.~ :~.' -' G-13A 481' FNL, 4496' FEL, SEC 7, T11N, R14E, UM (asp's 660592, 5971218) Prudhoe Bay Field 5. Elevation in feet (indicate KB, DF, etc.) 16. Lease Designation and Serial No. RKB 66 feetI ADL 28304 Prudhoe Bay Oil Pool 12. Date Spudded 13. Date T.D. Reached 14. Date Comp., Susp. Or Aband. 115. Water Depth, if offshore 16. No. of Completions February 13, 2001 February 19, 2001 February 22, 2001 I N/A feet MSL 1 17. Total Depth (MD + TVD) 18. Plug Back Depth (MD + TVD) 19. Directional Survey 120. Depth where SSSV set 21. Thickness of Permafrost 10844' MD /8990' TVD 10779' MD /8991' TVD YES r~ No DI 2099' feet MD 1900' (approx) 22. Type Electric or Other Logs Run MWD GR & Mem GR/CNL/Temp 23. CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD CASING SIZE WT. PER FT. GRADE TOP BOTTOM HOLE SIZE CEMENTING RECORDI AMOUNT PULLED 20" x 30' insulated n/a Surface 110' 36" 8 cubic yards concrete 13-3/8" 72# L-80 Surface 2673' 17-1/2" 3441 cuft AS II 9-5/8" 47# L-80 Surface 8649' 12-1/4" 1104 cu It Class G 7" 29# L-80 8137' 9090' 8-1/2" 336 cuft Class G 2-3/8" 4.6# L-80 8143' 10844' 3" 13 bbls Class G 24. Perforations open to Production (MD + TVD of Top and Bottom and 25. TUBING RECORD intewal, size and number) SIZE DEPTH SET (MD) PACKER SET (MD) 2" PJ , 2006 HMX charges, 6.S gm (.23' entrance hole, 19"pen) 4-1/2" 2116' 8092' 9445' - 9555' MD; 9015' - 9022' TVD; 6 SPF Zone lA 3-1/2" 9090' 9624' - 9940' MD; 9022' - 9012' TVD: 6 SPF Zone lA 10000' - 10160' MD; 9011' - 9002' 'I'VD; 6 SPF Zone lA 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. 10185' - 10260' MD; 9001' - 8997' TVD; 6 SPF Zone lA DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED 10330' - 10460' MD; 8997' - 8994' TVD; 6 SPF Zone lA 1500' 18 bbls 60/40 Methanol Water 10480' - 10600' MD; 8992' - 8991' TVD: 6 SPF Zone lA (See Sidetrack Summary for details) 10610' - 10690' MD; 8991' - 8989' TVD: 6 SPF Zone lA 27. PRODUCTION TEST Date First Production Method of Operation (Flowing, gas lift, etc.) March 3, 2001 Gas Lift Date o! Test Hours Tested Production for OIL-BBL GAS-MCF WATER-BBL CHOKE SIZE IGAS-OIL RATIO 3/6/2001 4.0 Test Period > I 11557 Flow Tubing Casing Pressure Calculated OIL-BBL GAS-MCF WATER-BBL OIL GRAVITY - APl (corr) Press. -183 psi 24-Hour Rate > 457 5283 20 28. CORE DATA Brief description of Iithology, porosity, fractures, apparent dips and pressence of oil, gas or water. Submit core chips. * This 10-407 is submitted as directed per the 10-401 form approved October 20, 2000 (Permit #200-163) RECEIVED Form 10-407 J Submit in duplicate Rev. 7-1-80 CONTINUED ON REVERSE SIDE ORIGINAL Alaska 0ii & Gas Cons. Commission Anchorage GEOLOGIC MARKERS FORMATION TESTS NAME Include interval tested, pressure data, all fluids recovered and MEAS. DEPTH TRUE VERT. DEPTH gravity, GOR, and time of each phase. Top of Sag River Sand 8689' 8388' Top of Shublik 8728' 8426' Top of Sadlerochit 8806' 8502' Top of Zone lA 9404' 9007' RECEIVED APR i 3 2001 Alaska Oil & Gas Cons. Commission Anchorage 31. LIST OF ATTACHMENTS Summary of G-13A CT Sidetrack Drilling Operations + End of Well Survey. 32. I hereby certify that the following is true and correct to the best of my knowledge. Signed ~~~I~ Title Coil Tubin,q Drlllln.q En.qlneer Date April 13, 2001 INSTRUCTIONS Prepared by Paul Rauf 564-5799. General: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. Item 1: Classification of Service wells: Gas injection, water injection, steam injection, air injection, salt water disposal, water supply for injection, observation, injection for in-situ combustion. Item 5: Indicate which elevation is used as reference (where not otherwise shown) for depth measurements given in other spaces on this form and in any attachments. Item 16 and 24: If this well is completed for separate production from more than one interval (multiple completion), so state in item 16, and in item 24 show the producing intervals for 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 cementing and the location of the cementing tool. Item 27: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut-in, Other-explain. Item 28: If no cores taken, indicate "none". Form 10-407 ORIGINAL BP EXPLORATION Page 1 of 1 Final Well I Event Summary Legal Well Name: G-13 Common Well Name: G-13A Event Name: REENTER+COMPLETE Start Date: 2/8/2001 End Date: .DATE TMD 24 HOUR SUMMARY 2/8/2001 9,112.0 (ft) ACCEPT RIG AT 10:00 HRS, 2/8/01. BOPE Press test. 2/912001 9,113.0 (ft) Mill out SWS nipple to 2.80", Mill cement. MU tiny tools. 2/10/2001 9,127.0 (ft) Mill on window/whipstock (2 runs) 2/11/2001 9,090.0 (fi) Mill window. Stack wt. Run TIW Whipstock. 211212001 9,092.0 (ft) Set and cmt whipstock. Mill out cement. 2/13/2001 9,103.0 (ft) Mill window, dress window, swap to FIoPro. Dress window. 211412001 9,292.0 (ft) Dress window, drill build section. Trip for motor. 2/15/2001 9,352.0 (fi) Drill 9293'-9352', POH for motor, RIH fishing string, WOW. 211612001 9,447.0 (fi) Drill build section. Perform weekly BOPE test. 2/17/2001 10,062.0 (fi) RIH, Drill lateral 9447'-10062'. 2/18/2001 10,645.0 (ft) Drill horizontal section, Tied-in with BHCS/GR. Drill horiz. 2/19/2001 10,840.0 (ft) Drill to TD of 10,840 f. Run 2 3/8" liner. Circ well to KCL. 2/20/2001 10,840.0 (ft) Cmt liner wi 13 bbls. CIO liner. Log CNL/GR/Temp 2/21/2001 10,840.0 (ft) COmplete CNl_/gr log. Wait on perf guns. MU & RIH with guns. 212212001 10,840.0 (fi) Perf well. FP well. RD BOPE. Move off well. Rig mods/standby. Printed: 4112/200t 5:50:58 PM BP EXPLORATION Page 1 of 9 Operations Summa Report Legal Well Name: G-13 Common Well Name: G-13A Spud Date: 7/13/1981 Event Name: REENTER+COMPLETE Start: 2/8/2001 End: Contractor Name: Rig Release: Group: COIL Rig Name: Rig Number: Sub Phase Description of Operations Date From-To Hours Task Code 2/8/2001 00:00 - 06:00 6.00 MOB PRE Move rig from J Pad to G Pad. No incidents. 06:00 - 10:00 4.00 MOB , PRE N/U TOT BOP to flow cross. 2" pipe/slips on bottom, 2 3/8" pipe/slips on top. 10:00 - 13:00 3.00 MOB PRE ACCEPT RIG AT 10:00 HRS, 02/08/01 ON G-13A. N/U BOPE TO 6" TREE. Berm crew requested for 10:30 hrs, arrived rig at 14:30 hrs. Second ~well in a row they have been 4 hours late. 13:00 - 15:00 2.00 MOB PRE Grease lock tree. No press test. Heat tree and grease lock again. Perform body test on stack. OK. Build berm and set cuttings tank with Peak bed truck. Spot trailers. 15:00 - 23:59 8.98 MOB PRE Perform initial BOPE press / function test. AOGCC witnessed by Jeff Jones. Tested all H2S and LEL Alarms. Test packoffs & inner reel valve. TIW valve failed (Baker). 2/9/2001 00:00 - 01:15 1.25 STWHIP WEXlT MUBHA #1 (1-step whipstock mill, 2.375 straight mtr, mha, cc: OAL: 15.49') 01:15 - 03:00 1.75 STWHIP WEXlT RIH with milling assy. 03:00 - 05:00 2.00 STWHIP WEXlT T, ag sws nipple at 8071' (no correction: ELM depth is 8071') 25K# up, 15k# dn wt. 1750/1.5 FS with 1# biozan. Milled from 8069.5' to 8069.7' Multiple stalls. 05:00 - 07:40 2.67 STWHIP WEXlT Continue milling 3 1/2" SWS nipple at 8069.7' - 8069.9'. Mill out bottom of nipple. 07:40 - 09:00 1.33 STWHIP WEXlT Backream thru nipple and ream down, 3 times. SWS nipple clean. RIH. 09:00 - 10:30 1.50 STWHIP WEXlT RIH tag cement at 8911 ft. Drill cement to 9060 ft at 20-80 fph 10:30 - 11:00 0.50 STWHIP WEXlT Drill cement from 9060 - 9079 ft. Motor locked up, holding 3500 psi, tight. Bleed off pressure with Baker surface choke. 11:00 - 12:30 1.50 STWHIP WEXlT POOH. Order another straight motor. Fill hole across top while POOH. 12:30 - 13:30 1.00 STWHIP WEXlT Change out motor and mill. Motor was locked up. N° rubber in mill ~orts. 13:30 - 15:00 1.50 STWHIP! WEXIT RIH with straight milling BHA. 15:00 - 17:50 2.83 STWHIP WEXIT Mill cement from 9079 - 9122 ft. 1.5 BPM, 2080 psi, 40-60 FPH. '~ 17:50 - 21:00 3.17 STWHIP WEXlT Mill window, correct CTD to top of whipstock depth at 9112 ft. [-10 'CTD]. Time mill at 9 rain / 0.1 ft. 1.5 BPM, 1820 psi, 1500 WOB. Mill to '21:00 - 22:30 1.50 STWHIP WEXlT POOH for window mill 22:30 - 23:30 1.00 STWHIP WEXlT LD mill & motor. 23:30 - 23:59 0.48 STWHIP WEXlT PU Baker tiny tools. 2/10/2001 00:00 - 00:45 0.75 STWHIP WEXlT Continue to mu BHA #3 (mill, 2.5 motor ,BS, ubho,mwd,xo, sperry or, cs,dc, cv, ls,cc. OAL: 57.6') 00:45 - 02:30 1.75 STWHIP WEXIT On well. RIH to 500'. Shallow test mwd. Good. Continue in hole. 02:30 - 03:00 0.50 STWHIP WEXIT ,Tag whipstock at 9122'. (no flag from previous run) . Orient to 190L. 03:00 - 04:00 1.00 STWHIP WEXlT Begin time milling with large radius one-step at 9112'. 2400@1.7 TF:206 Baker mwd & sperry orienter working well. Mill to 9112.3' 04:00 - 05:00 1.00 STWHIP WEXlT Continue time milling. 2400@1.7 TF:210. No WOB. 9112.5' 05:00 - 06:00 1.00 STWHIP WEXlT Continue time milling. 2500@1.7 TF:202. No WOB. 9113.0' 06:00 - 08:30 2.50 STWHIP WEXlT Continue time milling. 2500@1.7 TF:191. 9113.8 ft. 08:30 - 09:30 1.00 STWHIP WEXlT Continue time milling. 2500@1.7 TF:190. 9114.6 ft. 09:30 - 10:45 1.25 s'rWHIP WEXlT Continue time milling. 2500@1.7 TF:190. 9115.5 ft. 10:45- 13:30 2.75 STWHIP WEXlT Continue time milling. 2500@1.7. TF:190 9115.5, stacking wt. No progress. Seeing motor work across milled interval, instead of a clean Printed: 2/2612001 3:10:01 PM BP EXPLORATION Page 2 of 9 Operations Summary Report Legal Well Name: G-13 Common Well Name: G-13A Spud Date: 7/13/1981 Event Name: REENTER+COMPLETE Start: 2/8/2001 End: Contractor Name: Rig Release: Group: COIL Rig Name: Rig Number: Sub Phase Description of Operations Date From-To Hours Task Code 2/10/2001 10:45 - 13:30 2.75 STWHIP WEXlT bottom. 13:30 - 14:20 0.83 STWHIP, WEXlT Log tie-in with GR to BHCS/GR. Added 13 ft to CTD. So we were milling 13 ft deeper than thought. Flag CT at 8900' EOP. [8957.6 ft bit depth]. 14:20 - 15:40 1.33 STWHIP WEXlT POOH with Milling BHA #3 to check motor and mill. 15:40 - 16:15 0.58 STWHIP WEXlT Check motor / MWD offset. Offset was correct. Mill' not worn across center. Wear on mill 0.75" M/U new motor and mill. 16:15 - 16:45 0.50 STWHIP WEXIT SAFETY MEETING. Review operations differences between 2" and 2 3~8" CTD sidetracks. Review spill prevention practices. 16:45 - 18:15 1.50 STWHIP WEXIT RIH with MWD Milling BH^ #4, with a 2.5 deg bent motor and new 2.80" mill. Double Check Whipstock #2 setting record. Whipstock was set on .depth with BHCS/GR with top at 9112 ft. from CCL log. 18:15 - 18:30 0.25 STWHIP WEXIT Correct CTD to flag at 8900' EOP. [added 6 ft to CTD]. RIH. 18:30 - 19:30 1.00 STWHIP WEXIT Dry Tag PBTD at 9124.4 ft at several toolfaces. No preferred TF found. 19:30 - 21:00 1.50 STWHIP WEXIT Begin time milling at 9124'. 2600(~1.7 FS. TF:128R 21:00 - 23:00 2.00 STWHIP WEXIT Mill to 9127'. 3200(~1.7 TF:125R. Appear to be stacking wt. 23:00 - 23:45 0.75 STWHIP WEXIT Log gr tie in starting at 8940'. Add 4' correction (logging down). EOP flag at 8900'. 23:45 - 23:59 0.23 STWHIP WEXIT POOH for BHA. 2/11/2001 00:00 - 01:00 1.00 STWHIP WEXIT POOH for BHA. 01:00 - 02:00 1.00 STWHIP WEXIT LD 2.5 mtr. MU whipstock & string reamer on Weatherford straight mtr. OAL:16.58'. 02:00 - 03:45 1.75 s'rWHIP WEXIT RIH with mill assy. 03:45 - 04:00 0.25 STWHIP WEXIT Tag SWS nipple at 8071' (CT & ELM). Mill through same. 2150/1.6 fs 04:00 - 04:15 0.25 STWHIP WEXIT Continue to RIH. Tie into EOP flag (yellow) (Add 4.7" correction) 04:15-06:00 1.75 STWHIP WEXIT Tag whipstock at 9127'. 30k#up, 16k#dnwt. Begin milling. Millto 9128.0'. Appear to be milling ahead. 06:00 - 08:10 2.17 STWHIP WEXIT Milling, mill to 9129.9 ft. 3K WOB, 1.7/2780 psi. 1 FPH. Pick up clean. Ream down. 08:10 - 10:00 1.83 STWHIP WEXIT Milling, 1.7 bpm, 2920 psi, 4,500 - 5,500 # WOB, Mill to 9,130.7 ft. 10:00 - 12:00 2.00 STWHIP WEXIT Milling, 1.7 bpm, 3080 psi, 5500~ wob. 9131.0 ft. 12:00 - 13:40 1.67 STWHIP WEXIT Milling, 1.7 bpm, 3080 psi, 6000g wob, 9131.1 ft. No progress. Pick up, ream down, clean hole to 3130 ft. [tagged depth]. 13:40- 15:00 1.33 STWHIPI WEXIT POOH. 15:00- 16:00 1.00 STWHIP OTHR WEXIT L/O BH^. Prep for SWS E-Line unit. 16:00 - 18:00 2.00 STWHIP OTHR WEXIT Wait on SWS E-Line Unit. TIW 3.5" whipstock and running tool on location. 18:00 - 19:45 1.75 STWHIP OTHR WEXIT PJU SWS E-Line to Run TIW 3.5" Whipstock. 19:45 - 20:00 0.25 STWHIP OTHR WEXIT SAFETY MEETING to discuss handlign & running TIW/SWS whipstock tools. 20:00 - 21:00 1.00 STWHIP OTHR WEXIT Calibrate orienting tool. Finalize tool MU. 21:00 - 22:00 1.00 STWHIP OTHR WEXIT RIH w/whipstock assy. 22:00 - 23:59 1.98 s'rWHIP OTHR WEXIT RIH w/whipstock assy. Tie into collar log from previous whipstock (tied into BH^ sonic log) 2/12/2001 00:00 - 00:30 0.50 STWHIP OTHR WEXIT Set top of whipstock at 9090' elm. 174 deg orientation. Good indication of shot. Set 300# dn. Held. 00:30 - 01:30 1.00 STWHIP OTHR WEXIT POOH with setting tool. 01:30 - 02:15 0.75 STWHIP OTHR WEXIT MU cementing BHA. Stab on well. 02:15 - 04:00 1.75 STWHIP OTHR WEXIT RIH to 9080'. Circ at min rate. 04:00 - 04:30 0.50 STWHIP OTHR WEXIT Hold PJSM. Discuss safe area, pump schedules, clean up. 04:30 - 06:00 1.50 STWHIP OTHR WEXIT Clean out valves on cement triplex. Batch mix 6 bbls Clas G 15.8 ppg w/latex. Test lines to 4000 psi. Printed: 2/26/2001 3:10:O1 PM BP EXPLORATION Page 3 of 9 Operations Summa Report , Legal Well Name: G-13 Common Well Name: G-13A Spud Date: 7/13/1981 Event Name: REENTER+COMPLETE Start: 2/8/2001 End: Contractor Name: Rig Release: Group: COIL Rig Name: Rig Number: Sub Phase Description of Operations Date From-To Hours Task Code 2/12/2001 06:00 - 07:40 1.67 STWHIP OTHR WEXlT Pump 2 bbls water, 6.4 bbls G cmt with Latex, 2 bbls water. Displace with 39.9 bbls bio. Lay in 1:1. Pull to safety. 07:40 - 07:20 23.67 STWHIP OTHR WEXlT Wait on cement to settle. 07:20 - 08:20 1.00 STWHIP OTHR WEXlT Jet out cement to 9030 ft. RIH at 40 FPM, pump 1.7 BPM, 2300 psi. 08:20- 09:30 1.17 s'rWHIP OTHR WEXlT POOH. 09:30 - 10:00 0.50 STWHIP OTHR WEXlT M/U 2.80" mill and straight motor BHA. 10:00-11:15 1.25 STWHIP OTHR WEXlT RIH with milling BHA #7. Tag cement top at 9032 ft. [2 ft deep]. DS UCA sample at 1130 psi at 11:00 hrs. 11:15 - 13:00 1.75 S'TWHIP OTHR WEXlT Mill cement, 30-40 FPH, 250 psi motor work, 9032 - 9076 ft. 13:00- 14:20 1.33 STWHIP OTHR WEXlT Mill cement. 30 FPH, DS UCA sample at 2250 psi at 1300 hrs. Locate top of whipstock at 9084 ft. Correct CTD to 9090 ft [+6 ft] 14:20 - 18:00 3.67 STWHIP OTHR WEXlT Time milling at top of whipstock. 9 min/0.1 ft. 1.6 bpm, 2400 psi free spin, 15K down wt. Start at 9089.5 ft. Milling w/3000 psi, 1.6 bpm, 2500# web 18:00 - 19:30 1.50 STWHIP OTHR WEXIT Continue milling to 9091.3'. 3100~ web when finished milling. 19:30 - 21:15 1.75 STWHIP OTHR WEXIT POOH for window mill. 21:15 - 22:00 0.75 STWHIP OTHR WEXIT LD straight mtr. Minor wear on whipstock mill (2.8" gauge). MU 2.5 mtr w/1-step window mill. O^L:58.2 22:00 - 23:30 1.50 STWHIP OTHR WEXIT RIH with 1-step mill. Shallow test mwd. COntinue in hole. 23:30 - 23:59 0.48 S'rWHIP OTHR WEXIT Tag whipstock at 9091.6' (no correction !). cycle pumps to switch mwd from magnetic to gravity toolfaces. TF:210.R 2/13/2001 '00:00-00:30 0.50 STVVHIP OTHR WEXIT Orient to 210R. TF keeps walking to left. 3250/1.7fs. 28k#up, 16k# dn wt. TF:210R 00:30- 02:15 1.75 STWHIP OTHR WEXIT Begin time milling at 9089.9'. TF:210R 3400/1.7 Mill to 9092'. Suddenly lost all wt & mtr work. 02:15 - 02:30 0.25 STWHIP OTHR WEXIT PU & orient to 180R. 02:30 - 03:30 1.00 STWHIP OTHR WEXIT Mill ahead to 9096'. Minimal wt and mtr work. TF:174 03:30 - 04:00 0.50 STWHIP OTHR WEXIT Mill ahead to 9098'. ( Corrected TD:9103' after tie-in) 04:00 - 04:30 0.50 STWHIP OTHR WEXIT Log gr tie in from 8930'. Add 5' correction. EOP at 8900' (white/red) 04:30 - 06:15 1.75 STWHIP OTHR WEXIT POOH to check mill. See a lot of chert & sand in btms up sample. 06:15 - 07:00 0.75 STWHIP OTHR WEXIT At surface. LD 2.5 mtr & mill. MIU 1.7 deg motor and 2.8" taper mill. 07:00 - 09:00 2.00 STWHIP OTHR WEXIT RIH, shallow test BHI MWD. Cont. RIH. 09:00 - 09:20 0.33 STWHIP OTHR WEXIT Orient TF to Iowside. 09:20 - 14:00 4.67 STWHIP OTHR WEXIT Dress window with taper mill. Tied-in with GR. Stall at 9092.5 ft. Try several different tool faces to get out window. Stall each time at 9092.5 'f~. ~ Top of whipstock / window at 9090 ft. 14:00 - 16:20 2.33 STWHIP OTHR WEXIT iSwap to FIoPro while milling down. TF -- 210, 1.5bpm, 3100 psi, 9092.7 16:20 - 17:00 0.67 STWHIP OTHR WEXlT 'Milling, no progress, several stalls. Stop at 9092.7 ft. . Crushed tungsten carbide taper mill to aggressive for lip on 7" liner. 17:00 - 18:30 1.50 STWHIP OTHR WEXIT POOH for straight motor and diamond whipstock mill with string reamer. 18:30- 19:00 0.50' STWHIP OTHR WEXIT Lay down BHA #8. 19:00 - 19:30 0.50 STWHIP WEXIT Safety meeting prior to cutting coil. 19:30 - 20:15 0.75 STWHIP WEXIT Cut 200' of coil prior to picking up next BHA. 20:15 - 21:30 1.25 STWHIP OTHR WEXIT MU BHA #9, Straight motor, tapered whipstock mill and string reamer. 21:30 - 23:30 2.00 STWHIP OTHR WEXIT RIH with BHA #9. 23:30 - 23:59 0.48 STWHIP OTHR WEXlT Log tie in pass down from 8930' CTM. Made 0' correction. 2/14/2001 00:00 - 00:25 0.42 STWHIP OTHR WEXlT RIH. Tag top of WS at 9088.9. Pick up, run past with pumps off. Kick pumps back on. Tag top of obstruction/lip @ 9091.3'. Begin time Printed: 2/26/2001 3:10:01 PM BP EXPLORATION Page 4 of 9 Operations Summa Report Legal Well Name: G-13 Common Well Name: G-13A Spud Date: 7/13/1981 Event Name: REENTER+COMPLETE Start: 2/8/2001 End: Contractor Name: Rig Release: Group: COIL Rig Name: Rig Number: Sub Phase Description of Operations Date From-To Hours Task Code 2/14/2001 00:00 - 00:25 0.42 STWHIP OTHR WEXIT milling at 9089.4'. Free spin 3250 psi, 1.5 bpm. 00:25 - 01:00 0.58 STWHIP OTHR WEXlT 01:00 Update, 9090.8', first real motor work. Milling based on work and drill off. 01:00 - 01:30 0.50 S'I'WHIP OTHR WEXIT 01:30 Update, 9091.4', continue milling. 01:30 - 02:00 0.50 STWHIP OTHR WEXIT 02:00 Update, 9092.4', continue time milling, not seeing much motor work. 02:00 - 02:30 0.50 STWHIP OTHR WE×IT 02:30 Update, 9093.2', not seeing much motor work. 02:30 - 03:00 0.50 STWHIP OTHR WEXIT 03:00 Update, 9095.6', 1 stall, and some motor work. Stall at 9096.4', 03:00 - 03:30 0.50 STWHIP OTHR WEXIT 03:30 Update, time milled to 9097' by 03:30. Pulled back up through window pumps on, no problems or drag. PU weight through window = 24k lbs. 03:30 - 04:00 0.50 STWHIP OTHR WEXIT Tag bottom at 9097.7', drill ahead to 9098.7', back ream up through window again. Run up and down through window dry 2 times each with nothing seen on weight. Ran through it one last time down and up with pumps on. Nothing seen on weight or motor work. 04:00 - 05:00 1.00 STWHIP OTHR WEXIT POOH for Drilling BH^. 05:00 - 06:30 1.50 STWHIP WEXIT Tag up at surface with BHA #9, mill guaged at 2.80". Rig down milling BHA, pick up build section drilling BHA with a 2.2 deg motor and Hycalog 2.75" x 3.0" bi centered bit. 06:30 - 08:30 2.00 STWHIP PROD1 RIH with MWD BH^ #10. Shalllow test MWD, OK. RIH. 08:30-10:00 1.50 s'rWHIP PROD1 Tag TD of 9099 ft. Correct+2ftCTD. OrientTFto65R. 10:00 - 10:15 0.25 STWHIP PROD1 FIRE DRILL, call to pipe shed for welder related potential fire. Just a drill. 10:15 - 12:00 1.75 STWHIP PROD1 Drilling, TF = 65R. 1.6 bpm, 3000 psi, ROP = 20 FPH, Incl=3 deg. MD = '9120 ft 12:00 - 14:30 2.50 STWHIP PROD1 Drilling, TF = 30R, 1.6 bpm, 3000 psi, ROP = 20 FPH. Incl=6 deg, MD = 9140 ft. 14:30 - 16:00 1.50 s'rWHIP PROD1 Drilling, TF -- 35R, 1.6 bpm, 3000 psi, ROP = 40 FPH, Inc1=12 deg, MD=9155 ft 16:00 - 18:00 2.00 STWHIP PROD1 Drilling, TF = 10R, 1.6 bpm, 3000 psi, ROP -- 30 FPH, Incl--22 deg, MD=9189 ft Circulate up survey, trying to get valid azimuth. To close to 7" liner. 18:00 - 19:30 1.50 STWHIP PROD1 Drilling, TF -- 15R, 1.6 bpm, 3000 psi, ROP -- 30 FPH, Incl= 19:30 - 20:30 1.00 STWHIP PROD1 9214', Update @ 19:30. Drilling build at 45 fph, 3000 psi FS, 1.6 bpm, Inc=26.89 deg, Azi=62 deg, TF=30R. 20:30 - 21:30 1.00 STWHIP PROD1 9250', Update at 20:30. Drilling build at 40 fph, 3100 psi FS, 1.6 bpm, Inc=36.56 deg, Azi=92.87 deg, TF=30R. 21:30 - 22:00 0.50 STWHIP PROD1 9290', Update at 21:30. Drilling build at 40 fpm, 3100 psi FS, 1.6 bpm, Inc=50 deg, Azi=94 deg, TF--60R. 22:00 - 23:15 1.25 STWHIP MOTR PROD1 9293', BH^ packed off, pumping 3000 psi at 1 bpm. Possibly chunked the motor and plugged off the bit. POH to replace motor. 23:15 - 23:59 0.73 STWHIP MOTR PROD1 Tag up at surface. Rig down motor and bit. PT MHA ok. Check motor. Motor would not turn. Probably chunk stator. Bit clear of debris, but showing wear at the cutters on the pilot section. Will pick up Hughes bi center and new motor. 2/15/2001 00:00 - 00:30 0.50 STWHIP MOTR PROD1 Pick up BHA #11, 2.2 deg BHI motor, Hughes bi center bit. 00:30 - 02:00 1.50 STWHIP MOTR PROD1 RIH with BH^ #11. BHI 2.2 degree motor, and a Hughes bi centered bit. 02:00 - 02:20 0.33 STWHIP MOTR PROD1 Log tie in. Made a +4' correction at 8930'. 02:20 - 06:30 4.17 STWHIP MOTR PROD1 9293', RIH pumping @ 1.5 bpm, 2950 psi FS, Tag bottom, drilling at 60R TF. 06:30 - 07:00 0.50 STWHIP PROD1 Update at 06:30, drilling ahead at 9346', 1.6/3000/90R, ROP = 20 FPH. 07:00 - 07:30 0.50 STWHIP PROD1 Orient TF to 20R. Printed: 2126/2001 3:10:O1 PM BP EXPLORATION Page 5 of 9 Operations Summa Report Legal Well Name: G-13 Common Well Name: G-13A Spud Date: 7/13/1981 Event Name: REENTER+COMPLETE Start: 2/8/2001 End: Contractor Name: Rig Release: Group: COIL Rig Name: Rig Number: Date From - To Hours Task Sub Phase Description of Operations Code 2/15/2001 07:30 - 08:40 1.17 STWHIP PROD1 Drilling, TF=20R, 1.7 bpm, 3150 psi, ROP = 10 FPH. Weak motor, stalls with 300 psi motor work in good sand. MD = 9352 f. 08:40 - 10:00 1.33 STWHIP MOTR PROD1 POOH for weak motor. 10:00 - 11:00 1.00 STWHIP MOTR PROD1 2 3/8" motor unscrewed at top of adjustable section. These threads are not thread locked, so the motor can be adjusted on location. Rotor [1.5" x 6.1 ft ], bent section of motor [2 3/8" x 2.6 ft] and bit [2.75 x 0.6 ft] Total length of fish left in hole = 9.3 ft. 11:00 - 15:00 4.00 FISH MOTR PROD1 Order fishing tools from Baker. Wait on tools. 15:00 - 16:00 1.00 FISH MOTR PROD1 M/U 2.32" overshot w/1.5" grapple [sized for rotor], circ sub, XO, 2" pup, XO, 1 1/4" CSH pup, XO, circ sub, Hyd Disc, CTC. Total Length = 40.12 ff. 16:00 - 18:00 2.00 FISH MOTR PROD1 RIH with fishing BHA. Stop at 9050 ft. Circ. at min. rate. 0.2 bpm, 1100 psi. Wait on weather. Phase 3, 80 mph wind. 18:00 - 00:00 6.00 FISH PROD1 WAIT ON WEATHER. 80 MPH WIND. 2/16/2001 00:00 - 01:00 1.00 STWHIP WTHR PROD1 Wait on weather to moderate. 01:00 - 01:30 0.50 STWHIP PROD1 Safety meeting prior to resuming operations. 01:30 - 01:50 0.33 STWHIP MOTR PROD1 RIH to resume fishing motor. Tagged up at 9347', left TD at 9352' when drilling. Set down 10k lbs, pickup 30' clean set down 2 more times. No overpulls at pickup. Set down at 9347' each time. POH to inspect grapple. 01:50 - 03:40 1.83 STWHIP MOTR PROD1 POH to inspect BHA for fish. 03:40 - 04:30 0.83 STWHIP MOTR PROD1 Tag up at surface, recovered fish. 100% recovery, nothing left in well. Bit shows no sign of wear. Pickup BHA #13, 2.2 deg motor, Rerun same Hughes bi centered bit as on run #11. 04:30 - 06:15 1.75 STWHIP MOTR PROD1 RIH with BHA #13. 06:15 - 07:00 0.75 STWHIP MOTR PROD1 Thru window ok, Pumps on free spin 1.6 bpm, 3300 psi, TF--30R, RIH had to ream back in the hole from 8280'. Tag up at 9354', left on last run at 9353'. Resume drilling. 07:00-10:30 3.50 STWHIP iPRODI Drilling, TF=15R, 1.6/3400, ROP--40FPH, Incl=65deg. MD= 9418 ft 10:30 - 11:10 0.67 STWHIP PROD1 Wiper trip to window. Hole in good condition. 11:10-13:10 2.00 STWHIP PROD1 Drilling, TF=30R, 1.6/3400, ROP=10FPH, Incl=75deg. MD= 9434 ft. 13:10-15:30 2.33 STWHIP PROD1 Drilling, TF=30R, 1.6/3400, ROP-- 10FPH. Incl=79deg, MD= 9447 ft 15:30 - 17:45 2.25 STWHIP PROD1 POOH for 1.1 deg motor and new bit. Well landed at 86 deg. incl. per geo. 17:45 - 18:30 0.75 STWHIP PROD1 Lay out drilling BHA. 18:30 - 23:15 4.75 STWHIP PROD1 Perform weekly BOPE pressure / function test. AOGCC witness waived by Chuck Scheve, E-mail test report to ^OGCC. Made function test of HCR valve, and timed with stopwatch. Took approximately 1/2 second to function from full open to closed. The time was identical going from closed to open. It was repeated 3 times with the same results. 23:15 - 23:45 0.50 STWHIP PROD1 MU BHA #14, 1.1 deg motor, hycalog 2.75x3.0 bi center bit. 23:45 - 23:59 0.23 STWHIP PROD1 RIH with BHA #14. 2/17/2001 00:00 - 01:45 1.75 STWHIP PROD1 Continue RIH with BH^ #14. 01:45 - 02:10 0.42 STWHIP PROD1 Log tie in pass at 8930'. Made 0' correction. 02:10 - 04:00 1.83 STWHIP PROD1 On bottom drilling @ 9447', 1.6/3300/90L TF. Drilling at 70 fph. This Hycalog bi center bit appears to drill at about twice the rate of the Hughes bi center we used on the previous run. Printed: 2/26/2001 3:10:01 PM BP EXPLORATION Page 6 of 9 Operations Summa Report I Legal Well Name: (3-13 Common Well Name: G-13A Spud Date: 7/13/1981 Event Name: REENTER+COMPLETE Start: 2/8/2001 End: Contractor Name: Rig Release: Group: COIL Rig Name: Rig Number: Sub Phase Description of Operations Date From-To Hours Task Code 2/17/2001 ~04:00 - 04:15 0.25 STWHIP PROD1 SPILL DRILL, at the Green Tank. Good response from all hands. 04:15 - 06:45 2.50 STWHIP PROD1 Drilling, TF = 90L, 1.6 / 3300 psi, ROP = 40 FPH, Incl. = 88 deg. MD = 9556 ft 06:45 - 07:45 1.00 STWHIP PROD1 Drilling, TF = 90L, 1.6 / 3300 psi, ROP = 40 FPH, Incl = 88 deg. MD = 9585 ft. 07:45 - 08:30 0.75 STWHIP PROD1 Wiper trip to window. Hole in good conditon. 08:30 - 09:30 1.00 STWHIP PROD1 Drilling, TF -- 30L, 1.6/3300 psi, ROP -- 40 FPH, Incl = 91 deg. MD = 9617 ft. 09:30 - 10:00 0.50 STWHIP PROD1 Orient TF to 90L. 10:00 - 13:00 3.00 STVVHIP PROD1 Drilling, TF = 90L, 1.6 ~3300 psi, ROP = 60 FPH, Incl = 94 deg. MD = 9722 ft. 13:00 - 13:45 0.75 STWHIP PROD1 Wiper trip to window, Hole in good conditon. 13:45 - 14:50 1.08 STWHIP PROD1 Drilling, TF -- 95L, 1.6 / 3300 psi, ROP -- 60 FPH, Incl -' 89 deg. MD -- 9784 ft 14:50 - 16:50 2.00 STWHIP PROD1 , Drilling, TF = 90L, 1.613300 psi, ROP = 70 FPH, Incl = 92 deg, MD -' 9885 ft. 16:50 - 17:45 0.92 STVVHIP PROD1 Wiper trip to window, Hole in good condition. 17:45 - 18:10 0.42 STWHIP PROD1 Drilling, TF -- 60R, 1.6 / 3300 psi, ROP -- 60 FPH, Incl -- 94 deg. MD=9892 ft 18:10 - 19:30 1.33 STVVHIP PROD1 ;Orient around. 19:30 - 20:30 1.00 STWHIP PROD1 9952', Drilling ahead lateral section. 1.613300/90R TF. Inc 89.91. 20:30 - 20:50 0.33 STWHIP PROD1 9959', Stuck pipe. worked up to 63 k lbs 3 times. Can't get free. Call for crude. Continue to work pipe. Came down to minimum rate on pumps (0.2 bpm). LEt sit for 15 minutes. Pulled 63 klbs and popped free. Normal up weight is 25k lbs. 20:50 - 22:00 1.17 STWHIP PROD1 9959', Short trip to shoe. 22:00 - 23:59 1.98 STWHIP PROD1 9959', Return to drilling. Call for new mud for mud swap. 2/18/2001 00:00 - 01:00 1.00 STVVHIP PROD1 10062', Continue drilling lateral section. 1.6/3300/60L, Mud swap in progress. 01:00 - 01:30 0.50 STWHIP PROD1 10102', Short trip to the shoe. 01:30 - 03:30 2.00 STWHIP PROD1 Resume drilling lateral section 1.6/3000 psi/120R TF. 03:30 - 04:15 0.75 STWHIP PROD1 Update at 03:30, 10207', 1.7 bpm/3200/180R TF, making hole at 80 fph. 04:15 - 05:15 1.00 STWHIP PROD1 10250', begin wiper trip to window. Weight off bottom=25k lbs. 05:15 - 06:00 0.75 STWHIP PROD1 Orienting 06:00 - 07:45 1.75 STWHIP PROD1 Resume drilling lateral. TF = 80R. 1.6 / 3000 psi, Drill to 10351 ft. Stacking wt. 07:45 - 08:30 0.75 STWHIP PROD1 Wiper trip to window. 08:30 - 08:45 0.25 STVVHIP PROD1 Log Tie-in to BHCS/GR at 8933 ft. Add 17 ft to CTD. 08:45 - 09:30 0.75 STWHIP PROD1 RIH to TD. Clean hole to TD. 09:30 - 11:00 1.50 STWHIP PROD1 Drilling, TF -- 70R, 1.6 / 3100 psi, ROP = 60 FPH, 90 deg incl, 10,402 ft MD. 11:00-13:15 2.25 STWHIP PROD1 Drilling, TF=90R, 1.6 / 3100 psi, ROP=60FPH. 91degincl, 10,502 ft MD. 13:15 - 15:00 1.75 STVVHIP PROD1 Wiper trip to window, clean hole. 15:00 - 17:30 2.50 STWHIP PROD1 Drilling, TF -- 70L, 1.6 / 3100 psi, ROP = 60 FPH. 91 deg incl. 10,601 ft MD. 17:30 - 18:00 0.50 STWHIP PROD1 Orient TF 18:00 - 19:00 1.00 STWHIP PROD1 Drilling, TF = 90L 19:00 - 20:00 1.00 s'rWHIP PROD1 10635', Orienting. Trying to get consistent tool face. We get it set, then it flops around as soon as we attempt to drill. 20:00 - 22:10 2.17 STWHIP PROD1 POH to change out orienters. 22:10 - 22:50 0.67 STWHIP PROD1 Lay down BHA #14, Pick up BHA #15. Changed out motor, Battery in Printed: 2/26/2001 3:10:01 PM BP EXPLORATION Page 7 of 9 Operations Summa Report Legal Well Name: G-13 Common Well Name: G-13A Spud Date: 7/13/1981 Event Name: REENTER+COMPLETE Start: 2/8/2001 End: Contractor Name: Rig Release: Group: COIL Rig Name: Rig Number: Sub Phase Description of Operations Date From-To Hours Task Code 2/18/2001 22:10 - 22:50 0.67 STWHIP PROD1 MWD, orienter. ReRan same hycalog bicentered bit. Bit was in great shape other than 1 chipped cutter. 22:50 - 23:59 1.15 STWHIP PROD1 RIH BHA #15 2/19/2001 00:00 - 00:45 0.75 STWHIP 3ROD1 Continue to RIH with BHA #15. 1.1 deg motor, hycalog bi centered bit. 00:45 - 02:00 1.25 STWHIP PROD1 Log tie in pass. Made first pass over gamma spike at 8933', made +23' correction. Relog to confirm. Depth within 1', RIH to begin logging. 02:00 - 02:50 0.83 STWHIP PROD1 RIH to begin drilling. 02:50- 04:30 1.87 STWHIP PROD1 10850', Resume drilling 1.6/3150/120R 04:30 - 08:30 2.00 STWHIP PROD1 04:30 Update, 10713' 1.7/3300/120L TF. Drilled to 10842 ft MD. Stacking wt. 08:30 - 07:50 1.33 STWHIP PROD1 Wiper trip to window. Hole is clean. 07:50 - 08:20 0.50 STWHIP PROD1 Log Tie-in to BHCS/GR. [ - 1 ft on CTD] 08:20 - 10:00 1.67 STWHIP PROD1 RIH to TD. Tag TD at 10,840 ft MD. POOH to 7000 ft. Hole is clean. 10:00 - 12:30 2.50 STWHIP PROD1 Flag CT at 7000 ft EOP. POOH. 12:30 - 13:20 0.83 STWHIP PROD1 Lay out BHI MWD tools and motor. 13:20 - 14:45 1.42 CASE PROD1 Cut off CTC. Weld on completion CTC with 1.15" ID. Pump Dart and 1 1/8" steel ball to check meters and gauge ID of CT. Pump 1.7 - 2.3 BPM, Ball on seat at 38.80 bbls. 14:45 - 15:15 0.50 CASE PROD1 Prepare rig floor to run 2 3/8" liner. 15:15 - 15:45 0.50 CASE PROD1 SAFETY MEETING. Review differences in procedures to run smaller liner. 15:45 - 19:00 3.25 CASE PROD1 Make up 2-3/8" liner as per procedure. 19:00 - 19:30 0.50 CASE PROD1 Safety meeting prior to making up TIW eq. 19:30 - 20:00 0.50 CASE PROD1 Make up TIW deployment tool. 20:00 - 21'15 1.25 CASE PROD1 RIH with liner. Circulating at 0.2 bpm, 1800 psi, 0.5 bpm returns, 21:15 - 21:45 0.50 CASE PROD1 Weight check at window=28klbs up wt. RIH. Didn't see anything at window. Initial RIH down wt=16,800 lbs. 10000'=14klbs, TAg botttom at 10795' ctm. Pickup at 38klbs. Tag again @ 10795. 21:45 - 22:35 0.83 CASE PROD1 Drop 5/8" ball to release from liner deployment tool. Chase with mud. Pumping at 1.4 bpm. At 26 bbl away, drop pressure to 1500 psi to ~ ensure we can see release too shear. Having high back pressure. IOnly pumping at 0.1 bpm @ 1500 psi. Deployment slv is in straight hole. Ball should fall on seat. 22:35, 28.2 bbls away. 22:35 - 22:55 0.33 CASE PROD1 28.2 bbls away, CTP increased from 1700 to 2200 psi at 0.2 bpm, then fell off. Ball seat should shear at 4000 psi. Not a good indication of shear. TIW engineer does not want to increase rate. Continue to pump at 0.2 bpm. 22:55 - 23:15 0.33 CASE PROD1 38 bbls away (38.8 bbls coil capacity) land ball on seat. Pressure up to 4500 psi. Could not release from liner top. Cycle pressure 0-5000 psi. Tool released after 4 cycles. Pick up at 14000 lbs, confirmed release of liner. Bottom of liner at 10795'. 23:15 - 23:59 0.73 CASE PROD1 Circulate mud OOH. Displace with 2% KCL. 2/20/2001 00:00 - 01:00 1.00 CASE PROD1 Continue to circulate well to KCL. 01:00 - 01:30 0.50 CASE PROD1 Pre cementing safety meeting with Rig crew, DS CTU crew, pumping crew, TIW, BPX. Discuss pumping safety, walk arounds, possible high pressure to launch liner wiper plug. 01:30 - 02:15 0.75 CASE PROD1 Rig up cementers, begin mixing cement. Cement up to weight 02:10 AM, 4:30 hrs thicking time. 02:15 - 02:25 0.17 CASE PROD1 Cementers pump 5 bbls 2% KCL to warm lines. PT cementers to 5000 psi, ok. 02:25 - 03:20 0.92 CASE PROD1 On line with cementers. Pump 13 bbls of Class G cement at 1.5 bbl/min. Drop dart. Swap to rig pumps. Pump 2 bbls KCL. Check for dart, launched ok. Resume pumping KCL. Pumping At 2 bpm, 2500 Printed: 2/26/2001 3:10:01 PM BP EXPLORATION Page 8 of 9 Operations Summa Report Legal Well Name: G-13 Common Well Name: G-13A Spud Date: 7/13/1981 Event Name: REENTER+COMPLETE Start: 2/8/2001 End: Contractor Name: Rig Release: Group: COIL Rig Name: Rig Number: Sub Phase Description of Operations Date From-To Hours Task Code 2/20/2001 02:25 - 03:20 0.92 CASE PROD1 psi. 36 bbls away, drop rate to 0.75 bpm, pumping CTP=175 psi. Landed dart in wiper plug at 40 bbls away (CT vol 38.8 bbl). Pressured up coil to 5000 psi. Wiper plug would not shear. (Set for 2000 psi). Bring CTP from 0 to 5000 psi. 4 times. Would not shear. Were also getting returns on out micro motion when cycling pumps. 03:20 - 03:40 0.33 CASE PROD1 Cementers still rigged up. Have cementers bring CTP up to 6000 psi. Pumping at 1.75 bpm. Getting 1.3 bpm back. Some bypass going around dart. Repeated 2 times with cementers. Could not get liner wiper plug to release. Returns are 12.5 bbls since cement at shoe. Total cement pumped 13 bbls. Discontinue further attempts at releasing liner wiper dart. Un sting from deployment sleeve. Total fluid 3umped behind dart -- 53 bbls. If working, should have landed liner wiper plug in landing collar at 49 bbls away. 03:40 - 05:10 1.50 CASE PROD1 POOH. Pumping 1.7 bpm, through deployment sleeve. Getting 1 for 1 returns. Unstung from deployment sleeve, kicked on pumps. Jetted cement from top of liner while POH. While POH got cement returns at surface. Got 8-10 bbls of 12.5 ppg fluid with an additional 8 bbls of cement contaminated KCL brine. 05:10 - 05:30 0.33 CASE PROD1 Rig down TIW deployment tool. Plug and dart not on deployment tool. Left in hole, but not at landing collar. 05:30 - 07:00 1.50 CASE CASE PROD1 Waiting on Baker for mill and motor. 07:00 - 10:00 3.00 CASE CASE PROD1 M/U 1.85" 3 bladed mill, 1 11/16" motor, jars, Disc, CV, XO, 96 jts, I"CSH, XO, Disc, circ sub, CV, swivel and CTC. Total Length -- 2915.54 ft. 10:00 - 12:30 2.50 CASE CASE PROD1 No cement or fish at top of 2 3/8" Liner at 8,139 ft. Cont RIH. 12:30 - 13:30 1.00 CASE CASE PROD1 RIH, saw a little motor work at 9370 ft. Cont. RIH, 30 FPM, 0.7 BPM, 1800 psi. Tag PBTD at 10731 ft CTD, twice. Depth may be actual PBTD of 10774 ft. 13:30 - 15:00 1.50 CASE PROD1 POOH with milling BHA. 15:00 - 16:30 1.50 CASE PROD1 Stand back 48 stds of 1" CSH workstring. 16:30 - 17:00 0.50 CASE PROD1 L/O Baker motor and mill. 17:00 - 18:00 1.00 CASE PROD1 Prepare to run SWS Memory CNL/GRITemp log. 18:00 - 18:45 0.75 CASE PROD1 SAFETY MEETING, review procedures for MIU and RIH with CNL logging tools. Crew change out. 18:45 - 20:30 1.75 CASE PROD1 MU CNI_/GR/Temp log. RIH on 96 jts 1" CSH. BHA length 2919.03 20:30-21:15 0.75 CASE PROD1 PU injector. On well. RIH. 21:15 - 23:00 1.75 CASE PROD1 Log down from 8000' at 30 fpm. Tag PBTD at 10733'. 23:00 - 23:59 0.98 CASE PROD1 Log repeat pass OOH at 30 fpm. 2/21/2001 00:00 - 01:15 1.25 CASE PROD1 COntinue to log cnl/gr/temp repeat pass to 8000'. 01:15 - 02:00 0.75 CASE PROD1 RIH. Start 150k flo vis pill down coil. 02:00 - 02:30 0.50 CASE PROD1 Lay in pill 1:1. 02:30 - 04:30 2.00 CASE PROD1 POOH to CSH 04:30 - 06:30 2.00 CASE PROD1 Stand back wash pipe. 06:30 - 07:00 0.50 CASE PROD1 PJSM. LD CNL assy 07:00 - 08:00 1.00 CASE PROD1 Pressure test wellbore at 2100 psi for 1 hr. Lost 50 psi 08:00 - 17:00 9.00 CASE PROD1 ~WO perf guns. Original 4 spf was changed to 6 spf at last minute by APE. SWS reload entire string Tack weld WL unit to floor. Assemble inspected lubricator, sting good wire thru new packoff assy. Standback with CSH workstring 17:00 - 18:00 1.00 CASE PROD1 Load 59 perf guns in pipeshed 18:00 - 18:30 0.50 CASE PROD1 Hold PJSM regarding perfing procedures. 18:30 - 22:00 3.50 CASE PROD1 MU 1261' 6 spf 1.56" HSD Powerjet 2006 guns. Printed: 2/2612001 3:10:O1 PM BP EXPLORATION Page 9 of 9 Operations Summa Report Legal Well Name: G-13 Common Well Name: G-13A Spud Date: 7/13/1981 Event Name: REENTER+COMPLETE Start: 2/8/2001 End: Contractor Name: Rig Release: Group: COIL .Rig Name: Rig Number: Sub Phase Description of Operations Date From-To Hours Task Code 2/21/2001 22:00 - 23:30 1.50 CASE , PROD1 Run 50 its 1" CSH. MU to coil. Stab on well. '23:30 - 23:59 0.48 CASE PROD1 RIH with perf assy. BHA OAL: 2767'. 2/22/2001 00:00 - 01:15 1.25 CASE PROD1 RIH. Tag PDTD & correct to 10779' (based on CNL log tied into OH sonic) Add 34'. 28k# up, 16k# dn wt. 01:15 - 01:45 0.50 CASE PROD1 Drop 0.5" ball. Circulate to guns. 1.5 bpm@2550 psi. Slow to 0.7. Ball on seat at 39 bbls. Pressure & fire guns @ 2300 psi. Perf intervals: 9445'-9555', 9624-9940, 10000-10160, 10185-10260, 10330-10460, 10480-10600, 10610-10690'. 01:45 - 03:45 2.00 CASE PROD1 POOH with guns. No fluid loss while POOH. 03:45 - 06:30 2.75 CASE PROD1 At surface. Stand back CSH. 06:30 - 06:45 0.25 CASE PROD1 Safety mtg re: perf guns 06:45 - 10:00 3.25 CASE PROD1 LD perf guns-all shots fired. Load out perf guns. SI swab 10:00 - 12:00 2.00 CASE PROD1 Field Safety Stand Down at request of Field Mgr. Discuss HSE issues w/emphasis on spills 12:00 - 14:00 2.00 CASE PROD1 RIH w/nozzle and FP w/18 bbls MeOH from 1500'. Close swab (35) 14:00 - 16:00 2.00 CASE PROD1 RU DS N2 pumper. Blow down CT. Bleed off press 16:00 - 17:00 1.00 CASE PROD1 ND BOPE. NU tree cap and pressure test 17:00 - 18:00 1.00 CASE PROD1 Rig released at 1700 hrs 2/22/01. Move to DS/N #1 to G-Pad extension and set down 18:00 - 23:59 5.98 CASE PROD1 Begin Standby rate while performing modifications for Kuparuk work Printed: 2/2612001 3:10:01 PM TREE = 6" MCEVOY WB_LI-EAD= MCEVOY ACTUATOR= AXELSON KB. ELEV = 65.97' BF. ELEV = 37.52' 14.5" 12.6~ L-80 TDS, .KOP = 3200''liD= 3.958", .01522 bpf / i Max Angle = 96 @ 10090' Datum MD = 9177' Datum TV Dss= 8800' 1~3-3/8"cso, 72#,L-80 BTRS H 2672- IMinimum ID = 1.90" @ 8150' = TIW XO I START OF 2-3/8" LNR I 13-112" TBG, 9.2# L-80 TDS, .0087 bpf, ID =2.992" 13.5"PARKB:~SWSNIP, ID=2.8" H 8066' ITOP OF 7" LNR, 29~, L-80 B'FRS H 8137' ITOPOF 2-3/8" LIaR -TIW DEPLOY IVENT H 8143' SLV, ID = 2.25" / / G-13A SAFEI'Y NOTES: CTD HORIZONTAL SIDETRACK; 3.5" PARKER SWS i~P @ 8066' MILLB3 FROM 2.75" TO 2.80" 2099' 4.5" OTIS SSSVN, ID= D = 2.992" GAS UFT MANDRELS IsTI ~ I WDI DEV I ~'PEI VLV ILA~C.I SIZE I DATE ~l ~ I~°~ I~°°°1 o I~1 ~ I ~ I ~'~" I ~oo~ i~ls~l~l 21 la.LAI S/OI ~ I ~'5" I 3/2~00~ I 131~5815~1 21 IM~LAI DV I ~ I tS" I 3/2~00~ I /2 17~0172951 ~6 I~1 DY I ~ I ~.5" I 3/2~00~ I i~ is035177401 ~4 la.LAI OV I ~ I 1'5" I 3/2~001 8092' H 9-5/8" TIW HBBP PKR, ID = 4.00" 8150' -nw XO TO 2-3/8", 4.6# TBG, ID = 1.99" J ITOPOF7"29#LNR H 8137' 19-5/8" CSG, 47#, L-80 BTRS SHOE H 8649' PERFORATION SUMIV~ RY REF LOG: SWS Cl~. 2/21/01 ANGLEATTOP PERF: 82 Note: Refer to Production DB for historical perf data SIZE SPF NTERVAL OpnlSqz DATE 1-11/16" 6 9445- 9555 O 2/22/2001 1-11116" 6 9624- 9940 O 2/22/2001 1-11/16" 6 10000- 10160 O 2/22/2001 1-11116" 6 10185- 10260 O 2/22/2001 1-11116" 6 10330- 10460 O 2/22/2001 1-11116" 6 10480- 10600 O 2/22/2001 1-11116" 6 10610- 10690 O 2/22/2001 J~-3/8" 4.6~, L-80 ST-L LNI~ ID = 1.995"J 9090' ~M,,our W,N~OWI 9112' Id TOP OF WI'IPSTOCK I 9117' ]~RA TA~I I~To H ~07~9' I 17" LNR, 29~, L-80 BTRS SHOE H 9483' 12-3/8", 4.6#, L-80 ST-L LNR SHOEH 10844' DATE REV BY COMMENTS 02/22/01 STD SIDTRACK COIVPLETION 03/10/01 CI-I/KAK FINAL PRUDHOE BAY UNIT WELL: G-13A PERMIT No: 200-163 AFl No: 50-029-20600-0 BP Exploration (Alaska) ::¡;; Cl. 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If j~ ~ ~ ~~ lU!/iìOS1 &I~daa ie;!~~^ awl 2. -N Obp BP Amoco Baker Hughes INTEQ Survey Report INTEQ Comlmny: BP Amoco Field: Prudhoe Bay Site: PB G Pad WeB: G-13 WellFath: G-13A Date: 4/g/2001 'rime= 16:45'~5 Page: 1 Co-ordinate(NE) Reference: Well: G-13, True North Vertical (TVD) Reference: 20: 13 711311981 00:00 68.0 Sectiel (VS) Reference: Well (0.00N,0.00E,59.00Azi) Suryey Caleuintion Method: Minimum Curvature Db: Oracle Field: Prudhoe Bay North Slope UNITED STATES Map System:US State Plane Coordinate System 1927 Ceo Datum: NAD27 (Clarke 1866) Sys Datum: Mean Sea Level Map Zone: Alaska, Zone 4 Coordinate System: Well Centre Geomagnetic Model: BGGM2000 Site: PB G Pad TR-11-13 UNITED STATES: North Slope Site Position: Northing: From: Map Easting: Position Uncertainty: 0.00 ft (;round Level: 0.00 ff 5966832.87 ff Latitude: 70 18 58.211 N 656301.39 ff Longitude: 148 43 59.013 W North Reference: True GFM Convergence: 1.19 deg Well: G-13 Slot Name: 13 G-13 Well Position: +NI-S 2551.47 ft Northlng: 5969417.00 fi: Latitude: 70 19 23.303 N +F,/-W 1604.19 ft Easting: 657852.00 ff Longitude: 148 43 12.193 W Position Uncertainty: 0.00 ft We#path: G-13A Drilled From: G-13 500292060001 Tie*on Depth: 9090.00 ft Current Datum: 20: 13 7/13/1981 00:00 Height 66.00 fi: Above System Datum: Mean Sea Level Magnetic Data: 9/28/2000 Declination: 26.86 deg FieM StFength: 57474 nT Mag Dip Angle: 80.78 deg Vertical Section: Depth From (TVD) +NI-S +F,/-W Direction ff ff ff deg 0.00 0.00 0.00 59.00 Survey: MWD Start Date: 2/22/2001 Company: Baker Hughes INTEQ Engineer: Tool: MWD,MWD - Standard Tied-to: From: Definitive Path Annotation MD TVD 9090.00 8780.48 Kick-off Point 10840.00 8990.41 Projected to TD Survey MD iici AzJm TVD SSTVD N/S '~ MapN MipE DLS VS ft deg deg ff ff ff fi: ff ff deg/100fi: ff 9090.00 10.43 57.44 8780.48 8714.48 962.88 1526.72 5970411.71 659358.02 0.00 1804.58 9106.66 4.48 74.94 8796.99 8730.99 963.86 1528.62 5970412.73 659359.90 37.80 1806.71 9133.43 12.30 79.59 8823.46 8757.46 964.65 1532.44 5970413.60 659363.70 29.30 1810.39 9164.00 22.06 64.96 8852.63 8786.63 965.75 1541.39 5970414.88 659372.62 32.31 1818.62 9201.69 31.30 91.46 8886.28 8820.28 966.12 1558.26 5970415.61 659389.49 25.68 1833.28 9244.66 43.85 92.87 8920.27 . 8854.27 965.09 1564.39 5970415.13 6594 t 5.63 ' 29.27 1855.15 9277.73 51.76 95.33 8942.46 8876.46 963.30 1608.81 5970413.86 659440.07 24.54 1875.15 9309.99 58.44 102.36 8960.92 8894.92 959.18 1634.90 5970410.28 659466.24 27.33 1895.39 9341.00 54.14 103.09 8978.13 8912.13 963.50 1660.05 5970405.14 659491.51 14.00 1914.03 9370.00 60.99 102.01 8993.68 8927.68 948.19 1683.93 5970400.33 659515.49 23.83 1931.77 9402.19 72.24 104.82 9006.43 8940.43 94:1.32 1712.61 5970394.07 659544.31 35.85 1952.81 9431.04 80.94 104.40 9013.12 8947.12 934.25 1739.74 5970387.57 659571.58 30.19 1972.43 9464.04 64.81 103.42 9017.21 8951.21 926.38 1771.52 5970380.37 659603.52 12.09 1995.61 9497.84 86.48 99.20 9019.78 8953.78 919.77 1804.56 5970374.46 659636.69 13.39 2020.53 9528.06 68.50 94.27 9021.10 8955.10 916.24 1834.53 5970371.55 659666.73 17.61 2044.40 9559.89 87.62 89.00 9022.52 8956.52 915.04 1876.31 5970371.24 659708.51 12.77 2079.59 9604.49 91.75 85.49 9022.71 8956.71 916.71 1910.86 5970373.63 659743.01 15.66 2110.06 9636.57 91.64 80.56 9021.70 8955.70 920.60 1942.67 5970378.19 659774.74 15.36 2139.34 ( BP Amoco ( Baker Hughes INTEQ Survey Report Company: BP Amoco Date: 4/9/2001 ~ 16:45:25 Page: 2 l;ldd: Prudhoe Bay Co-ordi,,ate(NE) Referemce: Well: G-13, True North Site:. PB G Pad Vertical fTVD) Referemee:. 20: 13 7113/1981 00:00 66.0 WeB: G-13 ~m O'S) ~K~'~m~: Well (0.00N,0.00E,59.00Azi) Wdll~: G-13A SurveyCak~htl~m Method: Minimum Curvature Db: Oracle Survey MD lad Azb= TVD SS'I'VB N/S E/W MmpN MapE DLS VS 9676.24 93.60 75.29 9019.82 8953.82 928.88 1981.41 5970387.29 659813.29 13.99 2176.81 9710.49 93.51 71.07 9017.70 8951.70 938.77 2014.12 5970397.86 659845.78 12.30 2209.94 9743.44 89.38 68.61 9016.86 8950.86 950.12 2045.03 5970409.86 659876.45 14.59 2242.28 9774.42 87.89 63.69 9017.60 8951.60 962.64 2073.35 5970422.97 659904.49 16.59 2273.00 9804.19 89.64 60.52 9018.24 8952.24 976.56 2099.65 5970437.44 659930.49 12.16 2302.72 9835.17 92.28 56.31 9017.73 8951.73 992.78 2126.03 5970454.21 659956.52 16.04 2333.68 9883.15 95.44 49.98 9014.49 8948.49 1021.47 2164.31 5970483.69 659994.19 14.72 2381.27 9921.19 90.87 44.00 9012.40 8946.40 1047.37 2192.06 5970510.16 660021.39 19.76 2418.40 9958.67 90.52 36.97 9011.94 8945.94 1075.85 2216.38 5970539.15 660045.10 18.78 2453.91 9987.65 91.05 35.56 9011.55 8945.55 1099.22 2233.52 5970562.87 660061.74 5.20 2480.64 10018.00 89.82 27.13 9011.31 8945.31 1125.11 2249.29 5970569.09 660076.97 28.07 2507.49 10052.55 92.90 22.91 9010.49 8944.49 1156.40 2263.90 5970620.68 660090.91 15.12 2536.13 10089.52 98.36 23.61 9007.51 8941.51 1190.25 2278.45 5970654.82 660104.74 9.55 2566.03 10121.16 94.92 27.63 9004.40 8938.40 1218.61 2292.11 5970663.46 660117.80 14.03 2592.35 10155.29 92.64 31.00 9002.15 8936.15 1248.27 2308.63 5970713,46 660133.90 11.42 2621.96 10215.80 93.60 40.64 8998.85 8932.85 1297.14 2344.23 5970763.06 660168.26 16.31 2677.47 10241.00 92.37 42.95 8997.54 8931.54 1315.87 2361.03 5970782.14 660184.67 9.68 2701.52 10291.85 89.75 45.41 8996.59 8930.59 1352.32 2396.46 5970819.33 660219.32 7.07 2750.67 10370.81 89.29 54.20 8997.26 8931.26 1403.23 2456.71 5970871.49 660278.48 11.15 2828.53 10412.78 91.4,0 58.06 8997.00 8931.00 1426.62 2491.55 5970895.50 660312.82 10.48 2870.44 10444.11 94.83 50.33 8995.30 8929.30 1444,90 2516.90 5970914.41 660337.77 26.98 2901.56 10477.81 95.36 52.79 8992.31 8926.31 1465.77 2543.19 5970935.83 660363.62 7.44 2934.87 10507.93 90.79 51.38 8990.69 8924.69 1464.24 2566.91 5970954.80 660386.94 15.88 2964.71 10541.01 87.53 50.68 8991.18 8925.18 1505.04 2592.63 5970976.13 660412.21 10.08 2997.47 10575.74 90.61 45.41 8991.74 8925.74 1528.25 2618.44 5970999.87 660437.53 17.57 3031.54 10611.96 92.81 40.13 8990.66 8924.66 1554.81 2643.01 5971026.95 660461,53 15.79 3066.29 10543.87 91.64 38.73 8989.36 8923.36 1579.44 2663.26 5971051.99 660481.26 5.33 3096.33 10678.20 89.56 36.97 8988.94 8922.94 1606.54 2684.32 5971079.53 660501.74 8.39 3128.34 10725.93 87.53 30.64 8990.16 8924.16 1646.17 2710.86 5971119.70 660527.44 13.92 3171.49 10760.25 90.00 34.86 8990.90 8924.90 1675.01 2729.41 5971148.93 660545.38 14.24 3202.26 10789.05 90.43 35.92 8990.79 8924.79 1698.49 2746.09 5971172.75 660561.56 3.97 3228.65 10840.00 90.43 35.92 8990.41 8924.41 1739.75 2775.98 5971214.63 660590.57 0.00 3275.52 Scblumkerger Alaska Data & Consulting Services 3940 Arctic Blvd, Suite 300 Anchorage, AK 99503-5711 ATTN: Sherrle NO. 1092 Company: Field:' State of Alaska Alaska Oil & Gas Cons Comm Attn: Usa Weepie 333 West 7th Ave, Suite 100 Anchorage, AK 99501 3/20/01 Color Well Job # Log Description Date BlUeline Sepia Prints CD D.S. 5-11A / ~ (~-.-Oq"9 MEM PRODUCTION PROFILE 03m8101 1 '1 G-13A ,~_~/~/iO..~ 21135 MCNL (PDC) 02/21101 1 1- -1 Z-21A ,~[~)--IOI 21123 SCMT . 03/05/01 ~, ~ . . . . . .._ · . PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING ONE COPY EACH TO: BP Exploration (Alaska) Inc. Petrotectnlcal Data Center LR2-1 900 E. Benson Blvd. Anchorage, Alaska 99508 Date Delivered: RECEIVED FIAR 2 3 2001 Schlumberger GeOQuest 3940 Arctic Blvd,' SUite 300 Anchorage, AK 99503-5711 AI'rN: Sherrie Received ALASKA OIL AND GAS CONSERVATION CO~L~IISSION TONY KNOWLES, GOVERNOR 3001 PORCUPINE DRIVE ANCHORAGE. ALASKA 99501-3192 PHONE: (907) 279-1433 FAX: (907) 276-7542 Thomas McCarty CT Drilling Engineer BP Exploration (Alaska) Inc. P O Box 196612 Anchorage, AK 99519-6612 Re: Prudhoe Bay Unit G- 13A BP Exploration (Alaska) Inc. Permit No: 200-163 Sur Loc: 2224'SNL, 2368'WEL, Sec. 12, T11N, R13E, UM Btmhole Loc. 479'SNL, 468'EWL, Sec. 07, TllN, R14E, UM Dear Mr. McCarty: Enclosed is the' approved application for permit to redrill the above referenced well. The permit to redrill does not exempt you from obtaining additional permits required by law from other governmental agencies, and does not authorize conducting drilling operations until all other required permitting determinations are made. Blowout prevention equipment (BOPE) must be tested in accordance with 20 AAC 25 035. Sufficient notice (approximately 24 hours) must be given to allow a representative of the Commission to witness a test of BOPE installed prior to drilling new hole. Notice may be given by contacting the Commission petroleum field inspector on the North Slope pager at 659-3607. I~aniel T. Seamount, Jr. Commissioner BY ORDER OF THE COMMISSION DATED'this 2E;> ~ day of October, 2000 dlf/Enclosures Department of Fish & Game, Habitat Section w/o encl. Department of Environmental Conservation w/o encl. ' ' STATE OF ALASKA .' ALASKA(' ,L AND GAS CONSERVATION COMI~ SION PERMIT TO DRILL 20 AAC 25.005 Ddll Reddll 1 I b. Type of well I [] Service [] Development Gas [] Single Zone [] Multiple Zone la, Type of work B Re-Entry [] Deepen [] Exploratory [] Stratigraphic Test ~a Development oil 2. Name of Operator 5. Datum Elevation (DF or KB) 10. Field and Pool BP Exploration (Alaska) Inc. KBE = 66.00' Prudhoe Bay Field / Prudhoe 3. Address 6. Property Designation Bay Pool P.O. Box 196612, Anchorage, Alaska 99519-6612 ~ ~F~ADL 028304 4. Location of well at surface v~ .v'" ,,/ 7. Unit~roperty Name 11. Type Bond (See 20 ^^C 25.025) 2224' SNL, 2368' WEL, SEC. 12, T11 N, R13E, UM Prudhoe Bay Unit At top of productive interval 8. Well Number 1296' SNL, 902' WEL, SEC. 12, T11N, R13E, UM G-13A Number 2S100302630-277 At total depth 9. Approximate spud date 479' SNL.;.468' EWL, SEC. 07, T11N, R14E, UM 10/20/00 Amount $200,000.00 12. Distance to nearest property line 113. Distance to nearest well 14. Number of acres in property 15. Proposed depth (MD and TVD) ADL 028280, 468' MDI No Close Approach 2560 10845' MD / 8930' TVD 16. To be completed for deviated wells 17. Anticipated pressure {see 20 ^AC 25.035 (e) (2)} Kick Off Depth 9100' MD Maximum Hole Angle 94 ° Maximum surface 2120 psig, At total depth (TVD) 8800' / 3000 psig 18. Casing Program Specifications Setting Depth Size Top Bottom Quantity of Cement Hole Casin,q Weiqht Grade Couplin,q Len,qth MD TVD MD TVD (include sta.qe data) 3" 2-3/8" 4.6# L-80 FL4S 2045' 8800' 8430' 10845' 8930' 174 cu ft Class 'G' 19. To be completed for Redrill, Re-entry, and Deepen Operations. Present well condition summary v"'ORIGINAL Total depth: measured 9486 feet Plugs (measured) true vertical 9170 feet '/'' Effective depth: measured 9422 feet Junk (measured) 9' tailpipe fish at 9419' (05/90) true vertical 9107 feet Casing Length Size Cemented MD TVD Structural Conductor 80' 20" x 30" 8 cu yds Concrete 110' 110' Surface 2643' 13-3/8" 3441 cuff Arctic Set II 2673' 2673' Intermediate 8619' 9-5/8" 1104cu ftClass'G' ~ E C E IV ~ Ii) 8649' 8349' Production Liner 1346' 7" 336 cu ft Class 'G' 8137' - 9483' 7851' - 9167' OCT 09 ,:.:'.Li~,".,U , AJaska 0Jj & r::..~ .... L,c,.;~ 0OJ'.',$. b~jj't'):'/t;JSSJ0J-j Perforation depth: measured Open: 9276' - 9356' (2 Intervals) Anchorage Squeezed: 9188'- 9219' (2 Intervals); Straddle Packer Isolation: 9234'- 9251' true vertical Open: 8964' - 9042' (2 Intervals) Squeezed; 8877' - 8907' (2 Intervals); Staddle Packer Isolation: 8922' - 8939' 20. Attachments [] Filing Fee [] Property Plat [] BoP Sketch [] Diverter Sketch [] Drilling Program [] Drilling Fluid Program [] Time vs Depth PIct [] Refraction Analysis [] Seabed Report [] 20 ^AC 25.050 Requirements Contact Engineer Name/Number: Thomas McCarty, 564-5697 Prepared By Name/Number: Terrie Hubble, 564-4628 21. I hereby certify that the foregoing is true and correct to the best of my knowledge Signed Thomas UcC~,.-~.~ ~r~'..~-f..~ Title CT Drilling Engineer Date /f0 't'"'.:~i'li~t~'~'~tH~i ?~i!~:~!l~~i'~:~'"';i:"i ~ii~i~l~'i~i~"~i~'~;'~l"~i~ ' ~"'~'"'"%~r,i~i!~l'~ ........... ~ ~' '~'L~'%' ~,'J ' ?-r----', ~,~'," , ~ '" ~ '~ ' ' ' .... ~ ' "I',~.~l,,~ ,t.,i~:',~li~,~ r,~ · ~., '" Permit Number _ _ APl Number ~/ Approval Date See cover letter ,~..~'--/'~.~.~ 50- 029-20600-01 / ~ ,- ~;~ O- ~ for other requirements Conditions of Approval: Samples Required [] Yes ~ No Mud Log Required [] Yes. ~' No Hydrogen Sulfide Measures I~[Yes [] No Directional Survey Required ,l~'YesI'~ No Required Working Pressure for BOPE [] 2K [] 3K [] 4K [] 5K [] 10K [] 15K ,J~3.SK psi for CTU Other: ORIGINAL SIGNED BY by order of ~Approved By D T~ulnr Se~.m.,,-:,. :..-:,.. Commissioner the commission Date/~)-' Form 10-401 Rev. 12-01-85 Submit In Triplicate BPX G-13a Sidetrack Summary of Operations: G-13 is being sidetracked to target lower Zone I reserves. This sidetrack will be conducted in two phases. Phase 1: Set ClBP, perforate, set whipstock and squeeze straddle annulus: Planned for Oct. 12-15, 2000. · A Mechanical Integrity Test will be performed. · A whipstock drift and tubing caliper has been run showing the tubing in good condition. · CT E-Line will be used to set the ClBP, perforate the straddle, and set the whipstock. · Service coil will be used to cement the straddle annulus, clean out and pressure test. · Service coil will be used to mill the two string window. Phase 2: Drill and Complete sidetrack: Planned for Oct 20, 2000. Drilling coil will be used to drill and complete the directional hole as per attached plan. Mud Program: · Phase l& 2: Seawater · Phase 3: FIo-Pro (8.6 - 8.7 ppg) Disposal: · No annular injection on this well. · All drilling and completion fluids and all other Class II wastes will go to Grind & Inject. · All Class I wastes will go to Pad 3 for disposal. Casing Program: · 2 3/8", 4.6#, L-80, FL4S liner will be run from TD to approx. 8800' MD (TOL) and cemented with approx. 31 bbls. cement to bring cement to the top of the liner in the 3 ½" straddle. The liner will be pressure tested to 2200 psi and perforated with coiled tubing conveyed guns. Well Control: · BOP diagram is attached. · Pipe rams, blind rams and the CT pack off will be pressure tested to 400 psi and to 3500 psi. · The annular preventer will be tested to 400 psi and 2000 psi. Directional · See attached directional plan · Magnetic and inclination surveys will be taken every 30 ft. No gyro will be run. Logging · A Gamma Ray log will be run over all of the open hole section. · Memory Induction log will be run in the open hole. Hazards No faults or lost circulation are expected. Res. pressure is below normal. The highest H2S reading on G- Pad in 2000 was 60ppm. Reservoir Pressure Res. pressure is approx. 3000psi @ 8800ss based on a PBU with a down hole shut-in tool in 1996. Max. surface pressure with gas (0.1 psi/ft) to surface is 2120 psi. G-13a Potential Drilling Hazards Post on Rig 1. H2S is not expected on this well. The pad has not had a history of significant H2S production. The highest H2S reading on G-Pad in 2000 was 60 ppm. 2. BHP is expected to be 3000psi @ 8800ss based on a PBU with a down hole shut-in tool ran in 1996. 3. Maximum anticipated well head pressure w/full column of gas 2120psi. TREE: 6"McEVOYGKf. ELEV=65.97' .... ':LEV = 37.52' WELLHEAD: McEVOY mi ACTUATOR: AXELSON ; .-~ L... · 4-1/2 SSSV LANDING NIPPLE. 4 1/2" 12.6# L-80 TDS 9-5/8" DV Packer . ( MERLA w/ 1-1/2", RA LATCH) 2 7,630 7,296 , , I KOP: 3200' I I 8,035 7,740 MAX ANGLE: 23° @ 6200' I 31/2" 9.2# L-SO TDS . 3-1/2" 'SWS' NIPPLE TUBING ID: 2.992" ~ I I -4 ~ (PARKER)(2.75" ID) I 8,066 ' CAPACI'I'~: .0087 BBL/FT HBBP-R) (4.00" ID) I 8'0921 Top of 7" Liner I--~.~~' I I (HBBP-R) (4.00 ID) I 9,221 I 31/2" SLIDING SLEEVE PERFORATION SUMMARY _....... 20' BLAST JOINT 9,229 REF. LOG: SWS - BHCS 7-23-81 ~51/4" OD x 41/2" TDS) TIE IN LOG: 9,249 Size SPF Interval Open/Sqzed 2-5/8" _8 9,188 - 9,199 Sqzd/Strdl ; 2-5/8"u 9,203 - 9,219 Sqzd/Strdl PERM(4'00" ID)(ELMD) I 9,2609'255 Packer @ 9,221 ~ ~ ~ 7" TIV~HBBP) PACKER Packer @ 9,255 II 5" Open 5" Open 9' Tailpipe Lost 5-8-90 while i Setting Packer (31/2" SWS I 9,4191 Parker Nipple, 31/2" SWS I I / Parker Nipple, 31/2" WLEG) I 7" 29# L-80 BTRS I 9,483 1 I DATE REV. BY COMMENTS PRUDHOE BAY UNIT 6-19-82 Initial Ri~l Completion {3-lA ,,l'UU,~, ^ ~==,1't1' _Hig~..:.~w.o. rKover WELL: G-13 (42-12-11-13) ................... APl NO: 50-029-20600 1/19/99 Nords Updateto PC SEC 12; TN 11N; RGE 13E BP Exploration (Alaska) GAS LIFT MANDRELS ( MERLA w/ 1-1/2", RA LATCH) Ns MD(BKB) TVDss Dev 5 o,UOl o,wu 5,164 4,996 3 6,758 6,474 7,630 7,296 ~ 8,035 7,740 G-13A Proposed Completion 3 1/2" 9.2# L-80 TDS TUBING ID: 2.992" CAPACITY: .0087 BBL/FT 3-1/2' 'SWS' NIPPLE (PARKER) (2.75" ID) 8,066 T°P °f 7" LinerI 8,137 ~ 9-5/8" RET PACKER (TIW HaSP-R) (4.00" ID) 8,092 9-5/8", 47#/ft, L-80, BTRS 8,649 IPerforations - 9060, from 9050 2.5" power jets, single phased, Iow side 7" MARKER JOINT 9,186 7" TIW RET PACKER (HaSP-R) (4.00 ID) ITop of Whipstock @ 9100 1 IClBP set @ 9210 3 1/2" SLIDING SLEEVE I (OTIS "XA") (2.75" ID) 9,227 20' BLAST JOINT (5 1/4" OD x 4 1/2" TDS) 9,229 · 9,249 PBTDI 9,428I 7" 29# L'80 BTRSI 9,483I 7" TIW PERM PACKER (HASP) (4.00" ID) (ELMD) 9' Tailpipe Lost 5-8-90 while Setting Packer (3 1/2" SWS Parker Nipple, 3 1/2" SWS Parker Nipple, 3 1/2" WLEG) 9,255 9,260 a ø 0 0 0> ["'!/»O¡¡~J (+1"1;.10111/(-)'1;1'101; 0 0 ø ø 0 if> 8: ~ ~ U '" 0 ø" 0 ffi â § ~ E ~ g ~, -~;:; C ~ ~~ ~~ 8~ " [U!/;K!!i] 'I~<laa le::l!;.I"'J\ """J. Proposal Calculations BAKER HUGHES Coordinates provided in: TRUE and GRID relative to Wellhead INTEQ and ALASKA STATE PLANE Company: BP Exploration Alaska~ Inc. Vertical Sect. Plane: 59° TRUE Job No: Field: Prudhoe Ba~ Unit Mag. Declination: 26.870 AFE No: Well: G-13A Plan g4 Grid Correction: 1.190 AP1 No: 50-029-20600-01 Rig: CDR 1 Total Correction: 25.680 Coordinate System: TRUE Surface Location Dip: 80.780 Drilled from: G-13 X: 657852.0 RKB Height: 66.000 Y: 5969417.0 Meas. Incl. TRUE Subsea Coords. - True Coords. - ASP Dogleg Vertical Tool Face Build Turn Depth Angle Azi. TVD N(+)/S(-) E(+)/W(-) N(+)/S(-) E(+)/W(-) Severity Section Comments (ft) (deg) (de~) (ft) (ft) (ft) Lat. (Y) Dep. (X) (°/100ft) {ft) (deO} (°/100ft) (°/100ft) 9000.00 10.85 59.50 8626.03 954.20 1512.56 5970402.73 659344.05 0.82 1787.971 -157.02 -0.75 -1.7(] Tie-in Point from G-13 9100.00 10.38 57.20 8724.32 963.86 1528.24 5970412.72 659359.52 0.63 1806.38 -139.09 -0.47 -2.30 Kick-off Point 9110.00 8.52 71.66 8734.18 964.58 1529.70 5970413.47 659360.97 30.00 1808.01 135.00 -18.56 144.58 9120.00 7.45 91.96 8744.09 964.79 1531.05 5970413.71 659362.31 i 30.00 1809.27 120.73 - 10.76 203.07 9130.00 7.50 115.19 8754.00 964.49 1532.29 5970413.44 659363.56 30.01 1810.18 100.54 0.52 232.25 9140.00 9.29 131.82 8763.90 963.67 1533.49 5970412.641 659364.77 30.00 1810.78 62.00 17.92 166.30 9150.00 11.59 142.54 8773.73 962.34 1534.70 5970411.33 659366.01 30.00 1811.13 45.54 22.99 107.15 9160.00 14.15 149.60 8783.48 960.48 1535.93 5970409.51 659367.28 30.00 1811.23 35.06 25.59 70.64 2 9170.00 15.64 139.43 8793.15 958.41 1537.42 5970407.46 659368.81 30.03 1811.45 -65.27 14.91 -101.65 9180.00 17.52 131.19 8802.73 956.39 1539.43 5970405.49 659370.87 30.03 1812.13 -55.44 18.74 -82.42 9190.00 19.66 124.60 8812.21 954.44 1541.95 5970403.60 659373.42 30.03 1813.29 -47.54 21.48 -65.96 9200.00 22.01 119.30 8821.56 952.57 1544.97 5970401.79 659376.48 30.03 1814.91 -41.29 23.42 -52.93 9210.00 24.49 115.01 8830.74 950.78 1548.48 5970400.07 659380.03 30.03 1817.00 -36.34 24.80 -42.95 9220.00 27.071 111.47 8839.75 949.07 1552.48 5970398.44 659384.06 30.03 1819.54 -32.39 25.81 -35.36 9230.00 29.72 108.52 8848.54 947.45 1556.95 5970396.92 659388.56 30.03 1822.54 -29.21 26.55 -29.56 9240.00 32.43 106.01 8857.11 945.92 1561.88 5970395.49 659393.52 30.03 1825.98 -26.61 27.10 -25.07 9250.00 35.19 103.85 8865.42 944.49 1567.25 5970394.18 659398.93 30.03 1829.85 -24.46 27.53 -21.57 9260.00 37.97 101.97 8873.45 943.16 1573.06 5970392.97 659404.76 30.03 1834.14 -22.66 27.86 -18.8~ 9270.00 40.78 100.31 8881.18 941.94 1579.29 5970391.88 659411.01 30.03 1838.85 -21.15 28.13 - 16.59 9280.00 43.62 98.83 8888.58 940.82 1585.91 5970390.91 659417.66 30.03 1843.95 - 19.87 28.34 - 14.79 9290.00 46.47 97.50 8895.65 939.82 1592.91 5970390.05 659424.68 30.03 1849.44 - 18.78 28.51 - 13.33 9300.00 49.34 96.29 8902.35 938.93 1600.28 5970389.32 659432.06 30.03 1855.29 - 17.83 28.65 - 12. i 2 9310.00 52.21 95.18 8908.68 938.16 1607.99 5970388.71 659439.78 30.03 1861.50 - 17.02 28.77 - 11.12 9320.00 55.10 94.15 8914.60 937.51 1616.01 5970388.22 659447.82 30.03 1868.05 - 16.32 28.87 - 10.28 9330.00 57.99 93.19 8920.11 936.97 1624.34 5970387.86 659456.15 30.03 1874.91 -15.71 28.95 -9.58 9340.00 60.89 92.29 8925.20 936.56 1632.94 5970387.63 659464.76 30.03 1882.07 - 15.18 29.01 -9.00 9350.00 63.80 91.44 8929.84 936.28 1641.79 5970387.53 659473.62 30.03 1889.51 -14.72 29.07 -8.50 9360.00 66.71 90.63 8934.02 936.11 1650.87 5970387.56 659482.70 30.03 1897.21 - 14.33 29.12 -8.09 9370.00 69.63 89.86 8937.74 936.07 1660.15 5970387.72 659491.98 30.03 1905.141 - 13.99 29.16 -7.74 9380.00 72.55 89.11 8940.98 936.16 1669.61 5970388.00 659501.43 30.03 1913.29 - 13.70 29.19 -7.45 Meas. Incl. TRUE Subsea Coords. - True Coords. - ASP Dogleg Vertical Tool Face Build Turn · Depth Angle Azi. TVD N(+)/S(-) E(+)/W(-) N(+)/S(-) E(+)/W(-) Severity Section Comments (ft) (deg) (del~) (ft) (ft) (ft) Lat. (Y) Del>. (X) (°/100ft) (ft) (deg) (°/100ft) (o/100ft) 9390.00 75.47 88.39 8943.74 936.37 1679.22 5970388.41 659511.03 30.03 1921.64 -13.46 29.22 -7.22 9400.00 78.39 87.69 8946.00 936.70 1688.95 5970388.95 659520.76 30.03 1930.15 - 13.26 29.24 -7.03 9410.00 81.32 87.00 8947.76 937.16 1698.79 5970389.61 659530.58 30.03 1938.82 - 13.10 29.26 -6.88 9420.00 84.25 86.32 8949.01 937.74 1708.69 5970390.40 659540.46 30.03 1947.60 - 12.98: 29.27 -6.78 9430.00 87.17 85.65 8949.76 938.43 1718.64 5970391.31 659550.39 30.03 1956.49 -12.90 29.28 -6.71 9439.65 90.00 85.00 8950.001 939.22 1728.25 5970392.30 659559.99 30.05 1965.13 -12.99 29.28 -6.75 3 9450.00 90.01 84.17! 8950.00i 940.20 1738.55 5970393.49 659570.27 8.03 1974.47 -88.99 O. 14 -8.03 9500.00 90.09 80.15 8949.95 947.01 1788.08 5970401.35 659619.63 8.03 2020.43 -88.99 O. 14 -8.03 9550.00 90.16 76.14 8949.85 957.28 1837.00 5970412.64 659668.33 8.03 2067.65 -88.99 0.14 -8.03 9600.00 90.23 72.13 8949.68 970.95 1885.08 5970427.31 659716.11 8.03 2115.91 -89.00 O. 14 - 8.03 9650.00 90.29 68.11 8949.46 987.95 1932.09 5970445.30 659762.75 8.03 2164.96 -89.02 O. 14 -8.03 9700.00 90.36 64.10 8949.17 1008.20 1977.80 5970466.50 659808.01 8.03 2214.57 -89.03 0.13 -8.03 .~__ 9750.00 90.43 60.08 8948.83 1031.60 2021.97 5970490.82 659851.68 8.03 2264.48 -89.06 0.13! -8.03 9800.00 90.49 56.07 8948.43 1058.03 2064.40 5970518.14 659893.54 8.03 2314.46 -89.08 0.13 -8.03 9850.00 90.55 52.05 8947.98 1087.37 21 04.87 5970548.32 659933.38 8.03 2364.27 -89.12 0.12 -8.03 9900.00 90.61 48.04 8947.47 1119.47 2143.19 5970581.22 659971.02 8.03 2413.64: -89.15 0.12 -8.03 9950.00 90.66 44.02 8946.92 1154.18 2179.17 5970616.67 660006.25 8.03 2462.35 -89.19 0.11 -8.03 10000.00 90.71 40.01 8946.32 1191.31 2212.62 5970654.50 660038.92 8.03 2510.16 -89.24 0.10 -8.03 10050.00 90.76 35.99 8945.67 1230.70 2243.40 5970694.53 660068.85, 8.03 2556.83 -89.29 0.10 -8.03 10097.45 90.81 32.19 8945.02 1269.99 2269.99 5970734.36 660094.61 8.02 2599.85 -89.26 0.10 -8.02 4 10100.00 90.85 32.40 8944.98 1272.14 2271.35 5970736.54 660095.93 8.31 2602.13 79.27 1.55 8.17 10150.00 91.62 36.48 8943.91 1313.36 2299.61 5970778.34 660123.32 8.31 2647.58 79.27 1.54 8.17 10200.00 92.38 40.57 8942.16 1352.44 2330.73 5970818.07 660153.60 8.31 2694.39 79.36 1.52 8.17 10250.00 93.13 44.66 8939.75 1389.19 2364.54 5970855.52 660186.63 8.31 2742.29 79.50 ! .50 8.18 10297.00 93.82 48.50 8936.90 1421.43 2398.61 5970888.46 660220.01 8.28 2788.10 79.72 1.46 8.17 5 10300.00 93.77 48.75 8936.70 1423.41 2400.85 5970890.49 660222.21 8.66 2791.04 102.03 -1.81 8.49 10350.00 92.85 52.99 8933.82 1454.90 2439.57 5970922.78 660260.25 8.66 2840.44 102.05 -1.83 8.48 10400.00 91.92 57.23' 8931.73 1483.47 2480.53 5970952.20 660300.61 8.66 2890.27 102.29' - 1.86 8.47 10450.00 90.98 61.46 8930.461 1508.95 2523.52 5970978.58 660343.04 8.66 2940.25 102.47~ -1.88 8.46 10501.89 90.00 65.84 8930.02 1531.97 2570.01 5971002.58 660389.03 8.66 2991.95 102.63 -1.90 8.45 6 ~__ 10550.00 90.00 61.77 8930.02 1553.21 2613.16 5971024.72 660431.73 8.47 3039.88 -90.02 0.00 -8.47 10600.00 90.00 57.53 8930.02 1578.47 2656.30 5971050.88 660474.32 8.47 3089.87 -90.02 0.00 -8.47 10650.00 90.00 53.30 8930.02 1606.85 2697.46 5971080.11 660514.87 8.47 3139.76 -90.02 0.00 -8.47 10700.00 89.99 49.06 8930.03 1638.18 2736.40 5971112.26 660553.14 8.47 3189.28 -90.02 0.00 -8.47 10750.00 89.99 44.83 8930.03 1672.31 2772.93 5971147.14 660588.94 8.47 3238.17 -90.02 0.00 -8.47 10800.00 89.99 40.59 8930.04 1709.05 2806.83 5971184.58 660622.06 8.47 3286.15 -90.02 0.00 -8.47 10845.341 90.00 36.74 8930.04 1744.44 2835.15 5971220.56 660649.63 8.49 3328.65 -89.87 0.02 -8.49 TD STATE OF ALASKA ALASK~"~L AND GAS CONSERVATION COMIC" ~ · LICATION FOR SUNDRY APPROVAl. SION 1. Type of Request: [] Abandon [] Alter Casing [] Change Approved Program [] Suspend [] Repair Well [] Operation Shutdown 2. Name of Operator BP Exploration (Alaska) Inc. , 3. Address 5. P.O. Box 196612, Anchorage, Alaska 99519-6612 Location of well at surface 2224' SNL, 2368' WEL, SEC. 12, T11N, R13E, UM At top of productive interval 1296' SNL, 902' WEL, SEC. 12, T11N, R13E, UM At effective depth 1228' SNL, 791' WEL, SEC. 12, T11N, R13E, UM At total depth 1222' SNL, 782' WEL, SEC. 12, T11N, R13E, UM [] Plugging [] Time Extension [] Pull Tubing [] Vadance [] Re-Enter Suspended Well [] Stimulate [] Perforate [] Other Plug Back for Sidetrack Type of well: [] Development [] Exploratory [] Stratigraphic [] Service 6. Datum Elevation (DF or KB) KBE = 66.00' 7. Unit or Property Name Prudhoe Bay Unit 8. Well Number G-13 9. Permit Number 181-072 10. APl Number 50-029-20600-00 11. Field and Pool Prudhoe Bay Field / Prudhoe Bay Pool Present well condition summary Total depth: measured 9486 feet true vertical 9170 feet Effective depth: measured 9422 feet true vertical 9107 feet Casing Length Size Structural Conductor Surface Intermediate Production Liner 80' 20" x 30" 2643' 13-3/8" 8619' 9-5/8" 1346' 7" Plugs (measured) Junk (measured) 9' Tailpipe at 9419' (5/90) Cemented MD 8 cu yds Concrete 110' 3441 cuft Amtic Set II 2673' 1104 cu ft Class 'G' 8649' .. ~" !, iii 137' 336 cu ft Class 'G' ~. i{ ' [] - 9483' 'I'VD 110' 2673' 8349' 7851' - 9167' Perforation depth: measured true vertical Tubing (size, grade, and measured depth) Open: 9276'- 9356' (2 Intervals) ~. ..... ,. ~, ....~.~ U..',,~ ~-"~i'0 · , Squeezed: 9188'- 9219' (2 Intervals); S~!ad~ll~a(~ker. ls01ation:'~)~ - ~251 .~. Open: 8964"- 9042' (2 Intervals) Squeezed; 8877' - 8907' (2 Intervals); Staddle Packer Isolation: 8922' - 8939' 4-1/2", 12.6#, L-80 to 2116'; 3-1/2", 9.2#, L-80 to 9255' Packers and SSSV (type and measured depth) 7" TIW Perm Packer at 9255'; 7" TIW RET Packer at 9221'; 9-5/8" RET Packer at 8092' 4-1/2" SSSV LN at 2099' ' 13. Attachments [] Description Summary of Proposal 4. Estimated date for commencing operation October 12, 2000 16. If proposal was verbally approved Name of approver Date Approved Contact Engineer Name/Number: Thomas McCarty, 564-5697 [] Detailed Operations Program I15. Status of well classifications as: [] Oil [] Gas [] Suspended Service [] BOP Sketch Prepared By Name/Number: Terrfe Hubble, 564-4628 17. I hereby certify that the foregoing is true and correct to the best of my knowledge Signed Thomas Title CT Drilling Engineer . Conditions of Approval: Notify Commission so representative may witness Plug integrity ~ BOP Test ' Location clearance Mechanical Integrity Test ~ Subsequent form required 10- order of the Commission Date Approval No. cOmmissioner Date Form 10-403 Rev. 06/15/88 Submit In Triplicate ~ : ~ :I: ," "', I ~ » :-c'tXJ : ~ ~ '::~:':'~i~ : ~ ~ :.0 p:::>< I ~ U1 ",~::::::<-U : ~ (j.:I :I ,.:: ~ G) (0 ro I ~ ..,. 0 c..N , ': ',' , , O!11""O):' . I ~ Þ-4 .... . <...0 J> ' ,W,:þ 00, Z . ':". ~: ":IJ I Z m ...0 Z '0 Q'''''' , ' ': » I\):þ I : Z Z \J z ('") 0 (j.:I 1> : rrt, ':ç,,,::~ I -< to ....¡ 0'- < ~\~"Bjri ,~;;~~ L~ i ! ~ ~ g ~ J> 0" CJ ,:' Z',.:: ~); I :II :¡¡ ... (j.:I :::a "T'\ 0. :,:" 01 r I iiI ~ m n::2::1, ' .....» I K ::¡ .... C J> :Jt,. cP en UI ~ -Ù "'D r ..,'~.. ~ ~ ~ ~;tJ,,1 ;';¡" ~",.."..~ I ~ ~ 0 ,~~: ~ m ....¡ : :<: 0 ::tI .0. :>m.:' 0 /':\ ::tI ....¡ c ' ',.", * U ) Þ-4 0 m r- J> * ~ m ~ .... ,: *, ro.) '==' ~ n.J *, : : \...)'J :I: :::0 - 0 ...0 :::,:'* ' ~ C Þ-4 ~ ~ ~ ~~ ~ ~F OJ 0 ,:* r ~ ~,::!:i:,j; i : = Q ;ij;':;~s õ ~ * 0 * 0 * 0 * * * ~;;;~:I:C, .. \ I i 1 .~:!I " :",;Lo.":'" -i:¡¡ 'I. 'm ':":"'!\'I::,' I :¡¡:""*: (') I 0 ',: ""~':'<:::::=:"::".. ::,:",:.?,~,:,::,.f : c ,.'< .:" ." c)"'&' c .... ~ ~ ~ --___ ann. dis_.._.__ . ~ ADMINIST...._~RATION 1. Permit fee attached ........................ ~' N 2. Lease number appropriate.'~ .,~,~,~. ~,=~?~-:-/~,,~, ~. ,/.~ .: 5/~/~ N 3. Unique well name and*number ............. ~ .... N .~ DATE !o, ENGINEERING 4. Well located in a defined pool .................. 5. Well located proper distance from drilling unit boundary .... 6. Well located proper distance from other wells .......... 7. Sufficient acreage available in drilling unit ............ 8. If deviated, is wellbore plat included ............... 9. Operator only affected party ................... 10. Operator has appropriate bond in force ............. 11. Permit can be issued without conservation order ........ 12. Permit can be issued without administrative approval ...... 13. Can permit be approved before 15-day wait ........... 14. Conductor stdng provided ' Y 15. Surface casing protects all known USDWs ........... y 16. CMT vol adequate to circulate on conductor & surf csg ..... y 17. CMT vol adequate to tie-in long string to surf csg .... ~ . . . y 18. CMT will cover all known productive horizons .......... (~ 19. Casing designs adequate for C, T, B & permafrost ....... . 20. Adequate tankage or reserve pit ................. 21. If a re-drill, has a 10-403 for abandonment been approved... 22. Adequate Wellbore separation proposed ............. 23. If diverter required, does it meet regulations ....... .... 24. Drilling fluid program schematic & equip list adequate ..... (~ N ~~_~E'~--' --¢3 25. BOPEs, do they meet regulation ................ I.Y) N 26. B_..OP.E pres.s~m. !lng ap.p. ropdate; test to '~5(~ psig. . 27. ~noKe manimla complies w/APl RP-53 (May 84) ........ ~ N' ' \ 28. Work will occur without operation shutdown ........... 29. Is presence of H2S gas probable ................. Y GEOLOGY 30. Permit can be issued wi0 hydrogen sulfide measui, es Y ~ '~, ~_,~d'2Z ~ .'S ~-'" / ' ..... · .... ~ ~.~.. ?- /'rj.¢ ~-~' ~.~.~ 31. Data presented on potential overpressure zones . ...... . 32. Seismic analysis of shallow gas zones .......... '.'\ DATE 33. Seabed condition survey (if.off-shore) ....... '. · .~%'~.."' ' Y N . /¢~'/D°~.~ 34. Contact name/phone for weekly progress reports [e~lS~oratory only] Y N ' ANNULAR DISPOSAL35. With proper cementing records, this plan (A) will contain waste in a suitable receiving zone; ....... Y N ' ~ APPR DATE (B) will not contaminate freshwater; or cause drilling waste .... Y N ~ ~ (C) ~l~od~mei3air mechanical integrity of the well used for disposal; Y N (D) will not damage producing formation or impair recovery from a Y N ~ ~.. ' pool; and ' ~n~_ot cir ENGINEERING: U. ICIAnnular COMMISSION: Comments/ins'-. ....., O Z (' O Z -i c:~soffice\wordian~liana\checklist (rev. 02117100) 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 roadability of the Well History file and to simplify finding information, information of this '. nature is accumulated at the end ~)f the file under APPENDIX. No special effort has been made to chronologically organize this category of inforrnatio,n. **** REEL HEADER MWD 01/09/14 BHI 01 LIS Customer Format Tape tapel i st. txt **** TAPE HEADER **** MWD 01/09/14 110254 01 1.75" NaviGamma - Gamma Ray LIS COMMENT RECORD ]!!!!!]!!!!]]!!]!!! Remark File version 1.000 !!!!!!!!!!!!!!!!!!! Extract File: glen,las -version Information VERS.. 1.20: WRAP. NO: ~well Information Block CWLS log ASCII Standard -VERSION 1.20 One line per frame #MNEM.UNIT Data Type Information STRT.FT 9082.0000: Starting Depth STOP.FT 10840.0000: Ending Depth STEP.FT 0.5000: L~vel Spa~ing NULL, -999.2500: Absent Value COMP, COMPANY: BP Exploration Alaska WELL. WELL: FLD . FIELD: Prudhoe Bay unit LOC . LOCATION: 2224' SNL, 2368' WEL CNTY. COUNTY: North slope STAT. STATE: Alaska SRVC. SERVICE COMPANY: Baker Hughes INTEQ TOOL. TOOL NAME &TYPE: 1.75" NaviGamma - Gamma Ray DATE. LOG DATE: 19-Feb-01 API. API NYUMBER: 500292060001 -Parameter Information Block #MNEM. UNIT value Descri pti on #, SECT. 22 : Secti on TOWN. N 11N : Township RANG. 13E : Range PDAT. MSL : Permanent Datum EPD .F 0 : Elevation of Perm. Datum LMF . RKB : Log Measured from FAPD.F 65.97' : Feet Above Perm. Datum DMF . KB : Drilling Measured From EKB .F 65.97' : Elevation of Kelly Bushing EDF .F N/A : Elevation of Derrick Floor EGL .F N/A : Elevation of Ground Level CASE. F N/A : casing Depth 051 . DIRECTIONAL : other Services Line 1 -Remarks (1) All depths are Measured Depths (MD) unless otherwise noted. (2) All depths are Bit Depths unless otherwise noted, (3) All Gamma Ray data (GRAX) presented is realtime data, (4) well G-13A was kicked off from the original borehole of well G-13 ~ 9090' MD (8714' SSTVD), (5) well G-13A was drilled to TD ~ 10840' MD (8924' SSTVD) on Run 10, (6) The interval from 10860' MD (8925' SSTVD) tO 10840' MD (8924' SSTVD) was not logged due to sensor to bit offset, (7) The data presented is final and has been depth shifted to a PDC (Primary Depth Control) supplied by BPX (SWS,21 Feb, 2001). (8) A Magnetic Declination correction of 26.86 degrees has been applied to the Directional Surveys. Page 1 MNEMONICS: tapel i st. txt GRAX ROPS TVD -> Gamma Ray MWD-API [MWD] (MWD-API units) -> Rate of Penetration, (feet/hour) -> subsea True vertical Depth (SSTVD), (feet) SENSOR OFFSETS: RUN GAMMA DIRECTIONAL 6 17.75 ftm 22.54 ft. 7 18.10 ft. 22.89 ft. 8 18.10 ft. 22.89 ft. 9 17.67 ft. 22.46 ft. 10 17.76 ft. 22.35 ft. CURVE SHIFT DATA MEASURED, 9273.67 9280.95 9310.37 9340.02 9366.50 9400.76 9415.68 9435.69 9533.67 9549.96 9576.98 9599.47 9614.97 9623.20 9682.45 9778.00 9784.00 9898.12 10133.9 10330.1 10366.6 10421.4 10480.3 10612.3 10677.6 10751.4 BASELINE 9270.73 9281.79 9311.21 9340.44 9366.92 9403.29 9416.11 9438.63 9529.89 9550.59 9578.03. 9596.74. 9614.131 9624.46. 9687.50. 9781.99. 9789.47. 9901.27. 10129.5 10328.S 10366.4. 10420.1. 10476.9 10606.8 10679.1 10754.6 EOZ END DISPLACEMENT 2.94238 -0.84082 -0.84082 -0.420898 -0.419922 -2.52246 -0.420898 -2.94238 3.7832 -0.629883 -1.05078 2.73242 0.839844 -1.26172 -5.04395 -3.99316 . -5.46387 ' -~.15234 4.41406 1.68066 0.209961 1.26172 3.36328 5.46387 -1.4707 -3.15234 ! BASE CURVE: GROH, OFFSET CURVE: GRAX Tape subfile: i 100 records... Minimum record length: 8 by:es Maximum record length: 132 bytes **** FILE HEADER **** MWD .001 1024 *** INFORMATION TABLE: CONS MNEM VALU WDFN mwd.xtf LCC 150 CN BP Exploration Alaska. WN G-13A Page 2 FN COUN STAT Prudhoe Bay Unit North slope Alaska tapel i st. txt *** LIS COMMENT RECORD !!!!!!!!!!!!!!!!!!! Remark File Version 1.000 1. The data presented has been edited from the field raw data. 2 The data has been depth shifted to match the PDC supplied by BPX 3 The PDC used is a schlumberger Gamma Ray dated 21-Feb-01. ~* INFORMATION TABLE: CIFO MNEM CHAN DIMT (NAM ODEP i GR GRAX11 0,0 2 ROP ROPSll 0.0 FORMAT RECORD (TYPE# 64) Data record type is: 0 Datum Frame Size is: 12 bytes Logging direction is down (value= 255) optical Log Depth scale Units: Feet Frame spacing: 0.500000 Frame spacing units: [F ] Number of frames per record is: 84 one depth per frame (value= 0) Datum Specification Block sub-type is: FRAME SPACE = 0.500 * F ONE DEPTH PER FRAME Tape depth ID: F 2 Curves: Name Tool Code Samples units i GR MWD 68 1 AP1 2 ROP MWD 68 1 F/HR Total Data Records: 42 size Length 4 4 4 4 8 Tape File Start Depth Tape File End Depth Tape File Level Spacing Tape File Depth Units **** FILE TRAILER **** Tape subfile: 2 Minimum record length: Maximum record length 9082.000000 10840.000000 0.500000 feet 51 records... 54 bytes 4124 bytes **** FILE HEADER **** MWD .002 1024 *~ INFORMATION TABLE: CONS MNEM VALU WDFN mwd. xtf Page 3 tapel i st. txt LCC CN WN FN COUN STAT BP Exploration Alaska. G-13A Prudhoe Bay unit North slope Alaska *** LIS COMMENT RECORD *** !!!!!!!!!!!!!!!!!!! Remark File version 1.000 The data presented here is the unedited field raw data. *** INFORMATION TABLE: CIFO MNEM CHAN DIMT CNAM ODEP GRAX GRAX O. 0 ROPS 0.0 2 ROPS * FORMAT RECORD (TYPE# 64) Data record type is: 0 Datum Frame Size is 12 bytes Logging direction is down (value= 255) optical Log Depth scale units: Feet Frame spac! ng: 0. 500000 Frame spacing units: IF ] Number of frames per record is: 84 One depth per frame (value: 0) Datum Speci fi cation B1 ock Sub-type i s: FRAME SPACE = 0.500 * F ONE DEPTH PER FRAME Tape depth ID: F 2 curves: Name Tool code Samples units i GRAX MWD 68 i AP1 2 ROPS MWD 68 1 F/HR Size 4 4 Total Data Records: Tape File Start Depth Tape File End .Depth Tape File Levem 5pacing Tape File Depth units **** FILE TRAILER **** Tape subfile: 3 Minimum record length: Maximum record length: **** TAPE TRAILER **** MWD 01/09/14 110254 01 42 = 9082.000000 = 10840.000000 = 0.500000 = feet 51 records.,. 54 bytes 4124 bytes Length 4 4 8 Page 4 **** REEL TRAILER *~*~ MWD 01/09/14 BHI 01 Tape subfile: 4 Minimum record length: Maximum record length D Tape Subfile i is type: Tape subfile 2 is type: LIS LIS 2 records... 132 bytes 132 bytes DEPTH GR ROP 9082.0000 14.6640 -999.2500 9082.5000 12.0148 -999.2500 9100.0000 20.0071 -999.2500 9200.0000 16.9708 14.8775 9300.0000 90.3663 65.3518 9400.0000 53.2685 43.7609 9500.0000 52.8965 27.6148 9600.0000 104.9287 56.7929 9700.0000 60.6315 107.2513 9800.0000 58.6861 76.4134 9900.0000 79.1771 72.6158 10000.0000 66.1742 85.6202 10100.0000 51.8511 100.4436 10200.0000 45.2393 110.5634 10300.0000 67.3543 142.1589 10400.0000 61.9561 100.4541 10500.0000 55.1379 43.7986 10600.0000 50.7573 106.3674 10700.0000 66.0492 98.2042 10800.0000 61.4732 76.4278 10840.0000 -999.2500 -999.2500 Tape File Tape File Tape File Tape File Tape subfile 3 DEPTH 9082.0000 9082.5000 9100.0000 9200.0000 9300.0000 9400.0000 9500.0000 9600.0000 9700.0000 9800.0000 9900.0000 10000.0000 10100.0000 10200.0000 10300.0000 10400,0000 10500.0000 10600.0000 10700.0000 10800.0000 10840.0000 Start Depth = 9082.000000 End Depth = 10840.000000 Level Spacing = 0.S00000 Depth Units = feet is type: LIS GRAX ROPS 14.5540 -999.2500 15.1150 -999.2500 20.3690 -999.2500 19.5550 15.2420 80.6660 65.5820 61.2870 47.5550 50.5440 26.0210 96.1380 66.0160 61.7270 109.4930 56.7230 69.1770 74.1210 120.0000 60.8630 93.2200 55.2940 102.0420 44.1890 108.4870 68.0280 137.0000 57.2910 133.0450 53.6540 43.5280 63.5070 157.2000 66.1180 98.2600 60.6210 105.3600 -999.2500 -999.2500 Tape File Tape File Tape File Tape File Start Depth = 9082.000000 End Depth = 10840.000000 Level Spacing = 0.500000 Depth units = feet tapel i st. txt Page 5 Tape Subfile 4 is type: LZS tapelist.txt Page 6
